0001376139-22-000014 | 10-K | XBRL Viewer

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents (including $113 and $31, respectively, of consolidated variable interest entity (VIE))	$ 510	$ 667
Accounts receivable (including $88 and $37, respectively, of VIE)	299	178
Inventories (including $52 and $42, respectively, of VIE)	484	298
Prepaid expenses and other current assets (including $9 and $8, respectively, of VIE)	76	259
Total current assets	1,369	1,402
Property, plant and equipment, net (including $850 and $898, respectively, of VIE)	2,273	2,240
Other long-term assets (including $14 and $17, respectively, of VIE)	264	336
Total assets	3,906	3,978
Current liabilities:
Note payable and finance lease obligations (including $0 and $2, respectively, of VIE)	6	8
Accounts payable (including $50 and $25, respectively, of VIE)	409	282
Other current liabilities (including $111 and $49, respectively, of VIE)	741	369
Total current liabilities	1,156	659
Long-term liabilities:
Long-term debt and finance lease obligations, net of current portion (including $611 and $634, respectively, of VIE)	48	55
Deferred income taxes	268	368
Other long-term liabilities (including $12 and $8, respectively, of VIE)	58	49
Total long-term liabilities	1,980	2,100
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 and 100,629,209 shares issued as of December 31, 2021 and 2020, respectively	1	1
Additional paid-in-capital	1,510	1,510
Retained deficit	(956)	(490)
Treasury stock, 98,610 shares at cost	(2)	(2)
Total CVR stockholders’ equity	553	1,019
Noncontrolling interest	217	200
Total equity	770	1,219
Total liabilities and equity	$ 3,906	$ 3,978

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 510	$ 667
Accounts receivable	299	178
Inventories	484	298
Prepaid expenses and other current assets	76	259
Property, plant and equipment, net	2,273	2,240
Other long-term assets	264	336
Current liabilities:
Note payable and finance lease obligations	6	8
Accounts payable	409	282
Other current liabilities	741	369
Long-term liabilities:
Long-term debt and finance lease obligations, net of current portion	48	55
Other long-term liabilities	$ 58	$ 49
Equity:
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	350,000,000	350,000,000
Common stock, issued (in shares)	100,629,209	100,629,209
Treasury stock (in shares)	98,610	98,610
Variable Interest Entities
Current assets:
Cash and cash equivalents	$ 113	$ 31
Accounts receivable	88	37
Inventories	52	42
Prepaid expenses and other current assets	9	8
Property, plant and equipment, net	850	898
Other long-term assets	14	17
Current liabilities:
Note payable and finance lease obligations	0	2
Accounts payable	50	25
Other current liabilities	111	49
Long-term liabilities:
Long-term debt and finance lease obligations, net of current portion	611	634
Other long-term liabilities	$ 12	$ 8

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($)	12 Months Ended
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement [Abstract]
Net sales	$ 7,242,000,000	$ 3,930,000,000	$ 6,364,000,000
Operating costs and expenses:
Cost of materials and other	6,185,000,000	3,373,000,000	4,851,000,000
Direct operating expenses (exclusive of depreciation and amortization)	569,000,000	478,000,000	533,000,000
Depreciation and amortization	270,000,000	268,000,000	278,000,000
Cost of sales	7,024,000,000	4,119,000,000	5,662,000,000
Selling, general and administrative expenses (exclusive of depreciation and amortization)	119,000,000	86,000,000	117,000,000
Depreciation and amortization	9,000,000	10,000,000	9,000,000
Loss (gain) on asset disposal	3,000,000	7,000,000	(4,000,000)
Goodwill impairment	0	41,000,000	0
Operating income (loss)	87,000,000	(333,000,000)	580,000,000
Other (expense) income:
Interest expense, net	(117,000,000)	(130,000,000)	(102,000,000)
Investment income on marketable securities	81,000,000	41,000,000	0
Other income, net	15,000,000	7,000,000	13,000,000
Income (loss) before income tax expense	66,000,000	(415,000,000)	491,000,000
Income tax (benefit) expense	(8,000,000)	(95,000,000)	129,000,000
Net income (loss)	74,000,000	(320,000,000)	362,000,000
Less: Net income (loss) attributable to noncontrolling interest	49,000,000	(64,000,000)	(18,000,000)
Net income (loss) attributable to CVR Energy stockholders	$ 25,000,000	$ (256,000,000)	$ 380,000,000
Basic earnings (loss) per share (in dollars per share)	$ 0.25	$ (2.54)	$ 3.78
Diluted earnings (loss) per share (in dollars per share)	0.25	(2.54)	3.78
Dividends declared per share (in dollars per share)	$ 4.89	$ 1.20	$ 3.05
Weighted-average common shares outstanding:
Basic (in shares)	100,500,000	100,500,000	100,500,000
Diluted (in shares)	100,500,000	100,500,000	100,500,000

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Effect of turnaround accounting change	Total CVR Stockholders’ Equity	Total CVR Stockholders’ Equity Effect of turnaround accounting change	Common Stock	Additional Paid-In Capital	Additional Paid-In Capital Effect of turnaround accounting change	Retained Deficit	Treasury Stock	Noncontrolling Interest
Balance (in shares) at Dec. 31, 2018					100,629,209
Balance at Dec. 31, 2018	$ 1,943.0	$ 35.0	$ 1,286.0	$ 35.0	$ 1.0	$ 1,474.0	$ 35.0	$ (187.0)	$ (2.0)	$ 657.0
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(306.0)		(306.0)					(306.0)
Distributions from CVR Partners to public unitholders	(30.0)									(30.0)
Acquisition of CVR Refining non-controlling interest	(336.0)		(2.0)			(2.0)				(334.0)
Net income (loss)	362.0		380.0					380.0		(18.0)
Balance (in shares) at Dec. 31, 2019					100,629,209
Balance at Dec. 31, 2019	1,668.0		1,393.0		$ 1.0	1,507.0		(113.0)	(2.0)	275.0
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(121.0)		(121.0)					(121.0)
Acquisition of CVR Refining non-controlling interest						3.0				(4.0)
Changes in equity due to CVR Partners’ common unit repurchases	(8.0)		3.0			3.0				(11.0)
Net income (loss)	(320.0)		(256.0)					(256.0)		(64.0)
Balance (in shares) at Dec. 31, 2020					100,629,209
Balance at Dec. 31, 2020	1,219.0		1,019.0		$ 1.0	1,510.0		(490.0)	(2.0)	200.0
Increase (Decrease) in Stockholders' Equity
Dividends paid to CVR Energy stockholders	(492.0)		(492.0)					(492.0)
Distributions from CVR Partners to public unitholders	(31.0)									(31.0)
Acquisition of CVR Refining non-controlling interest						0.0				(0.1)
Changes in equity due to CVR Partners’ common unit repurchases	(1.0)									(1.0)
Other	1.0		1.0					1.0
Net income (loss)	74.0		25.0					25.0		49.0
Balance (in shares) at Dec. 31, 2021					100,629,209
Balance at Dec. 31, 2021	$ 770.0		$ 553.0		$ 1.0	$ 1,510.0		$ (956.0)	$ (2.0)	$ 217.0

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity.

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+ Details

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash flows from operating activities:
Net income (loss)	$ 74,000,000	$ (320,000,000)	$ 362,000,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	279,000,000	278,000,000	287,000,000
Loss on lower of cost or net realizable value adjustments	0	59,000,000	0
Goodwill impairment	0	41,000,000	0
Deferred income taxes	(98,000,000)	(30,000,000)	24,000,000
(Gain) loss on marketable securities	(81,000,000)	(34,000,000)	0
Loss (gain) on asset disposal	3,000,000	7,000,000	(4,000,000)
(Gain) loss on derivatives	(16,000,000)	10,000,000	14,000,000
Share-based compensation	46,000,000	4,000,000	17,000,000
Other non-cash items	12,000,000	10,000,000	6,000,000
Changes in assets and liabilities:
Accounts receivable	(91,000,000)	31,000,000	(40,000,000)
Inventories	(182,000,000)	9,000,000	(10,000,000)
Prepaid expenses and other current assets	12,000,000	(28,000,000)	16,000,000
Accounts payable	122,000,000	(121,000,000)	94,000,000
Deferred revenue	27,000,000	(2,000,000)	(15,000,000)
Other current liabilities	290,000,000	178,000,000	(1,000,000)
Other long-term assets and liabilities	(1,000,000)	(2,000,000)	(3,000,000)
Net cash provided by operating activities	396,000,000	90,000,000	747,000,000
Cash flows from investing activities:
Capital expenditures	(224,000,000)	(124,000,000)	(121,000,000)
Turnaround expenditures	(5,000,000)	(159,000,000)	(38,000,000)
Proceeds from sale of assets	7,000,000	1,000,000	37,000,000
Acquisition of pipeline assets	(20,000,000)	0	0
Investment in marketable securities		(140,000,000)	0
Investment in marketable securities	3,000,000
Other investing activities	1,000,000	(1,000,000)	1,000,000
Net cash used in investing activities	(238,000,000)	(423,000,000)	(121,000,000)
Cash flows from financing activities:
Proceeds from issuance of senior secured notes	550,000,000	1,000,000,000	0
Principal payments on senior secured notes	(582,000,000)	(500,000,000)	0
Call premium on extinguishment of debt	0	(5,000,000)	0
Repurchase of CVR Partners common units	(1,000,000)	(7,000,000)	0
Acquisition of CVR Refining common units	0	0	(301,000,000)
Dividends to CVR Energy’s stockholders	(241,000,000)	(121,000,000)	(306,000,000)
Distributions to noncontrolling interest holders	(31,000,000)	0	(30,000,000)
Other financing activities	(10,000,000)	(12,000,000)	(5,000,000)
Net cash (used in) provided by financing activities	(315,000,000)	355,000,000	(642,000,000)
Net (decrease) increase in cash and cash equivalents and restricted cash	(157,000,000)	22,000,000	(16,000,000)
Cash and cash equivalents and restricted cash, beginning of period	674,000,000	652,000,000	668,000,000
Cash and cash equivalents and restricted cash, end of period	$ 517,000,000	$ 674,000,000	$ 652,000,000

Organization and Nature of Business	12 Months Ended
Organization and Nature of Business	Dec. 31, 2021
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,” “we,” “us,” “our,” 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 (the “Petroleum Segment” or “CVR Refining”) and CVR Partners, LP (the “Nitrogen Fertilizer Segment” or “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. CVR’s common stock is listed on the New York Stock Exchange (“NYSE”) under the symbol “CVI.” Icahn Enterprises L.P. and its affiliates (“IEP”) owned approximately 71% of the Company’s outstanding common shares as of December 31, 2021. Stock Repurchase Program On October 23, 2019, the Board of Directors authorized a stock repurchase program (the “Stock Repurchase Program”). The Stock Repurchase Program enables the Company to repurchase up to $300 million of the Company’s common stock. Repurchases under the Stock Repurchase Program may be made from time-to-time through open market transactions, block trades, privately negotiated transactions or otherwise in accordance with applicable securities laws. The timing, price and amount of repurchases (if any) will be made at the discretion of management and are subject to market conditions as well as corporate, regulatory and other considerations. While the Stock Repurchase Program currently has a duration of four years, it does not obligate the Company to acquire any stock and may be terminated by the Board of Directors at any time. We did not repurchase any of our common stock during the years ended December 31, 2021, 2020, and 2019. CVR Refining, LP On January 17, 2019, the general partner of CVR Refining assigned to the Company its right to purchase all of the issued and outstanding CVR Refining common units not already owned by CVR Refining’s general partner or its affiliates. On January 29, 2019, the Company purchased all remaining CVR Refining 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 CVR Refining 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. Amounts drawn under the new credit agreement were fully repaid in February 2019. The consolidated results of operations and financial position of CVR Refining are reflected as CVR’s Petroleum Segment. Following this transaction, CVR Refining became a wholly-owned subsidiary of the Company and, therefore, is no longer accounted for as a variable interest entity (“VIE”). Effective February 8, 2019, CVR Refining’s reporting obligations under the Exchange Act were suspended. CVR Partners, LP Interest Holders - As of December 31, 2021, public common unitholders held approximately 64% of CVR Partners’ outstanding common units, and CVR Services, LLC (“CVR Services”), a wholly-owned subsidiary of CVR Energy, held approximately 36% of CVR Partners’ outstanding common units. In addition, CVR Services held 100% of CVR Partners’ general partner, CVR GP, LLC (“CVR GP”), which held a non-economic general partner interest in CVR Partners as of December 31, 2021. Following the acquisition of the non-controlling interest in CVR Refining in January 2019, the non-controlling interest reflected on the Consolidated Balance Sheets of CVR is only impacted by the net income of, and distributions from, CVR Partners. Unit Repurchase Program - On May 6, 2020, CVR Partners announced that the board of directors of its general partner (the “UAN GP Board”), on behalf of CVR Partners, authorized a unit repurchase program (the “Unit Repurchase Program”). The Unit Repurchase Program enabled CVR Partners to repurchase up to $10 million of its common units. On February 22, 2021, the UAN GP Board authorized an additional $10 million for the Unit Repurchase Program. During the year ended December 31, 2021, CVR Partners repurchased 24,378 common units on the open market in accordance with a repurchase agreement under Rules 10b5-1 and 10b-18 of the Securities Exchange Act of 1934, as amended, at a cost of $1 million, inclusive of transaction costs, or an average price of $21.70 per common unit. During the year ended December 31, 2020, as adjusted to reflect the impact of the 1-for-10 reverse unit split of CVR Partners’s common units that was effective as of November 23, 2020, CVR Partners repurchased 623,177 common units, respectively, at a cost of $7 million, inclusive of transaction costs, or an average price of $11.35 per common unit. As of December 31, 2021, CVR Partners had $12 million in authority remaining under the Unit Repurchase Program. This Unit Repurchase Program does not obligate CVR Partners to acquire any common units and may be cancelled or terminated by the UAN GP Board at any time. As a result of these repurchases, and the resulting change in CVR Energy’s ownership of CVR Partners while maintaining control, CVR Energy recognized a nominal increase to additional paid-in capital from the reduction of non-controlling interests totaling $0.1 million and the recognition of a deferred tax liability totaling $0.1 million from changes in its book versus tax basis in CVR Partners as of December 31, 2021. CVR Energy recognized an increase of $3 million to additional paid-in capital from the non-cash reduction of non-controlling interests totaling $4 million and the recognition of a deferred tax liability totaling $1 million from changes in its book versus tax basis in CVR Partners as of December 31, 2020. 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 Accounting Policies

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

(2) Summary of Significant Accounting Policies

Principles of Consolidation

The accompanying consolidated financial statements, prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”), 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, 2021, 2020, and 2019.

CVR Partners is considered a VIE. As the 100% owner of the general partner of CVR Partners, the Company has the sole ability to direct the activities that most significantly impact the economic performance of CVR Partners and is considered to be the primary beneficiary. In January 2019, following the CVRR Unit Purchase, CVR Refining was no longer considered a VIE and is 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.

Reclassifications

Certain reclassifications have been made within the consolidated financial statements for prior periods to conform with current presentation.

Use of Estimates

The consolidated financial statements are prepared in conformity with 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, investments in highly liquid money market accounts, and debt instruments with original maturities of three months or less.

Restricted Cash

Restricted cash consists of cash that must be maintained in a commercial escrow account pending resolution of certain litigation matters and is discussed further in Note 11 (“Commitments and Contingencies”).

Accounts Receivable, net

Accounts receivable, net 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 which is discussed further within Note 7 (“Revenue”).

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 was approximately 8% and 11% of the net accounts receivable balance at December 31, 2021 and 2020, respectively. During the year ended December 31, 2021, 2020 and 2019, the Company had nominal bad debt expense.

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 GAAP First-In, First-Out (“FIFO”) cost, or net realizable value. The Petroleum Segment’s unfinished and finished products inventory values were determined using the ability-to-bear methodology. Other inventories in the Petroleum and Nitrogen Fertilizer Segments, 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.

The carrying amounts of the Petroleum Segment’s inventories exceeded their net realizable value (market value) by $58 million resulting in the recognition of a lower of cost or net realizable value adjustment as of March 31, 2020. The $58 million loss represents the difference between the carrying value of the Petroleum Segment’s inventories accounted for using the FIFO method and selling prices for refined products subsequent to March 31, 2020. No adjustment was necessary as of December 31, 2021 or December 31, 2020.

Inventories consisted of the following:


	December 31,
(in millions)	2021		2020
Finished goods	$	215	$	133
Raw materials	177		83
In-process inventories	20		16
Parts and supplies	72		66
Total inventories	$	484	$	298

At December 31, 2021 and 2020, inventories related to the Nitrogen Fertilizer Segment included depreciation of approximately $3 million and $2 million, respectively.

Property, Plant and Equipment, net

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 and improvements						10 to 30
Buildings and improvements						1 to 30
Machinery and equipment						1 to 30
Furniture and fixtures						3 to 10
Right-of-use (“ROU”) finance leases						3 to 18
Other						5 to 30

Property, plant and equipment, net consisted of the following:


	December 31,
(in millions)	2021		2020
Machinery and equipment	$	4,033	$	3,881
Buildings and improvements	88		88
ROU finance leases	81		80
Land and improvements	71		47
Furniture and fixtures	37		38
Construction in progress	142		100
Other	15		15
	4,467		4,249
Less: Accumulated depreciation	(2,194)		(2,009)
Total property, plant and equipment, net	$	2,273	$	2,240

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

On May 21, 2019, a subsidiary of CVR Energy sold its crude oil storage terminal located in Cushing, Oklahoma and related assets (the “Terminal”). As part of this transaction, the Company received cash consideration of $43 million for the Terminal and related crude oil inventories resulting in a recognition of a gain on sale of $10 million. The carrying value of the inventory sold as part of this transaction has been presented on a net basis, with the proceeds on sale, within the net cash used in investing section of the Consolidated Statements of Cash Flows.

As of December 31, 2021, the Company had not identified the existence of an impairment indicator for its long-lived asset groups as outlined under Accounting Standards Codification (“ASC”) Topic 360, Property, Plant, and Equipment.

Leases

At inception, the Company determines whether an arrangement is a lease and the appropriate lease classification. Operating leases are included as operating lease ROU assets within Other long-term assets and lease liabilities within Other current liabilities and Other long-term liabilities on our Consolidated Balance Sheets. Finance leases are included as ROU finance leases within Property, plant, and equipment, net, and finance lease liabilities within Note payable and finance lease obligations and Long-term debt and finance lease obligations, net of current portion on our Consolidated Balance Sheets. Leases with an

ROU assets represent the Company’s right to use an underlying asset for the lease term, and lease liabilities represent the obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the commencement date based on the present value of minimum lease payments over the lease term using an incremental borrowing rate with a maturity similar to the lease term, as our leases do not generally provide an implicit rate. The lease term is modified to reflect options to extend or terminate the lease when it is reasonably certain we will exercise such option. The depreciable life of assets and leasehold improvements is limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise, in which case the depreciation policy in the “Property, Plant and Equipment, net” section above is applicable. The periodic lease payments are treated as payments of the lease obligation and interest is recorded as interest expense.

