Par Pacific (PARR) 10-K 2 Mar 20 2019 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Dec. 31, 2019	Feb. 18, 2020	Jun. 28, 2019
Cover page.
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
Document Transition Report	false
Entity File Number	001-36550
Entity Registrant Name	PAR PACIFIC HOLDINGS, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	84-1060803
Entity Address, Address Line One	825 Town & Country Lane, Suite 1500
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77024
City Area Code	281
Local Phone Number	899-4800
Title of 12(b) Security	Common stock, $0.01 par value
Trading Symbol	PARR
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 763,283,917
Entity Common Stock, Shares Outstanding		53,375,501
Documents Incorporated by Reference	Certain information required to be disclosed in Part III of this report is incorporated by reference from the registrant’s definitive proxy statement or an amendment to this report, which will be filed with the SEC not later than 120 days after the end of the fiscal year covered by this report.
Entity Central Index Key	0000821483
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current assets
Cash and cash equivalents	$ 126,015	$ 75,076
Restricted cash	2,413	743
Total cash, cash equivalents, and restricted cash	128,428	75,819
Trade accounts receivable	228,718	160,338
Inventories	615,872	322,065
Prepaid and other current assets	59,156	28,370
Total current assets	1,032,174	586,592
Property, plant, and equipment
Property, plant, and equipment	1,146,983	649,768
Less accumulated depreciation, depletion, and amortization	(185,040)	(111,507)
Property, plant, and equipment, net	961,943	538,261
Long-term assets
Operating lease assets	420,073
Investment in Laramie Energy, LLC	46,905	136,656
Intangible assets, net	21,549	23,947
Goodwill	195,919	153,397
Other long-term assets	21,997	21,881
Total assets	2,700,560	1,460,734
Current liabilities
Current maturities of long-term debt	12,297	33
Obligations under inventory financing agreements	656,162	373,882
Accounts payable	162,402	54,787
Deferred revenue	7,905	6,681
Accrued taxes	30,813	17,256
Operating lease liabilities	79,999
Other accrued liabilities	84,744	54,562
Total current liabilities	1,034,322	507,201
Long-term liabilities
Long-term debt, net of current maturities	599,634	392,607
Common stock warrants	8,206	5,007
Finance lease liabilities	6,227
Finance lease liabilities		6,123
Operating lease liabilities	340,909
Other liabilities	63,020	37,467
Total liabilities	2,052,318	948,405
Commitments and Contingencies (Note 16)
Stockholders’ equity
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued	0	0
Common stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2019 and December 31, 2018, 53,254,151 shares and 46,983,924 shares issued at December 31, 2019 and December 31, 2018, respectively	533	470
Additional paid-in capital	715,069	617,937
Accumulated deficit	(67,942)	(108,751)
Accumulated other comprehensive income	582	2,673
Total stockholders’ equity	648,242	512,329
Total liabilities and stockholders’ equity	$ 2,700,560	$ 1,460,734

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	3,000,000	3,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	53,254,151	46,983,924

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenues
Revenues	$ 1,399,134	$ 1,401,638	$ 1,409,409	$ 1,191,335	$ 879,112	$ 909,781	$ 856,396	$ 765,439	$ 5,401,516	$ 3,410,728	$ 2,443,066
Operating expenses
Cost of revenues (excluding depreciation)									4,803,589	3,003,116	2,054,627
Operating expense (excluding depreciation)									312,899	215,284	202,016
Depreciation, depletion, and amortization									86,121	52,642	45,989
General and administrative expense (excluding depreciation)									46,223	47,426	46,078
Acquisition and integration costs									4,704	10,319	395
Total operating expenses									5,253,536	3,328,787	2,349,105
Operating income	59,531	18,405	48,621	21,423	20,408	4,894	28,983	27,656	147,980	81,941	93,961
Other income (expense)
Interest expense and financing costs, net									(74,839)	(39,768)	(31,632)
Debt extinguishment and commitment costs									(11,587)	(4,224)	(8,633)
Other income (expense), net									2,516	1,046	911
Change in value of common stock warrants									(3,199)	1,801	(1,674)
Change in value of contingent consideration									0	(10,500)	0
Equity earnings (losses) from Laramie Energy, LLC									(89,751)	9,464	18,369
Total other expense, net									(176,860)	(42,181)	(22,659)
Income (loss) before income taxes									(28,880)	39,760	71,302
Income tax benefit (expense)									69,689	(333)	1,319
Net Income	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Income per share
Basic (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.23	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.58
Diluted (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.14	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.57
Weighted-average number of shares outstanding
Basic (in shares)									50,352	45,726	45,543
Diluted (in shares)									50,470	45,755	45,583

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Other comprehensive income (loss):
Other post-retirement benefits income (loss), net of tax									(2,091)	529	(52)
Total other comprehensive income (loss), net of tax									(2,091)	529	(52)
Comprehensive income									$ 38,718	$ 39,956	$ 72,569

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash flows from operating activities:
Net Income	$ 40,809,000	$ 39,427,000	$ 72,621,000
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation, depletion, and amortization	86,121,000	52,642,000	45,989,000
Debt extinguishment and commitment costs	11,587,000	4,224,000	8,633,000
Non-cash interest expense	9,118,000	7,127,000	7,276,000
Change in value of common stock warrants	3,199,000	(1,801,000)	1,674,000
Deferred taxes	(66,886,000)	661,000	(1,321,000)
Stock-based compensation	6,437,000	6,196,000	7,204,000
Unrealized (gain) loss on derivative contracts	9,350,000	2,122,000	(989,000)
Equity (earnings) losses from Laramie Energy, LLC	89,751,000	(9,464,000)	(18,369,000)
Net changes in operating assets and liabilities:
Trade accounts receivable	(36,652,000)	(35,790,000)	(19,100,000)
Collateral posted with broker for derivative transactions	(8,797,000)	(3,790,000)	2,499,000
Prepaid and other assets	(24,121,000)	(5,521,000)	37,645,000
Inventories	(195,440,000)	31,840,000	(146,533,000)
Deferred turnaround expenditures	(9,800,000)	0	0
Obligations under inventory financing agreements	121,985,000	(17,138,000)	143,034,000
Accounts payable, other accrued liabilities, and operating lease assets and liabilities	68,969,000	19,885,000	(33,780,000)
Net cash provided by operating activities	105,630,000	90,620,000	106,483,000
Cash flows from investing activities:
Acquisitions, net of cash acquired	(273,399,000)	(74,331,000)	0
Proceeds (expenditures) related to asset acquisition	3,226,000	(53,867,000)	0
Capital expenditures	(83,920,000)	(48,439,000)	(31,708,000)
Other investing activities	864,000	816,000	35,000
Net cash used in investing activities	(353,229,000)	(175,821,000)	(31,673,000)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs	0	19,318,000	0
Proceeds from borrowings	510,906,000	118,741,000	616,706,000
Repayments of borrowings	(241,336,000)	(118,751,000)	(603,770,000)
Net borrowings (repayments) on deferred payment arrangements and receivable advances	43,422,000	27,264,000	(2,198,000)
Payment of deferred loan costs	(13,450,000)	(379,000)	(10,064,000)
Exercise of stock options	8,171,000	0	0
Payments for debt extinguishment and commitment costs	(8,087,000)	(3,390,000)	(4,432,000)
Other financing activities, net	582,000	(860,000)	(993,000)
Net cash provided by (used in) financing activities	300,208,000	41,943,000	(4,751,000)
Net increase (decrease) in cash, cash equivalents, and restricted cash	52,609,000	(43,258,000)	70,059,000
Cash, cash equivalents, and restricted cash at beginning of period	75,819,000	119,077,000	49,018,000
Cash, cash equivalents, and restricted cash at end of period	128,428,000	75,819,000	119,077,000
Net cash received (paid) for:
Interest	(58,250,000)	(28,186,000)	(23,873,000)
Taxes	(136,000)	(49,000)	(1,478,000)
Non-cash investing and financing activities:
Accrued capital expenditures	6,386,000	6,199,000	2,926,000
ROU assets obtained in exchange for new finance lease liabilities	963,000
ROU assets obtained in exchange for new finance lease liabilities		1,678,000	165,000
ROU assets obtained in exchange for new operating lease liabilities	79,382,000
Common stock issued for business combination	36,980,000	0	0
Common stock issued to repurchase convertible notes	$ 74,290,000	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY - USD ($) shares in Thousands, $ in Thousands		Total	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Accumulated Other Comprehensive Income (Loss)
Balance (in shares) at Dec. 31, 2016			45,534
Balance at Dec. 31, 2016		$ 368,909	$ 455	$ 587,057	$ (220,799)	$ 2,196
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based compensation (in shares)			303
Stock-based compensation		7,204	$ 4	7,200
Purchase of common stock for retirement (in shares)			(61)
Purchase of common stock for retirement		(963)	$ (1)	(962)
Other comprehensive loss		(52)				(52)
Net income (loss)		72,621			72,621
Balance (in shares) at Dec. 31, 2017			45,776
Balance at Dec. 31, 2017		447,719	$ 458	593,295	(148,178)	2,144
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock in connection with acquisition (in shares)			1,108
Issuance of common stock in connection with acquisition		19,318	$ 11	19,307
Share-based compensation (in shares)			147
Stock-based compensation		6,196	$ 1	6,195
Purchase of common stock for retirement (in shares)			(47)
Purchase of common stock for retirement		(860)		(860)
Other comprehensive loss		529				529
Net income (loss)		39,427			39,427
Balance (in shares) at Dec. 31, 2018			46,984
Balance at Dec. 31, 2018		512,329	$ 470	617,937	(108,751)	2,673
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock in connection with acquisition (in shares)			2,364
Issuance of common stock in connection with acquisition		36,980	$ 23	36,957
Issuance of common stock for convertible notes repurchase, net (in shares)	[1]		3,243
Issuance of common stock for convertible notes repurchase, net	[1]	45,617	$ 32	45,585
Issuance of common stock for employee stock purchase plan (in shares)			68
Issuance of common stock for employee stock purchase plan		1,490	$ 1	1,489
Share-based compensation (in shares)			202
Stock-based compensation		6,213	$ 3	6,210
Purchase of common stock for retirement (in shares)			(54)
Purchase of common stock for retirement		$ (1,276)		(1,276)
Exercise of stock options (in shares)		483	447
Exercise of stock options		$ 8,171	$ 4	8,167
Other comprehensive loss		(2,091)				(2,091)
Net income (loss)		40,809			40,809
Balance (in shares) at Dec. 31, 2019			53,254
Balance at Dec. 31, 2019		$ 648,242	$ 533	$ 715,069	$ (67,942)	$ 582
[1]	The issuance of common stock for the repurchase of a portion of our 5.00% Convertible Senior Notes during the year ended December 31, 2019 is presented net of a $28.7 million write-off associated with the equity component of the repurchased notes.

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Parenthetical) - 5% Convertible Senior Notes due 2021 - USD ($) $ in Millions	Dec. 31, 2019	Jun. 30, 2016	Jun. 27, 2016
Debt instrument, interest rate	5.00%	5.00%
Convertible Debt
Debt instrument, interest rate	5.00%
Debt instrument, convertible, carrying amount of equity component	$ 28.7		$ 22.2

Overview

Overview	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Overview	Overview Par Pacific Holdings, Inc. and its wholly owned subsidiaries (“Par” or the “Company”) own and operate market-leading energy and infrastructure businesses. Our strategy is to acquire and develop businesses in logistically-complex markets. Currently, we operate in three primary business segments: 1) Refining - We own and operate four refineries with total throughput capacity of over 200 thousand barrels per day (“Mbpd”). Our refineries in Kapolei, Hawaii produce ultra-low sulfur diesel (“ULSD”), gasoline, jet fuel, marine fuel, low sulfur fuel oil (“LSFO”), and other associated refined products primarily for consumption in Hawaii. Our refinery in Newcastle, Wyoming produces gasoline, ULSD, jet fuel, and other associated refined products that are primarily marketed in Wyoming and South Dakota. Our refinery in Tacoma, Washington produces distillates, gasoline, asphalt, and other associated refined products primarily marketed in the Pacific Northwest. 2) Retail - We operate 124 retail outlets in Hawaii, Washington, and Idaho. Our retail outlets in Hawaii sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our Hawaii retail network includes Hele and “ 76 ” branded retail sites, company-operated convenience stores, 7-Eleven operated convenience stores, other sites operated by third parties, and unattended cardlock stations. In addition to the rebranding of 40 of our fueling stations in Hawaii to Hele as of December 31, 2019 , we rebranded 28 of our 34 company-operated convenience stores in Hawaii to “nomnom,” a new proprietary brand. Our retail outlets in Washington and Idaho sell gasoline, diesel, and retail merchandise and operate under the “ Cenex® ” and “ Zip Trip® ” brand names. 3) Logistics - We operate an extensive multi-modal logistics network spanning the Pacific, the Northwest, and the Rockies. We own and operate terminals, pipelines, a single-point mooring (“SPM”), and trucking operations to distribute refined products throughout the islands of Oahu, Maui, Hawaii, Molokai, and Kauai. We lease marine vessels for the movement of petroleum, refined products, and ethanol between the U.S. West Coast and Hawaii. We own and operate a crude oil pipeline gathering system, a refined products pipeline, storage facilities, and loading racks in Wyoming and a jet fuel storage facility and pipeline that serve Ellsworth Air Force Base in South Dakota. We own and operate logistics assets in Washington, including a marine terminal, a unit train-capable rail loading terminal, storage facilities, a truck rack, and a proprietary pipeline that serves McChord Air Force Base. As of December 31, 2019 , we owned a 46.0% equity investment in Laramie Energy, LLC (“ Laramie Energy ”), a joint venture entity operated by Laramie Energy II, LLC (“ Laramie ”). Laramie Energy is focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Principles of Consolidation and Basis of Presentation The consolidated financial statements include the accounts of Par Pacific Holdings, Inc. and its subsidiaries. All intercompany balances and transactions have been eliminated in consolidation. Certain amounts previously reported in our consolidated financial statements for prior periods have been reclassified to conform to the current presentation. Use of Estimates The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”) requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses and the related disclosures. Actual amounts could differ from these estimates. Cash and Cash Equivalents Cash and cash equivalents consist of all highly liquid investments with original maturities of three months or less. The carrying value of cash equivalents approximates fair value because of the short-term nature of these investments. Restricted Cash Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to cash held at commercial banks to support letter of credit facilities and certain ongoing bankruptcy recovery trust claims. Allowance for Doubtful Accounts We establish provisions for losses on trade receivables if it becomes probable that we will not collect all or part of the outstanding balances. We review collectibility and establish or adjust our allowance as necessary using the specific identification method. As of December 31, 2019 and 2018 , we did not have a significant allowance for doubtful accounts. Inventories Commodity inventories, excluding commodity inventories at the Washington refinery, are stated at the lower of cost or net realizable value using the first-in, first-out (“FIFO”) inventory accounting method. Commodity inventories at the Washington refinery are stated at the lower of cost or net realizable value using the last-in, first-out (“LIFO”) inventory accounting method. We value merchandise along with spare parts, materials, and supplies at average cost. As of December 31, 2019 , the excess of current replacement cost over LIFO inventory carrying value at the Washington refinery was approximately $6.4 million . All of the crude oil utilized at the Hawaii refineries is financed by J. Aron & Company LLC (“J. Aron”) under the Supply and Offtake Agreements as described in Note 11—Inventory Financing Agreements . The crude oil remains in the legal title of J. Aron and is stored in our storage tanks governed by a storage agreement. Legal title to the crude oil passes to us at the tank outlet. After processing, J. Aron takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by J. Aron on our behalf as inventory with a corresponding obligation on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we are obligated to repurchase the inventory. In connection with the consummation of the Washington Acquisition (as defined in Note 4—Acquisitions ), we became a party to an intermediation arrangement (the “ Washington Refinery Intermediation Agreement ”) with Merrill Lynch Commodities, Inc. (“ MLC ”) as described in Note 11—Inventory Financing Agreements . Under this arrangement, U.S. Oil (as defined in Note 4—Acquisitions ) purchases crude oil supplied from third-party suppliers and MLC provides credit support for certain crude oil purchases. MLC ’s credit support can consist of either providing a payment guaranty, causing the issuance of a letter of credit from a third party issuing bank, or purchasing crude oil directly from third parties on our behalf. U.S. Oil holds title to all crude oil and refined products inventories at all times and pledges such inventories, together with all receivables arising from the sales of same, exclusively to MLC . We enter into refined product and crude oil exchange agreements with other oil companies. Exchange receivables or payables are stated at cost and are presented within Trade accounts receivable and Accounts payable on our consolidated balance sheets. Renewable Identification Numbers Beginning in 2018, Inventories also include Renewable Identification Numbers (“RINs”) , sulfur credits, and other environmental credits. Our RINs assets, which include RINs purchased in the open market and RINs obtained by purchasing biofuels, which are blended into our refined products, are presented as Inventories on our consolidated balance sheets and stated at the lower of cost or net realizable value (“NRV”) as of the end of the reporting period. Our RINs obligations to comply with the Renewable Fuel Standard (“RFS”) (discussed in Note 16—Commitments and Contingencies ) are presented as Other accrued liabilities on our consolidated balance sheets and measured at fair value as of the end of the reporting period. Our sulfur credits and other environmental credits generated as part of our refining process are presented as Inventories on our consolidated balance sheets and stated at the lower of cost or NRV as of the end of the reporting period. The net cost of environmental credits is recognized within Cost of revenues (excluding depreciation) in our consolidated statements of operations. Investment in Laramie Energy, LLC We account for our Investment in Laramie Energy, LLC using the equity method as we have the ability to exert significant influence, but do not control its operating and financial policies. Our proportionate share of net income (loss) of this entity is included in Equity earnings (losses) from Laramie Energy, LLC in the consolidated statements of operations. The investment is reviewed for impairment when events or changes in circumstances indicate that there may have been an other-than-temporary decline in the value of the investment. During the year ended December 31, 2019, we recorded an impairment charge of $81.5 million on our consolidated statement of operations due to the significant decline in natural gas prices during the second and third quarters of 2019. Please read Note 3—Investment in Laramie Energy, LLC for further information. Property, Plant, and Equipment We capitalize the cost of additions, major improvements, and modifications to property, plant, and equipment. The cost of repairs and normal maintenance of property, plant, and equipment is expensed as incurred. Major improvements and modifications of property, plant, and equipment are those expenditures that either extend the useful life, increase the capacity, or improve the operating efficiency of the asset or the safety of our operations. We compute depreciation of property, plant, and equipment using the straight-line method, based on the estimated useful life of each asset as follows: Assets Lives in Years Refining 5 to 47 Logistics 3 to 30 Retail 3 to 30 Corporate 3 to 7 Software 3 to 5 We review property, plant, and equipment, operating leases, and other long-lived assets for impairment whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset, and a significant change in the asset’s physical condition or use. Lease Assets and Liabilities On January 1, 2019, we adopted Accounting Standards Update (“ASU”) No. 2016-02, Leases (Topic 842) , as amended by other ASUs issued through February 2019 (“ASU 2016-02” or “ASC 842”), using the modified retrospective transition method. Under this optional transition method, information presented prior to January 1, 2019 has not been restated and continues to be reported under the accounting standards in effect for the period. There was no adjustment to our opening retained earnings as a result of the adoption of this ASU. We determine whether a contract is or contains a lease when we have the right to control the use of the identified asset in exchange for consideration. Lease liabilities and right-of-use assets (“ROU assets”) are recognized at the commencement date based on the present value of lease payments over the lease term. We use our incremental borrowing rate in the calculation of present value unless the implicit rate can be readily determined, however, the lease liability associated with leases calculated through the use of implicit rates is not significant. Certain leases include provisions for variable payments based upon percentage of sales and/or other operating metrics; escalation provisions to adjust rental payments to reflect changes in price indices and fair market rents; and provisions for the renewal, termination, and/or purchase of the leased asset. We only consider fixed payments and those options that are reasonably certain to be exercised in the determination of the lease term and the initial measurement of lease liabilities and ROU assets. Expense for finance leases is recognized as amortization expense on a straight-line basis and interest expense on an effective rate basis over the lease term. Expense for operating lease payments is recognized as lease expense on a straight-line basis over the lease term. We do not separate lease and nonlease components of a contract. Leases with an initial term of 12 months or less are not recorded on the balance sheet. Finance lease ROU assets are presented within Property, plant, and equipment and Operating lease ROU assets within Operating lease assets on our consolidated balance sheets. Please read Note 15—Leases for further disclosures and information on leases. Asset Retirement Obligations We record asset retirement obligations (“AROs”) in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the liability. Our AROs arise from our refining, logistics, and retail operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in Depreciation, depletion, and amortization (“DD&A”) on our consolidated statements of operations and the related capitalized cost is depreciated over the asset’s useful life. The difference between the settlement amount and the recorded liability is recorded as a gain or loss on asset disposals in our consolidated statements of operations. We estimate settlement dates by considering our past practice, industry practice, contractual terms, management’s intent, and estimated economic lives. We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos) and removal or dismantlement requirements associated with the closure of our refining facilities, terminal facilities, or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines, or other equipment. Deferred Turnaround Costs Refinery turnaround costs, which are incurred in connection with planned major maintenance activities at our refineries, are deferred and amortized on a straight-line basis over the period of time estimated until the next planned turnaround (generally three to five years ). During 2019 , we recognized deferred turnaround costs of approximately $9.8 million . No deferred turnaround costs were recorded during 2018 and 2017 . Deferred turnaround costs are presented within Other long-term assets on our consolidated balance sheets. Goodwill and Other Intangible Assets Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment annually on October 1. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a quantitative test is required. Under the quantitative test, we compare the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss is recorded. Our intangible assets include relationships with customers, trade names, and trademarks. These intangible assets are amortized over their estimated useful lives on a straight-line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present. When we believe impairment indicators may exist, projections of the undiscounted future cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values. Environmental Matters We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and are presented within Other liabilities on our consolidated balance sheets. Environmental expenses are recorded in Operating expense (excluding depreciation) on our consolidated statements of operations. Derivatives and Other Financial instruments We are exposed to commodity price risk related to crude oil and refined products. We manage this exposure through the use of various derivative commodity instruments. These instruments include exchange traded futures and over-the-counter (“OTC”) swaps, forwards, and options. For our forward contracts that are derivatives, we have elected the normal purchase normal sale exclusion, as it is our policy to fulfill or accept the physical delivery of the product and we will not net settle. Therefore, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. We apply the accrual method of accounting to our forward contracts. All derivative instruments not designated as normal purchases or sales are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of these derivative instruments are recognized currently in earnings. We have not designated any derivative instruments as cash flow or fair value hedges and, therefore, do not apply hedge accounting treatment. In addition, we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Our embedded derivatives include: our obligations to repurchase crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements and to repay MLC for monthly crude oil and refined product financing under the Washington Refinery Intermediation Agreement and the redemption option and the related make-whole premium on our 5.00% Convertible Senior Notes . These liabilities were initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings. Please read Note 13—Derivatives and Note 14—Fair Value Measurements for information regarding our derivatives and other financial instruments. Income Taxes We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss (“NOL”) and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard and, to the extent this threshold is not met, a valuation allowance is recorded. We have determined that any uncertain tax positions outstanding at December 31, 2019 and 2018 would not have a material impact on our financial condition, results of operations, or cash flows as any uncertain tax positions taken would have been fully covered by the Company’s deferred tax assets related to its historical net operating losses and corresponding valuation allowance. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2016 , 2017 , and 2018 . However, since we have NOL carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a NOL deduction is claimed, the IRS may examine the year in which the NOL was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deduction was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed. Stock-Based Compensation We recognize the cost of share-based payments on a straight-line basis over the period the employee provides service, generally the vesting period, and include such costs in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) in the consolidated statements of operations. We account for forfeitures as they occur. The grant date fair value of restricted stock awards is equal to the market price of our common stock on the date of grant. The fair value of stock options is estimated using the Black-Scholes option-pricing model as of the date of grant. The fair value of the discount offered on the employee stock purchase plan is equal to 15% of the market price of our common stock on the purchase date. Revenue Recognition On January 1, 2018, we adopted ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09” or “ASC 606”), as amended by other ASUs, using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. As such, the comparative financial information for prior periods has not been adjusted and continues to be reported under Financial Accounting Standards Board (“FASB”) ASC Topic 605, Revenue Recognition (“ASC 605”). We did not identify any significant differences in our existing revenue recognition policies that require modification under the new standard; therefore, we did not recognize a cumulative adjustment on opening equity as of January 1, 2018. Refining and Retail Our refining and retail segment revenues are primarily associated with the sale of refined products. We recognize revenues upon physical delivery of refined products to a customer, which is the point in time at which control of the refined products is transferred to the customer. The refining segment’s contracts with its customers state the terms of the sale, including the description, quantity, delivery terms, and price of each product sold. Payments from customers are generally due in full within 2 to 30 days of product delivery or invoice date. We account for certain transactions on a net basis under FASB ASC Topic 845, “Nonmonetary Transactions.” These transactions include nonmonetary crude oil and refined product exchange transactions, certain crude oil buy/sell arrangements, and sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another. Upon adoption of ASC 606, we made an accounting policy election to apply the sales tax practical expedient, whereby all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within Cost of revenues (excluding depreciation). This change in our accounting policy did not have a material impact on our consolidated financial information for the years ended December 31, 2019 and 2018. Logistics We recognize transportation and storage fees as services are provided to a customer. Substantially all of our logistics revenues represent intercompany transactions that are eliminated in consolidation. Cost Classifications Cost of revenues (excluding depreciation) includes the hydrocarbon-related costs of inventory sold, transportation costs of delivering product to customers, crude oil consumed in the refining process, costs to satisfy our RINs obligations, and certain hydrocarbon fees and taxes. Cost of revenues (excluding depreciation) also includes the unrealized gains (losses) on derivatives and inventory valuation adjustments. Certain direct operating expenses related to our logistics segment are also included in Cost of revenues (excluding depreciation). Operating expense (excluding depreciation) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, and environmental compliance costs, as well as chemicals and catalysts and other direct operating expenses. The following table summarizes depreciation and finance lease amortization expense excluded from each line item in our consolidated statements of operations (in thousands): Year Ended December 31, 2019 2018 2017 Cost of revenues $ 16,882 $ 6,722 $ 6,029 Operating expense 55,181 28,037 22,861 General and administrative expense 3,145 4,233 2,929 Benefit Plans We recognize an asset for the overfunded status or a liability for the underfunded status of our defined benefit pension plans. The funded status is recorded within Other long-term liabilities. Certain changes in the plans’ funded status are recognized in Other comprehensive income (loss) in the period the change occurs. Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are categorized with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority given to unobservable inputs. The three levels of the fair value hierarchy are as follows: Level 1 – Assets or liabilities for which the item is valued based on quoted prices (unadjusted) for identical assets or liabilities in active markets. Level 2 – Assets or liabilities valued based on observable market data for similar instruments. Level 3 – Assets or liabilities for which significant valuation assumptions are not readily observable in the market; instruments valued based on the best available data, some of which is internally-developed and considers risk premiums that a market participant would require. The level in the fair value hierarchy within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. Our policy is to recognize transfers in and/or out of fair value hierarchy levels as of the end of the reporting period for which the event or change in circumstances caused the transfer. We have consistently applied these valuation techniques for the periods presented. The fair value of the J. Aron repurchase obligation derivative is measured using estimates of the prices and differentials assuming settlement at the end of the reporting period. Income (Loss) Per Share Basic income (loss) per share (“EPS”) is computed by dividing net income (loss) attributable to common stockholders by the sum of the weighted-average number of common shares outstanding and the weighted-average number of shares issuable under the warrants. The common stock warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Basic and diluted EPS are computed taking into account the effect of participating securities. Participating securities include restricted stock that has been issued but has not yet vested. Please read Note 19—Income (Loss) Per Share for further information. Foreign Currency Transactions We may, on occasion, enter into transactions denominated in currencies other than the U.S. dollar, which is our functional currency. Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in Other income (expense), net , in the accompanying consolidated statement of operations in the period in which the currency exchange rates change. Accounting Principles Not Yet Adopted In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“ASU 2016-13”). This ASU requires expected credit losses on financial instruments to be recorded over the estimated life of the financial instrument. Prior to this ASU, the guidance required recording of credit losses when those losses were incurred. ASU 2016-13 is applicable to credit losses and allowances on loans, debt securities, trade receivables, net investments in leases, off-balance-sheet credit exposures, reinsurance receivables, and certain other financial assets, but excludes derivative assets under FASB ASC Topic 815 “Derivatives and Hedging.” The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted, and primarily requires adoption on the modified retrospective transition method. On January 1, 2020, we adopted this ASU and our adoption did not have a material impact on our financial condition, results of operations, cash flows, or related disclosures. In January 2017, the FASB issued ASU No. 2017-04, Intangibles—Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment (“ASU 2017-04”), which eliminates Step 2 from the current goodwill impairment test. Under ASU 2017-04, an entity is no longer required to determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if that reporting unit had been acquired in a business combination. Under ASU 2017-04, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. This ASU should be applied prospectively from the date of adoption. This ASU will change the policy under which we perform our annual goodwill impairment assessment by eliminating Step 2 of the test. In August 2018, the FASB issued ASU No. 2018-13, Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement ( “ ASU 2018-13”). This ASU amends, adds, and removes certain disclosure requirements under FASB ASC Topic 820 “Fair Value Measurement.” The guidance in ASU 2018-13 is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. This ASU will result in expanded disclosures within our interim and annual footnote disclosures, however, we do not expect the adoption of ASU 2018-13 to have a material impact on our financial condition, results of operations, or cash flows. In August 2018, the FASB issued ASU No. 2018-14, Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans ( “ ASU 2018-14”). This ASU amends, adds, and removes certain disclosure requirements under FASB ASC Topic 715 “Compensation — Retirement Benefits.” The guidance in ASU 2018-14 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. This ASU will result in expanded disclosures within our interim and annual footnote disclosures, however, we do not expect the adoption of ASU 2018-14 to have a material impact on our financial condition, results of operations, or cash flows. In August 2018, the FASB issued ASU No. 2018-15, Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract ( “ ASU 2018-15”). This ASU requires entities to account for implementation costs incurred in a cloud computing agreement that is a service contract under the guidance in FASB ASC Topic 350, “Goodwill and Intangible Assets,” which results in a capitalized and amortizable intangible asset. The guidance in ASU 2018-15 is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. On January 1, 2020, we adopted ASU 2018-15 under the prospective method and information that was presented prior to January 1, 2020 has not been restated and continues to be reported under the accounting standards in effect for that period. The adoption of ASU 2018-15 did not have a material impact on our financial condition, results of operations, or cash flows. In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes ( “ ASU 2019-12”). The objective of ASU 2019-12 is to simplify the accounting for income taxes by removing certain exceptions to general principles and to clarify and amend guidance to improve consistency under FASB ASC 740 “Income Taxes.” The guidance in ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. We are in the process of determining the method(s) of adoption and the impact this guidance will have on our financial condition, results of operations, and cash flows. Accounting Principles Adopted On January 1, 2019, we adopted ASU No. 2016-02, Leases (Topic 842) , as amended by other ASUs issued through February 2019 (“ASU 2016-02” or “ASC 842”), using the modified retrospective transition method. Under this optional transition method, information presented prior to January 1, 2019 has not been restated and continues to b