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 maturity date of the facility. The deferred financing costs are included net within Long-term debt and finance lease obligations, net of current portion and in Other long-term liabilities for the line-of-credit arrangements where no debt balance exists.

Impairment of Long-Lived Assets and Goodwill

Long-lived assets (excluding goodwill, intangible assets with indefinite lives, and deferred tax 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 asset exceeds their fair value. Assets to be disposed of are reported at the lower of their carrying value or fair value less cost to sell.

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, while 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. The Company uses November 1 of each year as its annual valuation date for its goodwill impairment test.

One of the reporting units associated with our Nitrogen Fertilizer Segment’s Coffeyville, Kansas facility (the “Coffeyville Fertilizer Facility”) had a goodwill balance of $41 million at December 31, 2019. During the second quarter of 2020, following the completion of the spring planting season, the market pricing for ammonia and UAN, the Nitrogen Fertilizer Segment’s two primary products, experienced significant pricing declines driven by updated market expectations around supply and demand fundamentals which were expected to continue into the second half of 2020. Additionally, significant uncertainty remained as to the nature and extent of impacts to be seen on the overall demand for corn and soybean given reduced ethanol production and broader economic conditions which may negatively impact demand. Therefore in connection with the preparation of the financial statements for the three months ended June 30, 2020, given the pricing declines experienced in the second quarter of 2020, further muting of our near-term economic recovery assumptions, and market price performance of CVR Partners’ common units, the Company concluded an impairment indicator was present and a triggering event under ASC Topic 350, Intangibles-Goodwill and Other, had occurred as of June 30, 2020. Significant assumptions inherent in the valuation methodologies for goodwill are employed and include, but are not limited to, prospective financial information, growth rates, discount rates, inflationary factors, and cost of capital. Based on the interim quantitative analysis, it was determined that the estimated fair value of the Coffeyville Fertilizer Facility reporting unit did not exceed its carrying value. As a result, the Company recorded a full, non-cash impairment charge of $41 million during the year ended December 31, 2020.

As there was no goodwill balance at December 31, 2021 or 2020, no annual impairment review was performed. The Company performed its annual impairment review of goodwill for 2019 associated with the Coffeyville Fertilizer Facility

reporting unit and concluded there were no impairments. For the period ended December 31, 2019, no events or circumstances were identified which would trigger the performance of a quantitative analysis after reviewing all qualitative factors impacting the reporting unit including improved market conditions, financial results, and financial forecasts from those used in the fair value analysis for December 31, 2018, which resulted in the fair value of the Coffeyville Fertilizer Facility reporting unit exceeding its carrying value by approximately 36%.

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. Accrued amounts are reflected in Other current liabilities or Other long-term liabilities depending on when the Company expects to expend such amounts. Refer to Note 11 (“Commitments and Contingencies”) for further discussion.

Environmental, Health & Safety (“EHS”) Matters

The Petroleum Segment and Nitrogen Fertilizer Segment are subject to various federal, state, and local environmental, health, and safety rules and regulations. Liabilities related to future remediation costs of past environmental contamination of properties are recognized when the related costs are considered probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, internal and third-party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change, and such accruals can take into account the legal liability of other parties. Management periodically reviews and, as appropriate, revises its environmental accruals. Environmental expenditures for capital assets are capitalized at the time of the expenditure when such costs provide future economic benefits. Accrued amounts are reflected in Other current liabilities or Other long-term liabilities depending on when the Company expects to expend such amounts. Refer to Note 11 (“Commitments and Contingencies”) for further discussion.

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 Company’s revenue recognition patterns 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 Cost of materials and other on the Consolidated Statements of Operations.

•Nitrogen Fertilizer Segment - Revenue is recognized 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 Topic 606, Revenue from Contracts with Customers, resulted in the recognition of deferred revenue and related receivables, on a gross basis, associated with contracts that guarantee a price and supply of nitrogen fertilizer products 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 includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, purchased ammonia, purchased hydrogen, pet coke expenses, Renewable Identification Number (“RIN”) expenses, derivative gains 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 (exclusive of depreciation and amortization) 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

The Petroleum Segment uses futures contracts, swaps, 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 derivatives 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 8 (“Derivative Financial Instruments, Investments and Fair Value Measurements”) for further discussion of the Company’s derivative activity.

Other financial instruments consisting of cash and cash equivalents, restricted cash, 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 8 (“Derivative Financial Instruments, Investments and Fair Value Measurements”) for further fair value disclosures.

Turnaround Expenses

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, while the frequency of turnarounds in the Nitrogen Fertilizer Segment is every two to three years. Further details of each segment’s turnaround expensing method are discussed below.

Petroleum Segment - The Petroleum Segment follows the deferral method of accounting for turnaround activities. Under the deferral method, the costs of turnarounds are deferred and amortized on a straight-line basis over a four-year period of time, which represents the estimated time until the next turnaround occurs. The deferral method of accounting for turnarounds is considered preferable as it is more consistent with the accounting policy of our peer companies and better reflects the economic substance of the benefits earned from turnaround expenditures. Turnaround costs, and related accumulated amortization, are included in the Consolidated Balance Sheets as Other long-term assets. The amortization expense related to turnaround costs is included in Depreciation and amortization in the Consolidated Statements of Operations. During the years ended December 31, 2021, 2020, and 2019, the Petroleum Segment capitalized $8 million, $155 million, and $38 million, respectively.

Nitrogen Fertilizer Segment - The Nitrogen Fertilizer Segment follows the direct-expense method of accounting for turnaround activities. 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, 2021, 2020, and 2019, the Nitrogen Fertilizer Segment incurred turnaround expenses of $3 million, $1 million, and $10 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. See Note 9 (“Share-Based Compensation”) for further discussion.

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. In assessing the realizability of the deferred income tax assets, including net operating loss and state tax 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 income 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 income tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Further, the Company recognizes interest expense (income) and penalties on uncertain tax positions and income tax deficiencies (refunds) in Income tax (benefit) expense.

Earnings Per Share

There were no dilutive awards outstanding during the years ended December 31, 2021, 2020, and 2019.

Recent Accounting Pronouncements - Adoption of Income Tax Standard

In December 2019, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2019-12, Income Taxes (Topic 740). The ASU simplifies the accounting for income taxes by removing certain exceptions to the general principles in Topic 740 and modifies other areas of the topic to clarify the application of GAAP. Certain amendments within the standard are required to be applied on a retrospective basis and others on a prospective basis. Effective January 1, 2021, we adopted this ASU with no material impact on the Company’s consolidated financial position or results of operations.

Recent Accounting Pronouncements - Adoption of Codification Improvements Standard

In October 2020, the FASB issued ASU 2020-10, Codification Improvements. The ASU amends various sections of the codification in the FASB’s ongoing efforts to simplify and improve guidance. Effective January 1, 2021, we adopted this ASU with no material impact on the Company’s consolidated financial position or results of operations.

Recent Accounting Pronouncements - New Accounting Standards Issued But Not Yet Implemented

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848). This ASU was issued because, by the end of 2022, banks will no longer be required to report information that is used to determine London Interbank Offered Rate (“LIBOR”), which is used globally by all types of entities. As a result, LIBOR could be discontinued, as well as other interest rates used globally. ASU 2020-04 provides companies with optional expedients for contract modifications under Topics 310, 470, 842, and 815-15, excluded components of certain hedging relationships, fair value hedges, and cash flow hedges, as well as certain exceptions, which are intended to help ease the potential accounting burden associated with transitioning away from these reference rates. In January 2021, the FASB issued ASU 2021-01, Reference Rate Reform (Topic 848), which clarifies certain optional expedients and exceptions for contract modifications and hedge accounting. Companies can apply the ASU immediately. However, the guidance will only be available for a limited time (generally through December 31, 2022). The Company is currently evaluating the impact of adopting this new accounting standard, but does not expect it to have a material impact on its consolidated financial statements and related disclosures.

Equity Method Investments

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

(3) 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 have applied the equity method of accounting.

•Enable South Central Pipeline, LLC (“Enable JV”) - CVR Refining owns a 40% interest in Enable JV, which operates a 12-inch 26-mile crude oil pipeline with a capacity of approximately 115,000 barrels per day that is connected to the Wynnewood Refinery. The remaining interest in Enable JV is owned by Enable Midstream Partners, LP, which was merged with Energy Transfer LP in December 2021.

•Midway Pipeline, LLC (“Midway JV”) - CVR Refining owns a 50% interest in Midway JV, which operates a 16-inch 99-mile crude oil pipeline with a capacity of approximately 150,000 barrels per day which connects the Coffeyville Refinery to the Cushing Oklahoma oil hub. The remaining interest in Midway JV is owned by Plains Pipeline, L.P.


(in millions)	Enable JV		Midway JV		Total
Balance at December 31, 2019	6		75		81

Cash Distributions	(4)		(6)		(10)
Equity income	4		5		9
Balance at December 31, 2020	6		74		80
Cash Distributions	(3)		(8)		(11)
Equity income	3		7		10
Balance at December 31, 2021	$	6	$	73	$	79

Leases

12 Months Ended

Dec. 31, 2021

Leases [Abstract]

Leases

(4) Leases

Lease Overview

We lease certain pipelines, storage tanks, railcars, office space, land, and equipment across our refining, fertilizer, and corporate operations. Most leases include one or more options to renew, with renewal terms that can extend the lease term from one to 20 years or more. The exercise of lease renewal options is at our sole discretion. Certain leases also include options to purchase the leased property. Certain of our lease agreements include rental payments which are adjusted periodically for factors such as inflation. Our lease agreements do not contain any material residual value guarantees or material restrictive covenants. Additionally, we do not have any material lessor or sub-leasing arrangements.

Balance Sheet Summary as of December 31, 2021 and 2020

The following table summarizes the right of use asset and lease liability balances for the Company’s operating and finance leases at December 31, 2021 and 2020:


	December 31, 2021				December 31, 2020
(in millions)	Operating Leases		Finance Leases		Operating Leases		Finance Leases
ROU assets, net
Pipeline and storage	$	17	$	23	$	15	$	26
Railcars	6		—		8		—
Real estate and other	14		18		14		21
Lease liability
Pipelines and storage	$	17	$	35	$	16	$	38
Railcars	6		—		8		—
Real estate and other	14		19		14		22

Lease Expense Summary for the Year Ended December 31, 2021, 2020 and 2019

We recognize lease expense on a straight-line basis over the lease term and short-term lease expense within Direct operating expenses (exclusive of depreciation and amortization). For the year ended December 31, 2021, 2020, and 2019, we recognized lease expense comprised of the following components:


	Year Ended December 31,
(in millions)	2021		2020		2019
Operating lease expense	$	15	$	17	$	12
Finance lease expense:
Amortization of ROU asset	$	6	$	6	$	7
Interest expense on lease liability	5		6		6
Short-term lease expense	$	7	$	8	$	8

Lease Terms and Discount Rates

The following outlines the remaining lease terms and discount rates used in the measurement of the Company’s ROU assets and liabilities:


	December 31, 2021				December 31, 2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Weighted-average remaining lease term	4.1 years		7.2 years		3.1 years		8.1 years
Weighted-average discount rate	5.4	%	9.0	%	5.5	%	9.0	%

Maturities of Lease Liabilities

The following summarizes the remaining minimum lease payments through maturity of the Company’s right-of-use assets and liabilities at December 31, 2021:


(in millions)	Operating Leases		Finance Leases
Year Ended December 31,
2022	$	14	$	11
2023	12		10
2024	8		10
2025	3		10
2026	1		10
Thereafter	4		23
Total lease payments	42		74
Less: imputed interest	(5)		(20)
Total lease liability	$	37	$	54

On July 31, 2020, Coffeyville Resources Nitrogen Fertilizers, LLC (“CRNF”), a subsidiary of CVR Partners, and Messer LLC (“Messer”) entered into an On-Site Product Supply Agreement (the “Messer Agreement”). On February 21, 2022, CRNF entered into the First Amendment to the On-Site Product Supply Agreement (the “Messer Amendment”, and collectively, the “Amended Messer Agreement”) with Messer. Under the Amended Messer Agreement, among other obligations, Messer is obligated to supply and make certain capital improvements during the term of the Amended Messer Agreement, and CRNF is obligated to take as available and pay for, oxygen, nitrogen, and compressed dry air from Messer’s facility. This arrangement for CRNF’s purchase of oxygen, nitrogen, and dry air from Messer does not meet the definition of a lease under FASB Accounting Standards Codification (“ASC”) Topic 842, Leases, (“Topic 842”), as CRNF does not expect to receive substantially all of the output of Messer’s on-site production from its air separation unit over the life of the Amended Messer Agreement. The Amended Messer Agreement also obligates Messer to install a new oxygen storage vessel, related equipment and infrastructure (“Oxygen Storage Vessel” or “Vessel”) to be used solely by the Coffeyville Fertilizer Facility. This arrangement for the use of the Oxygen Storage Vessel meets the definition of a lease under Topic 842, as CRNF will receive all

output associated with the Vessel. Based on terms outlined in the Amended Messer Agreement, the Company expects the lease of the Oxygen Storage Vessel to be classified as a financing lease with an amount of approximately $25 million being capitalized upon lease commencement when the Vessel is placed in service.

Leases

(4) Leases

Lease Overview

Balance Sheet Summary as of December 31, 2021 and 2020

The following table summarizes the right of use asset and lease liability balances for the Company’s operating and finance leases at December 31, 2021 and 2020:


	December 31, 2021				December 31, 2020
(in millions)	Operating Leases		Finance Leases		Operating Leases		Finance Leases
ROU assets, net
Pipeline and storage	$	17	$	23	$	15	$	26
Railcars	6		—		8		—
Real estate and other	14		18		14		21
Lease liability
Pipelines and storage	$	17	$	35	$	16	$	38
Railcars	6		—		8		—
Real estate and other	14		19		14		22

Lease Expense Summary for the Year Ended December 31, 2021, 2020 and 2019


	Year Ended December 31,
(in millions)	2021		2020		2019
Operating lease expense	$	15	$	17	$	12
Finance lease expense:
Amortization of ROU asset	$	6	$	6	$	7
Interest expense on lease liability	5		6		6
Short-term lease expense	$	7	$	8	$	8

Lease Terms and Discount Rates

The following outlines the remaining lease terms and discount rates used in the measurement of the Company’s ROU assets and liabilities:


	December 31, 2021				December 31, 2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Weighted-average remaining lease term	4.1 years		7.2 years		3.1 years		8.1 years
Weighted-average discount rate	5.4	%	9.0	%	5.5	%	9.0	%

Maturities of Lease Liabilities

The following summarizes the remaining minimum lease payments through maturity of the Company’s right-of-use assets and liabilities at December 31, 2021:


(in millions)	Operating Leases		Finance Leases
Year Ended December 31,
2022	$	14	$	11
2023	12		10
2024	8		10
2025	3		10
2026	1		10
Thereafter	4		23
Total lease payments	42		74
Less: imputed interest	(5)		(20)
Total lease liability	$	37	$	54

Other Current Liabilities

12 Months Ended

Dec. 31, 2021

Other Liabilities Disclosure [Abstract]

Other Current Liabilities

(5) Other Current Liabilities

Other current liabilities were as follows:


	December 31,
(in millions)	2021		2020
Accrued Renewable Fuel Standards (“RFS”) obligation	$	494	$	214
Deferred revenue	87		31
Personnel accruals	46		23
Accrued taxes other than income taxes	45		32
Accrued interest	24		25
Share-based compensation	15		4
Operating lease liabilities	13		14

Accrued derivatives	2		17

Other accrued expenses and liabilities	15		9
Total other current liabilities	$	741	$	369

Long-Term Debt and Finance Lease Obligations

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Long-Term Debt and Finance Lease Obligations

(6) Long-Term Debt and Finance Lease Obligations


	December 31,
(in millions)	2021		2020
CVR Partners:
9.25% Senior Secured Notes, due June 2023 (1)	$	65	$	645
6.125% Senior Notes, due June 2028	550		—
Unamortized discount and debt issuance costs	(4)		(11)
Total CVR Partners debt	$	611	$	634
CVR Refining:

Finance lease obligations, net of current portion (2)	48		55

Total CVR Refining debt	48		55
CVR Energy:
5.250% Senior Notes, due February 2025	$	600	$	600
5.750% Senior Notes, due February 2028	400		400
Unamortized debt issuance cost	(5)		(6)
Total CVR Energy debt	995		994
Total long-term debt and finance lease obligations	$	1,654	$	1,683
Current portion of long-term debt and finance lease obligations (2) (3)	6		8
Total long-term debt and finance lease obligations, including current portion	$	1,660	$	1,691

(1)The call price of the 9.25% Senior Secured Notes due June 2023 (the “2023 UAN Notes”) decreased to par on June 15, 2021. On June 23, 2021, September 23, 2021, and December 22, 2021, CVR Partners redeemed $550 million, $15 million, and $15 million, respectively, of the 2023 UAN Notes, at par, plus accrued and unpaid interest on the redeemed portion. The remaining balance of $65 million was outstanding as of December 31, 2021. The $65 million outstanding balance of the 2023 UAN Notes was paid in full on February 22, 2022 at par, plus accrued and unpaid interest.

(2)Current portion of finance lease obligations was approximately $6 million and $6 million as of December 31, 2021 and 2020, respectively.

(3)The $2 million outstanding balance of the 6.50% Notes, due April 2021, was paid in full on April 15, 2021.

Credit Agreements


(in millions)	Total Capacity		Amount Borrowed as of December 31, 2021		Outstanding Letters of Credit		Available Capacity as of December 31, 2021		Maturity Date
CVR Partners:
Asset Based (“Nitrogen Fertilizer ABL”) Credit Agreement (1) (2)	$	35	$	—	$	—	$	35	September 30, 2024
CVR Refining:
Amended and Restated Asset Based (“Petroleum ABL”) Credit Agreement (3)	$	400	$	—	$	39	$	361	November 14, 2022

(1)On September 30, 2021, CVR Partners entered into a senior secured asset based ABL Credit Facility with an aggregate principal amount of up to $35 million with a maturity date of September 30, 2024 (the “Nitrogen Fertilizer ABL”) and terminated its $35 million ABL Credit Agreement, dated as of September 30, 2016, as amended (the “UAN 2016 ABL Credit Agreement”).

(2)Beginning September 30, 2021, loans under the Nitrogen Fertilizer ABL bear interest at an annual rate equal to, at the option of the borrowers, (i) (a) 1.615% plus the daily simple Secured Overnight Financing Rate (“SOFR”) or (b) 0.615% plus a base rate, if our quarterly excess availability is greater than or equal to 75%, (ii) (a) 1.865% plus SOFR or (b) 0.865% plus a base rate, if our quarterly excess availability is greater than or equal to 50% but less than 75%, or (iii) (a) 2.115% plus SOFR or (b) 1.115% plus a base rate, otherwise.

(3)Loans under the Petroleum ABL bear interest at an annual rate equal to (i) (a) 1.50% plus LIBOR, to the extent available, or (b) 0.50% plus a base rate, if our quarterly excess availability is greater than 50%, and (ii) (a) 1.75% plus LIBOR, to the extent available, or (b) 0.75% plus a base rate, otherwise.

CVR Partners

2028 UAN Notes - On June 23, 2021, CVR Partners and its subsidiary, CVR Nitrogen Finance Corporation (“Finance Co.” and, together with CVR Partners, the “Issuers”), completed a private offering of $550 million aggregate principal amount of 6.125% Senior Secured Notes due 2028 (the “2028 UAN Notes”). Interest on the 2028 UAN Notes is payable semi-annually in arrears on June 15 and December 15 each year, commencing on December 15, 2021. The 2028 UAN Notes mature on June 15, 2028, unless earlier redeemed or repurchased by the Issuers. The 2028 UAN Notes are jointly and severally guaranteed on a senior secured basis by all the existing domestic subsidiaries of CVR Partners, excluding Finance Co.

In relation to the issuance of the 2028 UAN Notes, CVR Partners received $547 million of net cash proceeds, net of underwriting fees and other third-party fees and expenses associated with the offering. The debt issuance costs of the 2028 UAN Notes totaled approximately $4 million and are being amortized over the term of the 2028 UAN Notes as interest expense using the effective-interest amortization method.

The Issuers may, at their option, at any time and from time to time prior to June 15, 2024, on any one or more occasions, redeem all or part of the 2028 UAN Notes, at a price equal to 100% of the principal amount plus a “make whole” premium, plus accrued and unpaid interest. On or after June 15, 2024, the Issuers may, on any one or more occasions, redeem all or part of the 2028 UAN Notes at the redemption prices set forth below, expressed as a percentage of the principal amount of the respective notes, plus accrued and unpaid interest to the applicable redemption date.


12-month period beginning June 15,						Percentage
2024						103.063%
2025						101.531%
2026 and thereafter						100.000%

The indenture governing the 2028 UAN Notes contains covenants that are substantially the same as the indenture governing the 2023 UAN Notes. However, the 2028 UAN Notes contain a permitted investment activity carveout that allows for the transfer of certain carbon capture assets to a joint venture for the purpose of monetizing potential tax credits.

2023 UAN Notes - On June 10, 2016, CVR Partners and Finance Co. (together the “2023 Notes Issuers”), certain subsidiary guarantors named therein and Wilmington Trust, National Association, as trustee and as collateral trustee, completed a private offering of $645 million aggregate principal amount of 9.25% Senior Secured Notes due 2023 (the “2023 UAN Notes”). The

2023 UAN Notes mature on June 15, 2023, unless earlier redeemed or repurchased by the issuers. Interest on the 2023 UAN Notes is payable semi-annually in arrears on June 15 and December 15 of each year. The 2023 UAN Notes are guaranteed on a senior secured basis by all of the Nitrogen Fertilizer Partnership’s existing subsidiaries.

On or after June 15, 2021, the 2023 Notes Issuers may redeem all or part of the 2023 UAN Notes at a price equal to 100% of the principal amount plus accrued and unpaid interest to the applicable redemption date. The 2023 UAN Notes contain customary covenants for a financing of this type that, among other things, restrict CVR Partners’ ability and the ability of certain of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Nitrogen Fertilizer Partnership’s units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from CVR Partners’ restricted subsidiaries to CVR Partners; (vii) consolidate, merge or transfer all or substantially all of CVR Partners’ assets; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries. In addition, the indenture contains customary events of default, the occurrence of which would result in or permit the trustee or the holders of at least 25% of the 2023 UAN Notes to cause the acceleration of the 2023 UAN Notes, in addition to the pursuit of other available remedies.

On June 23, 2021, CVR Partners redeemed $550 million aggregate principal amount of the outstanding 2023 UAN Notes at par and settled accrued interest of approximately $1 million through the date of redemption. As a result of the redemption, CVR Partners recognized in Interest expense, net an $8 million loss on extinguishment of debt in the second quarter of 2021, which includes the write-off of unamortized deferred financing costs and discount of $3 million and $5 million, respectively.

On September 23, 2021 and December 22, 2021, CVR Partners redeemed $15 million and $15 million respectively, in aggregate principal amount of the outstanding 2023 UAN Notes at par and settled accrued interest of less than $1 million through the date of each redemption. As a result of these redemptions and for the year ended December 31, 2021, CVR Partners recognized in Interest expense, net a loss on extinguishment of debt of less than $1 million in 2021, which includes the write-off of unamortized deferred financing costs and discount.

On February 22, 2022, CVR Partners redeemed all of the outstanding 2023 UAN Notes at par and settled accrued interest of approximately $1 million through the date of redemption. As a result of this transaction, CVR Partners will recognize a loss on extinguishment of debt of $1 million in the first quarter of 2022, which includes the write-off of unamortized deferred financing costs and discount of less than $1 million each.

Nitrogen Fertilizer ABL - On September 30, 2021, CVR Partners, LP and its subsidiaries, CVR Nitrogen, LP, East Dubuque Nitrogen Fertilizers, LLC, Coffeyville Resources Nitrogen Fertilizers, LLC, CVR Nitrogen Holdings, LLC, Finance Co. and CVR Nitrogen GP, LLC, entered into the Nitrogen Fertilizer ABL with Wells Fargo Bank National Association, a national banking association (“Wells Fargo”), as administrative agent, collateral agent, and lender. The Nitrogen Fertilizer ABL has an aggregate principal amount of availability of up to $35 million with an incremental facility, which permits an increase in borrowings of up to $15 million in the aggregate subject to additional lender commitments and certain other conditions. The proceeds of the loans may be used for general corporate purposes of CVR Partners and its subsidiaries. The Nitrogen Fertilizer ABL provides for loans and letters of credit, subject to meeting certain borrowing base conditions, with sub-limits of $4 million for swingline loans and $10 million for letters of credit. The Nitrogen Fertilizer ABL is scheduled to mature on September 30, 2024.

Loans under the Nitrogen Fertilizer ABL initially bear interest at an annual rate equal to, at the option of the borrowers, (i) 1.615% plus SOFR or (ii) 0.615% plus a base rate. Based on the previous quarter’s excess availability, such annual rate could increase to, at the option of the borrowers, (i) 2.115% plus SOFR or (ii) 1.115% plus a base rate. The borrowers must also pay a commitment fee on the unutilized commitments and also pay customary letter of credit fees.

The Nitrogen Fertilizer ABL contains customary covenants for a financing of this type and requires CVR Partners in certain circumstances to comply with a minimum fixed charge coverage ratio test and contains other restrictive covenants that limit the ability of CVR Partners and its subsidiaries ability to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue certain equity interests, create subsidiaries and unrestricted subsidiaries, and create certain restrictions on the ability to make distributions, loans, and asset transfers among CVR Partners or its subsidiaries.

In connection with the Nitrogen Fertilizer ABL, CVR Partners incurred lender and other third-party costs of $1 million, which have been deferred in Prepaid expenses and other current assets and Other long-term assets and are being amortized as interest expense over the term of the Nitrogen Fertilizer ABL using the straight-line amortization method.

CVR Refining

Petroleum ABL - On November 14, 2017, CVR Services, 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”, and collectively, the “Petroleum ABL”) with a group of lenders and Wells Fargo, as administrative agent and collateral agent. The Petroleum ABL 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 Petroleum ABL also includes a $200 million uncommitted incremental facility.

CVR Energy

2025 Notes and 2028 Notes - On January 27, 2020, CVR Energy completed a private offering of $600 million aggregate principal amount of 5.25% Senior Unsecured Notes due 2025 (the “2025 Notes”) and $400 million aggregate principal amount of 5.75% Senior Unsecured Notes due 2028 (the “2028 Notes” and, collectively with the 2025 Notes, the “Notes”). Interest on the Notes is payable semi-annually in arrears on February 15 and August 15 each year, commencing on August 15, 2020. The 2025 Notes mature on February 15, 2025, unless earlier redeemed or repurchased by the issuers. The 2028 Notes mature on February 15, 2028, unless earlier redeemed or repurchased by the issuers. The Notes are jointly and severally guaranteed on a senior unsecured basis by the wholly-owned subsidiaries of CVR Energy with the exception of CVR Partners and its subsidiaries and certain immaterial wholly-owned subsidiaries of CVR Energy.

In relation to the issuance of the Notes, the Company received $993 million of net cash proceeds, net of underwriting fees and other third-party fees and expenses associated with the offering. The debt issuance costs of the Notes totaled approximately $7 million and are being amortized over the terms of the respective notes as interest expense using the effective-interest amortization method.

On or after February 15, 2022 and February 15, 2023, we may on any one or more occasions, redeem all or part of the 2025 Notes and 2028 Notes, respectively, at the redemption prices set forth below expressed as a percentage of the principal amount of the respective notes, plus accrued and unpaid interest to the applicable redemption date.


2025 Notes		2028 Notes
12-month period beginning February 15,	Percentage	12-month period beginning February 15,	Percentage
2022	102.625%	2023	102.875%
2023	101.313%	2024	101.917%
2024 and thereafter	100.000%	2025	100.958%
		2026 and thereafter	100.000%

The indenture governing the Notes imposes covenants that will, among other things, limit our ability and the ability of our restricted subsidiaries to: (i) incur additional indebtedness or issue certain disqualified equity; (ii) create liens on certain assets to secure debt; (iii) pay dividends or make other equity distributions; (iv) purchase or redeem capital stock; (v) make certain investments; (vi) sell assets; (vii) agree to certain restrictions on the ability of restricted subsidiaries to make distributions, loans, or other asset transfers to us; (viii) consolidate, merge, sell, or otherwise dispose of all or substantially all of our assets; (ix) engage in transactions with affiliates; and (x) designate our restricted subsidiaries as unrestricted subsidiaries. In addition, the indenture contains customary events of default, the occurrence of which would result in or permit the trustee or the holders of at least 25% of the 2025 Notes and 2028 Notes to cause, amongst other available remedies, the acceleration of the respective notes.

Covenant Compliance

The Company is in compliance with all covenants of the Nitrogen Fertilizer ABL, the Petroleum ABL, and the senior notes as of December 31, 2021.

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-URI http://asc.fasb.org/topic&trid=2208564

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+ Details

Revenue

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue

(7) Revenue

The following tables present the Company’s revenue disaggregated by major product, which include a reconciliation of the disaggregated revenue by product and other revenue components for the Company’s reportable segments.


	Year Ended December 31, 2021
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	3,679	$	—	$	—	$	3,679
Distillates (1)	2,809		—		—		2,809
Ammonia	—		146		—		146
UAN	—		316		—		316
Other urea products	—		29		—		29

Freight revenue	21		31		—		52
Other (2)	163		11		(12)		162
Revenue from product sales	6,672		533		(12)		7,193

Crude oil sales	47		—		—		47
Other revenue (2)	2		—		—		2
Total revenue	$	6,721	$	533	$	(12)	$	7,242


	Year Ended December 31, 2020
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	1,882	$	—	$	—	$	1,882
Distillates (1)	1,543		—		—		1,543
Ammonia	—		94		—		94
UAN	—		198		—		198
Other urea products	—		15		—		15
Freight revenue	18		33		—		51
Other (2)	79		10		(6)		83
Revenue from product sales	3,522		350		(6)		3,866

Crude oil sales	63		—		—		63
Other revenue (2)	1		—		—		1
Total revenue	$	3,586	$	350	$	(6)	$	3,930


	Year Ended December 31, 2019
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	3,050	$	—	$	—	$	3,050
Distillates (1)	2,705		—		—		2,705
Ammonia	—		94		—		94
UAN	—		251		—		251
Other urea products	—		18		—		18
Freight revenue	23		33		—		56
Other (2)	129		8		(8)		129
Revenue from product sales	5,907		404		(8)		6,303

Crude oil sales	58		—		—		58
Other revenue (2)	3		—		—		3
Total revenue	$	5,968	$	404	$	(8)	$	6,364

(1)Distillates consist primarily of diesel fuel, kerosene, and jet fuel.

(2)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 on the Cushing, OK storage tanks.

Petroleum Segment

The Petroleum Segment’s revenue from product sales is recorded upon delivery 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. Qualifying excise and other taxes collected from the Petroleum Segment’s customers and remitted to governmental authorities are not included in reported revenues.

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

The Petroleum Segment may incur broker commissions or transportation costs prior to product transfer on some of its sales. The Petroleum Segment expenses these broker costs, since the contract durations are less than a year. 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 generally provides no warranty other than the implicit promise that goods delivered are free of liens and encumbrances and meet the agreed upon specification. The Petroleum Segment has determined that product returns or refunds are very rare and will account for them as they occur.

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

Nitrogen Fertilizer Segment

The Nitrogen Fertilizer Segment sells its products on a wholesale basis under a contract or by purchase order. The Nitrogen Fertilizer Segment’s contracts with customers generally contain fixed pricing and most have terms of less than one year. The Nitrogen Fertilizer Segment recognizes revenue at the point in time at which the customer obtains control of the product, which is generally upon delivery and acceptance by the customer. The customer acceptance point is stated in the contract and may be

at one of the Nitrogen Fertilizer Segment’s manufacturing facilities, at one of the Nitrogen Fertilizer Segment’s off-site loading facilities, or at the customer’s designated facility. Freight revenue recognized by the Nitrogen Fertilizer Segment represents the pass-through finished goods delivery costs incurred prior to customer acceptance and is reimbursed by customers. An offsetting expense for freight is included in Cost of materials and other. Qualifying excise and other taxes collected from the Nitrogen Fertilizer Segment’s customers and remitted to governmental authorities are not included in reported revenues.

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

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

The Nitrogen Fertilizer Segment has an immaterial amount of variable consideration for contracts with an original duration of less than a year. A small portion of the Nitrogen Fertilizer 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, 2021, the Nitrogen Fertilizer Segment had approximately $10 million of remaining performance obligations for contracts with an original expected duration of more than one year. The Nitrogen Fertilizer Segment expects to recognize approximately $6 million of these performance obligations as revenue by the end of 2022, an additional $4 million by 2023, and the remaining balance thereafter.

Contract Balances

The Nitrogen Fertilizer Segment’s deferred revenue is a contract liability that primarily relates to nitrogen 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, 2021 is presented below:


(in millions)
Balance at December 31, 2020	$	31
Add:
New prepay contracts entered into during the period (1)	147
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	(30)
Revenue recognized related to contracts entered into during the period	(60)
Other changes	(1)
Balance at December 31, 2021	$	87

(1)Includes $94 million where the payment associated with prepaid contracts was collected.

Major Customers

Petroleum Segment - The Petroleum Segment had one customer who comprised 16% of petroleum net sales for the year ended December 31, 2021 and two customers who comprised 26% and 25% of petroleum net sales for the years ended December 31, 2020 and 2019, respectively.

Nitrogen Fertilizer Segment - The Nitrogen Fertilizer Segment had one customer who comprised 13% for the year ended December 31, 2021 and two customers who comprised 26% and 28% of nitrogen fertilizer net sales for the years ended December 31, 2020 and 2019, respectively.

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
-Topic 606
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

+ Details

Derivative Financial Instruments, Investments and Fair Value Measurements

12 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments, Investments and Fair Value Measurements

(8) Derivative Financial Instruments, Investments and Fair Value Measurements

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. On a regular basis, the Company enters into commodity contracts with counterparties for the purchases or sale of crude oil, blendstocks, various finished products, and RINs. The contracts usually qualify for the normal purchase normal sale exception and follow the accrual method of accounting. All other derivative instruments are recorded at fair value using mark-to-market accounting on a periodic basis utilizing third-party pricing.

The Petroleum Segment holds derivative instruments, such as exchange-traded crude oil futures and 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 or upon settlement. The Petroleum Segment may enter into forward purchase or sale contracts associated with RINs. As of December 31, 2021, the Petroleum Segment had open fixed-price commitments to purchase a net 2 million RINs.

Commodity derivatives include commodity swaps and forward purchase and sale commitments. There were no outstanding commodity swap positions as of December 31, 2021 compared to 7 million barrels in outstanding commodity swap positions as of December 31, 2020. As of December 31, 2021 and 2020, there were approximately 1 million and 4 million barrels in forward purchase commitments, respectively, and 1 million and 2 million barrels in forward sale commitments, respectively.

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:


	Year Ended December 31,
(in millions)	2021		2020		2019
Forward purchases and sales contracts, net	$	25	$	53	$	20
Commodity swap instruments	(68)		(8)		—
Futures contracts	(1)		10		(1)
Total (loss) gain on derivatives, net	$	(44)	$	55	$	19

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 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)	2021		2020		2021		2020
Commodity derivatives	$	5	$	1	$	(7)	$	(5)

Less: Counterparty netting	(5)		(1)		5		1
Total net fair value of derivatives	$	—	$	—	$	(2)	$	(4)

Investments

Investments consist of equity securities, which are reported at fair value in our Consolidated Balance Sheets. These investments are considered trading securities. Investment income on marketable securities consists of the following:


	Year Ended December 31,
(in millions)	2021		2020		2019
Dividend income	$	—	$	7	$	—
Gain on marketable securities	81		34		—
Investment income on marketable securities	$	81	$	41	$	—

On June 10, 2021, the Company distributed its investment of 10,539,880 shares of common stock of Delek US Holdings, Inc. (“Delek”) in the form of a special dividend to its stockholders (the “Stock Distribution”). Following the Stock Distribution, the Company continued to hold a nominal investment in other marketable securities of Delek as of December 31, 2021. See further discussion of the distribution in Note 14 (“Related Party Transactions”).

Fair Value Measurements

In accordance with FASB ASC Topic 820 — Fair Value Measurements and Disclosures (“Topic 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.