Investment in Laramie Energy, L

Investment in Laramie Energy, LLC	12 Months Ended
	Dec. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Investment in Laramie Energy, LLC	Investment in Laramie Energy, LLC As of December 31, 2019 , we owned a 46.0% ownership interest in Laramie Energy, a joint venture entity focused on developing and producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado. Laramie Energy has a $400 million revolving credit facility secured by a lien on its natural gas and crude oil properties and related assets with a borrowing base currently set at $220 million . As of December 31, 2019 and 2018 , the balance outstanding on the revolving credit facility was approximately $201.2 million and $210.8 million , respectively. We are guarantors of Laramie Energy ’s credit facility, with recourse limited to the pledge of our equity interest in our wholly owned subsidiary, Par Piceance Energy Equity, LLC. Under the terms of its credit facility, Laramie Energy is generally prohibited from making future cash distributions to its owners, including us. Laramie Energy ’s credit facility matures on December 15, 2020. During the fourth quarter of 2019, Laramie Energy recorded an impairment loss of $355.2 million associated with the carrying value of proved reserves. As a result of Laramie Energy ’s impairment loss and the liquidity impact associated with the maturity of the revolving credit facility in December 2020, we updated the impairment evaluation of our investment in Laramie Energy as of December 31, 2019. The fair value estimate was determined using a discounted cash flow analysis based on reserves volumes and natural gas forward strip prices as of December 31, 2019. Based on our evaluation, we determined that the estimated fair value of our investment in Laramie Energy approximates carrying value as of December 31, 2019. At September 30, 2019, we conducted an impairment evaluation of our investment in Laramie Energy because of the significant decline in natural gas prices over the second quarter of 2019 and continued deterioration in the third quarter of 2019. Based on our evaluation, we determined that the estimated fair value of our investment in Laramie Energy was $51.8 million , compared to a carrying value of $133.3 million at September 30, 2019. The fair value estimate was determined using a discounted cash flow analysis based on natural gas forward strip prices as of September 30, 2019 for two years through December 31, 2021. A blend of 2021 forward strip pricing and third-party analyst pricing was used for years after 2021 through December 31, 2028. Other significant inputs used in the discounted cash flow analysis included proved and unproved reserves information, forecasts of operating expenditures, and the applicable discount rate. As part of our evaluation, we considered the likelihood that Colorado Interstate Gas (CIG) prices, which have declined from an average spot price of $2.48 ($/MMBtu) in the first quarter of 2019, to $1.84 ($/MMBtu) in the second quarter of 2019 and $1.77 ($/MMBtu) in the third quarter of 2019, will recover in the near term. Based on this significant decline in natural gas prices and the reduced likelihood that natural gas prices would recover in the near term, we concluded that the decline in the fair value of our investment in Laramie Energy was other than temporary. As a result, we recorded an impairment charge of $81.5 million in Equity earnings (losses) from Laramie Energy, LLC on our statement of operations for the year ended December 31, 2019. On March 4, 2019, Laramie entered into a binding agreement to divest an insignificant amount of producing property for approximately $17.5 million . This divestiture did not result in a change in our ownership percentage. On October 18, 2018 , Laramie Energy repurchased 138,795 of its Class A Units from certain unitholders for an aggregate purchase price of $14.8 million . As a result of this transaction, our ownership interest in Laramie Energy increased from 39.1% to 46.0% . On February 28, 2018 , Laramie Energy closed on a purchase and contribution agreement with an unaffiliated third party that contributed all of its oil and gas properties located in the Piceance Basin and a $20.0 million cash payment, collectively with a fair market value of $28.1 million , into Laramie Energy in exchange for 70,227 of Laramie Energy ’s newly issued Class A Units. The unaffiliated third party also contributed a $3.5 million cash payment for asset reclamation liabilities related to the properties conveyed. As a result of this transaction, our ownership interest in Laramie Energy decreased from 42.3% to 39.1% . The change in our equity investment in Laramie Energy is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Beginning balance $ 136,656 $ 127,192 $ 108,823 Equity earnings (losses) from Laramie Energy (175,018 ) 4,487 13,043 Accretion of basis difference 5,018 4,977 5,326 Adjustment of basis difference (1) 161,764 — — Impairment of our investment in Laramie Energy (81,515 ) — — Ending balance $ 46,905 $ 136,656 $ 127,192 ________________________________________________________ (1) Represents the reduction in our basis difference resulting from the asset impairment loss recorded by Laramie Energy for the year ended December 31, 2019. Summarized financial information for Laramie Energy is as follows (in thousands): December 31, 2019 2018 Current assets $ 23,367 $ 28,569 Non-current assets 393,575 788,515 Current liabilities 229,687 41,681 Non-current liabilities 85,287 293,084 Year Ended December 31, 2019 2018 2017 Natural gas and oil revenues $ 193,906 $ 226,974 $ 157,879 Income (loss) from operations (360,967 ) 34,206 6,019 Net income (loss) (380,473 ) 6,347 30,837 Laramie Energy’s net loss for the year ended December 31, 2019 includes an asset impairment loss of $355.2 million . Laramie Energy’s net loss for the year ended December 31, 2019 also includes $82.6 million and $4.3 million of DD&A expense and unrealized gains on derivative instruments, respectively. Laramie Energy’s net loss for the year ended December 31, 2019 also includes an asset impairment loss of $355.2 million . Laramie Energy’s net income for the year ended December 31, 2018 includes $66.6 million and $4.1 million of DD&A expense and unrealized losses on derivative instruments, respectively. Laramie Energy’s net income for the year ended December 31, 2017 includes $50.3 million and $46.2 million of DD&A expense and unrealized gains on derivative instruments, respectively. At September 30, 2019, our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $161.8 million . This difference arose primarily due to other-than-temporary impairments of our equity investment in Laramie Energy. As a result of Laramie Energy ’s $355.2 million impairment loss associated with the carrying value of proved reserves, there was no difference between our equity in the underlying net assets of Laramie Energy

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Acquisitions	Acquisitions Washington Acquisition On November 26, 2018 , we entered into a Purchase and Sale Agreement to acquire U.S. Oil & Refining Co. and certain affiliated entities (collectively, “ U.S. Oil ”), a privately-held downstream business (the “ Washington Acquisition ”). The Washington Acquisition included a 42 Mbpd refinery, a marine terminal, a unit train-capable rail loading terminal, and 2.9 MMbbls of refined product and crude oil storage. The refinery and associated logistics system are strategically located in Tacoma, Washington, and currently serve the Pacific Northwest market. On January 11, 2019 , we completed the Washington Acquisition for a total purchase price of $326.5 million , including acquired working capital, consisting of cash consideration of $289.5 million and approximately 2.4 million shares of Par’s common stock with a fair value of $37.0 million issued to the seller of U.S. Oil. The cash consideration was funded in part through cash on hand, proceeds from borrowings under a new term loan facility entered into with Goldman Sachs Bank USA, as administrative agent, of $250.0 million (the “ Term Loan B ”) and proceeds from borrowings under a term loan from the Bank of Hawaii of $45.0 million (the “ Par Pacific Term Loan ”). Please read Note 12—Debt for further information on the Term Loan B and Par Pacific Term Loan . During December 2018 and January 2019, we incurred $4.2 million and $5.4 million of commitment fees associated with the funding of the Washington Acquisition , respectively. Such commitment fees are presented as Debt extinguishment and commitment costs on our consolidated statements of operations for the years ended December 31, 2019 and 2018. In connection with the consummation of the Washington Acquisition , we assumed the Washington Refinery Intermediation Agreement with MLC that provides a structured financing arrangement based on U.S. Oil ’s crude oil and refined products inventories and associated accounts receivable. Please read Note 11—Inventory Financing Agreements for further information on the Washington Refinery Intermediation Agreement . We accounted for the Washington Acquisition as a business combination whereby the purchase price is allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of the acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with those of the Washington refinery and the utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. Goodwill recognized as a result of the Washington Acquisition is not expected to be deductible for income tax reporting purposes. A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 16,146 Accounts receivable 34,954 Inventories 98,367 Prepaid and other assets 5,320 Property, plant, and equipment 412,766 Operating lease assets 62,337 Goodwill (1) 42,522 Total assets (2) 672,412 Obligations under inventory financing agreements (116,873 ) Accounts payable (55,357 ) Current operating lease liabilities (21,571 ) Other current liabilities (18,411 ) Long-term operating lease liabilities (40,766 ) Deferred tax liability (92,103 ) Other non-current liabilities (804 ) Total liabilities (345,885 ) Total $ 326,527 ______________________________________________ (1) We allocated $24.7 million and $17.8 million of goodwill to our refining and logistics segments, respectively. (2) We allocated $403.9 million and $268.5 million of total assets to our refining and logistics segments, respectively. During the period from March 31, 2019 to December 31, 2019 , the purchase price allocation was adjusted to record an increase in the property, plant, and equipment valuation of $2.1 million , a decrease in the deferred tax liability of $3.7 million , and a net decrease in working capital adjustments of $1.8 million . Goodwill decreased $4.0 million as a result of these adjusting entries. As of December 31, 2019, we finalized the Washington Acquisition purchase price allocation. We incurred $2.2 million and $2.6 million of acquisition costs related to the Washington Acquisition for the years ended December 31, 2019 and 2018, respectively. These costs are included in Acquisition and integration costs on our consolidated statements of operations. The results of operations of U.S. Oil were included in our results beginning on January 11, 2019 . For the year ended December 31, 2019 , our results of operations included revenues of $1.2 billion and income before income taxes of $65.8 million related to U.S. Oil . The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the Washington Acquisition had been completed on January 1, 2018 (in thousands except per share information): Year Ended December 31, 2019 2018 Revenues $ 5,429,530 $ 4,709,850 Net income (loss) (4,547 ) 88,174 Income (loss) per share Basic $ (0.09 ) $ 1.81 Diluted $ (0.09 ) $ 1.79 These pro forma results were based on estimates and assumptions that we believe are reasonable. They are not necessarily indicative of our consolidated results of operations in future periods or the results that actually would have been realized had we been a combined company during the periods presented. The pro forma results for the years ended December 31, 2019 and 2018 include adjustments to remeasure U.S. Oil ’s LIFO inventory reserve as if the Washington Acquisition had been completed on January 1, 2018, record interest and other debt extinguishment costs related to issuance of the Term Loan B and Par Pacific Term Loan , and adjust U.S. Oil ’s historical depreciation expense as a result of the fair value adjustment to Property, plant, and equipment, net. The pro forma results for the year ended December 31, 2019 also include an adjustment to eliminate the $64.2 million tax benefit associated with a partial release of our valuation allowance in connection with the Washington Acquisition . Par West Acquisition On August 29, 2018 , we entered into a Topping Unit Purchase Agreement with IES Downstream, LLC (“ IES ”) to purchase certain of IES ’s refining units and related assets in addition to certain hydrocarbon and non-hydrocarbon inventory (collectively, the “ Par West Acquisition ”). On December 19, 2018 , we completed the asset purchase for total consideration of approximately $66.9 million , net of a $4.3 million receivable related to net working capital adjustments. The purchase price consisted of $47.6 million in cash and approximately 1.1 million shares of our common stock with a fair value of $19.3 million . We accounted for the Par West Acquisition as an asset acquisition whereby the purchase price was allocated entirely to the assets acquired. Of the total purchase price of $66.9 million , $45.2 million was allocated to property, plant, and equipment, $4.3 million to non-hydrocarbon inventory, and $17.4 million to hydrocarbon inventory. With the completion of the Par West Acquisition , we now have two refineries in Hawaii that are approximately two miles from one another: Par East, our legacy refinery assets, and Par West, the recently-acquired assets. We incurred $5.7 million of acquisition costs related to the Par West Acquisition for the year ended December 31, 2018. These costs are included in Acquisition and integration costs on our consolidated statement of operations. Northwest Retail Acquisition On January 9, 2018 , we entered into an Asset Purchase Agreement with CHS, Inc. to acquire twenty-one ( 21 ) owned retail gasoline, convenience store facilities and twelve ( 12 ) leased retail gasoline, convenience store facilities, all at various locations in Washington and Idaho (collectively, “ Northwest Retail ”). On March 23, 2018 , we completed the acquisition for cash consideration of approximately $74.5 million (the “ Northwest Retail Acquisition ”). As part of the Northwest Retail Acquisition , Par and CHS, Inc. entered into a multi-year branded petroleum marketing agreement for the continued supply of Cenex® -branded refined products to the acquired Cenex® Zip Trip convenience stores. In addition, the parties also entered into a multi-year supply agreement pursuant to which Par supplies refined products to CHS, Inc. within the Rocky Mountain and Pacific Northwest markets. We accounted for the acquisition of Northwest Retail as a business combination whereby the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Northwest Retail and utilization of our net operating loss carryforwards, as well as intangible assets that do not qualify for separate recognition. Goodwill recognized as a result of the Northwest Retail Acquisition is expected to be deductible for income tax reporting purposes. A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 200 Inventories 4,138 Prepaid and other current assets 243 Property, plant, and equipment 30,230 Goodwill (1) 46,210 Accounts payable and other current liabilities (759 ) Long-term capital lease obligations (5,244 ) Other non-current liabilities (487 ) Total $ 74,531 ________________________________________________________ (1) The total goodwill balance of $46.2 million was allocated to our retail segment. As of December 31, 2018, we finalized the Northwest Retail Acquisition purchase price allocation. We incurred $0.6 million of acquisition costs related to the Northwest Retail Acquisition for the year ended December 31, 2018. These costs are included in Acquisition and integration costs on our consolidated statement of operations.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition As of December 31, 2019 and 2018 , receivables from contracts with customers were $214.5 million and $148.4 million , respectively. Our refining segment recognizes deferred revenues when cash payments are received in advance of delivery of products to the customer. Deferred revenue was $7.9 million and $6.7 million as of December 31, 2019 and 2018 , respectively. We have elected to apply a practical expedient not to disclose the value of unsatisfied performance obligations for (i) contracts with an original expected duration of less than one year and (ii) contracts where the variable consideration has been allocated entirely to our unsatisfied performance obligation. The following table provides information about disaggregated revenue by major product line and includes a reconciliation of the disaggregated revenues to total segment revenues (in thousands): Year Ended December 31, 2019 Refining Logistics Retail Product or service: Gasoline $ 1,416,706 $ — $ 326,304 Distillates (1) 2,503,981 — 40,189 Other refined products (2) 1,242,401 — — Merchandise — — 90,480 Transportation and terminalling services — 199,226 — Other revenue 4,854 — 1,916 Total segment revenues (3) $ 5,167,942 $ 199,226 $ 458,889 Year Ended December 31, 2018 Refining Logistics Retail Product or service: Gasoline $ 981,090 $ — $ 317,434 Distillates (1) 1,770,381 — 39,835 Other refined products (2) 458,596 — — Merchandise — — 83,771 Transportation and terminalling services — 125,743 — Total segment revenues (3) $ 3,210,067 $ 125,743 $ 441,040 _______________________________________________________ (1) Distillates primarily include diesel and jet fuel. (2) Other refined products include fuel oil, gas oil, asphalt, and naphtha. (3) Refer to Note 21—Segment Information

Inventories

Inventories	12 Months Ended
	Dec. 31, 2019
Inventory Disclosure [Abstract]
Inventories	Inventories Inventories at December 31, 2019 and 2018 consisted of the following (in thousands): Titled Inventory Supply and Offtake Agreements (1) Total December 31, 2019 Crude oil and feedstocks $ 117,717 $ 148,303 $ 266,020 Refined products and blendstock 127,966 158,737 286,703 Warehouse stock and other (2) 63,149 — 63,149 Total $ 308,832 $ 307,040 $ 615,872 December 31, 2018 Crude oil and feedstocks $ 7,000 $ 117,877 $ 124,877 Refined products and blendstock 62,401 100,175 162,576 Warehouse stock and other (2) 34,612 — 34,612 Total $ 104,013 $ 218,052 $ 322,065 _________________________________________________________ (1) Please read Note 11—Inventory Financing Agreements for further information. (2) Includes $19.1 million and $5.0 million of RINs and environmental credits as of December 31, 2019 and 2018 , respectively. As of December 31, 2019 , there was no reserve for the lower of cost or net realizable value of inventory. As of December 31, 2018 , there was a $3.8 million reserve for the lower of cost or net realizable value of inventory. As of December 31, 2019 , the excess of current replacement cost over the LIFO inventory carrying value at the Washington refinery was approximately $6.4 million .

Prepaid and Other Current Asset

Prepaid and Other Current Assets	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid and Other Current Assets	Prepaid and Other Current Assets Prepaid and other current assets at December 31, 2019 and 2018 consisted of the following (in thousands): December 31, 2019 2018 Advances to suppliers $ 27,635 $ — Collateral posted with broker for derivative instruments (1) 10,306 2,759 Prepaid insurance 13,536 7,727 Derivative assets 2,075 5,164 Other 5,604 12,720 Total $ 59,156 $ 28,370 _________________________________________________________ (1) Our cash margin that is required as collateral deposits on our commodity derivatives cannot be offset against the fair value of open contracts except in the event of default. Please read Note 13—Derivatives for further information.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant, and Equipment Major classes of property, plant, and equipment, including assets acquired under finance leases, consisted of the following (in thousands): December 31, 2019 2018 Land $ 188,096 $ 117,559 Buildings and equipment (1) 937,926 512,870 Other (1) 20,961 18,939 Total property, plant, and equipment 1,146,983 649,368 Proved oil and gas properties — 400 Less accumulated depreciation, depletion, and amortization (185,040 ) (111,507 ) Property, plant, and equipment, net $ 961,943 $ 538,261 ______________________________________________________ (1) Please read Note 15—Leases for further disclosures and information on leases. Depreciation and finance lease amortization expense was approximately $75.2 million , $39.0 million , and $31.8 million for the years ended December 31, 2019 , 2018 , and 2017 , respectively.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The table below summarizes the changes in our recorded asset retirement obligations (in thousands): Year Ended December 31, 2019 2018 2017 Beginning balance $ 9,985 $ 9,103 $ 9,042 Obligations acquired — 487 — Accretion expense 331 395 369 Liabilities settled during period (136 ) — (308 ) Ending balance $ 10,180 $ 9,985 $ 9,103

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	Goodwill and Intangible Assets During the years ended December 31, 2019 and 2018 , the change in the carrying amount of goodwill was as follows (in thousands): Balance at January 1, 2018 $ 107,187 Acquisition of Northwest Retail (1) 46,210 Balance at December 31, 2018 153,397 Acquisition of U.S. Oil (1) 42,522 Balance at December 31, 2019 $ 195,919 ________________________________________________________ (1) Please read Note 4—Acquisitions for further discussion. Intangible assets consisted of the following (in thousands): December 31, 2019 2018 Intangible assets: Trade names and trademarks $ 6,267 $ 6,267 Customer relationships 32,064 32,064 Other 261 — Total intangible assets 38,592 38,331 Accumulated amortization: Trade name and trademarks (5,124 ) (5,037 ) Customer relationships (11,919 ) (9,347 ) Other — — Total accumulated amortization (17,043 ) (14,384 ) Net: Trade name and trademarks 1,143 1,230 Customer relationships 20,145 22,717 Other 261 — Total intangible assets, net $ 21,549 $ 23,947 Amortization expense was approximately $2.7 million , $2.7 million , and $3.3 million for the years ended December 31, 2019 , 2018 , and 2017 , respectively. Our intangible assets related to customer relationships and trade names have an average useful life of 13.5 years . Expected amortization expense for each of the next five years and thereafter is as follows (in thousands): Year Ended Amount 2020 $ 2,658 2021 2,658 2022 2,658 2023 2,658 2024 1,400 Thereafter 9,517 $ 21,549

Inventory Financing Agreements

Inventory Financing Agreements	12 Months Ended
	Dec. 31, 2019
Other Commitments [Abstract]
Inventory Financing Agreements	Inventory Financing Agreements Supply and Offtake Agreements On June 1, 2015, we entered into several agreements with J. Aron to support the operations of our Hawaii refineries (the “Supply and Offtake Agreements”). The Supply and Offtake Agreements mature on May 31, 2021 and have a one -year extension option upon mutual agreement of the parties. Under the Supply and Offtake Agreements, J. Aron may enter into agreements with third parties whereby J. Aron will remit payments to these third parties for refinery procurement contracts for which we will become immediately obligated to reimburse J. Aron. As of December 31, 2019 , we had no obligations due to J. Aron under this contractual undertakings agreement. On December 21, 2017, in connection with the issuance of the 7.75% Senior Secured Notes , we amended and restated the Supply and Offtake Agreements to update the terms of the collateral. On June 27, 2018 , we and J. Aron amended the Supply and Offtake Agreements to increase the amount that we may defer under the deferred payment arrangement. Prior to June 27, 2018 , we had the right to defer payments owed to J. Aron up to the lesser of $125 million or 85% of eligible accounts receivable and inventory. Effective June 27, 2018 , we have the right to defer payments owed to J. Aron up to the lesser of $165 million or 85% of eligible accounts receivable and inventory. On December 5, 2018 , we amended the Supply and Offtake Agreements to account for additional processing capacity expected to be provided through the Par West Acquisition . The December 5, 2018 amendment to the Supply and Offtake Agreements also (i) required us to increase our margin requirements by an aggregate $2.5 million by making certain additional margin payments on December 19, 2018 , March 1, 2019 , and June 3, 2019 , and (ii) only allows dividends, payments, or other distributions with respect to any equity interests in Par Hawaii Refining, LLC (“PHR”) in limited and restricted circumstances. During the term of the Supply and Offtake Agreements, J. Aron and we will identify mutually acceptable contracts for the purchase of crude oil from third parties. Per the Supply and Offtake Agreements, J. Aron will provide up to 150 Mbpd of crude oil to our Hawaii refineries . Additionally, we agreed to sell and J. Aron agreed to buy, at market prices, refined products produced at our Hawaii refineries . We will then repurchase the refined products from J. Aron prior to selling the refined products to our retail operations or to third parties. The agreements also provide for the lease of crude oil and certain refined product storage facilities to J. Aron. Following the expiration or termination of the Supply and Offtake Agreements, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at the leased storage facilities at then-current market prices. Though title to the crude oil and certain refined product inventories resides with J. Aron, the Supply and Offtake Agreements are accounted for similar to a product financing arrangement; therefore, the crude oil and refined products inventories will continue to be included on our consolidated balance sheets until processed and sold to a third party. Each reporting period, we record a liability in an amount equal to the amount we expect to pay to repurchase the inventory held by J. Aron based on current market prices. For the years ended December 31, 2019 , 2018 , and 2017 , we incurred approximately $35.5 million , $21.5 million , and $13.7 million , respectively, of inventory intermediation fees related to the Supply and Offtake Agreements, which are included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. For the years ended December 31, 2019 , 2018 , and 2017 , Interest expense and financing costs, net on our consolidated statements of operations includes approximately $5.9 million , $4.5 million , and $2.3 million of expenses related to the Supply and Offtake Agreements, respectively. The Supply and Offtake Agreements also include a deferred payment arrangement (“Deferred Payment Arrangement”) whereby we can defer payments owed under the agreements up to the lesser of $165 million or 85% of the eligible accounts receivable and inventory. Upon execution of the Supply and Offtake Agreements, we paid J. Aron a deferral arrangement fee of $1.3 million . The deferred amounts under the Deferred Payment Arrangement bear interest at a rate equal to three-month LIBOR plus 3.50% per annum. We also agreed to pay a deferred payment availability fee equal to 0.75% of the unused capacity under the Deferred Payment Arrangement. Amounts outstanding under the Deferred Payment Arrangement are included in Obligations under inventory financing agreements on our consolidated balance sheets. Changes in the amount outstanding under the Deferred Payment Arrangement are included within Cash flows from financing activities on the consolidated statements of cash flows. As of December 31, 2019 and 2018 , the capacity of the Deferred Payment Arrangement was $155.5 million and $77.4 million , respectively, and we had $97.5 million and $68.4 million outstanding, respectively. Under the Supply and Offtake Agreements, we pay or receive certain fees from J. Aron based on changes in market prices over time. In February 2016, we fixed the market fee for the period from December 1, 2016 through May 31, 2018 for $14.6 million to be settled in eighteen equal monthly payments. In 2017, we fixed the market fee for the period from June 1, 2018 through May 2021 for an additional $2.2 million . The receivable from J. Aron was recorded as a reduction to our Obligations under inventory financing agreements pursuant to our Master Netting Agreement. As of December 31, 2019 and 2018 , the receivable was $0.5 million and $2.5 million , respectively. Washington Refinery Intermediation Agreement In connection with the consummation of the Washington Acquisition , we became a party to the Washington Refinery Intermediation Agreement with MLC that provides a structured financing arrangement based on U.S. Oil ’s crude oil and refined products inventories and associated accounts receivable. Under this arrangement, U.S. Oil purchases crude oil supplied from third-party suppliers and MLC provides credit support for such crude oil purchases. MLC ’s credit support can consist of either providing a payment guaranty, causing the issuance of a letter of credit from a third-party issuing bank, or purchasing crude oil directly from third parties on our behalf. U.S. Oil holds title to all crude oil and refined products inventories at all times and pledges such inventories, together with all receivables arising from the sales of same, exclusively to MLC . On November 1, 2019 , we and MLC amended the Washington Refinery Intermediation Agreement and extended the term through June 30, 2021 , with an option for us to early terminate as early as March 31, 2021 . During the remaining term of the Washington Refinery Intermediation Agreement , MLC will make receivable advances to U.S. Oil based on an advance rate of 95% of eligible receivables, up to a total receivables advance maximum of $90.0 million (the “ MLC receivable advances ”), and additional advances based on crude oil and products inventories. Changes in the amount outstanding under the MLC receivable advances are included within Cash flows from financing activities on the consolidated statements of cash flows. The MLC receivable advances bear interest at a rate equal to three -month LIBOR plus 3.25% per annum. We also agreed to pay an availability fee equal to 1.50% of the unused capacity under the MLC receivable advances. As part of the November 1, 2019 amendment, the availability fee was amended to equal 0.75% of the unused capacity under the MLC receivable advances . As of December 31, 2019 , our outstanding balance under MLC receivable advances was equal to our borrowing base of $63.8 million . Additionally, as of December 31, 2019 , we had approximately $127.2 million in letters of credit outstanding through MLC ’s credit support. For the year ended December 31, 2019 , we incurred approximately $3.7 million of inventory intermediation fees related to the Washington Refinery Intermediation Agreement which are included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. For the year ended December 31, 2019 , Interest expense and financing costs, net on our consolidated statements of operations includes approximately $6.4 million of expenses related to the Washington Refinery Intermediation Agreement . The Supply and Offtake Agreements and the Washington Refinery Intermediation Agreement also provide us with the ability to economically hedge price risk on our inventories and crude oil purchases. Please read Note 13—Derivatives for further information.