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

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

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

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

The following tables set forth the assets and liabilities measured or disclosed at fair value on a recurring basis, by input level, as of December 31, 2021 and 2020:


	December 31, 2021
(in millions)	Level 1		Level 2		Level 3		Total
Location and Description


Other current assets (commodity derivatives)	$	—	$	1	$	—	$	1
Total Assets	$	—	$	1	$	—	$	1

Other current liabilities (commodity derivatives)	$	—	$	(2)	$	—	$	(2)

Other current liabilities (RFS obligation)	—		(494)		—		(494)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	—		(1,620)		—		(1,620)
Total Liabilities	$	—	$	(2,116)	$	—	$	(2,116)


	December 31, 2020
(in millions)	Level 1		Level 2		Level 3		Total
Location and Description

Prepaid expenses and other current assets (investments)	$	173	$	—	$	—	$	173



Total Assets	$	173	$	—	$	—	$	173
Note payable and finance lease obligations (current portion of long-term debt)	$	—	$	(2)	$	—	$	(2)
Other current liabilities (commodity derivatives)	—		(17)		—		(17)

Other current liabilities (RFS obligation)	—		(214)		—		(214)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	—		(1,604)		—		(1,604)
Total Liabilities	$	—	$	(1,837)	$	—	$	(1,837)

As of December 31, 2021 and 2020, the only financial assets and liabilities that are measured at fair value on a recurring basis are the Company’s investments, derivative instruments, long-term debt, and the RFS obligation. The estimated fair value of cash equivalents, included amounts invested in short-term money market funds, and restricted cash approximate their carrying amounts. 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, 2021.

Share-Based Compensation

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

Share-Based Compensation

(9) Share-Based Compensation

Overview

CVR Energy, CVR Refining, and CVR Partners all have Long-Term Incentive Plans (collectively, the “LTIPs”) that permit the granting of options, stock and unit appreciation rights, 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 or in connection with the LTIPs include the employees, officers, and directors of the Company, CVR Refining, and CVR Partners. The Company had 6.8 million shares or units, as applicable, available for future grants under our plans at December 31, 2021.

Incentive and Phantom Unit Awards

Incentive and phantom unit awards have been granted to officers, employees, and directors (collectively, the “Share-Based Awards”). As a result, Share-Based Awards that reflect the value and dividends or distributions of CVR Energy or CVR Partners, as applicable, have been granted and remain outstanding as of December 31, 2021. 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 through the vesting date. The Share-Based Awards are generally graded-vesting awards, which 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 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.

A summary of activity for the Company’s Share-Based Awards for the year ended December 31, 2021 is presented below:


	Shares or Units (1)	Weighted-Average Grant-Date Fair Value (per share or unit)		Aggregate Intrinsic Value (in millions)








Non-vested at December 31, 2020	2,454,641	$	19.01	$	37
Granted	950,744	19.46
Vested	(857,901)	21.14
Forfeited	(254,379)	19.66
Non-vested at December 31, 2021	2,293,105	$	18.23	$	62

(1)As of December 31, 2021, there are no outstanding awards under the LTIPs, and the only outstanding and unvested awards are issued in connection with and not under the LTIPs.

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 (the “2018 CEO Performance Award”). The payout of $1.9 million, paid in February 2019, under the 2018 CEO Performance Award was 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. Effective as of December 22, 2021, the Company entered into an amendment to the CEO Performance Award, which extended the end of the performance period thereunder to December 31, 2024, and changed the 30 day trading period on which the average closing price of the Company’s common stock is based to January 6, 2025 through February 20, 2025.

Compensation Expense

A summary of total share based compensation expense and unrecognized compensation expense related to the Share-Based Awards and the 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, 2021, 2020, and 2019 is presented below:


	Expenses						Unrecognized Expense
	For the year ended December 31,						At December 31, 2021
(in millions)	2021		2020		2019		Amount		Weighted-Average Remaining Years
Share based awards:
Incentive Units	$	22	$	3	$	12	$	27	2.4
Phantom Units	27		1		5		19		2.0

Performance awards:
CEO Performance Award (1)	(3)		—		—		10		3.0


Total expense	$	46	$	4	$	17	$	56

(1)All expenses, recognized and unrecognized, related to the CEO Performance Award are contingent upon whether the performance parameters are probable of being met. If the performance parameters are not met, no expense will be recognized.

The total tax benefit recognized during the years ended December 31, 2021, 2020, and 2019 related to compensation expense was $12 million, $1 million and $4 million respectively. As of December 31, 2021 and 2020, the Company had a liability of $23 million and $5 million, respectively, for cash settled non-vested Share-Based Awards and associated dividend and distribution equivalent rights. For the years ended December 31, 2021, 2020, and 2019, the Company paid cash of $30 million, $8 million, and $23 million, respectively, to settle liability-classified awards upon vesting.

Other Benefit Plans

The Company 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 the Company’s employees may participate. Participants in the Plans may elect to contribute a designated percentage of their eligible compensation in accordance with the Plans, subject to statutory limits. The Company provides a matching contribution of 100% of the first 6% of eligible compensation contributed by participants. Participants in both Plans are immediately vested in their individual contributions. The Plans provide for a three-year vesting schedule for the Company’s matching contributions and contain a provision to count service with predecessor organizations. The Company did not have contributions under the Plans for the year ended December 31, 2021, as the Company matching contributions for the Plans were suspended effective January 1, 2021, and had approximately $10 million and $9 million for the years ended December 31, 2020 and 2019, respectively. The Company matching contributions for the Plans resumed effective January 1, 2022.

Income Taxes

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Income Taxes

(10) Income Taxes

Tax Allocation Agreement

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”). 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 provided that AEP would pay all consolidated federal income taxes on behalf of the consolidated tax group. As a result, CVR Energy was required to make payments to AEP in an amount equal to the tax liability, if any, that it would have had 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, since that time, CVR Energy is no longer eligible to file as a member of the AEP consolidated federal income tax group. On August 2, 2018, CVR Energy became the parent of a new consolidated group for U.S. federal income tax purposes, filing and paying 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 or unitary tax returns with AEP. AEP’s federal income tax return for the periods ended December 31, 2017 and 2018 are currently under examination by the IRS.

As of December 31, 2021 and 2020, the Company recognized a nominal payable for state income taxes due to AEP. The payable is recognized in Other current liabilities in the Consolidated Balance Sheets. As of December 31, 2021 and 2020, the Company’s Consolidated Balance Sheets reflected a receivable of $26 million and $44 million, respectively, from the IRS and certain state jurisdictions.

Income Tax (Benefit) Expense

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


	Year Ended December 31,
(in millions)	2021		2020		2019
Current:
Federal	$	84	$	(63)	$	96
State	7		(5)		5
Total current	91		(68)		101
Deferred:
Federal	(76)		(1)		3
State	(23)		(26)		25
Total deferred	(99)		(27)		28
Total income tax (benefit) expense	$	(8)	$	(95)	$	129

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


	Year Ended December 31,
(in millions)	2021		2020		2019
Tax computed at federal statutory rate	$	14	$	(87)	$	103
State income taxes, net of federal tax benefit	3		(18)		29
Changes in enacted state tax rates, net of federal tax benefit	(10)		—		—
State tax incentives, net of federal tax expense	(6)		(7)		(4)


Noncontrolling interest	(10)		13		4
Goodwill impairment	—		3		—
Other, net	1		1		(3)

Total income tax (benefit) expense	$	(8)	$	(95)	$	129

Deferred Tax Assets and Liabilities

The income tax effect of temporary differences that give rise to the Deferred income tax assets and Deferred income tax liabilities at December 31, 2021 and 2020 are as follows:


	December 31,
(in millions)	2021		2020
Deferred income tax assets:
Personnel accruals	$	6	$	2
State tax credit carryforward, net	17		20
Net operating loss carryforward	2		9


Total gross deferred income tax assets	25		31
Deferred income tax liabilities:

Unrealized gain	—		(9)
Investment in CVR Partners	(70)		(67)
Investment in CVR Refining	(222)		(320)

Other	(1)		(3)
Total gross deferred income tax liabilities	(293)		(399)
Net deferred income tax liabilities	$	(268)	$	(368)

Although realization is not assured, management believes that it is more likely than not that all of the deferred income tax assets will be realized, and therefore, no valuation allowance was recognized as of December 31, 2021 and 2020.

As of December 31, 2021, CVR Energy has state tax credits of approximately $26 million, which are available to reduce future state income taxes. These credits, if not used, will begin expiring in 2036.

Uncertain Tax Positions

A reconciliation of unrecognized tax benefits is as follows:


	Year Ended December 31,
(in millions)	2021		2020		2019
Balance, beginning of year	$	17	$	22	$	23
Decrease based on prior year tax position	—		(2)		—
Increase in current year tax positions	—		—		2
Reductions related to expirations from statute of limitations	—		(3)		(3)
Balance, end of year	$	17	$	17	$	22

Included in the balance of unrecognized tax benefits as of December 31, 2021, 2020, and 2019 are $13 million, $13 million, and $15 million, respectively, of tax benefits that, if recognized, would affect the effective tax rate. Additionally, the Company reasonably believes that $5 million unrecognized tax positions related to state income tax credits will be recognized by the end of 2022 as a result of the expiration of statute of limitations. Approximately $7 million and $8 million of unrecognized tax benefits were netted with Deferred income tax asset carryforwards as of December 31, 2021 and 2020, respectively. The remaining unrecognized tax benefits are included in Other long-term liabilities in the Consolidated Balance Sheets.

CVR Energy recognized $1 million interest expense and $2 million liability for interest as of December 31, 2021, nominal interest expense and $1 million liability for interest as of December 31, 2020, and a nominal interest benefit and a nominal liability for interest as of December 31, 2019. No penalties were recognized during 2021, 2020, or 2019.

At December 31, 2021, the Company’s tax filings are generally open to examination in the United States for the tax years ended December 31, 2018 through December 31, 2020 and in various individual states for the tax years ended December 31, 2017 through December 31, 2020.

- Definition

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

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Commitments and Contingencies

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

(11) Commitments and Contingencies

Supply Commitments

The minimum required payments for unconditional purchase obligations are as follows:


(in millions)	Unconditional Purchase Obligations
Year Ended December 31,
2022	$	136
2023	85
2024	82
2025	82
2026	77
Thereafter	252
	$	714

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, pet coke, and natural gas to run

its facilities’ operations. For the years ended December 31, 2021, 2020, and 2019, amounts purchased under these supply agreements totaled approximately $176 million, $153 million, and $167 million, respectively.

Crude Oil Supply Agreement

Effective on August 4, 2021, an indirect, wholly-owned subsidiary of CVR Refining entered into the Second Amended and Restated Crude Oil Supply Agreement (the “2021 Supply Agreement”) with Vitol Inc. (“Vitol”) which superseded, in its entirety, the August 31, 2012 Amended and Restated Crude Oil Supply Agreement (the “2012 Supply Agreement” and collectively with the 2021 Supply Agreement, the “Crude Oil Supply Agreement”) between the parties. The 2021 Supply Agreement is on substantially similar terms as the 2012 Supply Agreement, other than revisions to certain inventory turnover and insurance provisions. 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 certain locations 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%, 33%, and 36% for the years ended December 31, 2021, 2020, and 2019, respectively. The Crude Oil Supply Agreement, which currently extends through December 31, 2022, 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

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

Call Option Lawsuits - In 2019, the Company, CVR Refining and its general partner, CVR Refining Holdings, IEP, and certain directors and affiliates (collectively, the “Call Defendants”) were named in at least one of nine now consolidated lawsuits filed in the Delaware Court of Chancery by purported former unitholders of CVR Refining, on behalf of themselves and an alleged class of similarly situated unitholders relating to the Company’s exercise of the call option (“Call Option”) under the CVR Refining Amended and Restated Agreement of Limited Partnership assigned to it by CVR Refining’s general partner (collectively, 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. In January 2020, the court dismissed CVR Holdings and certain former directors of CVR Refining’s general partner from the Call Option Lawsuits, though permitted some or all of the claims to proceed against each remaining defendant. Trial of the Call Option Lawsuits concluded in July 2021, and the parties are currently in post-trial proceedings. The Company believes the Call Option Lawsuits are without merit and is vigorously defending against them. The plaintiffs filed their Opening Post-Trial Brief on December 22, 2021, now quantifying alleged damages in excess of $300 million; the Call Defendants strongly dispute the plaintiffs’ claims and are preparing responsive briefings. Accordingly, the Company cannot determine at this time the outcome of the Call Option Lawsuits, including whether such outcome would have a material impact on the Company’s financial position, results of operations, or cash flows. However, while we firmly believe this matter is without merit, if it is concluded in a manner adverse to the Company, it could have a material effect on the Company’s financial position, results of operations, or cash flows.

The Call Defendants are also parties to two lawsuits relating to insurance coverage for the Call Option Lawsuits, one filed on January 27, 2021, in the 434th Judicial District Court of Fort Bend County, Texas by the Call Defendants’ primary and excess insurers (the “Insurers”) seeking a declaratory judgment determining that they owe no indemnity coverage for the Call Option Lawsuits in relation to insurance policies that have coverage limits of $50 million, and another filed on January 30, 2022 in the Superior Court of the State of Delaware by the Call Defendants against the Insurers for anticipatory breach of contract and breach of the implied covenant of good faith and fair dealing (the “Delaware Coverage Case”). On November 23, 2021, the court in the Delaware Coverage Case granted partial summary judgment in favor of the Call Defendants relating to the amount of the deductible. As both lawsuits are in their early stages, the Company cannot determine at this time the outcome of these lawsuits, including whether the outcome would 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 RFS, implemented by the Environmental Protection Agency (the “EPA”), which requires refiners to either blend renewable fuels into their transportation fuels or purchase renewable fuel credits, known as RINs, in lieu of blending. The Petroleum Segment is not able to blend the substantial majority of its transportation fuels and must either purchase RINs on the open market or obtain waiver credits for cellulosic biofuels, or other exemptions from the EPA, in order to comply with the RFS.

For the years ended December 31, 2021, 2020, and 2019, the Company recognized an expense of approximately $435 million, $190 million, and $43 million, respectively, for the Petroleum Segment’s compliance with the RFS (based on the 2020 renewable volume obligation (“RVO”) and proposed preliminary 2021 RVO range, for the respective periods, excluding the impacts of any exemptions or waivers to which the Petroleum Segment may be entitled). The recognized amounts are included within Cost of materials and other in the Consolidated Statements of Operations and represent costs to comply with the RFS obligation through purchasing of RINs not otherwise reduced by blending of ethanol or biodiesel. At each reporting period, to the extent RINs purchased and generated through blending are less than the RFS obligation (excluding the impact of exemptions or waivers to which the Petroleum Segment may be entitled), the remaining position is marked-to-market using RIN market prices at period end. As of December 31, 2021 and 2020, the Petroleum Segment’s RFS position was approximately $494 million and $214 million, respectively, which is recorded in Other current liabilities in the Consolidated Balance Sheets.

RFS Disputes - On June 25, 2021, the Supreme Court of the United States (the “Supreme Court”) overturned a decision of the 10th Circuit Court of Appeals (“10th Circuit”) vacating three small refinery exemptions (“SREs”) under the RFS, including one issued to the Wynnewood Refinery for 2017, to the extent such SREs were vacated based on failure to have continuously received an SRE in all applicable preceding years. Following the Supreme Court ruling, the Environmental Protection Agency (the “EPA”) notified WRC that it would reconsider WRC’s 2017 SRE on other grounds referenced in the 10th Circuit decision. On July 20, 2021, after remand from the Supreme Court, the 10th Circuit vacated its prior judgment, recalled its previous mandate denying WRC’s 2017 SRE, entered a new judgment and issued a new mandate transferring jurisdiction back to the EPA. On August 26, 2021, the EPA filed a Motion for Clarification asking the 10th Circuit whether the alternative holdings that supported the 10th Circuit’s prior judgment remain in effect and whether the new mandate returns the agency actions back to the EPA, which Motion for Clarification was denied. On September 15, 2021, WRC advised the EPA it considered its 2017 SRE intact and demanded that the EPA return the status of WRC’s 2017 SRE to “granted.” The EPA has not yet responded to WRC’s demand. Given the EPA’s failure to respond, we cannot currently estimate the outcome, impact or timing of resolution of this matter.

WRC and CRRM are also involved in or expected to be involved in several lawsuits relating to the RFS, including a lawsuit filed in 2019 in the D.C. Circuit by four ethanol and biofuels trade associations against the EPA claiming the EPA exceeded its authority in granting SREs for the 2018 compliance year, including the 2018 SRE granted to WRC’s Wynnewood Refinery (the “2018 SRE Lawsuit”), which 2018 SRE petitions were remanded by the court back to the EPA on December 8, 2021, with instructions to act on such petitions by April 7, 2022; a lawsuit by WRC against the EPA relating to damages sustained by WRC as a result of the EPA’s failure to timely issue WRC’s 2018 SRE (the “WRC 2018 SRE Lawsuit”); and a Petition for Review of the EPA’s February 2, 2022, final rule changing compliance deadlines under the RFS filed by WRC and CRRM with the D.C. Circuit on February 4, 2022 (the “Deadline Lawsuit”). The Company anticipates additional litigation to be filed in the future relating to the RFS, including one or more lawsuits by WRC against the EPA should it finalize the position set forth in its Proposed RFS Small Refinery Exemption Decision dated December 7, 2021 (the “Proposed Denial”), in which the EPA announced its intention to change its statutory interpretation of the CAA and deny 65 pending SRE petitions, including those submitted by WRC for 2019, 2020, and 2021, through which the Proposed Denial by the EPA has informed WRC it intends to also apply to deny all 2018 SREs previously approved by the EPA, including for WRC’s Wynnewood Refinery. These matters are in their early stages, and the Company cannot determine at this time the outcomes of these matters, including whether such outcomes would have a material impact on the Company’s financial position, results of operations, or cash flows.

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 KDHE alleging violations of the CAA and a 2012 Consent Decree (the “CD”) between Coffeyville Resources Refining & Marketing, LLC (“CRRM”), the United States (on behalf of the EPA) and the Kansas Department of Health and Environment (“KDHE”) at CRRM’s Coffeyville refinery, primarily relating to flares. In June 2020, a tolling agreement between the parties relating to such allegations expired, and the DOJ and KDHE sent demand letters relating to the

allegations (the “Stipulated Claims”) and seeking stipulated penalties under the CD. In February 2021, the DOJ and KDHE sent CRRM a statement of position under the CD regarding its demand for Stipulated Claims. As CRRM disputes most claims asserted by the government, in accordance with the CD, CRRM deposited funds into a commercial escrow account pending resolution of disputed claims. The escrowed funds are legally restricted for use and are included within Prepaid expenses and other current assets on the consolidated balance sheets. In April 2021, CRRM filed a petition for judicial review of the Stipulated Claims with the United States District Court for the District of Kansas (“D. Kan.”), in accordance with the dispute resolution provisions of the CD. On September 23, 2021, the court ordered briefing on CRRM’s petition, which was completed in December 2021. Separately, in December 2020, the DOJ and KDHE filed a supplement complaint in the D. Kan asserting nine counts for alleged violations of the CAA, the Kansas State Implementation Plan and Kansas law seeking civil penalties, injunctive and related relief, which they sought leave to amend on February 10, 2022, to add an additional eight counts under Part 63 of the National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries Subparts CC and R (“NESHAP”), Kansas law, and CRRM’s permits relating to flares, heaters, and related matters (collectively, the “Statutory Claims”). In March 2021, CRRM filed a partial motion to dismiss certain Statutory Claims, which is still pending with the D. Kan. Negotiations relating to the Stipulated Claims and the Statutory Claims are ongoing and the Company cannot determine at this time the outcome of these matters, including whether such outcome, or any subsequent enforcement or litigation relating thereto would have a material impact on the Company’s financial position, results of operations, or cash flows.