Debt

Debt	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Debt	Debt The following table summarizes our outstanding debt (in thousands): December 31, 2019 2018 5.00% Convertible Senior Notes due 2021 $ 48,665 $ 115,000 7.75% Senior Secured Notes due 2025 300,000 300,000 ABL Credit Facility — — Mid Pac Term Loan 1,433 1,466 Term Loan B 240,625 — Retail Property Term Loan 44,014 — Principal amount of long-term debt 634,737 416,466 Less: unamortized discount and deferred financing costs (22,806 ) (23,826 ) Total debt, net of unamortized discount and deferred financing costs 611,931 392,640 Less: current maturities, net of unamortized discount and deferred financing costs (12,297 ) (33 ) Long-term debt, net of current maturities $ 599,634 $ 392,607 Annual maturities of our long-term debt for the next five years and thereafter are as follows (in thousands): Year Ended Amount Due 2020 $ 14,054 2021 62,785 2022 14,187 2023 14,259 2024 50,080 Thereafter 479,372 Total $ 634,737 Additionally, as of December 31, 2019 and 2018 , we had approximately $0.2 million and $13.5 million in letters of credit outstanding under the ABL Credit Facility , respectively. As of December 31, 2019 , we also had $3.6 million in cash-collateralized letters of credit and surety bonds outstanding. Under the ABL Credit Facility , the indenture governing the 7.75% Senior Secured Notes and the Term Loan B Facility , our subsidiaries are restricted from paying dividends or making other equity distributions, subject to certain exceptions. 7.75% Senior Secured Notes Due 2025 On December 21, 2017 , Par Petroleum, LLC and Par Petroleum Finance Corp. (collectively, the “Issuers”), both our wholly owned subsidiaries, completed the issuance and sale of $300 million in aggregate principal amount of 7.75% Senior Secured Notes in a private placement under Rule 144A and Regulation S of the Securities Act of 1933, as amended. The net proceeds of $289.2 million (net of financing costs and original issue discount of 1% ) from the sale were used to repay the Hawaii Retail Credit Facilities , the Wyoming Refining Credit Facilities , the Par Wyoming Holdings Credit Agreement , and the J. Aron Forward Sale , and for general corporate purposes. The 7.75% Senior Secured Notes bear interest at a rate of 7.750% per year beginning December 21, 2017 (payable semi-annually in arrears on June 15 and December 15 of each year, beginning on June 15, 2018) and will mature on December 15, 2025 . The indenture governing the 7.75% Senior Secured Notes contains restrictive covenants limiting the ability of Par Petroleum, LLC and its Restricted Subsidiaries (as defined in the indenture) to, among other things, incur additional indebtedness, issue certain preferred shares, create liens on certain assets to secure debt, sell or otherwise dispose of all or substantially all assets, or pay dividends. The 7.75% Senior Secured Notes are secured on a pari passu basis by first priority liens (subject to the relative priority of permitted liens) on substantially all of the property and assets of the Issuers and the subsidiary guarantors, including but not limited to, material real property now owned or hereafter acquired by the Issuers or subsidiary guarantors and their equipment, intellectual property, and equity interests, but excluding certain property which is collateral under the ABL Credit Facility , the Supply and Offtake Agreements, and the Washington Refinery Intermediation Agreement . The 7.75% Senior Secured Notes are fully and unconditionally guaranteed on a senior secured basis, jointly and severally, by each of Par Petroleum, LLC ’s existing wholly owned subsidiaries (other than Par Petroleum Finance Corp.), and are guaranteed on a senior unsecured basis only as to the payment of principal and interest by Par Pacific Holdings, Inc. In the future, the 7.75% Senior Secured Notes will be guaranteed on a senior secured basis by additional subsidiaries of Par Petroleum, LLC that guarantee material indebtedness of the Issuers or otherwise become obligated with respect to material indebtedness under a credit facility, subject to certain exceptions. ABL Credit Facility On December 21, 2017 , in connection with the issuance of the 7.75% Senior Secured Notes , Par Petroleum, LLC , Par Hawaii, LLC (“ PHL ”, formerly known as Par Hawaii, Inc. and includes the assets previously owned by the dissolved entities Mid Pac Petroleum, LLC and HIE Retail, LLC ), Hermes Consolidated, LLC, and Wyoming Pipeline Company (collectively, the “ ABL Borrowers ”), entered into a Loan and Security Agreement dated as of December 21, 2017 (the “ ABL Credit Facility ”) with certain lenders and Bank of America, N.A., as administrative agent and collateral agent. The ABL Credit Facility provides for a revolving credit facility that provides for revolving loans and for the issuance of letters of credit (the “ ABL Revolver ”). On July 24, 2018 , we amended the ABL Credit Facility to increase the maximum principal amount at any time outstanding of the ABL Revolver by $10 million to $85 million , subject to a borrowing base. As of December 31, 2019 , the ABL Revolver had no outstanding balance and a borrowing base of approximately $57.6 million . The revolving loans under the ABL Revolver bear interest at a fluctuating rate per annum equal to (i) during the periods such revolving loan is a base rate loan, the base rate plus the applicable margin in effect from time to time, and (ii) during the periods such revolving loan is a LIBOR Loan, at LIBOR for the applicable interest period plus the applicable margin in effect from time to time. The base rate is equal to (i) daily LIBOR (“LIBOR Daily Floating Rate”) or (ii) if the LIBOR Daily Floating Rate is unavailable for any reason, a rate as calculated per the agreement (the “Prime Rate”) for such day. We also pay a de minimis fee for any undrawn amounts available under the ABL Revolver . The maturity date of the ABL Revolver is December 21, 2022 , on which date all revolving loans will be due and payable in full. The average effective interest rate for 2019 on the ABL Revolver loan was 4.3% . The applicable margins for the ABL Credit Facility and advances under the ABL Revolver are as specified below: Level Arithmetic Mean of Daily Availability (as a percentage of the borrowing base) Applicable Margin for Applicable Margin for 1 >50% 1.75% 0.75% 2 >30% but ≤ 50% 2.00% 1.00% 3 ≤ 30% 2.25% 1.25% The obligations of the ABL Borrowers are guaranteed by Par and Par Petroleum, LLC ’s existing and future direct or indirect domestic subsidiaries that are not borrowers under the ABL Credit Facility . The loans and letters of credit issued under the ABL Credit Facility are secured by a first-priority security interest in and lien on certain assets of the borrowers and the guarantors, including cash and cash equivalents and inventory, and excluding the assets of PHR and U.S. Oil . Mid Pac Term Loan On September 27, 2018 , Mid Pac Petroleum, LLC , now dissolved and whose assets are now included in PHL , our wholly owned subsidiary, entered into the Mid Pac Term Loan with American Savings Bank, FSB, which provided a term loan of up to $1.5 million . We received the proceeds on October 18, 2018 , which were used to purchase certain retail property. The Mid Pac Term Loan is scheduled to mature on October 18, 2028 . The Mid Pac Term Loan is payable monthly, bears interest at an annual rate of 4.375% , is secured by a first-priority lien on the real property purchased with the funds, including leases and rents on the property and the property’s fixed assets and fixtures, and is guaranteed by Par Petroleum, LLC . 5.00% Convertible Senior Notes Due 2021 In June 2016, we completed the issuance and sale of $115 million in aggregate principal amount of the 5.00% Convertible Senior Notes in a private placement under Rule 144A (the “Notes Offering”). The Notes Offering included the exercise in full of an option to purchase an additional $15 million in aggregate principal amount of the 5.00% Convertible Senior Notes granted to the initial purchasers. The net proceeds of $111.6 million (net of original issue discount of 3% ) from the sale of the 5.00% Convertible Senior Notes were used to finance a portion of the acquisition of the Wyoming refinery and related logistics assets (the “ WRC Acquisition ”), to repay $5 million in principal amount of the Term Loan (as defined below), and for general corporate purposes. The 5.00% Convertible Senior Notes bear interest at a rate of 5.00% per year beginning June 21, 2016 (payable semi-annually in arrears on June 15 and December 15 of each year, beginning on December 15, 2016 ) and will mature on June 15, 2021 . The initial conversion rate for the notes is 55.5556 shares of common stock per $1,000 principal amount of the 5.00% Convertible Senior Notes (or a total amount of 6,388,894 shares), which is equivalent to an initial conversion price of approximately $18.00 per share of common stock, subject to adjustment upon the occurrence of certain events. Conversions of the 5.00% Convertible Senior Notes will be settled in cash, shares of common stock, or a combination thereof at our election. The holders of the 5.00% Convertible Senior Notes may exercise their conversion rights at any time prior to the close of business on the business day immediately preceding the maturity date under certain circumstances. The 5.00% Convertible Senior Notes were not redeemable by us prior to June 20, 2019 . On or after June 20, 2019 , we may redeem all or any portion of the 5.00% Convertible Senior Notes if the last reported sales price of our common stock is at least 140% of the conversion price then in effect (i) on the trading day immediately preceding the date on which we provide notice of redemption and (ii) for at least 20 trading days (whether or not consecutive) during any 30 consecutive trading day period ending on, and including, the trading day immediately preceding the date on which we provide notice of redemption at a redemption price equal to 100% of the principal amount of the 5.00% Convertible Senior Notes to be redeemed, plus accrued and unpaid interest and a make-whole premium, which is equal to the present value of the remaining scheduled payments of interest on the 5.00% Convertible Senior Notes to be redeemed from the relevant redemption date to the maturity date of June 15, 2021 . We have determined that the redemption option and the related make-whole premium represent an embedded derivative that is not clearly and closely related to the 5.00% Convertible Senior Notes . Please read Note 13—Derivatives for further information on embedded derivatives. During May, June, and December 2019, we entered into privately negotiated exchange agreements with a limited number of holders (the “Noteholders”) to repurchase $66.3 million in aggregate principal amount of the 5.00% Convertible Senior Notes held by the Noteholders for an aggregate of $18.6 million in cash and approximately 3.2 million shares of Par’s common stock with a fair value of $74.3 million . We recognized a loss of approximately $6.1 million related to the extinguishment of the repurchased 5.00% Convertible Senior Notes in the year ended December 31, 2019. We separately account for the liability and equity components of the 5.00% Convertible Senior Notes . The fair value of the liability component was calculated using a discount rate of an identical debt instrument without a conversion feature. Based on this borrowing rate, the fair value of the liability component of the 5.00% Convertible Senior Notes on the issuance date was $89.3 million . The carrying amount of the equity component was determined to be $22.2 million by deducting the fair value of the liability component from the $111.6 million net proceeds of the 5.00% Convertible Senior Notes . The deferred financing costs of $0.6 million related to 5.00% Convertible Senior Notes were allocated on a proportionate basis between Long-term debt and Additional paid-in capital on the consolidated balance sheet. As of December 31, 2019 , the if-converted value was $14.2 million in excess of the outstanding principal amount of the 5.00% Convertible Senior Notes . As of December 31, 2019 , the outstanding principal amount of the 5.00% Convertible Senior Notes was $48.7 million , the unamortized discount and deferred financing cost was $3.9 million and the carrying amount of the liability component was $44.8 million . The unamortized discount and deferred financing costs will be amortized to Interest expense and financing costs, net over the term of the 5.00% Convertible Senior Notes . Term Loan B Facility On January 11, 2019 , Par Petroleum, LLC and Par Petroleum Finance Corp. entered into a new term loan facility with Goldman Sachs Bank USA, as administrative agent, and the lenders party thereto from time to time (the “ Term Loan B Facility ”). Pursuant to the Term Loan B Facility , the lenders made a term loan to the borrowers in the amount of $250.0 million (“ Term Loan B ”) on the closing date. The net proceeds from Term Loan B totaled $232.0 million after deducting the original issue discount, deferred financing costs, and commitment and other fees. Loans under the Term Loan B bear interest at a rate per annum equal to Adjusted LIBOR (as defined in the Term Loan B Facility ) plus an applicable margin of 6.75% or at a rate per annum equal to Alternate Base Rate (as defined in the Term Loan B Facility ) plus an applicable margin of 5.75% . The average effective interest rate for 2019 on the Term Loan B was 9.1% . In addition to the quarterly interest payments, the Term Loan B requires quarterly principal payments of $3.1 million . The Term Loan B matures on January 11, 2026 . The obligations of the borrowers under the Term Loan B Facility are guaranteed by Par Petroleum, LLC ’s and Par Petroleum Finance Corp. ’s existing and future direct or indirect domestic subsidiaries and, by Par Pacific Holdings, Inc. , with respect to principal and interest only. The Term Loan B Facility is secured on a pari passu basis by first priority liens (subject to the relative priority of permitted liens) on substantially all of the property and assets of Par Petroleum, LLC , Par Petroleum Finance Corp. , and their subsidiary guarantors, but excluding certain property which is collateral under the ABL Credit Facility , the Supply and Offtake Agreements, and the Washington Refinery Intermediation Agreement . Par Pacific Term Loan Agreement On January 9, 2019 , we entered into a loan agreement (the “ Par Pacific Term Loan Agreement ”) with the Bank of Hawaii (“BOH”). Pursuant to the Par Pacific Term Loan Agreement , BOH made a loan to the Company in the amount of $45.0 million (the “ Par Pacific Term Loan ”). During the term of the Par Pacific Term Loan , the interest payments were due monthly and were based on the outstanding principal balance multiplied by a floating rate equal to 3.50% above the applicable LIBOR rate (as defined in the Par Pacific Term Loan Agreement ) subject to an increased default interest rate in the event of a default. The average effective interest rate for 2019 on the Par Pacific Term Loan was 1.3% . The Par Pacific Term Loan Agreement was originally scheduled to mature on July 9, 2019 . We terminated and repaid all amounts outstanding under the Par Pacific Term Loan Agreement on March 29, 2019 using the proceeds of the Retail Property Term Loan (as defined below). We recognized approximately $0.1 million of debt extinguishment costs related to the unamortized deferred financing costs associated with the Par Pacific Term Loan Agreement in the year ended December 31, 2019. Retail Property Term Loan On March 29, 2019 , Par Pacific Hawaii Property Company, LLC (“ Par Property LLC ”), our wholly owned subsidiary, entered into a term loan agreement (the “ Retail Property Term Loan ”) with BOH, which provided a term loan in the principal amount of $45.0 million . The proceeds from the Retail Property Term Loan were used to repay and terminate the Par Pacific Term Loan Agreement . The Retail Property Term Loan is guaranteed by Par and secured by a lien on substantially all of the assets of Par Property LLC , including a mortgage lien on 21 retail properties in Hawaii (the “ Portfolio Properties ”). Certain covenants require us to maintain a loan-to-appraisal value of the Portfolio Properties ratio of not greater than 75% and an annual debt yield of at least 9% . Par is also subject to a minimum liquidity covenant measured on the last day of each fiscal quarter. The Retail Property Term Loan bears interest based on a floating rate equal to the applicable LIBOR for a one-month interest period plus 1.5% . The average effective interest rate for 2019 on the Retail Property Term Loan was 3.8% . Principal and interest payments are payable monthly based on a 20 -year amortization schedule, principal prepayments are allowed subject to applicable prepayment penalties, and the remaining unpaid principal, plus any unpaid interest or other charges, is due on April 1, 2024 , the maturity date of the Retail Property Term Loan . J. Aron Forward Sale As part of the May 8, 2017 amendment to the Supply and Offtake Agreements , we also entered into a $30 million forward sale of jet fuel to be delivered to J. Aron over the amended term (“ J. Aron Forward Sale ”). The proceeds from the J. Aron Forward Sale were used to pay a portion of the outstanding balance on the Term Loan (as defined below). The cost of the J. Aron Forward Sale was based upon an annual interest rate of 7% . Upon issuance of the 7.75% Senior Secured Notes on December 21, 2017 , we repaid in full and terminated the J. Aron Forward Sale and recognized $0.3 million of costs associated with the termination of the agreement, which is included within Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2017. Par Wyoming Holdings Credit Agreement On July 14, 2016 , in connection with the WRC Acquisition , Par Wyoming Holdings, LLC, our indirect wholly owned subsidiary, entered into the Par Wyoming Holdings Credit Agreement with certain lenders and Chambers Energy Management, LP, as agent, which provided for a single advance secured term loan to our subsidiary in the amount of $65.0 million (the “ Par Wyoming Holdings Term Loan ”) at the closing of the acquisition. The proceeds of the Par Wyoming Holdings Term Loan were used to pay a portion of the consideration for the acquisition, to pay certain fees and closing costs, and for general corporate purposes. The Par Wyoming Holdings Term Loan was originally scheduled to mature on July 14, 2021 . The Par Wyoming Holdings Term Loan bore interest at a rate equal to three-month LIBOR plus an applicable interest margin. With respect to cash interest, the applicable interest margin was at a rate per annum equal to 9.5% . With respect to paid-in-kind (“PIK”) interest, the applicable interest margin was at a rate per annum equal to 13% . Interest was payable in arrears on (a) the last day of each fiscal quarter, (b) the maturity date, and (c) the date of any repayment or prepayment of the Par Wyoming Holdings Term Loan . Upon issuance of the 7.75% Senior Secured Notes on December 21, 2017 , we repaid in full and terminated the Par Wyoming Holdings Credit Agreement and recognized $5.2 million of costs associated with the termination of the agreement, which is included within Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2017. Wyoming Refining Credit Facilities Wyoming Refining Company and its wholly owned subsidiary, Wyoming Pipeline Company, LLC , were borrowers (the “ Wyoming Refining Credit Facility Borrowers ”) under a Third Amended and Restated Loan Agreement dated as of April 30, 2015 (as amended, the “ Wyoming Refining Credit Facilities ”), with Bank of America, N.A., as the lender. The Wyoming Refining Credit Facilities remained in place following the consummation of the WRC Acquisition . On July 14, 2016 , and in connection with the consummation of the acquisition, the Wyoming Refining Credit Facilities were amended pursuant to a Third Amendment to Third Amended and Restated Loan Agreement (the “Third Loan Amendment”) and a Fourth Amendment to Third Amended and Restated Loan Agreement (the “Fourth Loan Amendment”). Pursuant to the Third Loan Amendment, which was entered into immediately prior to the consummation of the acquisition, Black Elk Refining, LLC was released from all of its obligations under the Wyoming Refining Credit Facilities and Par Wyoming, LLC joined and became a party to the Wyoming Refining Credit Facilities and the applicable security agreement and guaranteed all obligations of the borrowers under the Wyoming Refining Credit Facilities . The Fourth Loan Amendment was entered into immediately following the consummation of the acquisition and amended certain covenants in the Wyoming Refining Credit Facilities applicable to Par Wyoming, LLC and the Wyoming Refining Credit Facility Borrowers . On August 7, 2017, we entered into an amendment to the Wyoming Refining Credit Facilities to extend the maturity date from April 30, 2018 until June 30, 2019. The Wyoming Refining Credit Facilities originally provided for (a) a revolving credit facility in the maximum principal amount at any time outstanding of $30 million (“ Wyoming Refining Senior Secured Revolver ”), subject to a borrowing base, which provided for revolving loans and for the issuance of letters of credit and (b) certain term loans that are fully advanced (“ Wyoming Refining Senior Secured Term Loan ”). The Wyoming Refining Senior Secured Term Loan bore interest at a rate equal to monthly LIBOR plus 3.0% . The Wyoming Refining Senior Secured Term Loan required quarterly principal payments of $2.3 million . Upon issuance of the 7.75% Senior Secured Notes on December 21, 2017 , we repaid in full and terminated the Wyoming Refining Credit Facilities and recognized $0.1 million of costs associated with the termination of the agreement, which is included within Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2017. Hawaii Retail Credit Facilities On December 17, 2015 , we entered into the Hawaii Retail Credit Facilities in the form of a revolving credit facility up to $5 million (“ Hawaii Retail Revolving Credit Facilities ”) that provided for revolving loans and for the issuance of letters of credit and term loans (“ Hawaii Retail Term Loans ”) in the aggregate principal amount of $110 million . The proceeds of the Hawaii Retail Term Loans were used to repay in full existing indebtedness under the previous credit facilities, to pay transaction fees and expenses, to repay a portion of existing indebtedness under the Term Loan (as defined below), and to facilitate a cash distribution to Par. The Hawaii Retail Term Loans originally matured on December 17, 2022 and required principal payments of $2.75 million on the last business day of each fiscal quarter. The Hawaii Retail Revolving Credit Facilities originally matured on December 17, 2020 . The Hawaii Retail Term Loans and advances under the Hawaii Retail Revolving Credit Facilities bore interest at a fluctuating rate (i) during the periods such revolving loan or term loan, as applicable, equal to a Base Rate Loan, the Base Rate plus an applicable margin ranging from 1.50% to 2.25% , and (ii) during the periods such revolving loan or term loan, as applicable, equal to a Eurodollar Loan, the relevant Adjusted Eurodollar Rate for such Eurodollar Loan for the applicable interest period plus an applicable margin ranging from 2.50% to 3.25% . The effective interest rate for 2017 on the outstanding loan was 4.0% . Upon issuance of the 7.75% Senior Secured Notes on December 21, 2017 , we repaid in full and terminated the Hawaii Retail Credit Facilities and recognized $1.2 million of costs associated with the termination of the agreement, which is included within Debt extinguishment and commitment costs on our consolidated statement of operations for the year ended December 31, 2017. Term Loan On July 11, 2014 , we and certain subsidiaries entered into a Delayed Draw Term Loan and Bridge Loan Credit Agreement (“Credit Agreement”), amending and restating a previous borrowing arrangement with the lenders, to provide us with a term loan of up to $50.0 million (“Term Loan”) and a bridge loan of up to $75.0 million (“Bridge Loan”). The lenders under the Credit Agreement include ZCOF Par Petroleum Holdings, LLC, one of our significant stockholders. Proceeds from the Term Loan were used to fund a deposit for the acquisition of Mid Pac, which was subsequently dissolved and whose assets are now owned by PHL , to pay transaction costs, and for working capital and general corporate purposes. On June 15, 2016 , the Credit Agreement was amended to permit (i) the issuance of the 5.00% Convertible Senior Notes , (ii) the issuance of our 2.50% convertible subordinated bridge notes (the “Bridge Notes”), and (iii) the WRC Acquisition . We paid a consent fee of $2.5 million in connection with this amendment, $1.3 million of which was paid to an affiliate of Whitebox Advisors, LLC (“Whitebox”), previously one of our largest stockholders. On June 21, 2016 , we repaid $5 million of the Term Loan pursuant to the terms of the amendment, $3.3 million of which was allocated to an affiliate of Whitebox. Please read Note 22—Related Party Transactions for additional information. The Term Loan originally matured on July 11, 2018 and bore interest at either 10% per annum if paid in cash or 12% per annum if paid in kind, at our election, and had an original issue discount of 5% . On June 30, 2017, we fully repaid the Term Loan and terminated the Credit Agreement. A portion of the proceeds from the J. Aron Forward Sale and cash flows from operations were used to repay the full amount outstanding. We recorded Debt extinguishment and commitment costs of approximately $1.8 million related to unamortized deferred financing costs associated with the Term Loan in the year ended December 31, 2017. Cross Default Provisions Included within each of our debt agreements are affirmative and negative covenants and customary cross default provisions that require the repayment of amounts outstanding on demand unless the triggering payment default or acceleration is remedied, rescinded, or waived. As of December 31, 2019 , we were in compliance with all of our debt instruments. Guarantors In connection with our shelf registration statement on Form S-3, which was filed with the Securities and Exchange Commission (“SEC”) on February 6, 2019 and declared effective on February 15, 2019 (“Registration Statement”), we may sell non-convertible debt securities and other securities in one or more offerings with an aggregate initial offering price of up to $750.0 million . Any non-convertible debt securities issued under the Registration Statement may be fully and unconditionally guaranteed (except for customary release provisions), on a joint and several basis, by some or all of our subsidiaries, other than subsidiaries that are “minor” within the meaning of Rule 3-10 of Regulation S-X (the “Guarantor Subsidiaries”). We have no “independent assets or operations” within the meaning of Rule 3-10 of Regulation S-X and certain of the Guarantor Subsidiaries may be subject to restrictions on their ability to distribute funds to us, whether by cash dividends, loans, or advances.

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Commodity Derivatives We utilize commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, future purchases and sales of refined products, and crude oil consumption in our refining process. The derivative contracts that we execute to manage our price risk include exchange traded futures, options, and OTC swaps. Our futures, options, and OTC swaps are marked-to-market and changes in the fair value of these contracts are recognized within Cost of revenues (excluding depreciation) on our consolidated statements of operations. We are obligated to repurchase the crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements. Our Washington Refinery Intermediation Agreement contains forward purchase obligations for certain volumes of crude oil and refined products that are required to be settled at market prices on a monthly basis. We have determined that these obligations under the Supply and Offtake Agreements and Washington Refinery Intermediation Agreement contain embedded derivatives. As such, we have accounted for these embedded derivatives at fair value with changes in the fair value recorded in Cost of revenues (excluding depreciation) on our consolidated statements of operations. We have entered into forward purchase contracts for crude oil and forward purchases and sales contracts of refined products. We elect the normal purchases normal sales (“NPNS”) exception for all forward contracts that meet the definition of a derivative and are not expected to net settle. Any gains and losses with respect to these forward contracts designated as NPNS are not reflected in earnings until the delivery occurs. We elect to offset fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. Our consolidated balance sheets present derivative assets and liabilities on a net basis. Please read Note 14—Fair Value Measurements for the gross fair value and net carrying value of our derivative instruments. Our cash margin that is required as collateral deposits cannot be offset against the fair value of open contracts except in the event of default. Our open futures expire at various dates through October 2020 . At December 31, 2019 , our open commodity derivative contracts represented (in thousands of barrels): Contract type Purchases Sales Net Futures 3,360 (3,100 ) 260 Total 3,360 (3,100 ) 260 At December 31, 2019 , we also had option collars of 75 thousand barrels of crude oil per month that economically hedge our internally consumed fuel at our Hawaii refineries . These option collars have a weighted-average strike price ranging from a floor of $48.77 per barrel to a ceiling of $65.00 per barrel and expire in December 2020 . Interest Rate Derivatives We are exposed to interest rate volatility in our ABL Revolver , Term Loan B Facility, Retail Property Term Loan , Supply and Offtake Agreements, and Washington Refinery Intermediation Agreement . We may utilize interest rate swaps to manage our interest rate risk. As of December 31, 2019 , we had entered into an interest rate swap at an average fixed rate of 3.91% in exchange for the floating interest rate on the notional amounts due under the Retail Property Term Loan . This swap expires on April 1, 2024 , the maturity date of the Retail Property Term Loan . In February 2018, we terminated a separate $100 million floating interest rate swap originally maturing in March 2021 , which resulted in a realized gain of $3.7 million for the year ended December 31, 2018. In June 2016, we completed the issuance and sale of an aggregate of $115.0 million principal amount of the 5.00% Convertible Senior Notes . Please read Note 12—Debt for further discussion. Upon redemption of our 5.00% Convertible Senior Notes on or after June 20, 2019 at our election, we are obligated to pay a make-whole premium equal to the present value of the remaining scheduled payments of interest on the 5.00% Convertible Senior Notes to be redeemed from the relevant redemption date to the maturity date of June 15, 2021 . We have determined that the redemption option and the related make-whole premium represent an embedded derivative that is not clearly and closely related to the 5.00% Convertible Senior Notes . As such, we have accounted for this embedded derivative at fair value with changes in the fair value recorded in Interest expense and financing costs, net on our consolidated statements of operations. As of December 31, 2019 , this embedded derivative was deemed to have a de minimis fair value. The following table provides information on the fair value amounts (in thousands) of these derivatives as of December 31, 2019 and 2018 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2019 2018 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,075 $ 4,973 Commodity derivatives Other accrued liabilities (5,534 ) (700 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements 173 4,085 MLC terminal obligation derivative Obligations under inventory financing agreements (14,717 ) — Interest rate derivatives Prepaid and other current assets — 191 Interest rate derivatives Other accrued liabilities (314 ) — Interest rate derivatives Other liabilities (1,113 ) — _________________________________________________________ (1) Does not include cash collateral of $10.3 million and $2.7 million recorded in Prepaid and other current assets and $9.5 million and $8.3 million in Other long-term assets as of December 31, 2019 and 2018 , respectively. The following table summarizes the pre-tax gains (losses) recognized in Net income (loss) on our consolidated statements of operations resulting from changes in fair value of derivative instruments not designated as hedges charged directly to earnings (in thousands): Year Ended December 31, Statement of Operations Classification 2019 2018 2017 Commodity derivatives Cost of revenues (excluding depreciation) $ (1,547 ) $ (3,420 ) $ (4,517 ) J. Aron repurchase obligation derivative Cost of revenues (excluding depreciation) (3,912 ) 23,649 436 MLC terminal obligation derivative Cost of revenues (excluding depreciation) (19,326 ) — — Interest rate derivatives Interest expense and financing costs, net (1,506 ) 1,309 489

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis Purchase Price Allocation of U.S. Oil The fair values of the assets acquired and liabilities assumed as a result of the Washington Acquisition were estimated as of January 11, 2019 , the date of the acquisition, using valuation techniques described in notes (1) through (6) below. Valuation Fair Value Technique (in thousands) Net working capital excluding operating leases $ (35,854 ) (1) Property, plant, and equipment 412,766 (2) Operating lease assets 62,337 (3) Goodwill 42,522 (4) Current operating lease liabilities (21,571 ) (3) Long-term operating lease liabilities (40,766 ) (3) Deferred tax liability (92,103 ) (5) Other non-current liabilities (804 ) (6) Total $ 326,527 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of personal property was estimated using the cost approach. Key assumptions in the cost approach include determining the replacement cost by evaluating recent purchases of comparable assets or published data, and adjusting replacement cost for economic and functional obsolescence, location, normal useful lives, and capacity (if applicable). The fair value of real property was estimated using the market approach. Key assumptions in the market approach include determining the asset value by evaluating recent purchases of comparable assets under similar circumstances. (3) Operating lease assets and liabilities were recognized based on the present value of lease payments over the lease term using the incremental borrowing rate at acquisition of 9.6% . (4) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill. (5) The deferred tax liability was determined based on the differences between the tax bases of the assets acquired and the values of those assets recorded on our consolidated balance sheets as of the date of acquisition. (6) Other non-current liabilities are related to pension plan obligations. The underfunded status of the defined benefit plan represents the difference between the fair value of the plan’s assets and the projected benefit obligations. Purchase Price Allocation of Northwest Retail The fair values of the assets acquired and liabilities assumed as a result of the Northwest Retail Acquisition were estimated as of March 23, 2018 , the date of the acquisition, using valuation techniques described in notes (1) through (5) below. Valuation Fair Value Technique (in thousands) Net working capital $ 3,822 (1) Property, plant, and equipment 30,230 (2) Goodwill 46,210 (3) Long-term capital lease obligations (5,244 ) (4) Other non-current liabilities (487 ) (5) Total $ 74,531 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of property, plant, and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and obsolescence. The fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement. The fair value of capital lease assets was estimated using the income approach. Under the income approach, the annual lease market rental rate cash flow stream is estimated and then discounted to present value over the remaining life of the lease using a pre-tax discount rate based on expected return for the specific asset type and location. (3) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill. (4) Long-term capital lease obligations were estimated based on the present value of lease payments over the term of the lease. (5) Other non-current liabilities are primarily related to asset retirement obligations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. Investment in Laramie Energy At September 30, 2019, we conducted an impairment evaluation of our investment in Laramie Energy because of the significant decline in natural gas prices over the second quarter of 2019 and continued deterioration in the third quarter of 2019. We evaluate equity method investments for impairment when factors indicate that a decrease in the value of our investment has occurred and the carrying amount of our investment may not be recoverable. An impairment loss, based on the difference between the carrying value and the estimated fair value of the investment, is recognized in earnings when an impairment is deemed to be other than temporary. At September 30, 2019, we determined that the estimated fair value of our investment in Laramie Energy was $51.8 million , compared to a carrying value of $133.3 million . The fair value estimate was determined using a discounted cash flow analysis based on natural gas forward strip prices as of September 30, 2019 for two years through December 31, 2021. A blend of 2021 forward strip pricing and third-party analyst pricing was used for years after 2021 through December 31, 2028. Other significant inputs used in the discounted cash flow analysis included proved and unproved reserves information, forecasts of operating expenditures, and the applicable discount rate. As part of our evaluation, we considered the likelihood that Colorado Interstate Gas (“CIG”) prices, which have declined from an average spot price of $2.48 ($/MMBtu) in the first quarter of 2019, to $1.84 ($/MMBtu) in the second quarter of 2019 and $1.77 ($/MMBtu) in the third quarter of 2019, will recover in the near term. As a result, we recorded an impairment charge of $81.5 million on our statement of operations for the year ended December 31, 2019. We consider this to be a Level 3 fair value measurement. Assets and Liabilities Measured at Fair Value on a Recurring Basis Common stock warrants As of December 31, 2019 and 2018 , we had 354,350 common stock warrants outstanding. We estimate the fair value of our outstanding common stock warrants using the difference between the strike price of the warrant and the market price of our common stock, which is a Level 3 fair value measurement. As of December 31, 2019 and 2018 , the warrants had a weighted-average exercise price of $0.09 and $0.09 and a remaining term of 2.67 years and 3.67 years , respectively. The estimated fair value of the common stock warrants was $23.16 and $14.13 per share as of December 31, 2019 and 2018 , respectively. Increases in the value of our common stock will increase the value of the common stock warrants. Likewise, decreases in the value of our common stock will result in a decrease in the value of the common stock warrants. Derivative instruments We utilize commodity derivative contracts to manage our price exposure to our inventory positions, future purchases of crude oil, future purchases and sales of refined products, and cost of crude oil consumed in the refining process. We may utilize interest rate swaps to manage our interest rate risk. We are obligated to repurchase the crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements. Our Washington Refinery Intermediation Agreement contains forward purchase obligations for certain volumes of crude oil and refined products that are required to be settled at market prices on a monthly basis. We have determined that these obligations contain embedded derivatives, similar to forward purchase contracts of crude oil and refined products. As such, we have accounted for these embedded derivatives at fair value with changes in the fair value recorded in Cost of revenues (excluding depreciation) on our consolidated statements of operations. Upon redemption of our 5.00% Convertible Senior Notes on or after June 20, 2019 at our election, we are obligated to pay a make-whole premium equal to the present value of the remaining scheduled payments of interest on the 5.00% Convertible Senior Notes to be redeemed from the relevant redemption date to the maturity date of June 15, 2021 . We have determined that the redemption option and the related make-whole premium represent an embedded derivative that is not clearly and closely related to the 5.00% Convertible Senior Notes . As of December 31, 2019 and 2018 , this embedded derivative was deemed to have a de minimis fair value. We classify financial assets and liabilities according to the fair value hierarchy. Financial assets and liabilities classified as Level 1 instruments are valued using quoted prices in active markets for identical assets and liabilities. These include our exchange traded futures. Level 2 instruments are valued using quoted prices for similar assets and liabilities in active markets and inputs other than quoted prices that are observable for the asset or liability. Our Level 2 instruments include OTC swaps and options. These derivatives are valued using market quotations from independent price reporting agencies and commodity exchange price curves that are corroborated with market data. Level 3 instruments are valued using significant unobservable inputs that are not supported by sufficient market activity. The valuation of our J. Aron repurchase and MLC terminal obligations embedded derivatives requires that we make estimates of the prices and differentials assuming settlement at the end of the reporting period. Estimates of the J. Aron and MLC settlement prices are based on observable inputs, such as Brent and WTI indices, and unobservable inputs, such as contractual price differentials as defined in the Supply and Offtake Agreements and Washington Refinery Intermediation Agreement ; therefore they are classified as Level 3 instruments. We do not have other commodity derivatives classified as Level 3 at December 31, 2019 or 2018 . Please read Note 13—Derivatives for further information on derivatives. Financial Statement Impact Fair value amounts by hierarchy level as of December 31, 2019 and 2018 are presented gross in the tables below (in thousands): December 31, 2019 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 4,595 $ 2,075 $ — $ 6,670 $ (4,595 ) $ 2,075 Liabilities Common stock warrants $ — $ — $ (8,206 ) $ (8,206 ) $ — $ (8,206 ) Commodity derivatives (10,129 ) — — (10,129 ) 4,595 (5,534 ) J. Aron repurchase obligation derivative — — 173 173 — 173 MLC terminal obligation derivative — — (14,717 ) (14,717 ) — (14,717 ) Interest rate derivatives — (1,427 ) — (1,427 ) — (1,427 ) Total $ (10,129 ) $ (1,427 ) $ (22,750 ) $ (34,306 ) $ 4,595 $ (29,711 ) December 31, 2018 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 170 $ 5,234 $ — $ 5,404 $ (431 ) $ 4,973 Interest rate derivatives — 191 — 191 — 191 Total $ 170 $ 5,425 $ — $ 5,595 $ (431 ) $ 5,164 Liabilities Common stock warrants $ — $ — $ (5,007 ) $ (5,007 ) $ — $ (5,007 ) Commodity derivatives (870 ) (261 ) — (1,131 ) 431 (700 ) J.Aron repurchase obligation derivative — — 4,085 4,085 — 4,085 Total $ (870 ) $ (261 ) $ (922 ) $ (2,053 ) $ 431 $ (1,622 ) _________________________________________________________ (1) Does not include cash collateral of $19.8 million and $10.9 million as of December 31, 2019 and 2018 , respectively, included within Prepaid and other current assets and Other long-term assets on our consolidated balance sheets. A roll forward of Level 3 derivative instruments measured at fair value on a recurring basis is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Balance, beginning of period $ (922 ) $ (26,372 ) $ (25,134 ) Settlements 13,263 — — Acquired (8,654 ) — — Unrealized and realized income (loss) included in earnings (26,437 ) 25,450 (1,238 ) Balance, end of period $ (22,750 ) $ (922 ) $ (26,372 ) The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2019 and 2018 are as follows (in thousands): December 31, 2019 Carrying Value Fair Value 5.00% Convertible Senior Notes due 2021 (1) (3) $ 44,783 $ 66,477 7.75% Senior Secured Notes due 2025 (1) 292,015 309,375 Mid Pac Term Loan (2) 1,433 1,433 Term Loan B Facility (1) 230,474 240,625 Retail Property Term Loan (2) 43,226 43,226 Common stock warrants (2) 8,206 8,206 December 31, 2018 Carrying Value Fair Value 5.00% Convertible Senior Notes due 2021 (1) (3) $ 100,411 $ 121,488 7.75% Senior Secured Notes due 2025 (1) 290,763 270,000 Mid Pac Term Loan (2) 1,466 1,466 Common stock warrants (2) 5,007 5,007 _________________________________________________________ (1) The fair value measurements of the 5.00% Convertible Senior Notes , 7.75% Senior Secured Notes , and Term Loan B Facility are considered Level 2 measurements in the fair value hierarchy as discussed below. (2) The fair value measurements of the common stock warrants, Mid Pac Term Loan , and Retail Property Term Loan are considered Level 3 measurements in the fair value hierarchy. (3) The carrying value of the 5.00% Convertible Senior Notes excludes the fair value of the equity component, which was classified as equity upon issuance. The fair value of the 5.00% Convertible Senior Notes was determined by aggregating the fair value of the liability and equity components of the notes. The fair value of the liability component of the 5.00% Convertible Senior Notes was determined using a discounted cash flow analysis in which the projected interest and principal payments were discounted at an estimated market yield for a similar debt instrument without the conversion feature. The equity component was estimated based on the Black-Scholes model for a call option with strike price equal to the conversion price, a term matching the remaining life of the 5.00% Convertible Senior Notes , and an implied volatility based on market values of options outstanding as of December 31, 2019 . The fair value of the 5.00% Convertible Senior Notes is considered a Level 2 measurement in the fair value hierarchy. The fair value of the 7.75% Senior Secured Notes and the Term Loan B Facility were determined using a market approach based on quoted prices. The inputs used to measure the fair value are classified as Level 2 inputs within the fair value hierarchy because the 7.75% Senior Secured Notes and the Term Loan B Facility may not be actively traded. The Retail Property Term Loan is subject to a market-based floating interest rate. The Mid Pac Term Loan is subject to a fixed interest rate that approximates the long-term treasury rate. The carrying values of our Retail Property and Mid Pac Term Loans were determined to approximate fair value as of December 31, 2019 . The fair value of all non-derivative financial instruments recorded in current assets, including cash and cash equivalents, restricted cash, and trade accounts receivable, and current liabilities, including accounts payable, approximate their carrying value due to their short-term nature.

Leases Leases

Leases Leases	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Leases	Leases We have cancelable and non-cancelable finance and operating lease liabilities for the lease of land, vehicles, office space, retail facilities, and other facilities used in the storage and transportation of crude oil and refined products. Most of our leases include one or more options to renew, with renewal terms that can extend the lease term from one to 30 years or more. There are no material lease arrangements where we are the lessor and no material residual value guarantees associated with any of our leases. The following table provides information on the amounts (in thousands, except lease term and discount rates) of our leased assets and liabilities as of December 31, 2019 and their placement within our consolidated balance sheets: Lease type Balance Sheet Location December 31, 2019 Assets Finance Property, plant, and equipment $ 11,552 Finance Accumulated amortization (4,447 ) Finance Property, plant, and equipment, net $ 7,105 Operating Operating lease assets 420,073 Total leased assets $ 427,178 Liabilities Current Finance Other accrued liabilities $ 1,784 Operating Operating lease liabilities 79,999 Long-term Finance Finance lease liabilities 6,227 Operating Operating lease liabilities 340,909 Total lease liabilities $ 428,919 Weighted-average remaining lease term (in years) Finance 5.69 Operating 10.26 Weighted-average discount rate Finance 6.68 % Operating 7.88 % The following table summarizes the lease costs recognized on our consolidated statement of operations (in thousands): Lease cost type Year Ended December 31, 2019 Finance lease cost Amortization of finance lease assets $ 1,896 Interest on lease liabilities 521 Operating lease cost 100,384 Variable lease cost 11,663 Short-term lease cost 1,874 Net lease cost $ 116,338 The following table summarizes the supplemental cash flow information related to leases as follows (in thousands): Lease type Year Ended December 31, 2019 Cash paid for amounts included in the measurement of liabilities Financing cash flows from finance leases $ 2,167 Operating cash flows from finance leases 507 Operating cash flows from operating leases 99,713 Non-cash supplemental amounts ROU assets obtained in exchange for new finance lease liabilities 963 ROU assets obtained in exchange for new operating lease liabilities 79,382 The table below includes the estimated future undiscounted cash flows for finance and operating leases as of December 31, 2019 (in thousands): For the year ending December 31, Finance leases Operating leases Total 2020 $ 2,247 $ 109,727 $ 111,974 2021 1,593 69,091 70,684 2022 1,376 66,859 68,235 2023 1,345 53,088 54,433 2024 1,058 43,337 44,395 Thereafter 2,004 240,988 242,992 Total lease payments 9,623 583,090 592,713 Less amount representing interest (1,612 ) (162,182 ) (163,794 ) Present value of lease liabilities $ 8,011 $ 420,908 $ 428,919 Additionally, we have $9.0 million and $1.2 million in future undiscounted cash flows for three operating leases and three finance leases, respectively, that have not yet commenced. These leases are expected to commence when the lessor has made the equipment or location available to us to operate or begin construction, respectively. Due to the transition method elected, information presented prior to January 1, 2019 has not been restated for ASC 842 and continues to be reported under the accounting standards in effect for the period. As of December 31, 2018, we had capital lease obligations related primarily to the leases of 17 retail stations. Most capital leases included one or more options to renew, with renewal terms that could extend the lease term from one to 15 years or more. Certain leases included escalation clauses and/or purchase options. Additionally, as of December 31, 2018, we had various cancelable and noncancelable operating leases related to land, vehicles, office and retail facilities, railcars, barges, and other facilities used in the storage, transportation, and sale of crude oil and refined products. We had operating leases for most of our retail stations with an average of eight years remaining and generally contained renewal options and escalation clauses. Leases for facilities used in the storage, transportation, and sale of crude oil and refined products had various expiration dates extending to 2044. Rent expense for the years ended December 31, 2018 and 2017 was approximately $41.6 million and $41.2 million , respectively. At December 31, 2018 , the estimated minimum lease payments for capital and operating leases with initial or remaining non-cancelable lease terms in excess of one year were as follows (in thousands): Capital leases Operating leases 2019 $ 2,723 $ 62,589 2020 2,264 62,132 2021 1,757 39,821 2022 1,512 38,402 2023 1,148 38,827 Thereafter 2,600 191,717 Total minimum rental payments $ 12,004 $ 433,488 Less amount representing interest (1,865 ) Present value of minimum rental payments $ 10,139
Leases	Leases We have cancelable and non-cancelable finance and operating lease liabilities for the lease of land, vehicles, office space, retail facilities, and other facilities used in the storage and transportation of crude oil and refined products. Most of our leases include one or more options to renew, with renewal terms that can extend the lease term from one to 30 years or more. There are no material lease arrangements where we are the lessor and no material residual value guarantees associated with any of our leases. The following table provides information on the amounts (in thousands, except lease term and discount rates) of our leased assets and liabilities as of December 31, 2019 and their placement within our consolidated balance sheets: Lease type Balance Sheet Location December 31, 2019 Assets Finance Property, plant, and equipment $ 11,552 Finance Accumulated amortization (4,447 ) Finance Property, plant, and equipment, net $ 7,105 Operating Operating lease assets 420,073 Total leased assets $ 427,178 Liabilities Current Finance Other accrued liabilities $ 1,784 Operating Operating lease liabilities 79,999 Long-term Finance Finance lease liabilities 6,227 Operating Operating lease liabilities 340,909 Total lease liabilities $ 428,919 Weighted-average remaining lease term (in years) Finance 5.69 Operating 10.26 Weighted-average discount rate Finance 6.68 % Operating 7.88 % The following table summarizes the lease costs recognized on our consolidated statement of operations (in thousands): Lease cost type Year Ended December 31, 2019 Finance lease cost Amortization of finance lease assets $ 1,896 Interest on lease liabilities 521 Operating lease cost 100,384 Variable lease cost 11,663 Short-term lease cost 1,874 Net lease cost $ 116,338 The following table summarizes the supplemental cash flow information related to leases as follows (in thousands): Lease type Year Ended December 31, 2019 Cash paid for amounts included in the measurement of liabilities Financing cash flows from finance leases $ 2,167 Operating cash flows from finance leases 507 Operating cash flows from operating leases 99,713 Non-cash supplemental amounts ROU assets obtained in exchange for new finance lease liabilities 963 ROU assets obtained in exchange for new operating lease liabilities 79,382 The table below includes the estimated future undiscounted cash flows for finance and operating leases as of December 31, 2019 (in thousands): For the year ending December 31, Finance leases Operating leases Total 2020 $ 2,247 $ 109,727 $ 111,974 2021 1,593 69,091 70,684 2022 1,376 66,859 68,235 2023 1,345 53,088 54,433 2024 1,058 43,337 44,395 Thereafter 2,004 240,988 242,992 Total lease payments 9,623 583,090 592,713 Less amount representing interest (1,612 ) (162,182 ) (163,794 ) Present value of lease liabilities $ 8,011 $ 420,908 $ 428,919 Additionally, we have $9.0 million and $1.2 million in future undiscounted cash flows for three operating leases and three finance leases, respectively, that have not yet commenced. These leases are expected to commence when the lessor has made the equipment or location available to us to operate or begin construction, respectively. Due to the transition method elected, information presented prior to January 1, 2019 has not been restated for ASC 842 and continues to be reported under the accounting standards in effect for the period. As of December 31, 2018, we had capital lease obligations related primarily to the leases of 17 retail stations. Most capital leases included one or more options to renew, with renewal terms that could extend the lease term from one to 15 years or more. Certain leases included escalation clauses and/or purchase options. Additionally, as of December 31, 2018, we had various cancelable and noncancelable operating leases related to land, vehicles, office and retail facilities, railcars, barges, and other facilities used in the storage, transportation, and sale of crude oil and refined products. We had operating leases for most of our retail stations with an average of eight years remaining and generally contained renewal options and escalation clauses. Leases for facilities used in the storage, transportation, and sale of crude oil and refined products had various expiration dates extending to 2044. Rent expense for the years ended December 31, 2018 and 2017 was approximately $41.6 million and $41.2 million , respectively. At December 31, 2018 , the estimated minimum lease payments for capital and operating leases with initial or remaining non-cancelable lease terms in excess of one year were as follows (in thousands): Capital leases Operating leases 2019 $ 2,723 $ 62,589 2020 2,264 62,132 2021 1,757 39,821 2022 1,512 38,402 2023 1,148 38,827 Thereafter 2,600 191,717 Total minimum rental payments $ 12,004 $ 433,488 Less amount representing interest (1,865 ) Present value of minimum rental payments $ 10,139

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In the ordinary course of business, we are a party to various lawsuits and other contingent matters. We establish accruals for specific legal matters when we determine that the likelihood of an unfavorable outcome is probable and the loss is reasonably estimable. It is possible that an unfavorable outcome of one or more of these lawsuits or other contingencies could have a material impact on our financial condition, results of operations, or cash flows. Tesoro Earn-out Dispute On June 17, 2013, a wholly owned subsidiary of Par entered into a membership interest purchase agreement with Andeavor, formerly known as Tesoro Corporation (“Tesoro,” which changed its name to Andeavor Corporation before being purchased by Marathon Petroleum Company in October 2018), pursuant to which it purchased all of the issued and outstanding membership interests in Tesoro Hawaii, LLC, an entity that was renamed Hawaii Independent Energy, LLC, and thereafter renamed Par Hawaii Refining, LLC (“ PHR ”). The cash consideration for the acquisition was subject to an earn-out provision during the years 2014-2016, subject to, among other things, an annual earn-out cap of $20 million and an overall cap of $40 million . During 2016, we paid Tesoro a total of $16.8 million to settle the 2014 and 2015 earn-out periods. Tesoro disputed our calculation of the 2015 and 2016 earn-out amounts and asserted that it was entitled to an additional earn-out amount of $4.3 million for the 2015 earn-out period and a total earn-out amount of $8.3 million for the 2016 earn-out period. On March 22, 2018 , Tesoro agreed to settle the earn-out dispute and release and discharge any related claims in exchange for our payment of $10.5 million . United Steelworkers Union Dispute A portion of our employees at the Par East refinery are represented by the United Steelworkers Union (“USW”). On March 23, 2015, the union ratified a four-year extension of the collective bargaining agreement. On January 13, 2016, the USW filed a claim against PHR before the United States National Labor Relations Board (the “NLRB”) alleging a refusal to bargain collectively and in good faith. On March 29, 2016, the NLRB deferred final determination on the USW charge to the grievance/arbitration process under the extant collective bargaining agreement. Arbitration was commenced and concluded on October 1, 2018, with the arbitrator taking the matter under advisement thereafter. In a decision dated November 27, 2018, the arbitrator denied the grievance without prejudice to USW’s NLRB claim regarding retiree medical and short term disability benefits. On June 5, 2019, the NLRB approved the withdrawal of USW’s claim against PHR. Environmental Matters Like other petroleum refiners, our operations are subject to extensive and periodically-changing federal, state, and local environmental laws and regulations governing air emissions, wastewater discharges, and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent and the cost of compliance can be expected to increase over time. Periodically, we receive communications from various federal, state, and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective actions for these asserted violations. We intend to respond in a timely manner to all such communications and to take appropriate corrective action. Except as disclosed below, we do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations, or cash flows. The Par East refinery, our Wyoming refinery, and our Washington refinery, acquired in January 2019, were all granted small refinery status by the U.S. Environmental Protection Agency (“EPA”) for 2018. Owing to the receipt of these small refinery exemptions, our net income for the year ended December 31, 2019 includes $5.3 million of net RINs benefit . Wyoming Refinery Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the EPA and/or the Wyoming Department of Environmental Quality, some of which date back to the late 1970s and several of which remain in effect, requiring further actions at the Wyoming refinery. The largest cost component arising from these various decrees relates to the investigation, monitoring, and remediation of soil, groundwater, surface water and sediment contamination associated with the facility’s historic operations. Investigative work by Hermes Consolidated LLC, and its wholly owned subsidiary, Wyoming Pipeline Company (collectively, “WRC” or “Wyoming Refining”) and negotiations with the relevant agencies as to remedial approaches remain ongoing on a number of aspects of the contamination, meaning that investigation, monitoring, and remediation costs are not reasonably estimable for some elements of these efforts. As of December 31, 2019 , we have accrued $16.5 million for the well-understood components of these efforts based on current information, approximately one-third of which we expect to incur in the next five years and the remainder to be incurred over approximately 30 years . Additionally, we believe the Wyoming refinery will need to modify or close a series of wastewater impoundments in the next several years and replace those impoundments with a new wastewater treatment system. Based on current information, reasonable estimates we have received suggest costs of approximately $11.6 million to design and construct a new wastewater treatment system. Finally, among the various historic consent decrees, orders, and settlement agreements into which Wyoming Refining has entered, there are several penalty orders associated with exceedances of permitted limits by the Wyoming refinery’s wastewater discharges. Although the frequency of these exceedances has declined over time, Wyoming Refining may become subject to new penalty enforcement action in the next several years, which could involve penalties in excess of $100,000 . Regulation of Greenhouse Gases The EPA regulates greenhouse gases (“GHG”) under the federal Clean Air Act (“CAA”). New construction or material expansions that meet certain GHG emissions thresholds will likely require that, among other things, a GHG permit be issued in accordance with the federal CAA regulations and we will be required, in connection with such permitting, to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce GHG emissions. Furthermore, the EPA is currently developing refinery-specific GHG regulations and performance standards that are expected to impose GHG emission limits and/or technology requirements. These control requirements may affect a wide range of refinery operations. Any such controls could result in material increased compliance costs, additional operating restrictions for our business, and an increase in the cost of the products we produce, which could have a material adverse effect on our financial condition, results of operations, or cash flows. Additionally, the EPA’s final rule updating standards that control toxic air emissions from petroleum refineries imposed additional controls and monitoring requirements on flaring operations, storage tanks, sulfur recovery units, delayed coking units and required fenceline monitoring. Compliance with this rule has not had a material impact on our financial condition, results of operations, or cash flows to date. In 2007, the State of Hawaii passed Act 234, which required that GHG emissions be rolled back on a statewide basis to 1990 levels by the year 2020. In June of 2014, the Hawaii Department of Health (“DOH”) adopted regulations that require each major facility to reduce CO 2 emissions by 16% by 2020 relative to a calendar year 2010 baseline (the first year in which GHG emissions were reported to the EPA under 40 CFR Part 98). The Hawaii refineries ’ capacity to materially reduce fuel use and GHG emissions is limited because most energy conservation measures have already been implemented over the past 20 years. The regulation allows for “partnering” with other facilities (principally power plants) that have already dramatically reduced greenhouse emissions or are on schedule to reduce CO 2 emissions in order to comply independently with the state’s Renewable Portfolio Standards. The DOH’s GHG regulation allows, and the Hawaii refineries submitted, a GHG reduction plan which includes an assessment of alternatives which demonstrates that additional reductions are not cost-effective or necessary because the State of Hawaii has already reached the 1990 levels according to a report prepared by the DOH in January 2019. In 2007, the U.S. Congress passed the Energy Independence and Security Act of 2007 (the “EISA”) which, among other things, set a target fuel economy standard of 35 miles per gallon for the combined fleet of cars and light trucks in the U.S. by model year 2020 and contained an expanded Renewable Fuel Standard (the “RFS”). In August 2012, the EPA and National Highway Traffic Safety Administration (“NHTSA”) jointly adopted regulations that establish an average industry fuel economy of 54.5 miles per gallon by model year 2025. On August 8, 2018, the EPA and NHTSA jointly proposed to revise existing fuel economy standards for model years 2021-2025 and to set standards for 2026 for the first time. The agencies have not yet issued a final rule. Although the revised fuel economy standards are expected to be less stringent than the initial standards for model years 2021-2025, it is uncertain whether the revised standards will increase year over year. Higher fuel economy standards have the potential to reduce demand for our refined transportation fuel products. Under EISA, the RFS requires an increasing amount of renewable fuel to be blended into the nation’s transportation fuel supply, up to 36 billion gallons by 2022. In the near term, the RFS will be satisfied primarily with fuel ethanol blended into gasoline. We, and other refiners subject to the RFS, may meet the RFS requirements by blending the necessary volumes of renewable fuels produced by us or purchased from third parties. To the extent that refiners will not or cannot blend renewable fuels into the products they produce in the quantities required to satisfy their obligations under the RFS program, those refiners must purchase renewable credits, referred to as RINs, to maintain compliance. To the extent that we exceed the minimum volumetric requirements for blending of renewable fuels, we have the option of retaining these RINs for current or future RFS compliance or selling those RINs on the open market. The RFS may present production and logistics challenges for both the renewable fuels and petroleum refining and marketing industries in that we may have to enter into arrangements with other parties or purchase D3 waivers from the EPA to meet our obligations to use advanced biofuels, including biomass-based diesel and cellulosic biofuel, with potentially uncertain supplies of these new fuels. In October 2010, the EPA issued a partial waiver decision under the federal CAA to allow for an increase in the amount of ethanol permitted to be blended into gasoline from 10% (“E10”) to 15% (“E15”) for 2007 and newer light duty motor vehicles. In 2019, the EPA approved year-round sales of E15. There are numerous issues, including state and federal regulatory issues, that need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines; however, increased renewable fuel in the nation’s transportation fuel supply could reduce demand for our refined products. In March 2014, the EPA published a final Tier 3 gasoline standard that requires, among other things, that gasoline contain no more than 10 parts per million (“ppm”) sulfur on an annual average basis and no more than 80 ppm sulfur on a per-gallon basis. The standard also lowers the allowable benzene, aromatics, and olefins content of gasoline. The effective date for the new standard is January 1, 2017, however, approved small volume refineries had until January 1, 2020 to meet the standard. The Par East refinery was required to comply with Tier 3 gasoline standards within 30 months of June 21, 2016, the date it was disqualified from small volume refinery status. On March 19, 2015, the EPA confirmed the small refinery status of our Wyoming refinery. The Par East refinery, our Wyoming refinery, and our Washington refinery, acquired in January 2019, were all granted small refinery status by the EPA for 2018. As of January 1, 2020, all four of our refineries were compliant with the final Tier 3 gasoline standard. Beginning on June 30, 2014, new sulfur standards for fuel oil used by marine vessels operating within 200 miles of the U.S. coastline (which includes the entire Hawaiian Island chain) was lowered from 10,000 ppm (1%) to 1,000 ppm (0.1%). The sulfur standards began at the Hawaii refineries and were phased in so that by January 1, 2015, they were to be fully aligned with the International Marine Organization (“IMO”) standards and deadline. The more stringent standards apply universally to both U.S. and foreign-flagged ships. Although the marine fuel regulations provided vessel operators with a few compliance options such as installation of on-board pollution controls and demonstration unavailability, many vessel operators will be forced to switch to a distillate fuel while operating within the Emission Control Area (“ECA”). Beyond the 200 mile ECA, large ocean vessels are still allowed to burn marine fuel with up to 3.5% sulfur. Our Hawaii refineries are capable of producing the 1% sulfur residual fuel oil that was previously required within the ECA. Although our Hawaii refineries remain in a position to supply vessels traveling to and through Hawaii, the market for 0.1% sulfur distillate fuel and 3.5% sulfur residual fuel is much more competitive. In addition to U.S. fuels requirements, the IMO has also adopted newer standards that further reduce the global limit on sulfur content in maritime fuels to 0.5% beginning in 2020 (“IMO 2020”). Like the rest of the refining industry, we are focused on meeting these standards and may incur costs in producing lower-sulfur fuels. There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in the EISA, RFS, IMO 2020, and other fuel-related regulations. We may experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels. Environmental Agreement On September 25, 2013 , Par Petroleum, LLC (formerly Hawaii Pacific Energy, a wholly owned subsidiary of Par created for purposes of the PHR acquisition), Tesoro, and PHR entered into an Environmental Agreement (“Environmental Agreement”) that allocated responsibility for known and contingent environmental liabilities related to the acquisition of PHR , including the Consent Decree as described below. Consent Decree On July 18, 2016, PHR and subsidiaries of Tesoro entered into a consent decree with the EPA, the U.S. Department of Justice (“DOJ”), and other state governmental authorities concerning alleged violations of the federal CAA related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (“Consent Decree”), including the Par East refinery. As a result of the Consent Decree, PHR expanded its previously-announced 2016 Par East refinery turnaround to undertake additional capital improvements to reduce emissions of air pollutants and to provide for certain nitrogen oxide and sulfur dioxide emission controls and monitoring required by the Consent Decree. Tesoro is responsible under the Environmental Agreement for directly paying, or reimbursing PHR , for all reasonable third-party capital expenditures incurred pursuant to the Consent Decree to the extent related to acts or omissions prior to the date of the closing of the PHR acquisition. Tesoro is obligated to pay all applicable fines and penalties related to the Consent Decree. Through December 31, 2019 , Tesoro has reimbursed us for $12.2 million of our total capital expenditures incurred in connection with the Consent Decree. As of December 31, 2019 , all reimbursable capital expenditures incurred pursuant to the Consent Decree were collected. Net capital expenditures and reimbursements related to the Consent Decree for the years ended December 31, 2019 , 2018 , and 2017 are presented within Capital expenditures on our consolidated statement of cash flows for the related periods. Indemnification In addition to its obligation to reimburse us for capital expenditures incurred pursuant to the Consent Decree, Tesoro agreed to indemnify us for claims and losses arising out of related breaches of Tesoro’s representations, warranties, and covenants in the Environmental Agreement, certain defined “corrective actions” relating to pre-existing environmental conditions, third-party claims arising under environmental laws for personal injury or property damage arising out of or relating to releases of hazardous materials that occurred prior to the date of the closing of the PHR acquisition, any fine, penalty, or other cost assessed by a governmental authority in connection with violations of environmental laws by PHR prior to the date of the closing of the PHR acquisition, certain groundwater remediation work, fines, or penalties imposed on PHR by the Consent Decree related to acts or omissions of Tesoro prior to the date of the closing of the PHR acquisition, and claims and losses related to the Pearl City Superfund Site. Tesoro’s indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a deductible of $1 million and a cap of $15 million for certain of Tesoro’s indemnification obligations related to certain pre-existing conditions, as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions. Recovery Trusts We emerged from the reorganization of Delta Petroleum Corporation (“Delta”) on August 31, 2012 (“Emergence Date”), when the plan of reorganization (“Plan”) was consummated. On the Emergence Date, we formed the Delta Petroleum General Recovery Trust (“General Trust”). The General Trust was formed to pursue certain litigation against third parties, including preference actions, fraudulent transfer and conveyance actions, rights of setoff and other claims, or causes of action under the U.S. Bankruptcy Code and other claims and potential claims that Delta and its subsidiaries (collectively, “Debtors”) hold against third parties. On February 27, 2018, the Bankruptcy Court entered its final decree closing the Chapter 11 bankruptcy cases of Delta and the other Debtors, discharging the trustee for the General Trust, and finding that all assets of the General Trust were resolved, abandoned, or liquidated and have been distributed in accordance with the requirements of the Plan. In addition, the final decree required the Company or the General Trust, as applicable, to maintain the current accruals owed on account of the remaining claims of the U.S. Government and Noble Energy, Inc. As of December 31, 2019 , two related claims totaling approximately $22.4 million remained to be resolved by the trustee for the General Trust and we have accrued approximately $0.5 million representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end. One of the two remaining claims was filed by the U.S. Government for approximately $22.4 million relating to ongoing litigation concerning a plugging and abandonment obligation in Pacific Outer Continental Shelf Lease OCS-P 0320, comprising part of the Sword Unit in the Santa Barbara Channel, California. The second unliquidated claim, which is related to the same plugging and abandonment obligation, was filed by Noble Energy Inc., the operator and majority interest owner of the Sword Unit. We believe the probability of issuing stock to satisfy the full claim amount is remote, as the obligations upon which such proof of claim is asserted are joint and several among all working interest owners and Delta, our predecessor, only owned an approximate 3.4% aggregate working interest in the unit. The settlement of claims is subject to ongoing litigation and we are unable to predict with certainty how many shares will be required to satisfy all claims. Pursuant to the Plan, allowed claims are settled at a ratio of 54.4 shares per $1,000 of claim. Major Customers For the year ended December 31, 2017 , we had one customer in our refining segment that accounted for 10% of our consolidated revenues. No other customer accounted for more than 10% of our consolidated revenues during the years ended December 31, 2019 , 2018 , and 2017 .