Environmental Remediation - As of December 31, 2021 and 2020, environmental accruals representing estimated costs for future remediation efforts at certain Petroleum Segment sites totaled approximately $12 million and $11 million, respectively. These amounts are reflected in Other current liabilities or Other long-term liabilities depending on when the Company expects to expend such amounts.

Business Segments

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Business Segments

(12) Business Segments

The Company has 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, while the Nitrogen Fertilizer Segment is comprised entirely of the consolidated operations of CVR Partners and its subsidiaries. The other amounts reflect intercompany eliminations, corporate cash and cash equivalents, income tax activities, and other corporate activities that are not allocated to the operating segments. 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)	2021		2020		2019
Net sales:
Petroleum	$	6,721	$	3,586	$	5,968
Nitrogen Fertilizer	533		350		404
Other	(12)		(6)		(8)
Total net sales	$	7,242	$	3,930	$	6,364










Operating income (loss):
Petroleum	$	(27)	$	(281)	$	574
Nitrogen Fertilizer	134		(35)		27
Other	(20)		(17)		(21)
Total operating income (loss)	87		(333)		580
Interest expense, net	(117)		(130)		(102)

Investment income from marketable securities	81		41		—
Other income, net	15		7		13
Income (loss) before income tax expense	$	66	$	(415)	$	491
Depreciation and amortization:
Petroleum	$	203	$	202	$	202
Nitrogen Fertilizer	73		76		80
Other (2)	3		—		5
Total depreciation and amortization	$	279	$	278	$	287
Capital expenditures: (1)
Petroleum	$	50	$	90	$	89
Nitrogen fertilizer	26		16		20
Other (2)	150		15		5
Total capital expenditures	$	226	$	121	$	114

The following table summarizes total assets by segment:


	December 31,
(in millions)	2021		2020
Petroleum	$	3,368	$	2,991
Nitrogen Fertilizer	1,127		1,033
Other, including intersegment eliminations	(589)		(46)
Total assets	$	3,906	$	3,978

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures and business combinations.

(2)Other includes expenses related to and amounts incurred for the Wynnewood renewable diesel unit project.

- Definition

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

+ References

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+ Details

Supplemental Cash Flow Information

12 Months Ended

Dec. 31, 2021

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

(13) Supplemental Cash Flow Information

Cash flows related to income taxes, interest, leases, capital expenditures and deferred financing costs included in accounts payable, and non-cash dividends were as follows:


	Year Ended December 31,
(in millions)	2021		2020		2019
Supplemental disclosures:
Cash paid, net of refunds (received, net of payments) for income taxes	$	72	$	(2)	$	69
Cash paid for interest	114		107		104
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	15		17		16
Operating cash flows from finance leases	5		6		6
Financing cash flows from finance leases	6		5		5
Non-cash investing and financing activities:
Change in construction in progress included in accounts payable (1)	2		(3)		(7)
Change in deferred financing costs included in accounts payable	1		—		—
Non-cash dividends to CVR Energy stockholders	251		—		—

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures.

Cash, cash equivalents and restricted cash consisted of the following:


	December 31,
(in millions)	2021		2020
Cash and cash equivalents	$	510	$	667
Restricted cash (2)	7		7
Cash, cash equivalents and restricted cash	$	517	$	674

(2)The restricted cash balance is included within Prepaid expenses and other current assets on the Consolidated Balance Sheets.

Related Party Transactions

12 Months Ended

Dec. 31, 2021

Related Party Transactions

(14) Related Party Transactions

Activity associated with the Company’s related party arrangements for the years ended December 31, 2021, 2020, and 2019 is summarized below:


Expenses with related parties
	Year Ended December 31,
(in millions)	2021		2020		2019
Cost of materials and other:



Enable Joint Venture Transportation Agreement	$	11	$	11	$	12

Payments (received) made:

Dividends (1)	348		85		218

AEP Tax Allocation Agreement	—		—		(3)

(1)See below for a summary of the dividends paid to IEP for the years ended December 31, 2021, 2020, and 2019.

Enable 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, CVR Refining

entered into a terminalling services agreement with Enable JV under which it receives access to Enable JV’s terminal in Lawrence, Oklahoma to unload and pump crude oil into Enable JV’s pipeline for an initial term of 20 years.

Midway Joint Venture

For the years ended December 31, 2021, 2020, and 2019, CRRM incurred costs, which are included in Cost of materials and other, of $20 million, $17 million, and $21 million, respectively, from crude oil transportation services incurred on the Midway JV through Vitol as the intermediary purchasing agent.

Dividends to CVR Energy Stockholders

Dividends, if any, including the payment, amount and timing thereof, are determined in the discretion of CVR Energy’s board of directors (the “Board”). IEP, through its ownership of the Company’s common stock, is entitled to receive dividends that are declared and paid by the Company based on the number of shares held at each record date. No dividends were declared related to the fourth quarter of 2021, and there were no quarterly dividends declared or paid during 2021 related to the first, second, and third quarters of 2021 and fourth quarter of 2020. During the years ended December 31, 2020 and 2019, the Company paid dividends totaling $1.20 and $3.05 per common share, or $121 million and $306 million, respectively. Of these dividends, IEP received $85 million and $218 million, respectively, for the same periods.

On May 26, 2021, the Company announced a special dividend of approximately $492 million, or equivalent to $4.89 per share of the Company’s common stock, to be paid in a combination of cash (the “Cash Distribution”) and the Stock Distribution. On June 10, 2021, the Company distributed an aggregate amount of approximately $241 million, or $2.40 per share of the Company’s common stock, pursuant to the Cash Distribution, and approximately 10,539,880 shares of Delek common stock, which represented approximately 14.3% of the outstanding shares of Delek common stock, pursuant to the Stock Distribution. IEP received approximately 7,464,652 shares of common stock of Delek and $171 million in cash. The Stock Distribution was recorded as a reduction to equity through a derecognition of our investment in Delek, and the Company recognized a gain of $112 million from the initial investment in Delek through the date of the Stock Distribution.

Distributions to CVR Partners’ Unitholders

Distributions, if any, including the payment, amount and timing thereof, are subject to change at the discretion of the UAN GP Board. The following table presents distributions paid by CVR Partners to CVR Partners’ unitholders, including amounts received by the Company, as of December 31, 2021.



				Distributions Paid (in millions)
Related Period	Date Paid	Distribution Per Common Unit		Public Unitholders		CVR Energy		Total
2021 - 2nd Quarter	August 23, 2021	$	1.72	$	11	$	7	$	18
2021 - 3rd Quarter	November 22, 2021	2.93		20		11		31
Total dividends		$	4.65	$	31	$	18	$	49

There were no distributions declared or paid by CVR Partners related to the first quarter of 2021 and fourth quarter of 2020, and no distributions were declared or paid during 2020. During the year ended December 31, 2019, CVR Partners paid distributions totaling $4.00 per common unit on a split-adjusted basis, or $45 million. Of these distributions, CVR Energy received $16 million.

For the fourth quarter of 2021, CVR Partners, upon approval by the UAN GP Board on February 21, 2022, declared a distribution of $5.24 per common unit, or $56 million, which is payable March 14, 2022 to unitholders of record as of March 7, 2022. Of this amount, CVR Energy will receive approximately $20 million, with the remaining amount payable to public unitholders.

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Principles of Consolidation

Reclassifications

ReclassificationsCertain reclassifications have been made within the consolidated financial statements for prior periods to conform with current presentation.

Use of Estimates

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, investments in highly liquid money market accounts, and debt instruments with original maturities of three months or less.

Restricted Cash

Accounts Receivable, net

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

InventoriesInventories 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 GAAP First-In, First-Out (“FIFO”) cost, or net realizable value. The Petroleum Segment’s unfinished and finished products inventory values were determined using the ability-to-bear methodology. Other inventories in the Petroleum and Nitrogen Fertilizer Segments, 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, net


Asset						Range of Useful Lives, in Years
Land and improvements						10 to 30
Buildings and improvements						1 to 30
Machinery and equipment						1 to 30
Furniture and fixtures						3 to 10
Right-of-use (“ROU”) finance leases						3 to 18
Other						5 to 30

Property, plant and equipment, net consisted of the following:


	December 31,
(in millions)	2021		2020
Machinery and equipment	$	4,033	$	3,881
Buildings and improvements	88		88
ROU finance leases	81		80
Land and improvements	71		47
Furniture and fixtures	37		38
Construction in progress	142		100
Other	15		15
	4,467		4,249
Less: Accumulated depreciation	(2,194)		(2,009)
Total property, plant and equipment, net	$	2,273	$	2,240

Leases

initial expected term of 12 months or less are considered short-term and are not recorded on our Consolidated Balance Sheets. The Company recognizes lease expense for these leases on a straight-line basis over the expected lease term.ROU assets represent the Company’s right to use an underlying asset for the lease term, and lease liabilities represent the obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the commencement date based on the present value of minimum lease payments over the lease term using an incremental borrowing rate with a maturity similar to the lease term, as our leases do not generally provide an implicit rate. The lease term is modified to reflect options to extend or terminate the lease when it is reasonably certain we will exercise such option. The depreciable life of assets and leasehold improvements is limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise, in which case the depreciation policy in the “Property, Plant and Equipment, net” section above is applicable. The periodic lease payments are treated as payments of the lease obligation and interest is recorded as interest expense.

Deferred Financing Costs

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets and Goodwill

Goodwill

Loss Contingencies

Loss ContingenciesIn 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. Accrued amounts are reflected in Other current liabilities or Other long-term liabilities depending on when the Company expects to expend such amounts.

Environmental, Health & Safety (EHS) Matters

Environmental, Health & Safety (“EHS”) MattersThe Petroleum Segment and Nitrogen Fertilizer Segment are subject to various federal, state, and local environmental, health, and safety rules and regulations. Liabilities related to future remediation costs of past environmental contamination of properties are recognized when the related costs are considered probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, internal and third-party assessments of contamination, available remediation technology, site-specific costs, and currently enacted laws and regulations. In reporting environmental liabilities, no offset is made for potential recoveries. Loss contingency accruals, including those for environmental remediation, are subject to revision as further information develops or circumstances change, and such accruals can take into account the legal liability of other parties. Management periodically reviews and, as appropriate, revises its environmental accruals. Environmental expenditures for capital assets are capitalized at the time of the expenditure when such costs provide future economic benefits. Accrued amounts are reflected in Other current liabilities or Other long-term liabilities depending on when the Company expects to expend such amounts.

Revenue Recognition and Cost Classifications

Revenue Recognition

Other considerations - For both segments, excise and other taxes collected from customers and remitted to governmental authorities are excluded from reported revenues.

Cost ClassificationsCost of materials and other includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, purchased ammonia, purchased hydrogen, pet coke expenses, Renewable Identification Number (“RIN”) expenses, derivative gains 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 (exclusive of depreciation and amortization) 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

Turnaround Expenses

Share-Based Compensation

Income Taxes

Earnings Per Share

There were no dilutive awards outstanding during the years ended December 31, 2021, 2020, and 2019.

Recent Accounting Pronouncements

Recent Accounting Pronouncements - Adoption of Income Tax Standard

Recent Accounting Pronouncements - Adoption of Codification Improvements Standard

Recent Accounting Pronouncements - New Accounting Standards Issued But Not Yet Implemented

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Schedule of inventories

Inventories consisted of the following:


	December 31,
(in millions)	2021		2020
Finished goods	$	215	$	133
Raw materials	177		83
In-process inventories	20		16
Parts and supplies	72		66
Total inventories	$	484	$	298

Schedule of lives used in computing depreciation for depreciable assets and components of property, plant and equipment, net

The lives used in computing depreciation for significant asset classes are as follows:


Asset						Range of Useful Lives, in Years
Land and improvements						10 to 30
Buildings and improvements						1 to 30
Machinery and equipment						1 to 30
Furniture and fixtures						3 to 10
Right-of-use (“ROU”) finance leases						3 to 18
Other						5 to 30

Property, plant and equipment, net consisted of the following:


	December 31,
(in millions)	2021		2020
Machinery and equipment	$	4,033	$	3,881
Buildings and improvements	88		88
ROU finance leases	81		80
Land and improvements	71		47
Furniture and fixtures	37		38
Construction in progress	142		100
Other	15		15
	4,467		4,249
Less: Accumulated depreciation	(2,194)		(2,009)
Total property, plant and equipment, net	$	2,273	$	2,240

Equity Method Investments (Tables)

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Schedule of equity method investments


(in millions)	Enable JV		Midway JV		Total
Balance at December 31, 2019	6		75		81

Cash Distributions	(4)		(6)		(10)
Equity income	4		5		9
Balance at December 31, 2020	6		74		80
Cash Distributions	(3)		(8)		(11)
Equity income	3		7		10
Balance at December 31, 2021	$	6	$	73	$	79

Leases (Tables)

12 Months Ended

Dec. 31, 2021

Leases [Abstract]

Summary of right of use asset and lease liability balances for operating and finance leases

The following table summarizes the right of use asset and lease liability balances for the Company’s operating and finance leases at December 31, 2021 and 2020:


	December 31, 2021				December 31, 2020
(in millions)	Operating Leases		Finance Leases		Operating Leases		Finance Leases
ROU assets, net
Pipeline and storage	$	17	$	23	$	15	$	26
Railcars	6		—		8		—
Real estate and other	14		18		14		21
Lease liability
Pipelines and storage	$	17	$	35	$	16	$	38
Railcars	6		—		8		—
Real estate and other	14		19		14		22

Lease expense, terms, and discount rates

For the year ended December 31, 2021, 2020, and 2019, we recognized lease expense comprised of the following components:


	Year Ended December 31,
(in millions)	2021		2020		2019
Operating lease expense	$	15	$	17	$	12
Finance lease expense:
Amortization of ROU asset	$	6	$	6	$	7
Interest expense on lease liability	5		6		6
Short-term lease expense	$	7	$	8	$	8

The following outlines the remaining lease terms and discount rates used in the measurement of the Company’s ROU assets and liabilities:


	December 31, 2021				December 31, 2020
	Operating Leases		Finance Leases		Operating Leases		Finance Leases
Weighted-average remaining lease term	4.1 years		7.2 years		3.1 years		8.1 years
Weighted-average discount rate	5.4	%	9.0	%	5.5	%	9.0	%

Summary of remaining minimum lease payments for operating leases

The following summarizes the remaining minimum lease payments through maturity of the Company’s right-of-use assets and liabilities at December 31, 2021:


(in millions)	Operating Leases		Finance Leases
Year Ended December 31,
2022	$	14	$	11
2023	12		10
2024	8		10
2025	3		10
2026	1		10
Thereafter	4		23
Total lease payments	42		74
Less: imputed interest	(5)		(20)
Total lease liability	$	37	$	54

Summary of remaining minimum lease payments for finance leases

The following summarizes the remaining minimum lease payments through maturity of the Company’s right-of-use assets and liabilities at December 31, 2021:


(in millions)	Operating Leases		Finance Leases
Year Ended December 31,
2022	$	14	$	11
2023	12		10
2024	8		10
2025	3		10
2026	1		10
Thereafter	4		23
Total lease payments	42		74
Less: imputed interest	(5)		(20)
Total lease liability	$	37	$	54

Other Current Liabilities (Tables)

12 Months Ended

Dec. 31, 2021

Other Liabilities Disclosure [Abstract]

Other current liabilities

Other current liabilities were as follows:


	December 31,
(in millions)	2021		2020
Accrued Renewable Fuel Standards (“RFS”) obligation	$	494	$	214
Deferred revenue	87		31
Personnel accruals	46		23
Accrued taxes other than income taxes	45		32
Accrued interest	24		25
Share-based compensation	15		4
Operating lease liabilities	13		14

Accrued derivatives	2		17

Other accrued expenses and liabilities	15		9
Total other current liabilities	$	741	$	369

Long-Term Debt and Finance Lease Obligations (Tables)

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Schedule of long-term debt and finance lease obligations


	December 31,
(in millions)	2021		2020
CVR Partners:
9.25% Senior Secured Notes, due June 2023 (1)	$	65	$	645
6.125% Senior Notes, due June 2028	550		—
Unamortized discount and debt issuance costs	(4)		(11)
Total CVR Partners debt	$	611	$	634
CVR Refining:

Finance lease obligations, net of current portion (2)	48		55

Total CVR Refining debt	48		55
CVR Energy:
5.250% Senior Notes, due February 2025	$	600	$	600
5.750% Senior Notes, due February 2028	400		400
Unamortized debt issuance cost	(5)		(6)
Total CVR Energy debt	995		994
Total long-term debt and finance lease obligations	$	1,654	$	1,683
Current portion of long-term debt and finance lease obligations (2) (3)	6		8
Total long-term debt and finance lease obligations, including current portion	$	1,660	$	1,691

(2)Current portion of finance lease obligations was approximately $6 million and $6 million as of December 31, 2021 and 2020, respectively.

(3)The $2 million outstanding balance of the 6.50% Notes, due April 2021, was paid in full on April 15, 2021.

Credit Agreements


(in millions)	Total Capacity		Amount Borrowed as of December 31, 2021		Outstanding Letters of Credit		Available Capacity as of December 31, 2021		Maturity Date
CVR Partners:
Asset Based (“Nitrogen Fertilizer ABL”) Credit Agreement (1) (2)	$	35	$	—	$	—	$	35	September 30, 2024
CVR Refining:
Amended and Restated Asset Based (“Petroleum ABL”) Credit Agreement (3)	$	400	$	—	$	39	$	361	November 14, 2022

Debt instrument redemption

On or after June 15, 2024, the Issuers may, on any one or more occasions, redeem all or part of the 2028 UAN Notes at the redemption prices set forth below, expressed as a percentage of the principal amount of the respective notes, plus accrued and unpaid interest to the applicable redemption date.