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Stockholders' Equity	Stockholders’ Equity Common Stock Our certificate of incorporation contains restrictions on the transfer of certain of our securities in order to preserve the net operating loss carryovers, capital loss carryovers, general business credit carryovers, alternative minimum tax credit carryovers, and foreign tax credit carryovers, as well as any “net unrealized built-in loss” within the meaning of Section 382 of the Internal Revenue Service Code, of us or any direct or indirect subsidiary thereof. These restrictions include provisions regarding approval by our Board of Directors of transfers of common stock by holders of five percent or more of the outstanding common stock. Our debt agreements restrict the payment of dividends. Registration Rights Agreements In connection with our emergence from bankruptcy on August 31, 2012, we entered into a registration rights agreement (“Registration Rights Agreement”) providing the stockholders party thereto (“Stockholders”) with certain registration rights. The Registration Rights Agreement states that at any time after the consummation of a qualified public offering, any Stockholder or group of Stockholders that, together with its or their affiliates, holds more than fifteen percent of the Registrable Shares (as defined in the Registration Rights Agreement), will have the right to require us to file with the SEC a registration statement for a public offering of all or part of its Registrable Shares (each a “Demand Registration”), by delivery of written notice to the company (each, a “Demand Request”). Within 90 days after receiving the Demand Request, we must file with the SEC the registration statement with respect to the Demand Registration, subject to certain limitations as set forth in the Registration Rights Agreement. We are required to use commercially reasonable efforts to cause the registration statement to be declared effective as soon as practicable after such filing. In addition, subject to certain exceptions, if we propose to register any class of common stock for sale to the public, we are required, subject to certain conditions, to include all Registrable Shares with respect to which we have received written requests for inclusion. In connection with the closing of a private placement, we entered into an additional registration rights agreement with the purchasers of the shares. Under this registration rights agreement, we agreed to file a registration statement relating to the shares of common stock with the SEC within 60 days after the closing date of the sale which would be declared effective within 180 days of the closing date of the sale. We also agreed to use commercially reasonable efforts to keep the registration statement effective until the earliest to occur of (i) the disposition of all registrable securities, (ii) the availability under Rule 144 of the Securities Act of 1933, as amended, for each holder of registrable securities to immediately freely resell such registrable securities without volume restrictions, or (iii) the third anniversary of the effective date of the registration statement. This registration rights agreement also provides the right for a holder or group of holders of more than $50 million of registrable securities to demand that we conduct an underwritten public offering of the registrable securities. However, the demanding holders are limited to a total of three such underwritten offerings, with no more than one demand request for an underwritten offering made in any 365 day period. Additionally, this registration rights agreement contains customary indemnification rights and obligations for both us and the holders of registrable securities. If this registration statement does not remain effective for the applicable effectiveness period described above then from that date until cured, we must pay, as liquidated damages and not as a penalty, an amount in cash equal to 0.25% of the purchaser’s allocated purchase price per calendar month, not to exceed 0.75% of the allocated purchase price. The registration rights granted in each rights agreement are subject to customary indemnification and contribution provisions, as well as customary restrictions such as suspension periods and, if a registration is for an underwritten offering, limitations on the number of shares to be included in the underwritten offering imposed by the managing underwriter. In connection with the completion of the Company’s private unregistered offering of its 5.00% Convertible Senior Notes , the Company entered into a Registration Rights Agreement (the “Convertible Notes Registration Rights Agreement”), dated as of June 21, 2016, with the initial purchasers in the offering of the 5.00% Convertible Senior Notes . The Convertible Notes Registration Rights Agreement requires the Company (i) to file with the SEC a shelf registration statement covering resales of the shares of common stock, if any, issuable upon conversion of the 5.00% Convertible Senior Notes and in respect of any make-whole premium, (ii) to use its best efforts to cause, if not a well-known seasoned issuer, such shelf registration statement to be declared effective by the SEC within 180 days after June 21, 2016, and (iii) to use its best efforts to keep such shelf registration statement effective until the earlier of (A) the 120 th calendar day immediately following the maturity date of the 5.00% Convertible Senior Notes or (B) the date on which there are no longer outstanding any 5.00% Convertible Senior Notes or restricted shares of the common stock that have been received upon conversion of the 5.00% Convertible Senior Notes or in respect of any make-whole premium. If the Company does not fulfill its obligations under the Convertible Notes Registration Rights Agreement, it will be required to pay the holders of the 5.00% Convertible Senior Notes liquidated damages in the form of additional interest on the 5.00% Convertible Senior Notes . Such additional interest will accrue at a rate per year equal to: (i) 0.25% of the principal amount of the 5.00% Convertible Senior Notes to, and including, the 90 th day following such registration default and (ii) 0.50% of the principal amount of the 5.00% Convertible Senior Notes from, and after, the 91 st day following such registration default. In no event will the liquidated damages exceed 0.50% per year. Incentive Plans Our incentive compensation plans are described below. Long Term Incentive Plan On December 20, 2012, our Board of Directors (“Board”) approved the Par Petroleum Corporation 2012 Long Term Incentive Plan (“Incentive Plan” or “LTIP”). Under the Incentive Plan, the Board, or a committee of the Board, may grant incentive stock options, nonstatutory stock options, restricted stock, and restricted stock units to directors and other employees or those of our subsidiaries. On February 16, 2016 and February 27, 2018 , the Board approved the amendment and restatement of the Incentive Plan to increase the number of shares issuable under the Amended and Restated LTIP. The Company’s shareholders ratified the amended and restated Incentive Plan on June 2, 2016 and May 8, 2018 , respectively. The maximum number of shares that may be granted under the LTIP is 6.0 million shares of common stock. At December 31, 2019 , 1.8 million shares were available for future grants and awards under the LTIP. Restricted stock and restricted stock units awarded under the Incentive Plan are subject to restrictions, terms, and conditions, including forfeitures, as may be determined by the Board. During the period in which such restrictions apply, unless specifically provided otherwise in accordance with the terms of the Incentive Plan, the recipient of the restricted stock would be the record owner of the shares and have all of the rights of a stockholder with respect to the shares, including the right to vote and the right to receive dividends or other distributions made or paid with respect to the shares. The recipient of restricted stock units shall not have any of the rights of a stockholder of the Company until such units vest and convert into shares of common stock. The fair value of the restricted stock and stock units is generally determined based upon the quoted market price of our common stock on the date of grant. Restricted stock awards generally vest ratably over a four -year period. Restricted stock units do not vest ratably, rather they vest in full at the end of three years . Stock options are issued with an exercise price equal to the fair market value of our common stock on the date of grant and are subject to such other terms and conditions as may be determined by the Board. The options generally expire eight years from the grant date, unless granted by the Board for a shorter term. Option grants generally vest ratably over a four -year period. Stock Purchase Plan On June 12, 2014, the Board adopted a Stock Purchase Plan (as amended, the “SPP”) plan. The SPP is limited to the Company’s qualifying executive officers and directors who qualify as accredited investors under Rule 501(a) of the Securities Act of 1933, as amended. The SPP provides that each participant may, subject to compliance with securities laws and other regulations and only during “window periods” as described in our insider trading policy as in effect from time to time, until the later to occur of (a) December 31, 2015 or (b) the eighteen month anniversary of the date that the participant commenced his or her employment or service with us, purchase, in a single transaction, up to $1 million of shares of our common stock (“the SPP Shares”) at a per share purchase price equal to the closing price of the common stock on the date of purchase. The sale or transfer of the SPP Shares by such participant would be limited for the earlier of (i) two years from the date of purchase or (ii) the termination of the participant’s service with us or any affiliates for any reason. Additionally, the SPP provides that each purchasing participant will be granted a number of shares of restricted common stock under the Incentive Plan equal to 20% of the SPP Shares purchased with 50% of the restricted common stock vesting on each of the two annual anniversaries of the date of grant. Each purchasing participant will also be granted nonstatutory stock options with a 5 -year term to purchase a number of shares of common stock under the Incentive Plan (with an exercise price equal to the Fair Market Value as defined in the Incentive Plan on the date of grant) equal to certain specified percentages of the SPP Shares purchased based on a Black-Scholes model with 50% of the options vesting on each of the two annual anniversaries of the date of grant. Such percentages are as follows: 50% for a non-employee chairman of the Board, 35% for non-employee members of the Board, and 50% - 70% for executive officers. The following table summarizes our compensation costs recognized in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) under the Incentive Plan and Stock Purchase Plan (in thousands): Years Ended December 31, 2019 2018 2017 Restricted Stock Awards $ 3,490 $ 3,483 $ 4,263 Restricted Stock Units $ 1,269 $ 835 $ 502 Stock Option Awards $ 1,454 $ 1,878 $ 2,439 Employee Stock Purchase Plan On February 27, 2018 , our Board approved the Par Pacific Holdings, Inc. 2018 Employee Stock Purchase Plan (“ESPP”). Beginning in 2019, eligible employees may elect to purchase the Company’s common stock at 85% of the market price on the purchase date. Eligible employees may invest from 0% to 10% of their annual income subject to a $15 thousand annual maximum. The Board, or a committee of the Board, is authorized to set the market price discount percentages, any holding periods, and other purchasing terms and timing. The Company’s shareholders ratified the ESPP on May 8, 2018 . The maximum number of shares that may be issued under the ESPP is 500 thousand shares of common stock. At December 31, 2019 , 432 thousand shares remained available under the ESPP. During the year ended December 31, 2019 , we recognized $0.2 million of compensation costs in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) related to the 15% discount offered to employees under the ESPP. As of December 31, 2019 , employees purchased 68 thousand shares under the ESPP. Management Stock Purchase Plan On February 26, 2019 , our Board approved the Par Pacific Holdings, Inc. 2019 Management Stock Purchase Plan (the “MSPP”). The MSPP provides executive management with an opportunity to receive restricted stock units (“RSUs”) by converting a portion of their cash bonus compensation into RSUs (“Deferred RSUs”) and receiving awards of matching RSUs, the amount of which are determined by the amount of compensation converted (“Matching RSUs”). A Deferred RSU and a Matching RSU each represents a right to receive one share of the Company’s common stock in the future, subject to the terms and conditions of the MSPP, including, but not limited to, vesting requirements. Shares of common stock issued pursuant to awards of Deferred RSUs and Matching RSUs will be issued from the shares reserved for issuance under the LTIP. As of December 31, 2019 , no Deferred RSUs or Matching RSUs had been issued under the MSPP. Restricted Stock Awards and Restricted Stock Units The following table summarizes our restricted stock activity (in thousands, except per share amounts): Shares Weighted- Unvested balance at December 31, 2018 526 $ 17.29 Granted 295 17.43 Vested (213 ) 17.31 Forfeited (70 ) 16.64 Unvested balance at December 31, 2019 538 $ 16.95 The total fair value of restricted stock and restricted stock units that vested during the years ended December 31, 2019 , 2018 , and 2017 was $3.7 million , $3.3 million , and $4.0 million , respectively. The estimated weighted-average grant-date fair value per share of restricted stock and restricted stock units granted during the years ended December 31, 2019 , 2018 , and 2017 was $17.43 , $17.47 , and $15.49 , respectively. As of December 31, 2019 and 2018 , there was approximately $6.3 million and $5.8 million , of total unrecognized compensation costs related to restricted stock awards and restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 1.69 years and 2.46 years, respectively. Performance Restricted Stock Units The following table summarizes our performance restricted stock activity (in thousands, except per unit amounts): Units Weighted- Unvested balance at December 31, 2018 101 $ 16.14 Granted 48 17.00 Vested — — Forfeited (3 ) 17.34 Unvested balance at December 31, 2019 146 $ 16.33 These performance restricted stock units had a fair value of approximately $0.8 million , $0.8 million , and $0.7 million , respectively, and are subject to certain annual performance targets based on three-year-performance periods as defined by our Board of Directors. The estimated weighted-average grant-date fair value per share of performance restricted stock units granted during the years ended December 31, 2019 , 2018 , and 2017 was $17.00 , $17.34 , and $14.60 , respectively. As of December 31, 2019 and 2018 , there were approximately $0.9 million and $0.9 million of total unrecognized compensation costs related to the performance restricted stock units, which are expected to be recognized on a straight-line basis over a weighted-average period of 1.74 years and 1.87 years, respectively. Stock Option Grants The fair value of each option is estimated on the grant date using the Black-Scholes option pricing model. The expected term represents the period of time that options are expected to be outstanding and is based upon the term of the option. The expected volatility represents the extent to which our stock price is expected to fluctuate between the grant date and the expected term of the award. We do not use an expected dividend yield in our fair value measurement as we are restricted from the payment of dividends. The risk-free rate is the implied yield available on U.S. Treasury securities with a remaining term equal to the expected term of the option at the date of grant. The weighted-average assumptions used to measure stock options granted during 2019 , 2018 , and 2017 are presented below. 2019 2018 2017 Expected life from date of grant (years) 5.3 5.3 5.3 Expected volatility 34.3% 36.2% 42.0% Risk-free interest rate 2.46% 2.50% 1.97% The following table summarizes our stock option activity (in thousands, except per share amounts and term years): Number of Options Weighted-Average Weighted-Average Aggregate Outstanding balance at December 31, 2018 2,231 $ 19.27 4.8 $ — Issued 300 17.00 Exercised (483 ) 17.78 Forfeited / canceled (18 ) 17.00 Outstanding balance at December 31, 2019 2,030 $ 19.31 4.7 $ 7,981 Exercisable, end of year 1,275 $ 20.25 3.6 $ 3,816 The estimated weighted-average grant-date fair value per share of options granted during the year ended December 31, 2019 , 2018 , and 2017 was $5.98 , $6.30 , and $5.81 , respectively. As of December 31, 2019 and 2018 , there were approximately $2.7 million and $3.4 million , respectively, of total unrecognized compensation costs related to stock option awards, that are expected to be recognized on a straight-line basis over a weighted-average period of 1.69 and 2.32 years, respectively.

Benefit Plans

Benefit Plans	12 Months Ended
	Dec. 31, 2019
Retirement Benefits [Abstract]
Benefit Plans	Benefit Plans Defined Contribution Plans We maintain defined contribution plans for our employees. All eligible employees, other than our U.S. Oil employees, may participate in our Par plan after thirty days of service. All eligible employees at U.S. Oil & Refining Co. may participate in our U.S. Oil plan following the later of date of hire or age twenty-one . For all employees participating in the Par plan and non-union employees participating in the U.S. Oil plan, we match employee contributions up to a maximum of 6% of the employee’s eligible compensation, with the employer contributions vesting at 100% . For the years ended December 31, 2019 , 2018 , and 2017 , we made contributions to the plans totaling approximately $5.6 million , $4.0 million , and $3.6 million , respectively. Defined Benefit Plans We maintain defined benefit pension plans (the “Benefit Plans”) covering substantially all our Wyoming Refining employees and the employees of U.S. Oil covered by a collective bargaining agreement. Benefits under our Wyoming Refining plan are based on years of service and the employee’s highest average compensation received during five consecutive years of the last ten years of employment. Benefits under our U.S. Oil plan are based on the employee’s hourly rate of compensation at the beginning of each year of employment. Our funding policy is to contribute annually an amount equal to the pension expense, subject to the minimum funding requirements of the Employee Retirement Income Security Act of 1974 and the tax deductibility of such contributions. In December 2016, the Wyoming Refining Plan was amended (the “Plan Amendment”) to freeze all future benefit accruals for salaried plan participants. The changes in the projected benefit obligation and the fair value of plan assets of our Benefit Plans for the years ended December 31, 2019 and 2018 were as follows (in thousands): 2019 2018 Changes in projected benefit obligation: Projected benefit obligation as of the beginning of the period $ 27,539 $ 30,877 Acquired 16,831 — Service cost 910 548 Interest cost 1,794 1,107 Actuarial (gain) loss 6,688 (2,917 ) Benefits paid (1,620 ) (2,076 ) Projected benefit obligation as of the end of the period $ 52,142 $ 27,539 Changes in fair value of plan assets: Fair value of plan assets as of the beginning of the period $ 20,254 $ 23,461 Acquired 16,027 — Actual return (loss) on plan assets 6,405 (1,131 ) Employer contributions 1,800 — Benefits paid (1,620 ) (2,076 ) Fair value of plan assets as of the end of the period $ 42,866 $ 20,254 The underfunded status of our Benefit Plans is recorded within Other liabilities in our consolidated balance sheets. The reconciliation of the underfunded status of our Benefit Plans of December 31, 2019 and 2018 was as follows: 2019 2018 Projected benefit obligation $ 52,142 $ 27,539 Fair value of plan assets 42,866 20,254 Underfunded status $ 9,276 $ 7,285 Gross amounts recognized in accumulated other comprehensive income: (1) Net actuarial gain (loss) $ (2,622 ) $ 3,494 ____________________________________________________ (1) As of December 31, 2019 , we had an immaterial amount of service costs recognized in accumulated other comprehensive income. As of December 31, 2019 , we had $0.2 million in accumulated other comprehensive income that is expected to be amortized into net periodic benefit cost in 2020 . Weighted-average assumptions used to measure our projected benefit obligation as of December 31, 2019 , 2018 , and 2017 and net periodic benefit costs for the years ended December 31, 2019 , 2018 and 2017 are as follows: 2019 2018 2017 Projected benefit obligation: Wyoming Refining plan Discount rate (1) 3.30 % 4.20 % 3.65 % Rate of compensation increase 3.00 % 3.00 % 3.00 % U.S. Oil plan Discount rate (1) 3.10 % — % — % Rate of compensation increase 3.00 % — % — % Net periodic benefit costs: Wyoming Refining plan Discount rate (1) 4.20 % 3.65 % 4.20 % Expected long-term rate of return (2) 6.50 % 6.50 % 6.25 % Rate of compensation increase 3.00 % 3.00 % 4.30 % U.S. Oil plan Discount rate (1) 4.10 % — % — % Expected long-term rate of return (2) 6.00 % — % — % Rate of compensation increase 3.00 % — % — % _________________________________________________________ (1) In determining the discount rate, we use yields on high-quality fixed income investments with payments matched to the estimated distributions of benefits from our plans. (2) The expected long-term rate of return is based on a blend of historic returns of equity and debt securities. The net periodic benefit cost for the years ended December 31, 2019 , 2018 , and 2017 includes the following components: 2019 2018 2017 Components of net periodic benefit cost: Service cost $ 910 $ 548 $ 614 Interest cost 1,794 1,107 1,192 Expected return on plan assets (1,972 ) (1,258 ) (1,189 ) Amortization of net loss 95 — — Amortization of prior service cost 3 — — Net periodic benefit cost $ 830 $ 397 $ 617 The Service cost component of net periodic benefit cost is included in Operating expense (excluding depreciation) in our consolidated statement of operations for the years ended December 31, 2019 , 2018 , and 2017 . The other components of net periodic benefit cost are included in Other income (expense), net in our consolidated statement of operations for the years ended December 31, 2019 , 2018 , and 2017 . The weighted-average asset allocation for our Wyoming Refining plan at December 31, 2019 is as follows: Target Actual Asset category: Equity securities 54 % 56 % Debt securities 35 % 32 % Real estate 11 % 12 % Total 100 % 100 % The weighted-average asset allocation for our U.S. Oil plan at December 31, 2019 is as follows: Target Range Actual Asset category: Equity securities 40 - 80% 62 % Debt securities 20 - 60% 38 % Cash and Cash Equivalents 0 - 30% — % Total 100 % 100 % We have a long-term, risk-controlled investment approach using diversified investment options with minimal exposure to volatile investment options like derivatives. Our Benefit Plans’ assets are invested in pooled separate accounts administered by the Benefit Plans’ custodians. The underlying assets in the pooled separate accounts are invested in equity securities, debt securities, real estate, or cash and cash equivalents. The pooled separate accounts are valued based upon the fair market value of the underlying investments and are deemed to be Level 2. We intend to contribute $0.5 million to the U.S. Oil plan during 2020 . We do no t intend to make any contributions to the Wyoming Refining plan during 2020 . Based on current data and assumptions, the following benefit payments, which reflect expected future service, as appropriate, are expected to be paid over the next 10 years : Year Ended 2020 $ 2,215 2021 2,007 2022 2,082 2023 2,203 2024 2,234 Thereafter 13,095 $ 23,836

Income (Loss) Per Share

Income (Loss) Per Share	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Income (loss) per Share	Income (Loss) Per Share Basic income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the sum of the weighted-average number of common shares outstanding and the weighted-average number of shares issuable under the common stock warrants, representing 354 thousand shares for each of the years ended December 31, 2019 , 2018 , and 2017 . The common stock warrants are included in the calculation of basic income (loss) per share because they are issuable for minimal consideration. The following table sets forth the computation of basic and diluted income per share (in thousands, except per share amounts): Year Ended December 31, 2019 2018 2017 Net Income $ 40,809 $ 39,427 $ 72,621 Less: Undistributed income allocated to participating securities (1) 438 556 878 Net income attributable to common stockholders 40,371 38,871 71,743 Plus: Net income effect of convertible securities — — — Numerator for diluted income per common share $ 40,371 $ 38,871 $ 71,743 Basic weighted-average common stock shares outstanding 50,352 45,726 45,543 Plus: dilutive effects of common stock equivalents 118 29 40 Diluted weighted-average common stock shares outstanding 50,470 45,755 45,583 Basic income per common share $ 0.80 $ 0.85 $ 1.58 Diluted income per common share $ 0.80 $ 0.85 $ 1.57 ________________________________________________________ (1) Participating securities includes restricted stock that has been issued but has not yet vested. For the year ended December 31, 2019 , our calculation of diluted shares outstanding excluded 182 thousand shares of unvested restricted stock and 1.6 million stock options. For the year ended December 31, 2018 , our calculation of diluted shares outstanding excluded 68 thousand shares of unvested restricted stock and 1.3 million stock options. For the year ended December 31, 2017 , our calculation of diluted shares outstanding excluded 65 thousand shares of unvested restricted stock and 1.3 million stock options. As discussed in Note 12—Debt , we have the option of settling the 5.00% Convertible Senior Notes in cash or shares of common stock, or any combination thereof, upon conversion. For the years ended December 31, 2019 , 2018 , and 2017 , diluted income per share was determined using the if-converted method. Our calculation of diluted shares outstanding for years ended December 31, 2019 , 2018 , and 2017 excluded 5.1 million , 6.4 million , and 6.4 million

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes As of December 31, 2019 , we had approximately $1.4 billion in net operating loss carryforwards (“NOL carryforwards”); however, we currently have a valuation allowance against this and substantially all of our other deferred tax assets. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. For the year ended December 31, 2019 , we recorded an income tax benefit of $69.7 million primarily driven by a $64.2 million benefit associated with the partial release of our valuation allowance in connection with the recognition of deferred tax liabilities acquired as part of the Washington Acquisition . Management continues to conclude that we did not meet the “more likely than not” requirement in order to recognize deferred tax assets on the remaining amounts and a valuation allowance has been recorded for substantially all of our net deferred tax assets at December 31, 2019 and 2018 . In connection with our emergence from bankruptcy on August 31, 2012, we experienced an ownership change as defined under Section 382 of the Code. Section 382 generally places a limit on the amount of NOL carryforwards and other tax attributes arising before an ownership change that may be used to offset taxable income after an ownership change. We believe that we have qualified for an exception to the general limitation rules under Code Section 382(l)(5) which provides for substantially less restrictive limitations on our NOL carryforwards. Our amended and restated certificate of incorporation places restrictions upon the ability of certain equity interest holders to transfer their ownership interest in us. These restrictions are designed to provide us with the maximum assurance that another ownership change does not occur that could adversely impact our NOL carryforwards. We believe that any adjustment to our uncertain tax positions would no t have a material impact on our financial statements given the Company’s deferred tax and corresponding valuation allowance position as of December 31, 2019 . Our net taxable income must be apportioned to various states based upon the income tax laws of the states in which we derive our revenue. Our NOL carryforwards will not always be available to offset taxable income apportioned to the various states. The states from which our refining, retail, and logistics revenues are derived are not the same states in which our NOLs were incurred; therefore, we expect to incur state tax liabilities in connection with our refining, retail, and logistics operations. The Tax Cuts and Jobs Act enacted in 2017 lowered the Federal corporate tax rate from 35% to 21% and made numerous other tax law changes. GAAP requires companies to recognize the effect of tax law changes in the period of enactment. During 2018, we recorded a benefit for the release of $0.7 million of our valuation allowance to offset future temporary differences associated with the interest expense carryforwards available under the Tax Cuts and Jobs Act. During 2017, as a result of the change in rate, we remeasured our net deferred tax assets and the associated valuation allowance by $207.7 million . In 2017, we also released $0.8 million of valuation allowance related to Alternative Minimum Tax (“AMT”) credit carried forward from prior years that became refundable in connection with the Tax Cuts and Jobs Act. We will continue to assess the realizability of our deferred tax assets based on consideration of actual operating results. If sufficient positive evidence of improving actual operating results becomes available, the amount of the deferred tax asset considered more likely than not to be recognized would be increased with a corresponding reduction in income tax expense in the period recorded. Income tax expense (benefit) consisted of the following (in thousands): Year Ended December 31, 2019 2018 2017 Current: U.S.—Federal $ (3,203 ) $ (328 ) $ — U.S.—State 400 — 2 Deferred: U.S.—Federal (58,461 ) 426 (1,321 ) U.S.—State (8,425 ) 235 — Total $ (69,689 ) $ 333 $ (1,319 ) Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate to pretax income as a result of the following: Year Ended December 31, 2019 2018 2017 Federal statutory rate 21.0 % 21.0 % 35.0 % State income taxes, net of federal benefit (1.1 )% 0.6 % — % Change in valuation allowance related to current activity 227.1 % (21.3 )% (30.1 )% Change in valuation allowance related to change in tax rate — % — % (291.2 )% Change in tax rate — % — % 291.2 % Permanent items (4.3 )% 1.3 % 1.1 % Provision to return adjustments and other (1.4 )% (0.8 )% (7.9 )% Actual income tax rate 241.3 % 0.8 % (1.9 )% Deferred tax assets (liabilities) are comprised of the following (in thousands): December 31, 2019 2018 Deferred tax assets: Net operating loss $ 373,717 $ 396,033 Property, plant, and equipment — 8,323 Intangible assets — 444 Other 19,560 17,886 Total deferred tax assets 393,277 422,686 Valuation allowance (330,251 ) (394,196 ) Net deferred tax assets 63,026 28,490 Deferred tax liabilities: Inventory 5,738 — Property and equipment 64,281 — Investment in Laramie Energy 11,609 26,981 Convertible notes 2,285 2,658 Intangible assets 750 — Other 4,904 496 Total deferred tax liabilities 89,567 30,135 Total deferred tax liability, net $ (26,541 ) $ (1,645 ) We have NOL carryforwards as of December 31, 2019 of $1.4 billion for federal income tax purposes. If not utilized, the NOL carryforwards will expire during 2027 through 2036 . We also have AMT Credit Carryovers of $0.8 million which are refundable under the U.S. tax reform legislation effective in tax year 2019.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Segment Information	Segment Information We report the results for the following four reportable segments: (i) Refining , (ii) Retail , (iii) Logistics , and (iv) Corporate and Other. Commencing in the first quarter of 2018, the results of operations of Northwest Retail are included in our retail segment. Commencing January 11, 2019 , the results of operations of the Washington Acquisition are included in our refining and logistics segments. Summarized financial information concerning reportable segments consists of the following (in thousands): For the year ended December 31, 2019 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 5,167,942 $ 199,226 $ 458,889 $ (424,541 ) $ 5,401,516 Cost of revenues (excluding depreciation) 4,783,747 112,124 332,302 (424,584 ) 4,803,589 Operating expense (excluding depreciation) 234,582 11,010 67,307 — 312,899 Depreciation, depletion, and amortization 55,832 17,017 10,035 3,237 86,121 General and administrative expense (excluding depreciation) — — — 46,223 46,223 Acquisition and integration costs — — — 4,704 4,704 Operating income (loss) $ 93,781 $ 59,075 $ 49,245 $ (54,121 ) $ 147,980 Interest expense and financing costs, net (74,839 ) Debt extinguishment and commitment costs (11,587 ) Other income, net 2,516 Change in value of common stock warrants (3,199 ) Equity losses from Laramie Energy, LLC (89,751 ) Loss before income taxes (28,880 ) Income tax benefit 69,689 Net income $ 40,809 Total assets $ 1,907,318 $ 494,209 $ 232,150 $ 66,883 $ 2,700,560 Goodwill 77,927 55,232 62,760 — 195,919 Capital expenditures 34,492 40,730 6,869 1,829 83,920 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $424.5 million for the year ended December 31, 2019 . For the year ended December 31, 2018 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 3,210,067 $ 125,743 $ 441,040 $ (366,122 ) $ 3,410,728 Cost of revenues (excluding depreciation) 2,957,995 77,712 333,664 (366,255 ) 3,003,116 Operating expense (excluding depreciation) 146,320 7,782 61,182 — 215,284 Depreciation, depletion, and amortization 32,483 6,860 8,962 4,337 52,642 General and administrative expense (excluding depreciation) — — — 47,426 47,426 Acquisition and integration costs — — — 10,319 10,319 Operating income (loss) $ 73,269 $ 33,389 $ 37,232 $ (61,949 ) $ 81,941 Interest expense and financing costs, net (39,768 ) Debt extinguishment and commitment costs (4,224 ) Other income, net 1,046 Change in value of common stock warrants 1,801 Change in value of contingent consideration (10,500 ) Equity earnings from Laramie Energy, LLC 9,464 Income before income taxes 39,760 Income tax expense (333 ) Net income $ 39,427 Total assets $ 968,623 $ 130,138 $ 201,848 $ 160,125 $ 1,460,734 Goodwill 53,264 37,373 62,760 — 153,397 Capital expenditures 25,601 13,055 6,101 3,682 48,439 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $365.5 million for the year ended December 31, 2018 . For the year ended December 31, 2017 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 2,319,638 $ 121,470 $ 326,076 $ (324,118 ) $ 2,443,066 Cost of revenues (excluding depreciation) 2,062,804 66,301 249,097 (323,575 ) 2,054,627 Operating expense (excluding depreciation) 141,065 15,010 45,941 — 202,016 Depreciation, depletion, and amortization 29,753 6,166 6,338 3,732 45,989 General and administrative expense (excluding depreciation) — — — 46,078 46,078 Acquisition and integration costs — — — 395 395 Operating income (loss) $ 86,016 $ 33,993 $ 24,700 $ (50,748 ) $ 93,961 Interest expense and financing costs, net (31,632 ) Debt extinguishment and commitment costs (8,633 ) Other income, net 911 Change in value of common stock warrants (1,674 ) Equity earnings from Laramie Energy, LLC 18,369 Income before income taxes 71,302 Income tax benefit 1,319 Net income $ 72,621 Total assets $ 949,588 $ 118,304 $ 128,966 $ 150,549 $ 1,347,407 Goodwill 53,264 37,373 16,550 — 107,187 Capital expenditures 10,433 8,836 7,073 5,366 31,708 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $325.2 million for the year ended December 31, 2017 .