12-month period beginning June 15,						Percentage
2024						103.063%
2025						101.531%
2026 and thereafter						100.000%


2025 Notes		2028 Notes
12-month period beginning February 15,	Percentage	12-month period beginning February 15,	Percentage
2022	102.625%	2023	102.875%
2023	101.313%	2024	101.917%
2024 and thereafter	100.000%	2025	100.958%
		2026 and thereafter	100.000%

- Definition

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

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+ Details

Revenue (Tables)

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue disaggregated by major product


	Year Ended December 31, 2021
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	3,679	$	—	$	—	$	3,679
Distillates (1)	2,809		—		—		2,809
Ammonia	—		146		—		146
UAN	—		316		—		316
Other urea products	—		29		—		29

Freight revenue	21		31		—		52
Other (2)	163		11		(12)		162
Revenue from product sales	6,672		533		(12)		7,193

Crude oil sales	47		—		—		47
Other revenue (2)	2		—		—		2
Total revenue	$	6,721	$	533	$	(12)	$	7,242


	Year Ended December 31, 2020
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	1,882	$	—	$	—	$	1,882
Distillates (1)	1,543		—		—		1,543
Ammonia	—		94		—		94
UAN	—		198		—		198
Other urea products	—		15		—		15
Freight revenue	18		33		—		51
Other (2)	79		10		(6)		83
Revenue from product sales	3,522		350		(6)		3,866

Crude oil sales	63		—		—		63
Other revenue (2)	1		—		—		1
Total revenue	$	3,586	$	350	$	(6)	$	3,930


	Year Ended December 31, 2019
(in millions)	Petroleum		Nitrogen Fertilizer		Other / Eliminations		Consolidated
Gasoline	$	3,050	$	—	$	—	$	3,050
Distillates (1)	2,705		—		—		2,705
Ammonia	—		94		—		94
UAN	—		251		—		251
Other urea products	—		18		—		18
Freight revenue	23		33		—		56
Other (2)	129		8		(8)		129
Revenue from product sales	5,907		404		(8)		6,303

Crude oil sales	58		—		—		58
Other revenue (2)	3		—		—		3
Total revenue	$	5,968	$	404	$	(8)	$	6,364

(1)Distillates consist primarily of diesel fuel, kerosene, and jet fuel.

Summary of deferred revenue activity

A summary of the Nitrogen Fertilizer Segment’s deferred revenue activity during the year ended December 31, 2021 is presented below:


(in millions)
Balance at December 31, 2020	$	31
Add:
New prepay contracts entered into during the period (1)	147
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	(30)
Revenue recognized related to contracts entered into during the period	(60)
Other changes	(1)
Balance at December 31, 2021	$	87

(1)Includes $94 million where the payment associated with prepaid contracts was collected.

Derivative Financial Instruments, Investments and Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of gains (losses) 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:


	Year Ended December 31,
(in millions)	2021		2020		2019
Forward purchases and sales contracts, net	$	25	$	53	$	20
Commodity swap instruments	(68)		(8)		—
Futures contracts	(1)		10		(1)
Total (loss) gain on derivatives, net	$	(44)	$	55	$	19

Schedule of derivative offsetting assets

These amounts are recognized as current assets and current liabilities within the Prepaid expenses and other

current assets 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)	2021		2020		2021		2020
Commodity derivatives	$	5	$	1	$	(7)	$	(5)

Less: Counterparty netting	(5)		(1)		5		1
Total net fair value of derivatives	$	—	$	—	$	(2)	$	(4)

Schedule of derivative offsetting liabilities

These amounts are recognized as current assets and current liabilities within the Prepaid expenses and other

current assets 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)	2021		2020		2021		2020
Commodity derivatives	$	5	$	1	$	(7)	$	(5)

Less: Counterparty netting	(5)		(1)		5		1
Total net fair value of derivatives	$	—	$	—	$	(2)	$	(4)

Components of investment income from marketable securities

Investment income on marketable securities consists of the following:


	Year Ended December 31,
(in millions)	2021		2020		2019
Dividend income	$	—	$	7	$	—
Gain on marketable securities	81		34		—
Investment income on marketable securities	$	81	$	41	$	—

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

The following tables set forth the assets and liabilities measured or disclosed at fair value on a recurring basis, by input level, as of December 31, 2021 and 2020:


	December 31, 2021
(in millions)	Level 1		Level 2		Level 3		Total
Location and Description


Other current assets (commodity derivatives)	$	—	$	1	$	—	$	1
Total Assets	$	—	$	1	$	—	$	1

Other current liabilities (commodity derivatives)	$	—	$	(2)	$	—	$	(2)

Other current liabilities (RFS obligation)	—		(494)		—		(494)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	—		(1,620)		—		(1,620)
Total Liabilities	$	—	$	(2,116)	$	—	$	(2,116)


	December 31, 2020
(in millions)	Level 1		Level 2		Level 3		Total
Location and Description

Prepaid expenses and other current assets (investments)	$	173	$	—	$	—	$	173



Total Assets	$	173	$	—	$	—	$	173
Note payable and finance lease obligations (current portion of long-term debt)	$	—	$	(2)	$	—	$	(2)
Other current liabilities (commodity derivatives)	—		(17)		—		(17)

Other current liabilities (RFS obligation)	—		(214)		—		(214)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	—		(1,604)		—		(1,604)
Total Liabilities	$	—	$	(1,837)	$	—	$	(1,837)

Share-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

Schedule of share-based compensation activity

A summary of activity for the Company’s Share-Based Awards for the year ended December 31, 2021 is presented below:


	Shares or Units (1)	Weighted-Average Grant-Date Fair Value (per share or unit)		Aggregate Intrinsic Value (in millions)








Non-vested at December 31, 2020	2,454,641	$	19.01	$	37
Granted	950,744	19.46
Vested	(857,901)	21.14
Forfeited	(254,379)	19.66
Non-vested at December 31, 2021	2,293,105	$	18.23	$	62

(1)As of December 31, 2021, there are no outstanding awards under the LTIPs, and the only outstanding and unvested awards are issued in connection with and not under the LTIPs.


	Expenses						Unrecognized Expense
	For the year ended December 31,						At December 31, 2021
(in millions)	2021		2020		2019		Amount		Weighted-Average Remaining Years
Share based awards:
Incentive Units	$	22	$	3	$	12	$	27	2.4
Phantom Units	27		1		5		19		2.0

Performance awards:
CEO Performance Award (1)	(3)		—		—		10		3.0


Total expense	$	46	$	4	$	17	$	56

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Schedule of income tax (benefit) expense

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


	Year Ended December 31,
(in millions)	2021		2020		2019
Current:
Federal	$	84	$	(63)	$	96
State	7		(5)		5
Total current	91		(68)		101
Deferred:
Federal	(76)		(1)		3
State	(23)		(26)		25
Total deferred	(99)		(27)		28
Total income tax (benefit) expense	$	(8)	$	(95)	$	129

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

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


	Year Ended December 31,
(in millions)	2021		2020		2019
Tax computed at federal statutory rate	$	14	$	(87)	$	103
State income taxes, net of federal tax benefit	3		(18)		29
Changes in enacted state tax rates, net of federal tax benefit	(10)		—		—
State tax incentives, net of federal tax expense	(6)		(7)		(4)


Noncontrolling interest	(10)		13		4
Goodwill impairment	—		3		—
Other, net	1		1		(3)

Total income tax (benefit) expense	$	(8)	$	(95)	$	129

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 the Deferred income tax assets and Deferred income tax liabilities at December 31, 2021 and 2020 are as follows:


	December 31,
(in millions)	2021		2020
Deferred income tax assets:
Personnel accruals	$	6	$	2
State tax credit carryforward, net	17		20
Net operating loss carryforward	2		9


Total gross deferred income tax assets	25		31
Deferred income tax liabilities:

Unrealized gain	—		(9)
Investment in CVR Partners	(70)		(67)
Investment in CVR Refining	(222)		(320)

Other	(1)		(3)
Total gross deferred income tax liabilities	(293)		(399)
Net deferred income tax liabilities	$	(268)	$	(368)

Schedule of reconciliation of the unrecognized tax benefits

A reconciliation of unrecognized tax benefits is as follows:


	Year Ended December 31,
(in millions)	2021		2020		2019
Balance, beginning of year	$	17	$	22	$	23
Decrease based on prior year tax position	—		(2)		—
Increase in current year tax positions	—		—		2
Reductions related to expirations from statute of limitations	—		(3)		(3)
Balance, end of year	$	17	$	17	$	22

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Schedule of minimum required payments for unconditional purchase obligations

The minimum required payments for unconditional purchase obligations are as follows:


(in millions)	Unconditional Purchase Obligations
Year Ended December 31,
2022	$	136
2023	85
2024	82
2025	82
2026	77
Thereafter	252
	$	714

Business Segments (Tables)

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Summary of operating results, capital expenditures, and total asset information by segment

The following tables summarize operating results, capital expenditures, and total asset information by segment:


	Year Ended December 31,
(in millions)	2021		2020		2019
Net sales:
Petroleum	$	6,721	$	3,586	$	5,968
Nitrogen Fertilizer	533		350		404
Other	(12)		(6)		(8)
Total net sales	$	7,242	$	3,930	$	6,364










Operating income (loss):
Petroleum	$	(27)	$	(281)	$	574
Nitrogen Fertilizer	134		(35)		27
Other	(20)		(17)		(21)
Total operating income (loss)	87		(333)		580
Interest expense, net	(117)		(130)		(102)

Investment income from marketable securities	81		41		—
Other income, net	15		7		13
Income (loss) before income tax expense	$	66	$	(415)	$	491
Depreciation and amortization:
Petroleum	$	203	$	202	$	202
Nitrogen Fertilizer	73		76		80
Other (2)	3		—		5
Total depreciation and amortization	$	279	$	278	$	287
Capital expenditures: (1)
Petroleum	$	50	$	90	$	89
Nitrogen fertilizer	26		16		20
Other (2)	150		15		5
Total capital expenditures	$	226	$	121	$	114

The following table summarizes total assets by segment:


	December 31,
(in millions)	2021		2020
Petroleum	$	3,368	$	2,991
Nitrogen Fertilizer	1,127		1,033
Other, including intersegment eliminations	(589)		(46)
Total assets	$	3,906	$	3,978

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures and business combinations.

(2)Other includes expenses related to and amounts incurred for the Wynnewood renewable diesel unit project.

Supplemental Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2021

Supplemental Cash Flow Elements [Abstract]

Schedule of cash flows related to income taxes, interest, leases, capital expenditures, and deferred financing costs included in accounts payable, and non-cash dividends

Cash flows related to income taxes, interest, leases, capital expenditures and deferred financing costs included in accounts payable, and non-cash dividends were as follows:


	Year Ended December 31,
(in millions)	2021		2020		2019
Supplemental disclosures:
Cash paid, net of refunds (received, net of payments) for income taxes	$	72	$	(2)	$	69
Cash paid for interest	114		107		104
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	15		17		16
Operating cash flows from finance leases	5		6		6
Financing cash flows from finance leases	6		5		5
Non-cash investing and financing activities:
Change in construction in progress included in accounts payable (1)	2		(3)		(7)
Change in deferred financing costs included in accounts payable	1		—		—
Non-cash dividends to CVR Energy stockholders	251		—		—

(1)Capital expenditures are shown exclusive of capitalized turnaround expenditures.

Schedule of cash and cash equivalents

Cash, cash equivalents and restricted cash consisted of the following:


	December 31,
(in millions)	2021		2020
Cash and cash equivalents	$	510	$	667
Restricted cash (2)	7		7
Cash, cash equivalents and restricted cash	$	517	$	674

(2)The restricted cash balance is included within Prepaid expenses and other current assets on the Consolidated Balance Sheets.

Schedule of restricted cash

Cash, cash equivalents and restricted cash consisted of the following:


	December 31,
(in millions)	2021		2020
Cash and cash equivalents	$	510	$	667
Restricted cash (2)	7		7
Cash, cash equivalents and restricted cash	$	517	$	674

(2)The restricted cash balance is included within Prepaid expenses and other current assets on the Consolidated Balance Sheets.

Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2021

Schedule of related party transactions

Activity associated with the Company’s related party arrangements for the years ended December 31, 2021, 2020, and 2019 is summarized below:


Expenses with related parties
	Year Ended December 31,
(in millions)	2021		2020		2019
Cost of materials and other:



Enable Joint Venture Transportation Agreement	$	11	$	11	$	12

Payments (received) made:

Dividends (1)	348		85		218

AEP Tax Allocation Agreement	—		—		(3)

(1)See below for a summary of the dividends paid to IEP for the years ended December 31, 2021, 2020, and 2019.

Summary of distributions paid

The following table presents distributions paid by CVR Partners to CVR Partners’ unitholders, including amounts received by the Company, as of December 31, 2021.



				Distributions Paid (in millions)
Related Period	Date Paid	Distribution Per Common Unit		Public Unitholders		CVR Energy		Total
2021 - 2nd Quarter	August 23, 2021	$	1.72	$	11	$	7	$	18
2021 - 3rd Quarter	November 22, 2021	2.93		20		11		31
Total dividends		$	4.65	$	31	$	18	$	49

Organization and Nature of Business - Narrative (Details)				12 Months Ended
	Nov. 23, 2020	Oct. 23, 2019 USD ($)	Jan. 29, 2019 USD ($) $ / shares	Dec. 31, 2021 USD ($) $ / shares shares	Dec. 31, 2020 USD ($) $ / shares shares	Dec. 31, 2019 USD ($) shares	Feb. 22, 2021 USD ($)	May 06, 2020 USD ($)
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Stock Repurchase Program, authorized amount		$ 300,000,000					$ 10,000,000	$ 10,000,000
Duration of Stock Repurchase Program		4 years
Common stock repurchased (in shares) \| shares				24,378	623,177	0
Cash purchase price				$ 20,000,000	$ 0	$ 0
Percentage of interest held by public				64.00%
Reverse Unit Split, conversion ratio	0.1
Cost, inclusive of transaction costs, of repurchase of outstanding common units				$ 1,000,000	$ 7,000,000
Average price per common unit (in dollars per share) \| $ / shares				$ 21.70	$ 11.35
Amount remaining under Unit Repurchase Program				$ 12,000,000
Repurchase of CVR Partners' common units on open market and change in ownership while maintaining control						336,000,000
Recognition of deferred tax liability from change in book versus tax basis in CVR Partners				100,000	$ 1,000,000
Additional Paid-In Capital
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Repurchase of CVR Partners' common units on open market and change in ownership while maintaining control				0	(3,000,000)	2,000,000
Noncontrolling Interest
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Repurchase of CVR Partners' common units on open market and change in ownership while maintaining control				$ 100,000	$ 4,000,000	$ 334,000,000
CVR Partners
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by wholly-owned subsidiary				36.00%
CVR GP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Percentage of common units owned by general partner				100.00%
Term Loan Facility \| Credit Agreement
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Total Capacity			$ 105,000,000
CVR Refining
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Cash purchase price			$ 301,000,000
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
CVRR Affiliate Unit Purchase \| AEP and IEP
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Cash purchase price			$ 60,000,000
Majority Shareholder
Organization, Consolidation, and Presentation of Financial Statements [Line Items]
Ownership percentage held by controlling stockholder				71.00%

Summary of Significant Accounting Policies - Principles of Consolidation (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Other comprehensive income recognized	$ 0	$ 0	$ 0

- Definition

Amount after tax and reclassification adjustments of other comprehensive income (loss).

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669619-108580

Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124442407-227067

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=123467817&loc=d3e21463-112644

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32136-110900

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(21))
-URI http://asc.fasb.org/extlink&oid=123367319&loc=SL114868664-224227

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 55
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=124507222&loc=d3e1436-108581

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 20
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32211-110900

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6450520&loc=d3e32583-110901

Reference 9: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124442411-227067

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669625-108580

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(23))
-URI http://asc.fasb.org/extlink&oid=120399700&loc=SL114874048-224260

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04(19))
-URI http://asc.fasb.org/extlink&oid=120400993&loc=SL114874131-224263

+ Details

Summary of Significant Accounting Policies - Accounts Receivable, net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounts Receivable, net
Bad debt expense	$ 0	$ 0	$ 0
Accounts receivable \| Credit concentration \| One customer
Accounts Receivable, net
Largest concentrations of credit for any one customer	8.00%	11.00%

Summary of Significant Accounting Policies - Schedule of Inventories (Details) - USD ($)	3 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Inventories, carrying amounts in excess of market value			$ 0	$ 59,000,000	$ 0
Finished goods		$ 133,000,000	215,000,000	133,000,000
Raw materials		83,000,000	177,000,000	83,000,000
In-process inventories		16,000,000	20,000,000	16,000,000
Parts and supplies		66,000,000	72,000,000	66,000,000
Total inventories		298,000,000	484,000,000	298,000,000
Petroleum
Segment Reporting Information [Line Items]
Inventories, carrying amounts in excess of market value	$ 58,000,000	0	0
Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Depreciation of inventories		$ 2,000,000	$ 3,000,000	$ 2,000,000

Summary of Significant Accounting Policies - Property, Plant and Equipment, net (Details) - USD ($) $ in Millions		12 Months Ended
	May 21, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]		Total property, plant and equipment, net	Total property, plant and equipment, net
ROU finance leases		$ 81	$ 80
Property, plant and equipment, gross		4,467	4,249
Less: Accumulated depreciation		(2,194)	(2,009)
Total property, plant and equipment, net		2,273	2,240
Gain on disposal of property, plant and equipment		(3)	(7)	$ 4
Assets Sold in Purchase and Sale Agreement
Property, Plant and Equipment [Line Items]
Cash consideration received	$ 43
Gain on disposal of property, plant and equipment	$ 10
Land and improvements
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		71	47
Buildings and improvements
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		88	88
Machinery and equipment
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		4,033	3,881
Furniture and fixtures
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		37	38
Other
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		15	15
Construction in progress
Property, Plant and Equipment [Line Items]
Gross property, plant and equipment		$ 142	$ 100
Minimum
Property, Plant and Equipment [Line Items]
Right-of-use (ROU) finance leases, Useful life		3 years
Minimum \| Land and improvements
Property, Plant and Equipment [Line Items]
Useful life		10 years
Minimum \| Buildings and improvements
Property, Plant and Equipment [Line Items]
Useful life		1 year
Minimum \| Machinery and equipment
Property, Plant and Equipment [Line Items]
Useful life		1 year
Minimum \| Furniture and fixtures
Property, Plant and Equipment [Line Items]
Useful life		3 years
Minimum \| Other
Property, Plant and Equipment [Line Items]
Useful life		5 years
Maximum
Property, Plant and Equipment [Line Items]
Right-of-use (ROU) finance leases, Useful life		18 years
Maximum \| Land and improvements
Property, Plant and Equipment [Line Items]
Useful life		30 years
Maximum \| Buildings and improvements
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 \| Furniture and fixtures
Property, Plant and Equipment [Line Items]
Useful life		10 years
Maximum \| Other
Property, Plant and Equipment [Line Items]
Useful life		30 years