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2019
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Term Loan Certain of our stockholders, or affiliates of our stockholders, were the lenders under our Term Loan. In previous years, they received common stock warrants exercisable for shares of common stock in connection with the origination of the Term Loan. On June 15, 2016 , the Term Loan was amended to permit (i) the issuance of the 5.00% Convertible Senior Notes , (ii) the issuance of the Bridge Notes, and (iii) the WRC Acquisition . We paid a consent fee of $2.5 million in connection with this amendment, $1.3 million of which was paid to an affiliate of Whitebox, previously one of our largest stockholders. On June 21, 2016 , we repaid $5 million of the Term Loan pursuant to the terms of the amendment, $3.3 million of which was allocated to an affiliate of Whitebox. On June 30, 2017, we fully repaid and terminated the Term Loan. Convertible Notes Offering In June 2016, we issued $115 million in aggregate principal amount of our 5.00% Convertible Senior Notes in a private placement under Rule 144A in the Notes Offering. Please read Note 12—Debt for further discussion. Prior to the Notes Offering, we also entered into a backstop convertible note commitment letter with funds managed by Highbridge Capital Management, LLC (“Highbridge”) and funds managed on behalf of Whitebox (collectively, the “Backstop Convertible Note Purchasers”), pursuant to which the Backstop Convertible Note Purchasers committed to purchase $100 million aggregate principal amount of senior unsecured convertible notes due 2021, which would be issued in a private offering pursuant to an exemption from the registration requirements of the Securities Act. The obligations of the Backstop Convertible Note Purchasers to purchase convertible notes automatically terminated upon the consummation of the Notes Offering, provided that each of the Back Up Convertible Note Purchasers and their respective affiliates were allocated the opportunity to purchase at least $32.5 million of the 5.00% Convertible Senior Notes offered in the Notes Offering. Affiliates of Whitebox and Highbridge purchased an aggregate of $47.5 million and $40.4 million , respectively, principal amount of the 5.00% Convertible Senior Notes in the Notes Offering. Equity Group Investments (“EGI”) - Service Agreement On September 17, 2013, we entered into a letter agreement (“Services Agreement”) with Equity Group Investments (“EGI”), an affiliate of Zell Credit Opportunities Fund, LP (“ZCOF”), which owns 10% or more of our common stock directly or through affiliates. Pursuant to the Services Agreement, EGI agreed to provide us with ongoing strategic, advisory, and consulting services that may include (i) advice on financing structures and our relationship with lenders and bankers, (ii) advice regarding public and private offerings of debt and equity securities, (iii) advice regarding asset dispositions, acquisitions, or other asset management strategies, (iv) advice regarding potential business acquisitions, dispositions, or combinations involving us or our affiliates, or (v) such other advice directly related or ancillary to the above strategic, advisory, and consulting services as may be reasonably requested by us. EGI does not receive a fee for the provision of the strategic, advisory, or consulting services set forth in the Services Agreement, but may be periodically reimbursed by us, upon request, for (i) travel and out-of-pocket expenses, provided that, in the event that such expenses exceed $50 thousand in the aggregate with respect to any single proposed matter, EGI will obtain our consent prior to incurring additional costs, and (ii) provided that we provide prior consent to their engagement with respect to any particular proposed matter, all reasonable fees and disbursements of counsel, accountants, and other professionals incurred in connection with EGI’s services under the Services Agreement. In consideration of the services provided by EGI under the Services Agreement, we agreed to indemnify EGI for certain losses relating to or arising out of the Services Agreement or the services provided thereunder. The Services Agreement has a term of one year and will be automatically extended for successive one -year periods unless terminated by either party at least 60 days prior to any extension date. There were no costs incurred related to this agreement during the years ended December 31, 2019 , 2018 , or 2017 .

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited) Summarized quarterly data for the years ended December 31, 2019 and 2018 consisted of the following (in thousands, except per share amounts): Year Ended December 31, 2019 Q1 Q2 Q3 Q4 Revenues $ 1,191,335 $ 1,409,409 $ 1,401,638 $ 1,399,134 Operating income 21,423 48,621 18,405 59,531 Net income (loss) 61,092 28,169 (83,891 ) 35,439 Net income (loss) per share Basic $ 1.23 $ 0.56 $ (1.65 ) $ 0.68 Diluted $ 1.14 $ 0.56 $ (1.65 ) $ 0.68 Year Ended December 31, 2018 Q1 Q2 Q3 Q4 Revenues $ 765,439 $ 856,396 $ 909,781 $ 879,112 Operating income 27,656 28,983 4,894 20,408 Net income (loss) 15,185 16,178 (5,822 ) 13,886 Net income (loss) per share Basic $ 0.33 $ 0.35 $ (0.13 ) $ 0.30 Diluted $ 0.33 $ 0.35 $ (0.13 ) $ 0.30

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
Supplemental Oil and Gas Disclosures (Unaudited)	Supplemental Oil and Gas Disclosures (Unaudited) Our share of Laramie Energy's capitalized costs related to oil and gas activities are as follows (in thousands): December 31, 2019 2018 Company’s share of Laramie Energy Unproved properties $ 14,722 $ 16,379 Proved properties 211,083 473,763 225,805 490,142 Accumulated depreciation, depletion, and amortization (63,791 ) (150,075 ) Total $ 162,014 $ 340,067 Our share of Laramie Energy's costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands): Year Ended December 31, 2019 2018 2017 Company’s share of Laramie Energy Acquisition costs $ — $ — $ — Development costs—other 32,748 50,867 49,273 Total $ 32,748 $ 50,867 $ 49,273 For the years ended December 31, 2019 , 2018 , and 2017 , neither we nor Laramie Energy incurred exploratory well costs so no amounts were capitalized or expensed during these respective periods. Accordingly, there were no suspended exploratory well costs at December 31, 2019 , 2018 , and 2017 that were being evaluated. As of December 31, 2019 and 2018, we had no significant capitalized costs related to our other non-operated natural gas and oil interests. For the years ended December 31, 2019 and 2018, we incurred no significant costs related to our other non-operated natural gas and oil interests. A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Company Revenue Oil and gas revenues $ 156 $ 51 $ 288 Expenses Production costs 87 191 29 Depletion and amortization 6 17 66 Results of operations of oil and gas producing activities $ 63 $ (157 ) $ 193 Company’s share of Laramie Energy Revenue Oil and gas revenues $ 89,073 $ 93,493 $ 66,783 Expenses Production costs 41,446 42,706 32,606 Impairment of proved properties (1) 163,401 — — Depletion, depreciation, and amortization 38,011 26,819 21,277 Results of operations of oil and gas producing activities $ (153,785 ) $ 23,968 $ 12,900 Total results of operations of oil and gas producing activities $ (153,722 ) $ 23,811 $ 13,093 __________________________________________________ (1) Please read Note 3—Investment in Laramie Energy, LLC for further disclosures and information on Laramie Energy's impairment of proved properties.

Oil and Gas Reserve Information

Oil and Gas Reserve Information	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
Oil and Gas Reserves Information	Oil and Gas Reserve Information There are numerous uncertainties inherent in estimating quantities of proved crude oil and natural gas reserves. Crude oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be precisely measured. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of crude oil and natural gas that are ultimately recovered. Estimates of our crude oil and natural gas reserves and present values as of December 31, 2019 , 2018 , and 2017 , were prepared by Netherland, Sewell & Associates, Inc., independent reserve engineers. A summary of changes in estimated quantities of proved reserves for the years ended December 31, 2019 , 2018 , and 2017 is as follows: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) Company Balance at January 1, 2017 330 7 8 420 Revisions of quantity estimate 109 2 3 139 Extensions and discoveries — — — — Production (47 ) (2 ) — (59 ) Balance at December 31, 2017 392 7 11 500 Revisions of quantity estimate (269 ) (2 ) (10 ) (341 ) Extensions and discoveries — — — — Production (34 ) (1 ) — (40 ) Balance at December 31, 2018 89 4 1 119 Revisions of quantity estimate 222 1 7 270 Extensions and discoveries — — — — Acquisitions and divestitures (30 ) (3 ) — (48 ) Production (20 ) (1 ) — (26 ) Balance at December 31, 2019 261 1 8 315 Company ’ s share of Laramie Energy Balance at January 1, 2017 309,802 967 8,544 366,871 Revisions of quantity estimate 1,344 211 (434 ) 3 Extensions and discoveries — — — — Acquisitions and divestitures — — — — Production (18,104 ) (71 ) (608 ) (22,178 ) Balance at December 31, 2017 (2) 293,042 1,107 7,502 344,696 Revisions of quantity estimate 47,871 732 5,602 85,875 Extensions and discoveries — — — — Acquisitions and divestitures 22,391 12 191 23,609 Production (25,513 ) (106 ) (712 ) (30,421 ) Balance at December 31, 2018 (3) 337,791 1,745 12,583 423,759 Revisions of quantity estimate (69,924 ) (681 ) (6,287 ) (111,732 ) Extensions and discoveries — — — — Acquisitions and divestitures — — — — Production (29,677 ) (126 ) (883 ) (35,731 ) Balance at December 31, 2019 (4) 238,190 938 5,413 276,296 Total at December 31, 2019 238,451 939 5,421 276,611 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) During 2017 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, decreased by 22,095 MMcfe or approximately 6% . Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 22,178 MMcfe. The remaining change in estimated proved reserves was due to performance and other changes to the Company’s share of Laramie Energy’s proved developed producing and developed non-producing reserves. (3) During 2018 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, increased by 78,682 MMcfe or approximately 23% . The Company’s share of Laramie Energy’s revisions of quantity estimate increased primarily due to: 1) additions of 60,679 MMcfe of proved undeveloped reserves primarily located within Laramie Energy’s northern acreage, 2) 11,614 MMcfe of positive revisions associated with 13 probable locations that were converted to proved developed reserves during 2018, and 3) 13,582 MMcfe of positive revisions due to performance improvements and other changes to the Company’s share of Laramie Energy’s proved developed and undeveloped reserves. Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 30,421 MMcfe. During 2018, Laramie Energy closed on a purchase and contribution agreement with an unaffiliated third party that contributed 23,609 MMcfe of proved developed reserves in the Piceance Basin. (4) During 2019 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, decreased by 147,267 MMcfe or approximately 35% . The decreased was primarily due to: 1) 57,212 MMcfe downward revision driven by the removal of proved undeveloped locations from the development plan due to unfavorable market conditions, and 2) 54,520 MMcfe downward revision due to decreases in average natural gas prices in 2019 compared to 2018. Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 35,731 MMcfe. A summary of proved developed and undeveloped reserves for the years ended December 31, 2019 , 2018 , and 2017 is presented below: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) December 31, 2017 Proved developed reserves Company 392 7 11 500 Company’s share of Laramie Energy 174,464 658 4,589 205,946 Total 174,856 665 4,600 206,446 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy 118,578 449 2,913 138,750 Total 118,578 449 2,913 138,750 December 31, 2018 Proved developed reserves Company 89 4 1 119 Company’s share of Laramie Energy 256,363 1,420 8,868 318,091 Total 256,452 1,424 8,869 318,210 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy 81,428 325 3,715 105,668 Total 81,428 325 3,715 105,668 December 31, 2019 Proved developed reserves Company 261 1 8 315 Company’s share of Laramie Energy 238,190 938 5,413 276,296 Total 238,451 939 5,421 276,611 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy — — — — Total — — — — __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. Price per MMbtu WTI per Bbl Base pricing, before adjustments for contractual December 31, 2017 $ 2.68 $ 51.34 December 31, 2018 2.47 65.56 December 31, 2019 2.04 55.85 ______________________________________________ (1) Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors. Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests. December 31, 2019 2018 2017 (in thousands) Company Future net cash flows $ 833 $ 398 $ 1,802 Future costs Production 509 123 902 Development and abandonment 37 35 — Income taxes (1) — — — Future net cash flows 287 240 900 10% discount factor (106 ) (110 ) (328 ) Discounted future net cash flows $ 181 $ 130 $ 572 Company’s share of Laramie Energy Future net cash flows $ 669,271 $ 1,283,890 $ 1,026,005 Future costs Production 398,193 583,112 491,748 Development and abandonment 25,277 93,546 109,248 Income taxes (1) — — — Future net cash flows 245,801 607,232 425,009 10% discount factor (105,966 ) (288,130 ) (209,188 ) Discounted future net cash flows $ 139,835 $ 319,102 $ 215,821 Total discounted future net cash flows $ 140,016 $ 319,232 $ 216,393 _______________________________________________ (1) No income tax provision is included in the standardized measure of discounted future net cash flows calculation shown above as we do not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings. The principal sources of changes in the standardized measure of discounted net cash flows for the years ended December 31, 2019 , 2018 , and 2017 are as follows (in thousands): Company Company ’ s Share of Laramie Total Balance at January 1, 2017 $ 285 $ 141,142 $ 141,427 Sales of oil and gas production during the period, net of production costs (28 ) (29,911 ) (29,939 ) Net change in prices and production costs (60 ) 35,597 35,537 Revisions of previous quantity estimates, estimated timing of development and other 346 37,692 38,038 Previously estimated development and abandonment costs incurred during the period — 17,187 17,187 Accretion of discount 29 14,114 14,143 Balance at December 31, 2017 572 215,821 216,393 Sales of oil and gas production during the period, net of production costs (127 ) (47,165 ) (47,292 ) Acquisitions and divestitures — 35,182 35,182 Net change in prices and production costs 20 (1,365 ) (1,345 ) Revisions of previous quantity estimates, estimated timing of development and other (392 ) 54,311 53,919 Previously estimated development and abandonment costs incurred during the period — 40,736 40,736 Accretion of discount 57 21,582 21,639 Balance at December 31, 2018 130 319,102 319,232 Sales of oil and gas production during the period, net of production costs (55 ) (59,093 ) (59,148 ) Acquisitions and divestitures (143 ) — (143 ) Net change in prices and production costs (24 ) (114,195 ) (114,219 ) Revisions of previous quantity estimates, estimated timing of development and other 260 (64,333 ) (64,073 ) Previously estimated development and abandonment costs incurred during the period — 26,444 26,444 Accretion of discount 13 31,910 31,923 Balance at December 31, 2019 $ 181 $ 139,835 140,016

Condensed Financial Information

Condensed Financial Information of Registrant	12 Months Ended
	Dec. 31, 2019
Condensed Financial Information Disclosure [Abstract]
Condensed Financial Information of Parent Company Only Disclosure	SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT PAR PACIFIC HOLDINGS, INC. (PARENT ONLY) BALANCE SHEETS (in thousands, except share data) December 31, 2019 December 31, 2018 ASSETS Current assets Cash and cash equivalents $ 6,309 $ 28,701 Restricted cash 743 743 Total cash, cash equivalents, and restricted cash 7,052 29,444 Prepaid and other current assets 12,325 11,711 Due from subsidiaries 180,686 43,928 Total current assets 200,063 85,083 Property, plant, and equipment Property, plant, and equipment 20,961 18,939 Less accumulated depreciation, depletion, and amortization (12,117 ) (9,034 ) Property, plant, and equipment, net 8,844 9,905 Long-term assets Operating lease assets 4,276 — Investment in subsidiaries 636,742 638,975 Other long-term assets 1,128 3,334 Total assets $ 851,053 $ 737,297 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities Accounts payable $ 2,597 $ 8,312 Operating lease liabilities 698 — Other accrued liabilities 14,591 12,349 Due to subsidiaries 125,778 96,963 Total current liabilities 143,664 117,624 Long-term liabilities Long-term debt, net of current maturities 44,783 100,411 Common stock warrants 8,206 5,007 Finance lease liabilities 223 475 Operating lease liabilities 5,629 — Other liabilities 306 1,451 Total liabilities 202,811 224,968 Stockholders’ equity Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued — — Common stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2019 and December 31, 2018, 53,254,151 shares and 46,983,924 shares issued at December 31, 2019 and December 31, 2018, respectively 533 470 Additional paid-in capital 715,069 617,937 Accumulated deficit (67,942 ) (108,751 ) Accumulated other comprehensive income 582 2,673 Total stockholders’ equity 648,242 512,329 Total liabilities and stockholders’ equity $ 851,053 $ 737,297 This statement should be read in conjunction with the notes to consolidated financial statements. SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT PAR PACIFIC HOLDINGS, INC. (PARENT ONLY) STATEMENTS OF OPERATIONS (in thousands) Year Ended December 31, 2019 2018 2017 Operating expenses Depreciation and amortization $ 2,969 $ 4,092 $ 2,871 General and administrative expense (excluding depreciation) 20,017 20,721 18,922 Acquisition and integration costs 28 10,118 192 Total operating expenses 23,014 34,931 21,985 Operating loss (23,014 ) (34,931 ) (21,985 ) Other income (expense) Interest expense and financing costs, net (9,952 ) (10,867 ) (13,709 ) Debt extinguishment and commitment costs (6,091 ) — (1,804 ) Other income, net 2,303 1,155 631 Change in value of common stock warrants (3,199 ) 1,801 (1,674 ) Equity in earnings (losses) from subsidiaries 81,097 81,942 111,162 Total other income (expense), net 64,158 74,031 94,606 Income before income taxes 41,144 39,100 72,621 Income tax benefit (expense) (335 ) 327 — Net income $ 40,809 $ 39,427 $ 72,621 This statement should be read in conjunction with the notes to consolidated financial statements. STATEMENTS OF COMPREHENSIVE INCOME (in thousands) Year Ended December 31, 2019 2018 2017 Net income $ 40,809 $ 39,427 $ 72,621 Other comprehensive income (loss): (1) Other post-retirement benefits income (loss), net of tax (2,091 ) 529 (52 ) Total other comprehensive income (loss), net of tax (2,091 ) 529 (52 ) Comprehensive income $ 38,718 $ 39,956 $ 72,569 ____________________________________________________ (1) Other comprehensive income (loss) relates to benefit plans at our subsidiaries. SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT PAR PACIFIC HOLDINGS, INC. (PARENT ONLY) STATEMENTS OF CASH FLOWS (in thousands) Year Ended December 31, 2019 2018 2017 Cash flows from operating activities: Net income $ 40,809 $ 39,427 $ 72,621 Adjustments to reconcile net income to cash used in operating activities: Depreciation and amortization 2,969 4,092 2,871 Non-cash interest expense 4,600 4,925 5,617 Change in value of common stock warrants 3,199 (1,801 ) 1,674 Stock-based compensation 6,437 6,196 7,204 Equity in losses (income) of subsidiaries (81,097 ) (81,942 ) (111,162 ) Debt extinguishment and commitment costs 6,091 — 1,804 Net changes in operating assets and liabilities: Prepaid and other assets 1,592 (2,604 ) (2,568 ) Accounts payable, other accrued liabilities, and operating lease assets and liabilities (8,441 ) 5,601 3,088 Net cash used in operating activities (23,841 ) (26,106 ) (18,851 ) Cash flows from investing activities: Investments in subsidiaries — — (2,072 ) Distributions from subsidiaries 16,673 — 70,645 Capital expenditures (1,829 ) (3,682 ) (5,366 ) Due to (from) subsidiaries (6,519 ) (25,102 ) 80,762 Other investing activities 31 — — Net cash provided by (used in) investing activities 8,356 (28,784 ) 143,969 Cash flows from financing activities: Proceeds from sale of common stock, net of offering costs — 19,318 — Proceeds from borrowings 63,406 10,770 — Repayments of borrowings (76,323 ) (11,253 ) (68,873 ) Payment of deferred loan costs (252 ) — — Exercise of stock options 8,171 — — Payment for debt extinguishment and commitment costs (1,899 ) — — Other financing activities, net (10 ) (860 ) (993 ) Net cash provided by (used in) financing activities (6,907 ) 17,975 (69,866 ) Net increase (decrease) in cash, cash equivalents, and restricted cash (22,392 ) (36,915 ) 55,252 Cash, cash equivalents, and restricted cash at beginning of period 29,444 66,359 11,107 Cash, cash equivalents, and restricted cash at end of period $ 7,052 $ 29,444 $ 66,359 Supplemental cash flow information: Net cash received (paid) for: Interest $ (5,357 ) $ (5,750 ) $ (7,856 ) Taxes (220 ) (49 ) (1,478 ) Non-cash investing and financing activities: Accrued capital expenditures $ 497 $ 714 $ 370 ROU assets obtained in exchange for new finance lease liabilities 198 539 165 ROU assets obtained in exchange for new operating lease liabilities 134 — — Common stock issued for business combination 36,980 — — Non-cash contribution to subsidiary for business combination (36,980 ) — — Common stock issued to repurchase convertible notes 74,290 — — This statement should be read in conjunction with the notes to consolidated financial statements.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Principles of Consolidation and Basis of Presentation	Principles of Consolidation and Basis of Presentation The consolidated financial statements include the accounts of Par Pacific Holdings, Inc. and its subsidiaries. All intercompany balances and transactions have been eliminated in consolidation. Certain amounts previously reported in our consolidated financial statements for prior periods have been reclassified to conform to the current presentation.
Use of Estimates	Use of Estimates The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”) requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses and the related disclosures. Actual amounts could differ from these estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents consist of all highly liquid investments with original maturities of three months or less. The carrying value of cash equivalents approximates fair value because of the short-term nature of these investments.
Restricted Cash	Restricted Cash Restricted cash consists of cash not readily available for general purpose cash needs. Restricted cash relates to cash held at commercial banks to support letter of credit facilities and certain ongoing bankruptcy recovery trust claims.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts
Inventories	Inventories Commodity inventories, excluding commodity inventories at the Washington refinery, are stated at the lower of cost or net realizable value using the first-in, first-out (“FIFO”) inventory accounting method. Commodity inventories at the Washington refinery are stated at the lower of cost or net realizable value using the last-in, first-out (“LIFO”) inventory accounting method. We value merchandise along with spare parts, materials, and supplies at average cost. As of December 31, 2019 , the excess of current replacement cost over LIFO inventory carrying value at the Washington refinery was approximately $6.4 million . All of the crude oil utilized at the Hawaii refineries is financed by J. Aron & Company LLC (“J. Aron”) under the Supply and Offtake Agreements as described in Note 11—Inventory Financing Agreements . The crude oil remains in the legal title of J. Aron and is stored in our storage tanks governed by a storage agreement. Legal title to the crude oil passes to us at the tank outlet. After processing, J. Aron takes title to the refined products stored in our storage tanks until they are sold to our retail locations or to third parties. We record the inventory owned by J. Aron on our behalf as inventory with a corresponding obligation on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties and we are obligated to repurchase the inventory. In connection with the consummation of the Washington Acquisition (as defined in Note 4—Acquisitions ), we became a party to an intermediation arrangement (the “ Washington Refinery Intermediation Agreement ”) with Merrill Lynch Commodities, Inc. (“ MLC ”) as described in Note 11—Inventory Financing Agreements . Under this arrangement, U.S. Oil (as defined in Note 4—Acquisitions ) purchases crude oil supplied from third-party suppliers and MLC provides credit support for certain crude oil purchases. MLC ’s credit support can consist of either providing a payment guaranty, causing the issuance of a letter of credit from a third party issuing bank, or purchasing crude oil directly from third parties on our behalf. U.S. Oil holds title to all crude oil and refined products inventories at all times and pledges such inventories, together with all receivables arising from the sales of same, exclusively to MLC . We enter into refined product and crude oil exchange agreements with other oil companies. Exchange receivables or payables are stated at cost and are presented within Trade accounts receivable and Accounts payable on our consolidated balance sheets.
Renewable Identification Numbers	Renewable Identification Numbers Beginning in 2018, Inventories also include Renewable Identification Numbers (“RINs”) , sulfur credits, and other environmental credits. Our RINs assets, which include RINs purchased in the open market and RINs obtained by purchasing biofuels, which are blended into our refined products, are presented as Inventories on our consolidated balance sheets and stated at the lower of cost or net realizable value (“NRV”) as of the end of the reporting period. Our RINs obligations to comply with the Renewable Fuel Standard (“RFS”) (discussed in Note 16—Commitments and Contingencies ) are presented as Other accrued liabilities on our consolidated balance sheets and measured at fair value as of the end of the reporting period. Our sulfur credits and other environmental credits generated as part of our refining process are presented as Inventories on our consolidated balance sheets and stated at the lower of cost or NRV as of the end of the reporting period. The net cost of environmental credits is recognized within Cost of revenues (excluding depreciation) in our consolidated statements of operations.
Investment in Laramie Energy, LLC	Investment in Laramie Energy, LLC We account for our Investment in Laramie Energy, LLC using the equity method as we have the ability to exert significant influence, but do not control its operating and financial policies. Our proportionate share of net income (loss) of this entity is included in Equity earnings (losses) from Laramie Energy, LLC
Property Plant and Equipment	Property, Plant, and Equipment We capitalize the cost of additions, major improvements, and modifications to property, plant, and equipment. The cost of repairs and normal maintenance of property, plant, and equipment is expensed as incurred. Major improvements and modifications of property, plant, and equipment are those expenditures that either extend the useful life, increase the capacity, or improve the operating efficiency of the asset or the safety of our operations. We compute depreciation of property, plant, and equipment using the straight-line method, based on the estimated useful life of each asset as follows: Assets Lives in Years Refining 5 to 47 Logistics 3 to 30 Retail 3 to 30 Corporate 3 to 7 Software 3 to 5 We review property, plant, and equipment, operating leases, and other long-lived assets for impairment whenever events or changes in business circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicated when the undiscounted cash flows estimated to be generated by those assets are less than the assets’ carrying value. If this occurs, an impairment loss is recognized for the difference between the fair value and carrying value. Factors that indicate potential impairment include a significant decrease in the market value of the asset, operating or cash flow losses associated with the use of the asset, and a significant change in the asset’s physical condition or use.
Asset Retirement Obligations	Asset Retirement Obligations We record asset retirement obligations (“AROs”) in the period in which we have a legal obligation, whether by government action or contractual arrangement, to incur these costs and can make a reasonable estimate of the liability. Our AROs arise from our refining, logistics, and retail operations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. When the liability is initially recorded, we capitalize the cost by increasing the book value of the related long-lived tangible asset. The liability is accreted to its estimated settlement value with accretion expense recognized in Depreciation, depletion, and amortization (“DD&A”) on our consolidated statements of operations and the related capitalized cost is depreciated over the asset’s useful life. The difference between the settlement amount and the recorded liability is recorded as a gain or loss on asset disposals in our consolidated statements of operations. We estimate settlement dates by considering our past practice, industry practice, contractual terms, management’s intent, and estimated economic lives. We cannot currently estimate the fair value for certain AROs primarily because we cannot estimate settlement dates (or range of dates) associated with these assets. These AROs include hazardous materials disposal (such as petroleum manufacturing by-products, chemical catalysts, and sealed insulation material containing asbestos) and removal or dismantlement requirements associated with the closure of our refining facilities, terminal facilities, or pipelines, including the demolition or removal of certain major processing units, buildings, tanks, pipelines, or other equipment.
Deferred Turnaround Costs	Deferred Turnaround Costs Refinery turnaround costs, which are incurred in connection with planned major maintenance activities at our refineries, are deferred and amortized on a straight-line basis over the period of time estimated until the next planned turnaround (generally three to five years ). During 2019 , we recognized deferred turnaround costs of approximately $9.8 million . No deferred turnaround costs were recorded during 2018 and 2017 . Deferred turnaround costs are presented within Other long-term assets on our consolidated balance sheets.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets Goodwill represents the amount the purchase price exceeds the fair value of net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment annually on October 1. We assess the recoverability of the carrying value of goodwill during the fourth quarter of each year or whenever events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable. We first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying value. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a quantitative test is required. Under the quantitative test, we compare the carrying value of the net assets of the reporting unit to the estimated fair value of the reporting unit. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss is recorded. Our intangible assets include relationships with customers, trade names, and trademarks. These intangible assets are amortized over their estimated useful lives on a straight-line basis. We evaluate the carrying value of our intangible assets when impairment indicators are present. When we believe impairment indicators may exist, projections of the undiscounted future cash flows associated with the use of and eventual disposition of the intangible assets are prepared. If the projections indicate that their carrying values are not recoverable, we reduce the carrying values to their estimated fair values.
Environmental Matters	Environmental Matters We capitalize environmental expenditures that extend the life or increase the capacity of facilities as well as expenditures that prevent environmental contamination. We expense costs that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation. We record liabilities when environmental assessments and/or remedial efforts are probable and can be reasonably estimated. Cost estimates are based on the expected timing and extent of remedial actions required by governing agencies, experience gained from similar sites for which environmental assessments or remediation have been completed, and the amount of our anticipated liability considering the proportional liability and financial abilities of other responsible parties. Usually, the timing of these accruals coincides with the completion of a feasibility study or our commitment to a formal plan of action. Estimated liabilities are not discounted to present value and are presented within Other liabilities on our consolidated balance sheets. Environmental expenses are recorded in Operating expense (excluding depreciation) on our consolidated statements of operations.
Derivatives and Other Financial Instruments	Derivatives and Other Financial instruments We are exposed to commodity price risk related to crude oil and refined products. We manage this exposure through the use of various derivative commodity instruments. These instruments include exchange traded futures and over-the-counter (“OTC”) swaps, forwards, and options. For our forward contracts that are derivatives, we have elected the normal purchase normal sale exclusion, as it is our policy to fulfill or accept the physical delivery of the product and we will not net settle. Therefore, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements. We apply the accrual method of accounting to our forward contracts. All derivative instruments not designated as normal purchases or sales are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of these derivative instruments are recognized currently in earnings. We have not designated any derivative instruments as cash flow or fair value hedges and, therefore, do not apply hedge accounting treatment. In addition, we may have other financial instruments, such as warrants or embedded debt features, that may be classified as liabilities when either (a) the holders possess rights to net cash settlement, (b) physical or net equity settlement is not in our control, or (c) the instruments contain other provisions that cause us to conclude that they are not indexed to our equity. Our embedded derivatives include: our obligations to repurchase crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements and to repay MLC for monthly crude oil and refined product financing under the Washington Refinery Intermediation Agreement and the redemption option and the related make-whole premium on our 5.00% Convertible Senior Notes . These liabilities were initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.
Income Taxes	Income Taxes We use the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and net operating loss (“NOL”) and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted income tax rates expected to apply to taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in income tax rates is recognized in the results of operations in the period that includes the enactment date. The realizability of deferred tax assets is evaluated quarterly based on a “more likely than not” standard and, to the extent this threshold is not met, a valuation allowance is recorded. We have determined that any uncertain tax positions outstanding at December 31, 2019 and 2018 would not have a material impact on our financial condition, results of operations, or cash flows as any uncertain tax positions taken would have been fully covered by the Company’s deferred tax assets related to its historical net operating losses and corresponding valuation allowance. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2016 , 2017 , and 2018 . However, since we have NOL carryforwards, the IRS has the ability to make adjustments to items that originate in a year otherwise barred by the statute of limitations in order to re-determine tax for an open year to which those items are carried. Therefore, in a year in which a NOL deduction is claimed, the IRS may examine the year in which the NOL was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deduction was claimed. Any penalties or interest as a result of an examination will be recorded in the period assessed.
Stock Based Compensation	Stock-Based Compensation We recognize the cost of share-based payments on a straight-line basis over the period the employee provides service, generally the vesting period, and include such costs in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation)
Revenue Recognition	Revenue Recognition On January 1, 2018, we adopted ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09” or “ASC 606”), as amended by other ASUs, using the modified retrospective method applied to all contracts that were not completed as of January 1, 2018. As such, the comparative financial information for prior periods has not been adjusted and continues to be reported under Financial Accounting Standards Board (“FASB”) ASC Topic 605, Revenue Recognition (“ASC 605”). We did not identify any significant differences in our existing revenue recognition policies that require modification under the new standard; therefore, we did not recognize a cumulative adjustment on opening equity as of January 1, 2018. Refining and Retail Our refining and retail segment revenues are primarily associated with the sale of refined products. We recognize revenues upon physical delivery of refined products to a customer, which is the point in time at which control of the refined products is transferred to the customer. The refining segment’s contracts with its customers state the terms of the sale, including the description, quantity, delivery terms, and price of each product sold. Payments from customers are generally due in full within 2 to 30 days of product delivery or invoice date. We account for certain transactions on a net basis under FASB ASC Topic 845, “Nonmonetary Transactions.” These transactions include nonmonetary crude oil and refined product exchange transactions, certain crude oil buy/sell arrangements, and sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another. Upon adoption of ASC 606, we made an accounting policy election to apply the sales tax practical expedient, whereby all taxes assessed by a governmental authority that are both imposed on and concurrent with a revenue-producing transaction and collected from our customers will be recognized on a net basis within Cost of revenues (excluding depreciation). This change in our accounting policy did not have a material impact on our consolidated financial information for the years ended December 31, 2019 and 2018. Logistics We recognize transportation and storage fees as services are provided to a customer. Substantially all of our logistics revenues represent intercompany transactions that are eliminated in consolidation. Cost Classifications Cost of revenues (excluding depreciation) includes the hydrocarbon-related costs of inventory sold, transportation costs of delivering product to customers, crude oil consumed in the refining process, costs to satisfy our RINs obligations, and certain hydrocarbon fees and taxes. Cost of revenues (excluding depreciation) also includes the unrealized gains (losses) on derivatives and inventory valuation adjustments. Certain direct operating expenses related to our logistics segment are also included in Cost of revenues (excluding depreciation). Operating expense (excluding depreciation) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, and environmental compliance costs, as well as chemicals and catalysts and other direct operating expenses.
Benefit Plans	Benefit Plans We recognize an asset for the overfunded status or a liability for the underfunded status of our defined benefit pension plans. The funded status is recorded within Other long-term liabilities. Certain changes in the plans’ funded status are recognized in Other comprehensive income (loss) in the period the change occurs.
Fair Value Measurements	Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are categorized with the highest priority given to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority given to unobservable inputs. The three levels of the fair value hierarchy are as follows: Level 1 – Assets or liabilities for which the item is valued based on quoted prices (unadjusted) for identical assets or liabilities in active markets. Level 2 – Assets or liabilities valued based on observable market data for similar instruments. Level 3 – Assets or liabilities for which significant valuation assumptions are not readily observable in the market; instruments valued based on the best available data, some of which is internally-developed and considers risk premiums that a market participant would require. The level in the fair value hierarchy within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. Our policy is to recognize transfers in and/or out of fair value hierarchy levels as of the end of the reporting period for which the event or change in circumstances caused the transfer. We have consistently applied these valuation techniques for the periods presented. The fair value of the J. Aron repurchase obligation derivative is measured using estimates of the prices and differentials assuming settlement at the end of the reporting period.
Loss (Loss) Per Share	Income (Loss) Per Share Basic income (loss) per share (“EPS”) is computed by dividing net income (loss) attributable to common stockholders by the sum of the weighted-average number of common shares outstanding and the weighted-average number of shares issuable under the warrants. The common stock warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Basic and diluted EPS are computed taking into account the effect of participating securities. Participating securities include restricted stock that has been issued but has not yet vested. Please read Note 19—Income (Loss) Per Share for further information.
Foreign Currency Transactions	Foreign Currency Transactions We may, on occasion, enter into transactions denominated in currencies other than the U.S. dollar, which is our functional currency. Gains and losses resulting from changes in currency exchange rates between the functional currency and the currency in which a transaction is denominated are included in Other income (expense), net , in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.
Accounting Principles Adopted and Not Yet Adopted	Accounting Principles Not Yet Adopted In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“ASU 2016-13”). This ASU requires expected credit losses on financial instruments to be recorded over the estimated life of the financial instrument. Prior to this ASU, the guidance required recording of credit losses when those losses were incurred. ASU 2016-13 is applicable to credit losses and allowances on loans, debt securities, trade receivables, net investments in leases, off-balance-sheet credit exposures, reinsurance receivables, and certain other financial assets, but excludes derivative assets under FASB ASC Topic 815 “Derivatives and Hedging.” The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted, and primarily requires adoption on the modified retrospective transition method. On January 1, 2020, we adopted this ASU and our adoption did not have a material impact on our financial condition, results of operations, cash flows, or related disclosures. In January 2017, the FASB issued ASU No. 2017-04, Intangibles—Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment (“ASU 2017-04”), which eliminates Step 2 from the current goodwill impairment test. Under ASU 2017-04, an entity is no longer required to determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if that reporting unit had been acquired in a business combination. Under ASU 2017-04, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. This ASU should be applied prospectively from the date of adoption. This ASU will change the policy under which we perform our annual goodwill impairment assessment by eliminating Step 2 of the test. In August 2018, the FASB issued ASU No. 2018-13, Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement ( “ ASU 2018-13”). This ASU amends, adds, and removes certain disclosure requirements under FASB ASC Topic 820 “Fair Value Measurement.” The guidance in ASU 2018-13 is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. This ASU will result in expanded disclosures within our interim and annual footnote disclosures, however, we do not expect the adoption of ASU 2018-13 to have a material impact on our financial condition, results of operations, or cash flows. In August 2018, the FASB issued ASU No. 2018-14, Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans ( “ ASU 2018-14”). This ASU amends, adds, and removes certain disclosure requirements under FASB ASC Topic 715 “Compensation — Retirement Benefits.” The guidance in ASU 2018-14 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. This ASU will result in expanded disclosures within our interim and annual footnote disclosures, however, we do not expect the adoption of ASU 2018-14 to have a material impact on our financial condition, results of operations, or cash flows. In August 2018, the FASB issued ASU No. 2018-15, Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract ( “ ASU 2018-15”). This ASU requires entities to account for implementation costs incurred in a cloud computing agreement that is a service contract under the guidance in FASB ASC Topic 350, “Goodwill and Intangible Assets,” which results in a capitalized and amortizable intangible asset. The guidance in ASU 2018-15 is effective for fiscal years and interim periods beginning after December 15, 2019, with early adoption permitted. On January 1, 2020, we adopted ASU 2018-15 under the prospective method and information that was presented prior to January 1, 2020 has not been restated and continues to be reported under the accounting standards in effect for that period. The adoption of ASU 2018-15 did not have a material impact on our financial condition, results of operations, or cash flows. In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes ( “ ASU 2019-12”). The objective of ASU 2019-12 is to simplify the accounting for income taxes by removing certain exceptions to general principles and to clarify and amend guidance to improve consistency under FASB ASC 740 “Income Taxes.” The guidance in ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. We are in the process of determining the method(s) of adoption and the impact this guidance will have on our financial condition, results of operations, and cash flows. Accounting Principles Adopted On January 1, 2019, we adopted ASU No. 2016-02, Leases (Topic 842) , as amended by other ASUs issued through February 2019 (“ASU 2016-02” or “ASC 842”), using the modified retrospective transition method. Under this optional transition method, information presented prior to January 1, 2019 has not been restated and continues to be reported under the accounting standards in effect for the period. There was no adjustment to our opening retained earnings as a result of the adoption of this ASU. ASU 2016-02 required lessees to recognize a ROU asset and lease liability on the balance sheet for all rights and obligations created by leases. The new standard provided a number of optional practical expedients. We have elected: • the package of practical expedients, permitting us to carry forward our conclusions regarding lease identification, classification, and initial direct costs for contracts that commenced prior to the effective date; • the practical expedient pertaining to land easements, allowing us to account for existing land easements under our previous accounting policy; • the short-term lease exemption, which states that leases that are 12 months or less are exempt from balance sheet reporting; and • the practical expedient that allows us to combine lease and non-lease components. ASC 842 had a material impact on our consolidated balance sheet; however, it did not materially impact our consolidated statement of operations or statement of cash flows. As a result of the adoption of ASC 842, we recorded ROU assets and lease liabilities related to operating leases of $347 million and $349 million , respectively. Our accounting for finance leases remained substantially unchanged. Additionally, we acquired operating lease assets and lease liabilities of $62 million in connection with the Washington Acquisition (as defined in Note 4—Acquisitions ). Please read Note 15—Leases for further disclosures and information. On January 1, 2019, we adopted ASU No. 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income ( “ ASU 2018-02”) and elected not to reclassify to retained earnings the stranded effects in Accumulated Other Comprehensive Income related to the changes in the statutory tax rate that were charged to income from continuing operations under the requirements of FASB ASC Topic 740, “Income Taxes.” The adoption of ASU 2018-02 did not have a material impact on our financial condition, results of operations, and cash flows.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Property Plant And Equipment Estimated Useful Life	We compute depreciation of property, plant, and equipment using the straight-line method, based on the estimated useful life of each asset as follows: Assets Lives in Years Refining 5 to 47 Logistics 3 to 30 Retail 3 to 30 Corporate 3 to 7 Software 3 to 5
Summary of Depreciation Expense	The following table summarizes depreciation and finance lease amortization expense excluded from each line item in our consolidated statements of operations (in thousands): Year Ended December 31, 2019 2018 2017 Cost of revenues $ 16,882 $ 6,722 $ 6,029 Operating expense 55,181 28,037 22,861 General and administrative expense 3,145 4,233 2,929

Investment in Laramie Energy,_2

Investment in Laramie Energy, LLC (Tables)	12 Months Ended
	Dec. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	The change in our equity investment in Laramie Energy is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Beginning balance $ 136,656 $ 127,192 $ 108,823 Equity earnings (losses) from Laramie Energy (175,018 ) 4,487 13,043 Accretion of basis difference 5,018 4,977 5,326 Adjustment of basis difference (1) 161,764 — — Impairment of our investment in Laramie Energy (81,515 ) — — Ending balance $ 46,905 $ 136,656 $ 127,192 ________________________________________________________ (1) Represents the reduction in our basis difference resulting from the asset impairment loss recorded by Laramie Energy for the year ended December 31, 2019.
Equity Method Investees Financial Information	Summarized financial information for Laramie Energy is as follows (in thousands): December 31, 2019 2018 Current assets $ 23,367 $ 28,569 Non-current assets 393,575 788,515 Current liabilities 229,687 41,681 Non-current liabilities 85,287 293,084 Year Ended December 31, 2019 2018 2017 Natural gas and oil revenues $ 193,906 $ 226,974 $ 157,879 Income (loss) from operations (360,967 ) 34,206 6,019 Net income (loss) (380,473 ) 6,347 30,837

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 16,146 Accounts receivable 34,954 Inventories 98,367 Prepaid and other assets 5,320 Property, plant, and equipment 412,766 Operating lease assets 62,337 Goodwill (1) 42,522 Total assets (2) 672,412 Obligations under inventory financing agreements (116,873 ) Accounts payable (55,357 ) Current operating lease liabilities (21,571 ) Other current liabilities (18,411 ) Long-term operating lease liabilities (40,766 ) Deferred tax liability (92,103 ) Other non-current liabilities (804 ) Total liabilities (345,885 ) Total $ 326,527 ______________________________________________ (1) We allocated $24.7 million and $17.8 million of goodwill to our refining and logistics segments, respectively. (2) We allocated $403.9 million and $268.5 million of total assets to our refining and logistics segments, respectively. A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 200 Inventories 4,138 Prepaid and other current assets 243 Property, plant, and equipment 30,230 Goodwill (1) 46,210 Accounts payable and other current liabilities (759 ) Long-term capital lease obligations (5,244 ) Other non-current liabilities (487 ) Total $ 74,531 ________________________________________________________ (1) The total goodwill balance of $46.2 million was allocated to our retail segment.
Business Acquisition, Pro Forma Information	The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the Washington Acquisition had been completed on January 1, 2018 (in thousands except per share information): Year Ended December 31, 2019 2018 Revenues $ 5,429,530 $ 4,709,850 Net income (loss) (4,547 ) 88,174 Income (loss) per share Basic $ (0.09 ) $ 1.81 Diluted $ (0.09 ) $ 1.79

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table provides information about disaggregated revenue by major product line and includes a reconciliation of the disaggregated revenues to total segment revenues (in thousands): Year Ended December 31, 2019 Refining Logistics Retail Product or service: Gasoline $ 1,416,706 $ — $ 326,304 Distillates (1) 2,503,981 — 40,189 Other refined products (2) 1,242,401 — — Merchandise — — 90,480 Transportation and terminalling services — 199,226 — Other revenue 4,854 — 1,916 Total segment revenues (3) $ 5,167,942 $ 199,226 $ 458,889 Year Ended December 31, 2018 Refining Logistics Retail Product or service: Gasoline $ 981,090 $ — $ 317,434 Distillates (1) 1,770,381 — 39,835 Other refined products (2) 458,596 — — Merchandise — — 83,771 Transportation and terminalling services — 125,743 — Total segment revenues (3) $ 3,210,067 $ 125,743 $ 441,040 _______________________________________________________ (1) Distillates primarily include diesel and jet fuel. (2) Other refined products include fuel oil, gas oil, asphalt, and naphtha. (3) Refer to Note 21—Segment Information

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2019
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	Inventories at December 31, 2019 and 2018 consisted of the following (in thousands): Titled Inventory Supply and Offtake Agreements (1) Total December 31, 2019 Crude oil and feedstocks $ 117,717 $ 148,303 $ 266,020 Refined products and blendstock 127,966 158,737 286,703 Warehouse stock and other (2) 63,149 — 63,149 Total $ 308,832 $ 307,040 $ 615,872 December 31, 2018 Crude oil and feedstocks $ 7,000 $ 117,877 $ 124,877 Refined products and blendstock 62,401 100,175 162,576 Warehouse stock and other (2) 34,612 — 34,612 Total $ 104,013 $ 218,052 $ 322,065 _________________________________________________________ (1) Please read Note 11—Inventory Financing Agreements for further information. (2) Includes $19.1 million and $5.0 million of RINs and environmental credits as of December 31, 2019 and 2018 , respectively.

Prepaid and Other Current Ass_2

Prepaid and Other Current Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Prepaid and other current assets at December 31, 2019 and 2018 consisted of the following (in thousands): December 31, 2019 2018 Advances to suppliers $ 27,635 $ — Collateral posted with broker for derivative instruments (1) 10,306 2,759 Prepaid insurance 13,536 7,727 Derivative assets 2,075 5,164 Other 5,604 12,720 Total $ 59,156 $ 28,370 _________________________________________________________ (1) Our cash margin that is required as collateral deposits on our commodity derivatives cannot be offset against the fair value of open contracts except in the event of default. Please read Note 13—Derivatives for further information.

Property, Plant and Equipment D

Property, Plant and Equipment Disclosure (Tables)	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Major classes of property, plant, and equipment, including assets acquired under finance leases, consisted of the following (in thousands): December 31, 2019 2018 Land $ 188,096 $ 117,559 Buildings and equipment (1) 937,926 512,870 Other (1) 20,961 18,939 Total property, plant, and equipment 1,146,983 649,368 Proved oil and gas properties — 400 Less accumulated depreciation, depletion, and amortization (185,040 ) (111,507 ) Property, plant, and equipment, net $ 961,943 $ 538,261 ______________________________________________________ (1) Please read Note 15—Leases for further disclosures and information on leases.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The table below summarizes the changes in our recorded asset retirement obligations (in thousands): Year Ended December 31, 2019 2018 2017 Beginning balance $ 9,985 $ 9,103 $ 9,042 Obligations acquired — 487 — Accretion expense 331 395 369 Liabilities settled during period (136 ) — (308 ) Ending balance $ 10,180 $ 9,985 $ 9,103

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	During the years ended December 31, 2019 and 2018 , the change in the carrying amount of goodwill was as follows (in thousands): Balance at January 1, 2018 $ 107,187 Acquisition of Northwest Retail (1) 46,210 Balance at December 31, 2018 153,397 Acquisition of U.S. Oil (1) 42,522 Balance at December 31, 2019 $ 195,919 ________________________________________________________ (1) Please read Note 4—Acquisitions for further discussion.
Schedule of Finite-Lived Intangible Assets	Intangible assets consisted of the following (in thousands): December 31, 2019 2018 Intangible assets: Trade names and trademarks $ 6,267 $ 6,267 Customer relationships 32,064 32,064 Other 261 — Total intangible assets 38,592 38,331 Accumulated amortization: Trade name and trademarks (5,124 ) (5,037 ) Customer relationships (11,919 ) (9,347 ) Other — — Total accumulated amortization (17,043 ) (14,384 ) Net: Trade name and trademarks 1,143 1,230 Customer relationships 20,145 22,717 Other 261 — Total intangible assets, net $ 21,549 $ 23,947
Finite-lived Intangible Assets Amortization Expense	Expected amortization expense for each of the next five years and thereafter is as follows (in thousands): Year Ended Amount 2020 $ 2,658 2021 2,658 2022 2,658 2023 2,658 2024 1,400 Thereafter 9,517 $ 21,549

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Schedule of Debt	The following table summarizes our outstanding debt (in thousands): December 31, 2019 2018 5.00% Convertible Senior Notes due 2021 $ 48,665 $ 115,000 7.75% Senior Secured Notes due 2025 300,000 300,000 ABL Credit Facility — — Mid Pac Term Loan 1,433 1,466 Term Loan B 240,625 — Retail Property Term Loan 44,014 — Principal amount of long-term debt 634,737 416,466 Less: unamortized discount and deferred financing costs (22,806 ) (23,826 ) Total debt, net of unamortized discount and deferred financing costs 611,931 392,640 Less: current maturities, net of unamortized discount and deferred financing costs (12,297 ) (33 ) Long-term debt, net of current maturities $ 599,634 $ 392,607
Contractual Obligation, Fiscal Year Maturity Schedule	Annual maturities of our long-term debt for the next five years and thereafter are as follows (in thousands): Year Ended Amount Due 2020 $ 14,054 2021 62,785 2022 14,187 2023 14,259 2024 50,080 Thereafter 479,372 Total $ 634,737
Schedule Of Applicable Margin For Debt Instrument	The applicable margins for the ABL Credit Facility and advances under the ABL Revolver are as specified below: Level Arithmetic Mean of Daily Availability (as a percentage of the borrowing base) Applicable Margin for Applicable Margin for 1 >50% 1.75% 0.75% 2 >30% but ≤ 50% 2.00% 1.00% 3 ≤ 30% 2.25% 1.25%

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts of Outstanding Derivative Positions	At December 31, 2019 , our open commodity derivative contracts represented (in thousands of barrels): Contract type Purchases Sales Net Futures 3,360 (3,100 ) 260 Total 3,360 (3,100 ) 260
Fair Value, Assets Measured on Recurring Basis	The following table provides information on the fair value amounts (in thousands) of these derivatives as of December 31, 2019 and 2018 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2019 2018 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,075 $ 4,973 Commodity derivatives Other accrued liabilities (5,534 ) (700 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements 173 4,085 MLC terminal obligation derivative Obligations under inventory financing agreements (14,717 ) — Interest rate derivatives Prepaid and other current assets — 191 Interest rate derivatives Other accrued liabilities (314 ) — Interest rate derivatives Other liabilities (1,113 ) — _________________________________________________________ (1) Does not include cash collateral of $10.3 million and $2.7 million recorded in Prepaid and other current assets and $9.5 million and $8.3 million in Other long-term assets as of December 31, 2019 and 2018 , respectively. Fair value amounts by hierarchy level as of December 31, 2019 and 2018 are presented gross in the tables below (in thousands): December 31, 2019 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 4,595 $ 2,075 $ — $ 6,670 $ (4,595 ) $ 2,075 Liabilities Common stock warrants $ — $ — $ (8,206 ) $ (8,206 ) $ — $ (8,206 ) Commodity derivatives (10,129 ) — — (10,129 ) 4,595 (5,534 ) J. Aron repurchase obligation derivative — — 173 173 — 173 MLC terminal obligation derivative — — (14,717 ) (14,717 ) — (14,717 ) Interest rate derivatives — (1,427 ) — (1,427 ) — (1,427 ) Total $ (10,129 ) $ (1,427 ) $ (22,750 ) $ (34,306 ) $ 4,595 $ (29,711 ) December 31, 2018 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 170 $ 5,234 $ — $ 5,404 $ (431 ) $ 4,973 Interest rate derivatives — 191 — 191 — 191 Total $ 170 $ 5,425 $ — $ 5,595 $ (431 ) $ 5,164 Liabilities Common stock warrants $ — $ — $ (5,007 ) $ (5,007 ) $ — $ (5,007 ) Commodity derivatives (870 ) (261 ) — (1,131 ) 431 (700 ) J.Aron repurchase obligation derivative — — 4,085 4,085 — 4,085 Total $ (870 ) $ (261 ) $ (922 ) $ (2,053 ) $ 431 $ (1,622 ) _________________________________________________________ (1) Does not include cash collateral of $19.8 million and $10.9 million as of December 31, 2019 and 2018 , respectively, included within Prepaid and other current assets and Other long-term assets on our consolidated balance sheets.
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The following table summarizes the pre-tax gains (losses) recognized in Net income (loss) on our consolidated statements of operations resulting from changes in fair value of derivative instruments not designated as hedges charged directly to earnings (in thousands): Year Ended December 31, Statement of Operations Classification 2019 2018 2017 Commodity derivatives Cost of revenues (excluding depreciation) $ (1,547 ) $ (3,420 ) $ (4,517 ) J. Aron repurchase obligation derivative Cost of revenues (excluding depreciation) (3,912 ) 23,649 436 MLC terminal obligation derivative Cost of revenues (excluding depreciation) (19,326 ) — — Interest rate derivatives Interest expense and financing costs, net (1,506 ) 1,309 489

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements, Nonrecurring	The fair values of the assets acquired and liabilities assumed as a result of the Northwest Retail Acquisition were estimated as of March 23, 2018 , the date of the acquisition, using valuation techniques described in notes (1) through (5) below. Valuation Fair Value Technique (in thousands) Net working capital $ 3,822 (1) Property, plant, and equipment 30,230 (2) Goodwill 46,210 (3) Long-term capital lease obligations (5,244 ) (4) Other non-current liabilities (487 ) (5) Total $ 74,531 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of property, plant, and equipment was estimated using the cost approach. Under the cost approach, the total replacement cost of the property is determined based on industry sources with adjustments for regional factors. The total cost is then adjusted for depreciation based on the physical age of the assets and obsolescence. The fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement. The fair value of capital lease assets was estimated using the income approach. Under the income approach, the annual lease market rental rate cash flow stream is estimated and then discounted to present value over the remaining life of the lease using a pre-tax discount rate based on expected return for the specific asset type and location. (3) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill. (4) Long-term capital lease obligations were estimated based on the present value of lease payments over the term of the lease. (5) Other non-current liabilities are primarily related to asset retirement obligations. AROs are calculated based on the present value of the estimated removal and other closure costs using our credit-adjusted risk-free rate. The fair values of the assets acquired and liabilities assumed as a result of the Washington Acquisition were estimated as of January 11, 2019 , the date of the acquisition, using valuation techniques described in notes (1) through (6) below. Valuation Fair Value Technique (in thousands) Net working capital excluding operating leases $ (35,854 ) (1) Property, plant, and equipment 412,766 (2) Operating lease assets 62,337 (3) Goodwill 42,522 (4) Current operating lease liabilities (21,571 ) (3) Long-term operating lease liabilities (40,766 ) (3) Deferred tax liability (92,103 ) (5) Other non-current liabilities (804 ) (6) Total $ 326,527 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of personal property was estimated using the cost approach. Key assumptions in the cost approach include determining the replacement cost by evaluating recent purchases of comparable assets or published data, and adjusting replacement cost for economic and functional obsolescence, location, normal useful lives, and capacity (if applicable). The fair value of real property was estimated using the market approach. Key assumptions in the market approach include determining the asset value by evaluating recent purchases of comparable assets under similar circumstances. (3) Operating lease assets and liabilities were recognized based on the present value of lease payments over the lease term using the incremental borrowing rate at acquisition of 9.6% . (4) The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill. (5) The deferred tax liability was determined based on the differences between the tax bases of the assets acquired and the values of those assets recorded on our consolidated balance sheets as of the date of acquisition. (6) Other non-current liabilities are related to pension plan obligations. The underfunded status of the defined benefit plan represents the difference between the fair value of the plan’s assets and the projected benefit obligations.
Fair Value, Assets Measured on Recurring Basis	The following table provides information on the fair value amounts (in thousands) of these derivatives as of December 31, 2019 and 2018 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2019 2018 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,075 $ 4,973 Commodity derivatives Other accrued liabilities (5,534 ) (700 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements 173 4,085 MLC terminal obligation derivative Obligations under inventory financing agreements (14,717 ) — Interest rate derivatives Prepaid and other current assets — 191 Interest rate derivatives Other accrued liabilities (314 ) — Interest rate derivatives Other liabilities (1,113 ) — _________________________________________________________ (1) Does not include cash collateral of $10.3 million and $2.7 million recorded in Prepaid and other current assets and $9.5 million and $8.3 million in Other long-term assets as of December 31, 2019 and 2018 , respectively. Fair value amounts by hierarchy level as of December 31, 2019 and 2018 are presented gross in the tables below (in thousands): December 31, 2019 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 4,595 $ 2,075 $ — $ 6,670 $ (4,595 ) $ 2,075 Liabilities Common stock warrants $ — $ — $ (8,206 ) $ (8,206 ) $ — $ (8,206 ) Commodity derivatives (10,129 ) — — (10,129 ) 4,595 (5,534 ) J. Aron repurchase obligation derivative — — 173 173 — 173 MLC terminal obligation derivative — — (14,717 ) (14,717 ) — (14,717 ) Interest rate derivatives — (1,427 ) — (1,427 ) — (1,427 ) Total $ (10,129 ) $ (1,427 ) $ (22,750 ) $ (34,306 ) $ 4,595 $ (29,711 ) December 31, 2018 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 170 $ 5,234 $ — $ 5,404 $ (431 ) $ 4,973 Interest rate derivatives — 191 — 191 — 191 Total $ 170 $ 5,425 $ — $ 5,595 $ (431 ) $ 5,164 Liabilities Common stock warrants $ — $ — $ (5,007 ) $ (5,007 ) $ — $ (5,007 ) Commodity derivatives (870 ) (261 ) — (1,131 ) 431 (700 ) J.Aron repurchase obligation derivative — — 4,085 4,085 — 4,085 Total $ (870 ) $ (261 ) $ (922 ) $ (2,053 ) $ 431 $ (1,622 ) _________________________________________________________ (1) Does not include cash collateral of $19.8 million and $10.9 million as of December 31, 2019 and 2018 , respectively, included within Prepaid and other current assets and Other long-term assets on our consolidated balance sheets.
Reconcilliation of Level 3 Derivative Instruments, Fair Value	A roll forward of Level 3 derivative instruments measured at fair value on a recurring basis is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Balance, beginning of period $ (922 ) $ (26,372 ) $ (25,134 ) Settlements 13,263 — — Acquired (8,654 ) — — Unrealized and realized income (loss) included in earnings (26,437 ) 25,450 (1,238 ) Balance, end of period $ (22,750 ) $ (922 ) $ (26,372 )
Schedule of Carrying Value and Fair Value of Long Term Debt and Other Financial Instruments	The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2019 and 2018 are as follows (in thousands): December 31, 2019 Carrying Value Fair Value 5.00% Convertible Senior Notes due 2021 (1) (3) $ 44,783 $ 66,477 7.75% Senior Secured Notes due 2025 (1) 292,015 309,375 Mid Pac Term Loan (2) 1,433 1,433 Term Loan B Facility (1) 230,474 240,625 Retail Property Term Loan (2) 43,226 43,226 Common stock warrants (2) 8,206 8,206 December 31, 2018 Carrying Value Fair Value 5.00% Convertible Senior Notes due 2021 (1) (3) $ 100,411 $ 121,488 7.75% Senior Secured Notes due 2025 (1) 290,763 270,000 Mid Pac Term Loan (2) 1,466 1,466 Common stock warrants (2) 5,007 5,007 _________________________________________________________ (1) The fair value measurements of the 5.00% Convertible Senior Notes , 7.75% Senior Secured Notes , and Term Loan B Facility are considered Level 2 measurements in the fair value hierarchy as discussed below. (2) The fair value measurements of the common stock warrants, Mid Pac Term Loan , and Retail Property Term Loan are considered Level 3 measurements in the fair value hierarchy. (3) The carrying value of the 5.00% Convertible Senior Notes excludes the fair value of the equity component, which was classified as equity upon issuance.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Assets and Liabilities, Lessee	The following table provides information on the amounts (in thousands, except lease term and discount rates) of our leased assets and liabilities as of December 31, 2019 and their placement within our consolidated balance sheets: Lease type Balance Sheet Location December 31, 2019 Assets Finance Property, plant, and equipment $ 11,552 Finance Accumulated amortization (4,447 ) Finance Property, plant, and equipment, net $ 7,105 Operating Operating lease assets 420,073 Total leased assets $ 427,178 Liabilities Current Finance Other accrued liabilities $ 1,784 Operating Operating lease liabilities 79,999 Long-term Finance Finance lease liabilities 6,227 Operating Operating lease liabilities 340,909 Total lease liabilities $ 428,919 Weighted-average remaining lease term (in years) Finance 5.69 Operating 10.26 Weighted-average discount rate Finance 6.68 % Operating 7.88 %
Lease, Cost	The following table summarizes the lease costs recognized on our consolidated statement of operations (in thousands): Lease cost type Year Ended December 31, 2019 Finance lease cost Amortization of finance lease assets $ 1,896 Interest on lease liabilities 521 Operating lease cost 100,384 Variable lease cost 11,663 Short-term lease cost 1,874 Net lease cost $ 116,338 The following table summarizes the supplemental cash flow information related to leases as follows (in thousands): Lease type Year Ended December 31, 2019 Cash paid for amounts included in the measurement of liabilities Financing cash flows from finance leases $ 2,167 Operating cash flows from finance leases 507 Operating cash flows from operating leases 99,713 Non-cash supplemental amounts ROU assets obtained in exchange for new finance lease liabilities 963 ROU assets obtained in exchange for new operating lease liabilities 79,382
Operating Lease, Liability, Maturity	The table below includes the estimated future undiscounted cash flows for finance and operating leases as of December 31, 2019 (in thousands): For the year ending December 31, Finance leases Operating leases Total 2020 $ 2,247 $ 109,727 $ 111,974 2021 1,593 69,091 70,684 2022 1,376 66,859 68,235 2023 1,345 53,088 54,433 2024 1,058 43,337 44,395 Thereafter 2,004 240,988 242,992 Total lease payments 9,623 583,090 592,713 Less amount representing interest (1,612 ) (162,182 ) (163,794 ) Present value of lease liabilities $ 8,011 $ 420,908 $ 428,919
Finance Lease, Liability, Maturity	The table below includes the estimated future undiscounted cash flows for finance and operating leases as of December 31, 2019 (in thousands): For the year ending December 31, Finance leases Operating leases Total 2020 $ 2,247 $ 109,727 $ 111,974 2021 1,593 69,091 70,684 2022 1,376 66,859 68,235 2023 1,345 53,088 54,433 2024 1,058 43,337 44,395 Thereafter 2,004 240,988 242,992 Total lease payments 9,623 583,090 592,713 Less amount representing interest (1,612 ) (162,182 ) (163,794 ) Present value of lease liabilities $ 8,011 $ 420,908 $ 428,919
Schedule of Future Minimum Lease Payments for Capital Leases	At December 31, 2018 , the estimated minimum lease payments for capital and operating leases with initial or remaining non-cancelable lease terms in excess of one year were as follows (in thousands): Capital leases Operating leases 2019 $ 2,723 $ 62,589 2020 2,264 62,132 2021 1,757 39,821 2022 1,512 38,402 2023 1,148 38,827 Thereafter 2,600 191,717 Total minimum rental payments $ 12,004 $ 433,488 Less amount representing interest (1,865 ) Present value of minimum rental payments $ 10,139
Schedule of Future Minimum Rental Payments for Operating Leases	At December 31, 2018 , the estimated minimum lease payments for capital and operating leases with initial or remaining non-cancelable lease terms in excess of one year were as follows (in thousands): Capital leases Operating leases 2019 $ 2,723 $ 62,589 2020 2,264 62,132 2021 1,757 39,821 2022 1,512 38,402 2023 1,148 38,827 Thereafter 2,600 191,717 Total minimum rental payments $ 12,004 $ 433,488 Less amount representing interest (1,865 ) Present value of minimum rental payments $ 10,139