Summary of Significant Accounting Policies - Impairment of Long-Lived Assets and Goodwill (Details)	3 Months Ended	12 Months Ended
	Jun. 30, 2020 product	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018
Goodwill [Line Items]
Goodwill		$ 0	$ 0
Goodwill impairment		$ 0	$ 41,000,000	$ 0
Coffeyville reporting unit, percentage of fair value in excess of carrying value					36.00%
Nitrogen Fertilizer
Goodwill [Line Items]
Goodwill				$ 41,000,000
Number of primary products experiencing significant pricing declines \| product	2

Summary of Significant Accounting Policies - Turnaround Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Petroleum Segment
Planned Major Maintenance Activities [Line Items]
Amortization period	4 years
Turnaround costs capitalized	$ 8	$ 155	$ 38
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 expenses incurred	$ 3	$ 1	$ 10
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 Accounting Policies - Earnings Per Share (Details) - shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Dilutive awards outstanding (in shares)	0	0	0

Equity Method Investments - Additional Information (Details)	12 Months Ended
	Dec. 31, 2021 bbl / d mi
Enable JV
Related Party Transaction [Line Items]
Pipeline length (in miles) \| mi	26
Pipeline capacity, barrels per day \| bbl / d	115,000
Midway JV
Related Party Transaction [Line Items]
Pipeline length (in miles) \| mi	99
Pipeline capacity, barrels per day \| bbl / d	150,000
Enable JV \| Enable JV
Related Party Transaction [Line Items]
Joint venture interest	40.00%
Midway JV \| Midway JV
Related Party Transaction [Line Items]
Joint venture interest	50.00%

Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Equity Method Investments [Roll Forward]
Balance at beginning of period	$ 80	$ 81
Cash Distributions	(11)	(10)
Equity income	10	9
Balance at end of period	79	80
Enable JV
Equity Method Investments [Roll Forward]
Balance at beginning of period	6	6
Cash Distributions	(3)	(4)
Equity income	3	4
Balance at end of period	6	6
Midway JV
Equity Method Investments [Roll Forward]
Balance at beginning of period	74	75
Cash Distributions	(8)	(6)
Equity income	7	5
Balance at end of period	$ 73	$ 74

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Jul. 31, 2020
Minimum
Lessee, Lease, Description [Line Items]
Renewal term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Renewal term	20 years
Financing lease not yet commenced, amount expected to be capitalized at commencement		$ 25

Leases - Balance Sheet Summary (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Operating Leases
Lease liability	$ 37
Finance Leases
Lease liability	54
Pipeline and storage
Operating Leases
ROU assets, net	17	$ 15
Lease liability	17	16
Finance Leases
ROU assets, net	23	26
Lease liability	35	38
Railcars
Operating Leases
ROU assets, net	6	8
Lease liability	6	8
Finance Leases
ROU assets, net	0	0
Lease liability	0	0
Real estate and other
Operating Leases
ROU assets, net	14	14
Lease liability	14	14
Finance Leases
ROU assets, net	18	21
Lease liability	$ 19	$ 22

Leases - Lease Expense Summary (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease expense	$ 15	$ 17	$ 12
Finance lease expense:
Amortization of ROU asset	6	6	7
Interest expense on lease liability	5	6	6
Short-term lease expense	$ 7	$ 8	$ 8

Leases - Lease Terms and Discount Rates (Details)	Dec. 31, 2021	Dec. 31, 2020
Weighted-average remaining lease term
Operating Leases	4 years 1 month 6 days	3 years 1 month 6 days
Finance Leases	7 years 2 months 12 days	8 years 1 month 6 days
Weighted-average discount rate
Operating Leases	5.40%	5.50%
Finance Leases	9.00%	9.00%

Leases - Summary of Remaining Minimum Lease Payments (Details) $ in Millions	Dec. 31, 2021 USD ($)
Operating Leases
2022	$ 14
2023	12
2024	8
2025	3
2026	1
Thereafter	4
Total lease payments	42
Less: imputed interest	(5)
Total lease liability	37
Finance Leases
2022	11
2023	10
2024	10
2025	10
2026	10
Thereafter	23
Total lease payments	74
Less: imputed interest	(20)
Lease liability	$ 54

Other Current Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Other Liabilities Disclosure [Abstract]
Accrued Renewable Fuel Standards (“RFS”) obligation	$ 494	$ 214
Deferred revenue	87	31
Personnel accruals	46	23
Accrued taxes other than income taxes	45	32
Accrued interest	24	25
Share-based compensation	$ 15	$ 4
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Total other current liabilities	Total other current liabilities
Operating lease liabilities	$ 13	$ 14
Accrued derivatives	2	17
Other accrued expenses and liabilities	15	9
Total other current liabilities	$ 741	$ 369

Long-Term Debt and Finance Lease Obligations - Schedule of Long-term Debt (Details) - USD ($) $ in Millions				12 Months Ended
	Dec. 22, 2021	Sep. 23, 2021	Jun. 23, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 15, 2021	Jan. 27, 2020	Jun. 10, 2016
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs				$ (4)	$ (11)
Total debt, net of current portion				$ 611	$ 634
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]				Total long-term debt and finance lease obligations, net of current portion	Total long-term debt and finance lease obligations, net of current portion
Finance lease obligations, net of current portion				$ 48	$ 55
Total long-term debt and finance lease obligations, net of current portion				48	55
Current portion of long-term debt and finance lease obligations				6	8
Total long-term debt and finance lease obligations, including current portion				1,660	1,691
Payment for redemption of debt				582	500	$ 0
Current portion of finance lease obligations				6	6
CVR Energy
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs				(5)	(6)
Total debt, net of current portion				995	994
Senior Notes \| 9.25% Senior Secured Notes, due June 2023
Debt Instrument [Line Items]
Total long-term debt, net of current portion, before finance lease obligations, debt issuance costs and discount				$ 65	645
Stated interest rate				9.25%					9.25%
Payment for redemption of debt	$ 15	$ 15	$ 550
Senior Notes \| 6.125% Senior Secured Notes, due June 2028
Debt Instrument [Line Items]
Total long-term debt, net of current portion, before finance lease obligations, debt issuance costs and discount				$ 550
Stated interest rate			6.125%	6.125%
Senior Notes \| 5.250% Senior Notes, due February 2025
Debt Instrument [Line Items]
Stated interest rate								5.25%
Senior Notes \| 5.750% Senior Notes, due February 2028
Debt Instrument [Line Items]
Stated interest rate								5.75%
Senior Notes \| 6.50% Senior Notes due April 2021
Debt Instrument [Line Items]
Stated interest rate							6.50%
Outstanding balance classified as short-term debt							$ 2
Senior Notes \| CVR Energy \| 5.250% Senior Notes, due February 2025
Debt Instrument [Line Items]
Total long-term debt, net of current portion, before finance lease obligations, debt issuance costs and discount				$ 600	600
Stated interest rate				5.25%
Senior Notes \| CVR Energy \| 5.750% Senior Notes, due February 2028
Debt Instrument [Line Items]
Total long-term debt, net of current portion, before finance lease obligations, debt issuance costs and discount				$ 400	$ 400
Stated interest rate				5.75%

Long-Term Debt and Finance Lease Obligations - Credit Agreement (Details) - USD ($)	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2021	Sep. 30, 2021	Nov. 14, 2017
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Capacity	$ 35,000,000	$ 35,000,000
Amount Borrowed	0	0
Outstanding Letters of Credit	0	0
Available Capacity	35,000,000	35,000,000
Aggregate principal amount of availability (up to)	$ 35,000,000	35,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| SOFR \| Quarterly Excess Availability Greater Than 75%
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.615%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| SOFR \| Quarterly Excess Availability Greater Than 50% But Less Than 75%
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.865%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| SOFR \| Quarterly Excess Availability Not Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.115%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Base Rate \| Quarterly Excess Availability Greater Than 75%
Line of Credit Facility [Line Items]
Basis spread on variable rate	0.615%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Base Rate \| Quarterly Excess Availability Greater Than 50% But Less Than 75%
Line of Credit Facility [Line Items]
Basis spread on variable rate	0.865%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Base Rate \| Quarterly Excess Availability Not Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.115%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Wells Fargo Bank National Association
Line of Credit Facility [Line Items]
Total Capacity			$ 35,000,000
Aggregate principal amount of availability (up to)			35,000,000
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement
Line of Credit Facility [Line Items]
Total Capacity				$ 400,000,000
Aggregate principal amount of availability (up to)				$ 400,000,000
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Capacity	$ 400,000,000	400,000,000
Amount Borrowed	0	0
Outstanding Letters of Credit	39,000,000	39,000,000
Available Capacity	361,000,000	361,000,000
Aggregate principal amount of availability (up to)	$ 400,000,000	$ 400,000,000
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Base Rate \| Quarterly Excess Availability Not Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate		0.75%
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Base Rate \| Quarterly Excess Availability Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate		0.50%
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| LIBOR \| Quarterly Excess Availability Not Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate		1.75%
Amended and Restated Asset Based (Petroleum ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| LIBOR \| Quarterly Excess Availability Greater Than 50%
Line of Credit Facility [Line Items]
Basis spread on variable rate		1.50%
UAN ABL Credit Agreement \| Line of Credit \| Revolving Credit Facility
Line of Credit Facility [Line Items]
Borrowing capacity terminated			$ 35,000,000

Long-Term Debt and Finance Lease Obligations - CVR Partners (Details) - USD ($)					3 Months Ended			12 Months Ended
	Dec. 22, 2021	Sep. 23, 2021	Jun. 23, 2021	Jun. 15, 2021	Mar. 31, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Feb. 22, 2022	Sep. 30, 2021	Jun. 10, 2016
Debt Instrument [Line Items]
Proceeds from issuance of senior secured notes								$ 550,000,000	$ 1,000,000,000	$ 0
Payment for redemption of debt								582,000,000	$ 500,000,000	$ 0
Loss on extinguishment of debt							$ 8,000,000	$ 1,000,000
Forecast
Debt Instrument [Line Items]
Loss on extinguishment of debt					$ 1,000,000
6.125% Senior Secured Notes, due June 2028
Debt Instrument [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased								100.00%
6.125% Senior Secured Notes, due June 2028 \| Redemption, period one
Debt Instrument [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased								103.063%
6.125% Senior Secured Notes, due June 2028 \| Senior Notes
Debt Instrument [Line Items]
Debt instrument face amount			$ 550,000,000
Stated interest rate			6.125%			6.125%		6.125%
Proceeds from issuance of senior secured notes			$ 547,000,000
Debt issuance costs			4,000,000
9.25% Senior Secured Notes, due June 2023 \| Redemption, period one
Debt Instrument [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased				100.00%
9.25% Senior Secured Notes, due June 2023 \| Senior Notes
Debt Instrument [Line Items]
Debt instrument face amount													$ 645,000,000
Stated interest rate						9.25%		9.25%					9.25%
Minimum percentage of notes held in order to cause acceleration of notes upon occurrence of events of default				25.00%
Payment for redemption of debt	$ 15,000,000	$ 15,000,000	550,000,000
Accrued interest settled upon redemption	$ 1,000,000		$ 1,000,000
Deferred financing charges							3,000,000
Unamortized discount							$ 5,000,000
9.25% Senior Secured Notes, due June 2023 \| Senior Notes \| Forecast
Debt Instrument [Line Items]
Deferred financing charges					1,000,000
Unamortized discount					$ 1,000,000
9.25% Senior Secured Notes, due June 2023 \| Senior Notes \| Subsequent Event
Debt Instrument [Line Items]
Accrued interest settled upon redemption											$ 1,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit
Debt Instrument [Line Items]
Debt issuance costs						$ 1,000,000		$ 1,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility
Debt Instrument [Line Items]
Total Capacity						$ 35,000,000		$ 35,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Quarterly Excess Availability Greater Than 75% \| SOFR
Debt Instrument [Line Items]
Basis spread on variable rate						1.615%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Quarterly Excess Availability Greater Than 75% \| Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate						0.615%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Quarterly Excess Availability Not Greater Than 50% \| SOFR
Debt Instrument [Line Items]
Basis spread on variable rate						2.115%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Revolving Credit Facility \| Quarterly Excess Availability Not Greater Than 50% \| Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate						1.115%
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Wells Fargo Bank National Association \| Revolving Credit Facility
Debt Instrument [Line Items]
Total Capacity												$ 35,000,000
Incremental facility, increase limit												15,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Wells Fargo Bank National Association \| Swingline Loans
Debt Instrument [Line Items]
Total Capacity												4,000,000
Asset Based (Nitrogen Fertilizer ABL) Credit Agreement \| Line of Credit \| Wells Fargo Bank National Association \| Letter of Credit
Debt Instrument [Line Items]
Total Capacity												$ 10,000,000

Long-Term Debt and Finance Lease Obligations - 2028 UAN Notes, Redemption (Details) - 6.125% Senior Secured Notes, due June 2028	12 Months Ended
	Dec. 31, 2021
Debt Instrument, Redemption [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased	100.00%
Redemption, period one
Debt Instrument, Redemption [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased	103.063%
Redemption, period two
Debt Instrument, Redemption [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased	101.531%
Redemption, period three
Debt Instrument, Redemption [Line Items]
Redemption of notes, percentage of par value at which notes were repurchased	100.00%

Long-Term Debt and Finance Lease Obligations - CVR Refining (Details) - Amended and Restated Asset Based (Petroleum ABL) Credit Agreement	Nov. 14, 2017 USD ($)
Debt Instrument [Line Items]
Total Capacity	$ 400,000,000
Uncommitted incremental facility	200,000,000
Letter of Credit
Debt Instrument [Line Items]
Total Capacity	60,000,000
Swingline Loans
Debt Instrument [Line Items]
Total Capacity	$ 40,000,000

Long-Term Debt and Finance Lease Obligations - CVR Energy (Details) - USD ($)		12 Months Ended
	Jan. 27, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Net cash proceeds received		$ 550,000,000	$ 1,000,000,000	$ 0
2025 and 2028 Notes \| Senior Notes
Debt Instrument [Line Items]
Net cash proceeds received	$ 993,000,000
Debt issuance costs	7,000,000
5.250% Senior Notes, due February 2025 \| Senior Notes
Debt Instrument [Line Items]
Debt instrument face amount	$ 600,000,000
Stated interest rate	5.25%
Minimum percentage of notes held in order to cause acceleration of notes upon occurrence of events of default	25.00%
5.750% Senior Notes, due February 2028 \| Senior Notes
Debt Instrument [Line Items]
Debt instrument face amount	$ 400,000,000
Stated interest rate	5.75%
Minimum percentage of notes held in order to cause acceleration of notes upon occurrence of events of default	25.00%

Long-Term Debt and Finance Lease Obligations - 2025 Notes and 2028 Notes, Redemption (Details) - Senior Notes	12 Months Ended
	Dec. 31, 2021
5.250% Senior Notes, due February 2025 \| Redemption, period one
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	102.625%
5.250% Senior Notes, due February 2025 \| Redemption, period two
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	101.313%
5.250% Senior Notes, due February 2025 \| Redemption, period three
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	100.00%
5.750% Senior Notes, due February 2028 \| Redemption, period one
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	102.875%
5.750% Senior Notes, due February 2028 \| Redemption, period two
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	101.917%
5.750% Senior Notes, due February 2028 \| Redemption, period three
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	100.958%
5.750% Senior Notes, due February 2028 \| Redemption, period four
Debt Instrument, Redemption [Line Items]
Redemption prices as percentage of principal amount	100.00%

Revenue - Revenue Disaggregated by Major Product (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Total revenue	$ 7,242	$ 3,930	$ 6,364
Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	7,193	3,866	6,303
Gasoline
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,679	1,882	3,050
Distillates
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,809	1,543	2,705
Ammonia
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	146	94	94
UAN
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	316	198	251
Other urea products
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	29	15	18
Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	52	51	56
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	162	83	129
Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	47	63	58
Other revenue
Disaggregation of Revenue [Line Items]
Other revenue	2	1	3
Operating Segments \| Petroleum
Disaggregation of Revenue [Line Items]
Total revenue	6,721	3,586	5,968
Operating Segments \| Petroleum \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6,672	3,522	5,907
Operating Segments \| Petroleum \| Gasoline
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,679	1,882	3,050
Operating Segments \| Petroleum \| Distillates
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,809	1,543	2,705
Operating Segments \| Petroleum \| Ammonia
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Petroleum \| UAN
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Petroleum \| Other urea products
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Petroleum \| Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	21	18	23
Operating Segments \| Petroleum \| Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	163	79	129
Operating Segments \| Petroleum \| Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	47	63	58
Operating Segments \| Petroleum \| Other revenue
Disaggregation of Revenue [Line Items]
Other revenue	2	1	3
Operating Segments \| Nitrogen Fertilizer
Disaggregation of Revenue [Line Items]
Total revenue	533	350	404
Operating Segments \| Nitrogen Fertilizer \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	533	350	404
Operating Segments \| Nitrogen Fertilizer \| Gasoline
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Nitrogen Fertilizer \| Distillates
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Nitrogen Fertilizer \| Ammonia
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	146	94	94
Operating Segments \| Nitrogen Fertilizer \| UAN
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	316	198	251
Operating Segments \| Nitrogen Fertilizer \| Other urea products
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	29	15	18
Operating Segments \| Nitrogen Fertilizer \| Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	31	33	33
Operating Segments \| Nitrogen Fertilizer \| Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11	10	8
Operating Segments \| Nitrogen Fertilizer \| Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Operating Segments \| Nitrogen Fertilizer \| Other revenue
Disaggregation of Revenue [Line Items]
Other revenue	0	0	0
Other / Eliminations
Disaggregation of Revenue [Line Items]
Total revenue	(12)	(6)	(8)
Other / Eliminations \| Revenue from product sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(12)	(6)	(8)
Other / Eliminations \| Gasoline
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Distillates
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Ammonia
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| UAN
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Other urea products
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Freight revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(12)	(6)	(8)
Other / Eliminations \| Crude oil sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0
Other / Eliminations \| Other revenue
Disaggregation of Revenue [Line Items]
Other revenue	$ 0	$ 0	$ 0

Revenue - Additional information (Details)	12 Months Ended
Revenue - Additional information (Details)	Dec. 31, 2021
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 \| Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	15 days
Nitrogen Fertilizer \| Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Payment terms	30 days

Revenue - Remaining Performance Obligation (Details) - Nitrogen Fertilizer Segment $ in Millions	Dec. 31, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 10
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 6
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 4
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction, period

Revenue - Summary of Deferred Revenue Activity (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Change in Contract with Customer, Liability [Roll Forward]
Balance at December 31, 2020	$ 31
Less:
Balance at December 31, 2021	87
Nitrogen Fertilizer Segment
Change in Contract with Customer, Liability [Roll Forward]
Balance at December 31, 2020	31
Add:
New prepay contracts entered into during the period	147
Less:
Revenue recognized that was included in the contract liability balance at the beginning of the period	(30)
Revenue recognized related to contracts entered into during the period	(60)
Other changes	(1)
Balance at December 31, 2021	87
Prepaid contracts, payment collected	$ 94

Revenue - Major Customers (Details) - Net Sales - Customer concentration	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Petroleum \| Two Customers
Major Customers and Suppliers
Concentration risk		26.00%	25.00%
Petroleum \| One customer
Major Customers and Suppliers
Concentration risk	16.00%
Nitrogen Fertilizer \| Two Customers
Major Customers and Suppliers
Concentration risk		26.00%	28.00%
Nitrogen Fertilizer \| One customer
Major Customers and Suppliers
Concentration risk	13.00%

Derivative Financial Instruments, Investments and Fair Value Measurements - Additional Information (Details) bbl in Millions		12 Months Ended
	Jun. 10, 2021 shares	Dec. 31, 2021 derivative bbl	Dec. 31, 2020 bbl
Delek US Holdings, Inc.
Derivative [Line Items]
Dividends paid to CVR Energy stockholders (in shares) \| shares	10,539,880
Commodity Swap
Derivative [Line Items]
Outstanding positions \| derivative		0
Number of barrels			7
Forward Contracts \| Purchase Commitments
Derivative [Line Items]
Number of barrels		1	4
Forward Contracts \| Sale Commitments
Derivative [Line Items]
Number of barrels		1	2
Forward Contracts, RINs \| Purchase Commitments
Derivative [Line Items]
Outstanding positions \| derivative		2,000,000

Derivative Financial Instruments, Investments and Fair Value Measurements - Schedule of Gains (Losses) on Derivatives (Details) - Cost of materials and other - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Total (loss) gain on derivatives, net	$ (44)	$ 55	$ 19
Forward purchases and sales contracts, net
Derivative Instruments, Gain (Loss) [Line Items]
Total (loss) gain on derivatives, net	25	53	20
Commodity swap instruments
Derivative Instruments, Gain (Loss) [Line Items]
Total (loss) gain on derivatives, net	(68)	(8)	0
Futures contracts
Derivative Instruments, Gain (Loss) [Line Items]
Total (loss) gain on derivatives, net	$ (1)	$ 10	$ (1)

Derivative Financial Instruments, Investments and Fair Value Measurements - Schedule of Derivative Offsetting Assets and Liabilities (Details) - Commodity derivatives - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current Assets
Derivative Assets
Commodity derivatives	$ 5	$ 1
Less: Counterparty netting	(5)	(1)
Total net fair value of derivatives	0	0
Current Liabilities
Derivative Liabilities
Commodity derivatives	(7)	(5)
Less: Counterparty netting	5	1
Total net fair value of derivatives	$ (2)	$ (4)

Derivative Financial Instruments, Investments and Fair Value Measurements - Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Dividend income	$ 0	$ 7	$ 0
Gain on marketable securities	81	34	0
Investment income on marketable securities	$ 81	$ 41	$ 0

Derivative Financial Instruments, Investments and Fair Value Measurements - Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - Recurring - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Prepaid expenses and other current assets (investments)		$ 173
Total Assets	$ 1	173
Note payable and finance lease obligations (current portion of long-term debt)		(2)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	(1,620)	(1,604)
Total Liabilities	(2,116)	(1,837)
Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	1
Other current liabilities (commodity derivatives)	(2)	(17)
RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities (RFS obligation)	(494)	(214)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Prepaid expenses and other current assets (investments)		173
Total Assets	0	173
Note payable and finance lease obligations (current portion of long-term debt)		0
Long-term debt and finance lease obligations, net of current portion (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 (commodity derivatives)	0	0
Level 1 \| RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities (RFS obligation)	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Prepaid expenses and other current assets (investments)		0
Total Assets	1	0
Note payable and finance lease obligations (current portion of long-term debt)		(2)
Long-term debt and finance lease obligations, net of current portion (long-term debt)	(1,620)	(1,604)
Total Liabilities	(2,116)	(1,837)
Level 2 \| Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current assets (commodity derivatives)	1
Other current liabilities (commodity derivatives)	(2)	(17)
Level 2 \| RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities (RFS obligation)	(494)	(214)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Prepaid expenses and other current assets (investments)		0
Total Assets	0	0
Note payable and finance lease obligations (current portion of long-term debt)		0
Long-term debt and finance lease obligations, net of current portion (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 (commodity derivatives)	0	0
Level 3 \| RFS obligation
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other current liabilities (RFS obligation)	$ 0	$ 0

Share-Based Compensation - Additional Information (Details)			1 Months Ended	12 Months Ended
	Dec. 22, 2021	Nov. 01, 2017 USD ($) agreement $ / shares	Feb. 28, 2019 USD ($)	Dec. 31, 2021 USD ($) plan shares	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares or units available for future grants (in shares) \| shares				6,800,000
Amount of payout				$ 30,000,000	$ 8,000,000	$ 23,000,000
Total tax benefit recognized during the year related to compensation expense				12,000,000	1,000,000	4,000,000
Liability for cash settled nonvested awards and associated dividend and distribution equivalent rights				$ 23,000,000	5,000,000
Number of defined-contribution 401(k) plans \| plan				2
Matching contribution, percent				100.00%
Percent of eligible compensation contributed by participants				6.00%
Vesting period				3 years
Matching contributions made by the company				$ 0	$ 10,000,000	$ 9,000,000
Share-Based Awards
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
Share-Based Awards \| Vesting Year One
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage				33.33%
Share-Based Awards \| Vesting Year Two
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage				33.33%
Share-Based Awards \| Vesting Year Three
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage				33.33%
Performance Awards \| 2018 CEO Performance Award
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
Amount of payout			$ 1,900,000
Maximum cash payment		$ 10,000,000
Period for determination of cash payment value	30 days	30 days
Maximum price per share to trigger maximum cash payment (in dollars per share) \| $ / shares		$ 60

Share-Based Compensation - Summary of Incentive and Phantom Unit Awards Activity (Details) - Share-Based Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Shares or Units (1)
Non-vested at the beginning of the period (in shares)	2,454,641
Granted (in shares)	950,744
Vested (in shares)	(857,901)
Forfeited (in shares)	(254,379)
Non-vested at the end of the period (in shares)	2,293,105
Weighted-Average Grant-Date Fair Value (per share or unit)
Non-vested at the beginning of the period (in dollars per share)	$ 19.01
Granted (in dollars per share)	19.46
Vested (in dollars per share)	21.14
Forfeited (in dollars per share)	19.66
Non-vested at the end of the period (in dollars per share)	$ 18.23
Aggregate Intrinsic Value	$ 62	$ 37
LTIPs
Shares or Units (1)
Non-vested at the end of the period (in shares)	0

Share-Based Compensation - Schedule of Share-based Compensation Activity (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 46	$ 4	$ 17
Unrecognized Expense	56
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	22	3	12
Unrecognized Expense	$ 27
Weighted-Average Remaining Years	2 years 4 months 24 days
Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ 27	1	5
Unrecognized Expense	$ 19
Weighted-Average Remaining Years	2 years
Performance Awards \| CEO Performance Award (1)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expenses	$ (3)	$ 0	$ 0
Unrecognized Expense	$ 10
Weighted-Average Remaining Years	3 years

Income Taxes - Additional Information (Details) - USD ($)	1 Months Ended	12 Months Ended
	Aug. 31, 2018	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Taxes [Line Items]
Payable for state income taxes due to AEP		$ 0	$ 0
Receivable from the IRS and state jurisdictions		26,000,000	44,000,000
Valuation allowance		0	0
Unrecognized tax benefits which, if recognized, would impact the company's effective tax rate		13,000,000	13,000,000	$ 15,000,000
Unrecognized tax benefits netted with deferred tax asset carryforwards		7,000,000	8,000,000
Interest expense (benefit) recognized on uncertain tax positions		1,000,000	0	0
Liability for interest		2,000,000	1,000,000	0
Penalties recognized on uncertain tax positions		0	$ 0	$ 0
State
Income Taxes [Line Items]
Tax credit carry-forwards		26,000,000
Unrecognized tax benefits reasonably possible to be recognized in next fiscal year		$ 5,000,000
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%
Exchange Offer, CVR Refining Common Units for CVR Energy Common Stock
Income Taxes [Line Items]
Number of shares tendered in exchange offer (in shares)	21,625,106
Common stock exchanged in the exchange offer (in shares)	13,699,549

Income Taxes - Schedule of Income Tax (Benefit) Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current:
Federal	$ 84	$ (63)	$ 96
State	7	(5)	5
Total current	91	(68)	101
Deferred:
Federal	(76)	(1)	3
State	(23)	(26)	25
Total deferred	(99)	(27)	28
Total income tax (benefit) expense	$ (8)	$ (95)	$ 129

- Definition

Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

+ References + Details

Income Taxes - Reconciliation of Total Income Tax (Benefit) Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Tax computed at federal statutory rate	$ 14	$ (87)	$ 103
State income taxes, net of federal tax benefit	3	(18)	29
Changes in enacted state tax rates, net of federal tax benefit	(10)	0	0
State tax incentives, net of federal tax expense	(6)	(7)	(4)
Noncontrolling interest	(10)	13	4
Goodwill impairment	0	3	0
Other, net	1	1	(3)
Total income tax (benefit) expense	$ (8)	$ (95)	$ 129

- Definition

Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

+ References + Details

Income Taxes - Schedule of Income Tax Effect of Temporary Differences (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred income tax assets:
Personnel accruals	$ 6	$ 2
State tax credit carryforward, net	17	20
Net operating loss carryforward	2	9
Total gross deferred income tax assets	25	31
Deferred income tax liabilities:
Unrealized gain	0	(9)
Investment in CVR Partners and CVR Refining	(222)	(320)
Other	(1)	(3)
Total gross deferred income tax liabilities	(293)	(399)
Net deferred income tax liabilities	$ (268)	$ (368)

Income Taxes - Schedule of Reconciliation of the Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of the unrecognized tax benefits
Balance, beginning of year	$ 17	$ 22	$ 23
Decrease based on prior year tax position	0	(2)	0
Increase in current year tax positions	0	0	2
Reductions related to expirations from statute of limitations	0	(3)	(3)
Balance, end of year	$ 17	$ 17	$ 22

Commitments and Contingencies - Schedule of Minimum Required Payments for Unconditional Purchase Obligations (Details) $ in Millions	Dec. 31, 2021 USD ($)
Unconditional Purchase Obligations
2022	$ 136
2023	85
2024	82
2025	82
2026	77
Thereafter	252
Unconditional Purchase Obligations	$ 714

Commitments and Contingencies - Supply Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Amounts purchased under supply agreements	$ 176	$ 153	$ 167

Commitments and Contingencies - Crude Oil Supply Agreement (Details) - Crude Oil Supply Agreement		12 Months Ended
	Aug. 31, 2012	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
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%	33.00%	36.00%

Commitments and Contingencies - Contingencies (Details)				12 Months Ended
Commitments and Contingencies - Contingencies (Details)	Dec. 22, 2021 USD ($)	Jun. 25, 2021 claimant	Jan. 27, 2021 USD ($)	Jan. 30, 2022 lawsuit	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($) lawsuit plaintiff	Dec. 07, 2021 petition
Small Refinery Exemption
Loss Contingencies [Line Items]
Number of lawsuits filed \| petition								65
Number of refineries whose SREs were vacated under RFS program \| claimant		3
Number of ethanol and biofuels trade associations that filed lawsuit against the EPA \| plaintiff							4
EHS \| Petroleum
Loss Contingencies [Line Items]
Expense for compliance with RFS					$ 435,000,000	$ 190,000,000	$ 43,000,000
RFS obligation					$ 494,000,000	$ 214,000,000
Call Option Lawsuits
Loss Contingencies [Line Items]
Number of lawsuits filed \| lawsuit							9
Indemnity insurance, coverage limit			$ 50,000,000
Call Option Lawsuits \| Subsequent Event
Loss Contingencies [Line Items]
Number of lawsuits relating to insurance coverage \| lawsuit				2
Call Option Lawsuits \| Minimum
Loss Contingencies [Line Items]
Loss contingency, damages sought	$ 300,000,000

Commitments and Contingencies - Environmental, Health, and Safety ("EHS") Matters (Details) - EHS $ in Millions		1 Months Ended
	Feb. 10, 2022 count	Dec. 31, 2020 USD ($) count	Dec. 31, 2021 USD ($)
Loss Contingencies [Line Items]
Environmental accruals \| $		$ 11	$ 12
Clean Air Act Matter
Loss Contingencies [Line Items]
Number of counts asserted related to alleged violations		9
Clean Air Act Matter \| Subsequent Event
Loss Contingencies [Line Items]
Number of counts asserted related to alleged violations	8

Business Segments - Additional Information (Details)	12 Months Ended
Business Segments - Additional Information (Details)	Dec. 31, 2021 segment
Segment Reporting [Abstract]
Number of operating segments	2
Number of reportable segments	2

Business Segments - Summary of Operating Results, Capital Expenditures, and Total Asset Information by Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Net sales	$ 7,242	$ 3,930	$ 6,364
Operating income (loss)	87	(333)	580
Interest expense, net	(117)	(130)	(102)
Investment income on marketable securities	81	41	0
Other income, net	15	7	13
Income (loss) before income tax expense	66	(415)	491
Depreciation and amortization	279	278	287
Capital expenditures	226	121	114
Total assets	3,906	3,978
Operating Segments \| Petroleum
Segment Reporting Information [Line Items]
Net sales	6,721	3,586	5,968
Operating income (loss)	(27)	(281)	574
Depreciation and amortization	203	202	202
Capital expenditures	50	90	89
Total assets	3,368	2,991
Operating Segments \| Nitrogen Fertilizer
Segment Reporting Information [Line Items]
Net sales	533	350	404
Operating income (loss)	134	(35)	27
Depreciation and amortization	73	76	80
Capital expenditures	26	16	20
Total assets	1,127	1,033
Other
Segment Reporting Information [Line Items]
Net sales	(12)	(6)	(8)
Operating income (loss)	(20)	(17)	(21)
Depreciation and amortization	3	0	5
Capital expenditures	150	15	$ 5
Total assets	$ (589)	$ (46)

Supplemental Cash Flow Information - Schedule of Cash Flows Related to Income Taxes, Interest, Leases, Capital Expenditures and Deferred Financing Costs Included in Accounts Payable and Non-Cash Dividends (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Supplemental disclosures:
Cash paid, net of refunds (received, net of payments) for income taxes	$ 72	$ (2)	$ 69
Cash paid for interest	114	107	104
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	15	17	16
Operating cash flows from finance leases	5	6	6
Financing cash flows from finance leases	6	5	5
Non-cash investing and financing activities:
Change in construction in progress included in accounts payable	2	(3)	(7)
Change in deferred financing costs included in accounts payable	1	0	0
Non-cash dividends to CVR Energy stockholders	$ 251	$ 0	$ 0

Supplemental Cash Flow Information - Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents	$ 510	$ 667
Restricted cash	7	7
Cash, cash equivalents and restricted cash	$ 517	$ 674	$ 652	$ 668

Related Party Transactions - Expenses Incurred and Payments Made to Related Parties (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Cost of materials and other	$ 6,185	$ 3,373	$ 4,851
Dividends	241	121	306
Enable Joint Venture Transportation Agreement \| Joint Venture Transportation Agreement
Related Party Transaction [Line Items]
Cost of materials and other	11	11	12
IEP
Related Party Transaction [Line Items]
Dividends	348	85	218
AEP Tax Allocation Agreement \| Tax Allocation Agreement
Related Party Transaction [Line Items]
Payments (received) made:	$ 0	$ 0	$ (3)

Related Party Transactions - Enable Joint Venture Agreement and Midway Joint Venture (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Joint Venture Agreement \| Enable JV
Related Party Transaction [Line Items]
Initial term of agreement	20 years
Crude Oil Transportation Services \| Midway JV
Related Party Transaction [Line Items]
Costs incurred	$ 20	$ 17	$ 21

Related Party Transactions - Dividends to CVR Energy Stockholders (Details) $ / shares in Units, $ in Millions			3 Months Ended	12 Months Ended
	Jun. 10, 2021 USD ($) $ / shares shares	May 26, 2021 USD ($) $ / shares	Dec. 31, 2021 $ / shares	Dec. 31, 2021 USD ($) $ / shares	Dec. 31, 2020 USD ($) $ / shares	Dec. 31, 2019 USD ($) $ / shares
Related Party Transaction [Line Items]
Dividends declared related to quarterly results (in dollars per share) \| $ / shares			$ 0	$ 0
Dividends paid related to quarterly results (in dollars per share) \| $ / shares				$ 0
Dividends paid				$ 241	$ 121	$ 306
Dividends declared per share (in dollars per share) \| $ / shares		$ 4.89		$ 4.89	$ 1.20	$ 3.05
Dividend per share (in dollars per share) \| $ / shares					$ 1.20	$ 3.05
Proceeds from dividends received	$ 171
Realized gain on investment	112
IEP
Related Party Transaction [Line Items]
Dividends paid				$ 348	$ 85	$ 218
Delek US Holdings, Inc.
Related Party Transaction [Line Items]
Dividends paid	$ 241
Special dividend		$ 492
Dividend per share (in dollars per share) \| $ / shares	$ 2.40
Dividends paid to CVR Energy stockholders (in shares) \| shares	10,539,880
Outstanding shares of common stock, percent	0.143
Common stock dividends, shares received (in shares) \| shares	7,464,652

Related Party Transactions - Distributions to CVR Partners' Unitholders (Details) - USD ($) $ / shares in Units, $ in Millions					12 Months Ended
	Mar. 14, 2022	Feb. 21, 2022	Nov. 22, 2021	Aug. 23, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Distributions paid (in dollars per share)			$ 2.93	$ 1.72	$ 4.65	$ 0	$ 4.00
Distributions paid			$ 31	$ 18	$ 49		$ 45
Distributions declared related to quarterly results (in dollars per share)					$ 0
Distributions paid related to quarterly results (in dollars per share)					$ 0
Distributions declared (in dollars per share)						$ 0
Forecast
Related Party Transaction [Line Items]
Proceeds from distribution	$ 20
Subsequent Event
Related Party Transaction [Line Items]
Distributions declared (in dollars per share)		$ 5.24
Distributions declared		$ 56
CVR Energy
Related Party Transaction [Line Items]
Distributions paid			11	7	$ 18		$ 16
Public Unitholders
Related Party Transaction [Line Items]
Distributions paid			$ 20	$ 11	$ 31