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Share-based Payment Arrangement, Restricted Stock and Restricted Stock Unit, Activity	The following table summarizes our restricted stock activity (in thousands, except per share amounts): Shares Weighted- Unvested balance at December 31, 2018 526 $ 17.29 Granted 295 17.43 Vested (213 ) 17.31 Forfeited (70 ) 16.64 Unvested balance at December 31, 2019 538 $ 16.95 The following table summarizes our performance restricted stock activity (in thousands, except per unit amounts): Units Weighted- Unvested balance at December 31, 2018 101 $ 16.14 Granted 48 17.00 Vested — — Forfeited (3 ) 17.34 Unvested balance at December 31, 2019 146 $ 16.33
Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan	The following table summarizes our compensation costs recognized in General and administrative expense (excluding depreciation) and Operating expense (excluding depreciation) under the Incentive Plan and Stock Purchase Plan (in thousands): Years Ended December 31, 2019 2018 2017 Restricted Stock Awards $ 3,490 $ 3,483 $ 4,263 Restricted Stock Units $ 1,269 $ 835 $ 502 Stock Option Awards $ 1,454 $ 1,878 $ 2,439
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	The weighted-average assumptions used to measure stock options granted during 2019 , 2018 , and 2017 are presented below. 2019 2018 2017 Expected life from date of grant (years) 5.3 5.3 5.3 Expected volatility 34.3% 36.2% 42.0% Risk-free interest rate 2.46% 2.50% 1.97%
Schedule of Share-based Compensation, Stock Options, Activity	The following table summarizes our stock option activity (in thousands, except per share amounts and term years): Number of Options Weighted-Average Weighted-Average Aggregate Outstanding balance at December 31, 2018 2,231 $ 19.27 4.8 $ — Issued 300 17.00 Exercised (483 ) 17.78 Forfeited / canceled (18 ) 17.00 Outstanding balance at December 31, 2019 2,030 $ 19.31 4.7 $ 7,981 Exercisable, end of year 1,275 $ 20.25 3.6 $ 3,816

Benefit Plans (Tables)

Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2019
Retirement Benefits [Abstract]
Schedule of Defined Benefit Plans Disclosures	The changes in the projected benefit obligation and the fair value of plan assets of our Benefit Plans for the years ended December 31, 2019 and 2018 were as follows (in thousands): 2019 2018 Changes in projected benefit obligation: Projected benefit obligation as of the beginning of the period $ 27,539 $ 30,877 Acquired 16,831 — Service cost 910 548 Interest cost 1,794 1,107 Actuarial (gain) loss 6,688 (2,917 ) Benefits paid (1,620 ) (2,076 ) Projected benefit obligation as of the end of the period $ 52,142 $ 27,539 Changes in fair value of plan assets: Fair value of plan assets as of the beginning of the period $ 20,254 $ 23,461 Acquired 16,027 — Actual return (loss) on plan assets 6,405 (1,131 ) Employer contributions 1,800 — Benefits paid (1,620 ) (2,076 ) Fair value of plan assets as of the end of the period $ 42,866 $ 20,254
Schedule of Accumulated and Projected Benefit Obligations	The reconciliation of the underfunded status of our Benefit Plans of December 31, 2019 and 2018 was as follows: 2019 2018 Projected benefit obligation $ 52,142 $ 27,539 Fair value of plan assets 42,866 20,254 Underfunded status $ 9,276 $ 7,285 Gross amounts recognized in accumulated other comprehensive income: (1) Net actuarial gain (loss) $ (2,622 ) $ 3,494 ____________________________________________________ (1) As of December 31, 2019 , we had an immaterial amount of service costs recognized in accumulated other comprehensive income. As of December 31, 2019 , we had $0.2 million in accumulated other comprehensive income that is expected to be amortized into net periodic benefit cost in 2020 .
Schedule of Assumptions Used	Weighted-average assumptions used to measure our projected benefit obligation as of December 31, 2019 , 2018 , and 2017 and net periodic benefit costs for the years ended December 31, 2019 , 2018 and 2017 are as follows: 2019 2018 2017 Projected benefit obligation: Wyoming Refining plan Discount rate (1) 3.30 % 4.20 % 3.65 % Rate of compensation increase 3.00 % 3.00 % 3.00 % U.S. Oil plan Discount rate (1) 3.10 % — % — % Rate of compensation increase 3.00 % — % — % Net periodic benefit costs: Wyoming Refining plan Discount rate (1) 4.20 % 3.65 % 4.20 % Expected long-term rate of return (2) 6.50 % 6.50 % 6.25 % Rate of compensation increase 3.00 % 3.00 % 4.30 % U.S. Oil plan Discount rate (1) 4.10 % — % — % Expected long-term rate of return (2) 6.00 % — % — % Rate of compensation increase 3.00 % — % — % _________________________________________________________ (1) In determining the discount rate, we use yields on high-quality fixed income investments with payments matched to the estimated distributions of benefits from our plans. (2) The expected long-term rate of return is based on a blend of historic returns of equity and debt securities.
Schedule of Net Benefit Costs	The net periodic benefit cost for the years ended December 31, 2019 , 2018 , and 2017 includes the following components: 2019 2018 2017 Components of net periodic benefit cost: Service cost $ 910 $ 548 $ 614 Interest cost 1,794 1,107 1,192 Expected return on plan assets (1,972 ) (1,258 ) (1,189 ) Amortization of net loss 95 — — Amortization of prior service cost 3 — — Net periodic benefit cost $ 830 $ 397 $ 617
Schedule of Allocation of Plan Assets	The weighted-average asset allocation for our Wyoming Refining plan at December 31, 2019 is as follows: Target Actual Asset category: Equity securities 54 % 56 % Debt securities 35 % 32 % Real estate 11 % 12 % Total 100 % 100 % The weighted-average asset allocation for our U.S. Oil plan at December 31, 2019 is as follows: Target Range Actual Asset category: Equity securities 40 - 80% 62 % Debt securities 20 - 60% 38 % Cash and Cash Equivalents 0 - 30% — % Total 100 % 100 %
Schedule of Expected Benefit Payments	Based on current data and assumptions, the following benefit payments, which reflect expected future service, as appropriate, are expected to be paid over the next 10 years : Year Ended 2020 $ 2,215 2021 2,007 2022 2,082 2023 2,203 2024 2,234 Thereafter 13,095 $ 23,836

Income (Loss) Per Share (Tables

Income (Loss) Per Share (Tables)	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Schedule of Computation of Basic and Diluted Earnings per Share	The following table sets forth the computation of basic and diluted income per share (in thousands, except per share amounts): Year Ended December 31, 2019 2018 2017 Net Income $ 40,809 $ 39,427 $ 72,621 Less: Undistributed income allocated to participating securities (1) 438 556 878 Net income attributable to common stockholders 40,371 38,871 71,743 Plus: Net income effect of convertible securities — — — Numerator for diluted income per common share $ 40,371 $ 38,871 $ 71,743 Basic weighted-average common stock shares outstanding 50,352 45,726 45,543 Plus: dilutive effects of common stock equivalents 118 29 40 Diluted weighted-average common stock shares outstanding 50,470 45,755 45,583 Basic income per common share $ 0.80 $ 0.85 $ 1.58 Diluted income per common share $ 0.80 $ 0.85 $ 1.57 ________________________________________________________ (1) Participating securities includes restricted stock that has been issued but has not yet vested.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Income tax expense (benefit) consisted of the following (in thousands): Year Ended December 31, 2019 2018 2017 Current: U.S.—Federal $ (3,203 ) $ (328 ) $ — U.S.—State 400 — 2 Deferred: U.S.—Federal (58,461 ) 426 (1,321 ) U.S.—State (8,425 ) 235 — Total $ (69,689 ) $ 333 $ (1,319 )
Schedule of Effective Income Tax Rate Reconciliation	Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate to pretax income as a result of the following: Year Ended December 31, 2019 2018 2017 Federal statutory rate 21.0 % 21.0 % 35.0 % State income taxes, net of federal benefit (1.1 )% 0.6 % — % Change in valuation allowance related to current activity 227.1 % (21.3 )% (30.1 )% Change in valuation allowance related to change in tax rate — % — % (291.2 )% Change in tax rate — % — % 291.2 % Permanent items (4.3 )% 1.3 % 1.1 % Provision to return adjustments and other (1.4 )% (0.8 )% (7.9 )% Actual income tax rate 241.3 % 0.8 % (1.9 )%
Schedule of Deferred Tax Assets and Liabilities	Deferred tax assets (liabilities) are comprised of the following (in thousands): December 31, 2019 2018 Deferred tax assets: Net operating loss $ 373,717 $ 396,033 Property, plant, and equipment — 8,323 Intangible assets — 444 Other 19,560 17,886 Total deferred tax assets 393,277 422,686 Valuation allowance (330,251 ) (394,196 ) Net deferred tax assets 63,026 28,490 Deferred tax liabilities: Inventory 5,738 — Property and equipment 64,281 — Investment in Laramie Energy 11,609 26,981 Convertible notes 2,285 2,658 Intangible assets 750 — Other 4,904 496 Total deferred tax liabilities 89,567 30,135 Total deferred tax liability, net $ (26,541 ) $ (1,645 )

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Summarized financial information concerning reportable segments consists of the following (in thousands): For the year ended December 31, 2019 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 5,167,942 $ 199,226 $ 458,889 $ (424,541 ) $ 5,401,516 Cost of revenues (excluding depreciation) 4,783,747 112,124 332,302 (424,584 ) 4,803,589 Operating expense (excluding depreciation) 234,582 11,010 67,307 — 312,899 Depreciation, depletion, and amortization 55,832 17,017 10,035 3,237 86,121 General and administrative expense (excluding depreciation) — — — 46,223 46,223 Acquisition and integration costs — — — 4,704 4,704 Operating income (loss) $ 93,781 $ 59,075 $ 49,245 $ (54,121 ) $ 147,980 Interest expense and financing costs, net (74,839 ) Debt extinguishment and commitment costs (11,587 ) Other income, net 2,516 Change in value of common stock warrants (3,199 ) Equity losses from Laramie Energy, LLC (89,751 ) Loss before income taxes (28,880 ) Income tax benefit 69,689 Net income $ 40,809 Total assets $ 1,907,318 $ 494,209 $ 232,150 $ 66,883 $ 2,700,560 Goodwill 77,927 55,232 62,760 — 195,919 Capital expenditures 34,492 40,730 6,869 1,829 83,920 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $424.5 million for the year ended December 31, 2019 . For the year ended December 31, 2018 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 3,210,067 $ 125,743 $ 441,040 $ (366,122 ) $ 3,410,728 Cost of revenues (excluding depreciation) 2,957,995 77,712 333,664 (366,255 ) 3,003,116 Operating expense (excluding depreciation) 146,320 7,782 61,182 — 215,284 Depreciation, depletion, and amortization 32,483 6,860 8,962 4,337 52,642 General and administrative expense (excluding depreciation) — — — 47,426 47,426 Acquisition and integration costs — — — 10,319 10,319 Operating income (loss) $ 73,269 $ 33,389 $ 37,232 $ (61,949 ) $ 81,941 Interest expense and financing costs, net (39,768 ) Debt extinguishment and commitment costs (4,224 ) Other income, net 1,046 Change in value of common stock warrants 1,801 Change in value of contingent consideration (10,500 ) Equity earnings from Laramie Energy, LLC 9,464 Income before income taxes 39,760 Income tax expense (333 ) Net income $ 39,427 Total assets $ 968,623 $ 130,138 $ 201,848 $ 160,125 $ 1,460,734 Goodwill 53,264 37,373 62,760 — 153,397 Capital expenditures 25,601 13,055 6,101 3,682 48,439 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $365.5 million for the year ended December 31, 2018 . For the year ended December 31, 2017 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 2,319,638 $ 121,470 $ 326,076 $ (324,118 ) $ 2,443,066 Cost of revenues (excluding depreciation) 2,062,804 66,301 249,097 (323,575 ) 2,054,627 Operating expense (excluding depreciation) 141,065 15,010 45,941 — 202,016 Depreciation, depletion, and amortization 29,753 6,166 6,338 3,732 45,989 General and administrative expense (excluding depreciation) — — — 46,078 46,078 Acquisition and integration costs — — — 395 395 Operating income (loss) $ 86,016 $ 33,993 $ 24,700 $ (50,748 ) $ 93,961 Interest expense and financing costs, net (31,632 ) Debt extinguishment and commitment costs (8,633 ) Other income, net 911 Change in value of common stock warrants (1,674 ) Equity earnings from Laramie Energy, LLC 18,369 Income before income taxes 71,302 Income tax benefit 1,319 Net income $ 72,621 Total assets $ 949,588 $ 118,304 $ 128,966 $ 150,549 $ 1,347,407 Goodwill 53,264 37,373 16,550 — 107,187 Capital expenditures 10,433 8,836 7,073 5,366 31,708 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $325.2 million for the year ended December 31, 2017 .

Quarterly Financial Data (Una_2

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Summarized quarterly data for the years ended December 31, 2019 and 2018 consisted of the following (in thousands, except per share amounts): Year Ended December 31, 2019 Q1 Q2 Q3 Q4 Revenues $ 1,191,335 $ 1,409,409 $ 1,401,638 $ 1,399,134 Operating income 21,423 48,621 18,405 59,531 Net income (loss) 61,092 28,169 (83,891 ) 35,439 Net income (loss) per share Basic $ 1.23 $ 0.56 $ (1.65 ) $ 0.68 Diluted $ 1.14 $ 0.56 $ (1.65 ) $ 0.68 Year Ended December 31, 2018 Q1 Q2 Q3 Q4 Revenues $ 765,439 $ 856,396 $ 909,781 $ 879,112 Operating income 27,656 28,983 4,894 20,408 Net income (loss) 15,185 16,178 (5,822 ) 13,886 Net income (loss) per share Basic $ 0.33 $ 0.35 $ (0.13 ) $ 0.30 Diluted $ 0.33 $ 0.35 $ (0.13 ) $ 0.30

Supplemental Oil and Gas Disc_2

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
Oil and Gas Property Successful Effort Method	Our share of Laramie Energy's capitalized costs related to oil and gas activities are as follows (in thousands): December 31, 2019 2018 Company’s share of Laramie Energy Unproved properties $ 14,722 $ 16,379 Proved properties 211,083 473,763 225,805 490,142 Accumulated depreciation, depletion, and amortization (63,791 ) (150,075 ) Total $ 162,014 $ 340,067
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	Our share of Laramie Energy's costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands): Year Ended December 31, 2019 2018 2017 Company’s share of Laramie Energy Acquisition costs $ — $ — $ — Development costs—other 32,748 50,867 49,273 Total $ 32,748 $ 50,867 $ 49,273
Capitalized Exploratory Well Costs, Roll Forward	A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows (in thousands): Year Ended December 31, 2019 2018 2017 Company Revenue Oil and gas revenues $ 156 $ 51 $ 288 Expenses Production costs 87 191 29 Depletion and amortization 6 17 66 Results of operations of oil and gas producing activities $ 63 $ (157 ) $ 193 Company’s share of Laramie Energy Revenue Oil and gas revenues $ 89,073 $ 93,493 $ 66,783 Expenses Production costs 41,446 42,706 32,606 Impairment of proved properties (1) 163,401 — — Depletion, depreciation, and amortization 38,011 26,819 21,277 Results of operations of oil and gas producing activities $ (153,785 ) $ 23,968 $ 12,900 Total results of operations of oil and gas producing activities $ (153,722 ) $ 23,811 $ 13,093 __________________________________________________ (1) Please read Note 3—Investment in Laramie Energy, LLC for further disclosures and information on Laramie Energy's impairment of proved properties.

Oil and Gas Reserve Informati_2

Oil and Gas Reserve Information (Tables)	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	A summary of changes in estimated quantities of proved reserves for the years ended December 31, 2019 , 2018 , and 2017 is as follows: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) Company Balance at January 1, 2017 330 7 8 420 Revisions of quantity estimate 109 2 3 139 Extensions and discoveries — — — — Production (47 ) (2 ) — (59 ) Balance at December 31, 2017 392 7 11 500 Revisions of quantity estimate (269 ) (2 ) (10 ) (341 ) Extensions and discoveries — — — — Production (34 ) (1 ) — (40 ) Balance at December 31, 2018 89 4 1 119 Revisions of quantity estimate 222 1 7 270 Extensions and discoveries — — — — Acquisitions and divestitures (30 ) (3 ) — (48 ) Production (20 ) (1 ) — (26 ) Balance at December 31, 2019 261 1 8 315 Company ’ s share of Laramie Energy Balance at January 1, 2017 309,802 967 8,544 366,871 Revisions of quantity estimate 1,344 211 (434 ) 3 Extensions and discoveries — — — — Acquisitions and divestitures — — — — Production (18,104 ) (71 ) (608 ) (22,178 ) Balance at December 31, 2017 (2) 293,042 1,107 7,502 344,696 Revisions of quantity estimate 47,871 732 5,602 85,875 Extensions and discoveries — — — — Acquisitions and divestitures 22,391 12 191 23,609 Production (25,513 ) (106 ) (712 ) (30,421 ) Balance at December 31, 2018 (3) 337,791 1,745 12,583 423,759 Revisions of quantity estimate (69,924 ) (681 ) (6,287 ) (111,732 ) Extensions and discoveries — — — — Acquisitions and divestitures — — — — Production (29,677 ) (126 ) (883 ) (35,731 ) Balance at December 31, 2019 (4) 238,190 938 5,413 276,296 Total at December 31, 2019 238,451 939 5,421 276,611 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) During 2017 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, decreased by 22,095 MMcfe or approximately 6% . Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 22,178 MMcfe. The remaining change in estimated proved reserves was due to performance and other changes to the Company’s share of Laramie Energy’s proved developed producing and developed non-producing reserves. (3) During 2018 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, increased by 78,682 MMcfe or approximately 23% . The Company’s share of Laramie Energy’s revisions of quantity estimate increased primarily due to: 1) additions of 60,679 MMcfe of proved undeveloped reserves primarily located within Laramie Energy’s northern acreage, 2) 11,614 MMcfe of positive revisions associated with 13 probable locations that were converted to proved developed reserves during 2018, and 3) 13,582 MMcfe of positive revisions due to performance improvements and other changes to the Company’s share of Laramie Energy’s proved developed and undeveloped reserves. Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 30,421 MMcfe. During 2018, Laramie Energy closed on a purchase and contribution agreement with an unaffiliated third party that contributed 23,609 MMcfe of proved developed reserves in the Piceance Basin. (4) During 2019 , the Company’s estimated proved reserves, inclusive of the Company’s share of Laramie Energy’s estimated proved reserves, decreased by 147,267 MMcfe or approximately 35% . The decreased was primarily due to: 1) 57,212 MMcfe downward revision driven by the removal of proved undeveloped locations from the development plan due to unfavorable market conditions, and 2) 54,520 MMcfe downward revision due to decreases in average natural gas prices in 2019 compared to 2018. Production volumes related to our share of Laramie Energy’s estimated proved reserves resulted in a decrease of 35,731 MMcfe. A summary of proved developed and undeveloped reserves for the years ended December 31, 2019 , 2018 , and 2017 is presented below: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) December 31, 2017 Proved developed reserves Company 392 7 11 500 Company’s share of Laramie Energy 174,464 658 4,589 205,946 Total 174,856 665 4,600 206,446 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy 118,578 449 2,913 138,750 Total 118,578 449 2,913 138,750 December 31, 2018 Proved developed reserves Company 89 4 1 119 Company’s share of Laramie Energy 256,363 1,420 8,868 318,091 Total 256,452 1,424 8,869 318,210 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy 81,428 325 3,715 105,668 Total 81,428 325 3,715 105,668 December 31, 2019 Proved developed reserves Company 261 1 8 315 Company’s share of Laramie Energy 238,190 938 5,413 276,296 Total 238,451 939 5,421 276,611 Proved undeveloped reserves Company — — — — Company’s share of Laramie Energy — — — — Total — — — — __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. Price per MMbtu WTI per Bbl Base pricing, before adjustments for contractual December 31, 2017 $ 2.68 $ 51.34 December 31, 2018 2.47 65.56 December 31, 2019 2.04 55.85 ______________________________________________ (1) Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests. December 31, 2019 2018 2017 (in thousands) Company Future net cash flows $ 833 $ 398 $ 1,802 Future costs Production 509 123 902 Development and abandonment 37 35 — Income taxes (1) — — — Future net cash flows 287 240 900 10% discount factor (106 ) (110 ) (328 ) Discounted future net cash flows $ 181 $ 130 $ 572 Company’s share of Laramie Energy Future net cash flows $ 669,271 $ 1,283,890 $ 1,026,005 Future costs Production 398,193 583,112 491,748 Development and abandonment 25,277 93,546 109,248 Income taxes (1) — — — Future net cash flows 245,801 607,232 425,009 10% discount factor (105,966 ) (288,130 ) (209,188 ) Discounted future net cash flows $ 139,835 $ 319,102 $ 215,821 Total discounted future net cash flows $ 140,016 $ 319,232 $ 216,393 _______________________________________________ (1) No income tax provision is included in the standardized measure of discounted future net cash flows calculation shown above as we do not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The principal sources of changes in the standardized measure of discounted net cash flows for the years ended December 31, 2019 , 2018 , and 2017 are as follows (in thousands): Company Company ’ s Share of Laramie Total Balance at January 1, 2017 $ 285 $ 141,142 $ 141,427 Sales of oil and gas production during the period, net of production costs (28 ) (29,911 ) (29,939 ) Net change in prices and production costs (60 ) 35,597 35,537 Revisions of previous quantity estimates, estimated timing of development and other 346 37,692 38,038 Previously estimated development and abandonment costs incurred during the period — 17,187 17,187 Accretion of discount 29 14,114 14,143 Balance at December 31, 2017 572 215,821 216,393 Sales of oil and gas production during the period, net of production costs (127 ) (47,165 ) (47,292 ) Acquisitions and divestitures — 35,182 35,182 Net change in prices and production costs 20 (1,365 ) (1,345 ) Revisions of previous quantity estimates, estimated timing of development and other (392 ) 54,311 53,919 Previously estimated development and abandonment costs incurred during the period — 40,736 40,736 Accretion of discount 57 21,582 21,639 Balance at December 31, 2018 130 319,102 319,232 Sales of oil and gas production during the period, net of production costs (55 ) (59,093 ) (59,148 ) Acquisitions and divestitures (143 ) — (143 ) Net change in prices and production costs (24 ) (114,195 ) (114,219 ) Revisions of previous quantity estimates, estimated timing of development and other 260 (64,333 ) (64,073 ) Previously estimated development and abandonment costs incurred during the period — 26,444 26,444 Accretion of discount 13 31,910 31,923 Balance at December 31, 2019 $ 181 $ 139,835 140,016

Overview - Additional Informati

Overview - Additional Information (Detail) barrel / d in Thousands	12 Months Ended
	Dec. 31, 2019barrel / dsegmentgasoline_store_facilityrefinery	Oct. 18, 2018	Feb. 28, 2018	Mar. 01, 2016
Operating segments | segment	3
Number of owned and operated refineries | refinery	4
Oil and gas refinery | barrel / d	200
Number of retail outlets	124
Number of fueling stations, rebranded	40
Convenience stores, rebranded	28
Convenience store facilities	34
Laramie Energy Company
Ownership of Laramie Energy, LLC	46.00%	46.00%	39.10%	42.30%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 11, 2019	Jan. 01, 2019	Jun. 30, 2016
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Inventory, LIFO reserve	$ 6,400,000
Amortization period of planned major maintenance activities, minimum	3 years
Amortization period of planned major maintenance activities, maximum	5 years
Deferred turnaround expenditures	$ 9,800,000	$ 0	$ 0
Depreciation expense excluded from cost of revenues	16,882,000	6,722,000	6,029,000
Depreciation expense excluded from operating expense	55,181,000	28,037,000	22,861,000
Depreciation expense excluded from general and administrative expense	3,145,000	4,233,000	2,929,000
Operating lease assets	420,073,000
Present value of lease liabilities	$ 420,908,000
Refining Equipment | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	5 years
Refining Equipment | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	47 years
Logistic | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Logistic | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	30 years
Retail Site | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Retail Site | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	30 years
Corporate | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Corporate | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	7 years
Software | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Software | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	5 years
Accounting Standards Update 2016-02
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Operating lease assets					$ 347,000,000
Present value of lease liabilities					$ 349,000,000
Washington Refinery Acquisition
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Operating lease assets				$ 62,000,000
Laramie Energy Company
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Impairment charge	$ 81,515,000	$ 0	$ 0
5% Convertible Senior Notes due 2021
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Debt instrument, interest rate	5.00%					5.00%
Convertible Debt | 5% Convertible Senior Notes due 2021
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Debt instrument, interest rate	5.00%

Investment in Laramie Energy,_3

Investment in Laramie Energy, LLC - Additional Information (Detail) - USD ($)	Oct. 18, 2018	Feb. 28, 2018	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Sep. 30, 2019	Mar. 04, 2019	Mar. 01, 2016
Schedule of Equity Method Investments [Line Items]
Depreciation, depletion, and amortization				$ 86,121,000	$ 52,642,000	$ 45,989,000
Unrealized gain (loss) on derivative contracts				$ (9,350,000)	(2,122,000)	989,000
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Ownership of Laramie Energy, LLC	46.00%	39.10%	46.00%	46.00%					42.30%
Impairment loss				$ 355,200,000
Equity method investments, fair value							$ 51,800,000
Equity method investment, aggregate cost							133,300,000
Impairment charge				81,515,000	0	0
Depreciation, depletion, and amortization				82,600,000	66,600,000	50,300,000
Unrealized gain (loss) on derivative contracts				4,300,000	(4,100,000)	$ 46,200,000
Amount of equity in underlying assets exceeding carrying value			$ 0	0			$ 161,800,000
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Impairment loss			355,200,000
Disposal group, property, plant and equipment								$ 17,500,000
Unaffiliated Third Party | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Equity method investments, fair value		$ 28,100,000
Investment in Laramie Energy, LLC		$ 20,000,000
Shares issued (in shares)		70,227
Additional payments to acquire equity method investments		$ 3,500,000
Revolving Credit Facility | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Line credit maximum borrowing amount			400,000,000	400,000,000
Current borrowing capacity			220,000,000	220,000,000
Balance outstanding on the revolving credit facility			$ 201,200,000	$ 201,200,000	$ 210,800,000
Capital Unit, Class A | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Stock repurchased during period (in shares)	138,795
Stock repurchased during period	$ 14,800,000

Investment in Laramie Energy,_4

Investment in Laramie Energy, LLC - Change in Equity Investment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance	$ 136,656
Equity earnings (losses) from Laramie Energy, LLC	(89,751)	$ 9,464	$ 18,369
Ending balance	46,905	136,656
Laramie Energy Company
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance	136,656	127,192	108,823
Equity earnings (losses) from Laramie Energy, LLC	(175,018)	4,487	13,043
Accretion of basis difference	5,018	4,977	5,326
Adjustment of basis difference	161,764	0	0
Impairment of our investment in Laramie Energy	(81,515)	0	0
Ending balance	$ 46,905	$ 136,656	$ 127,192

Investment in Laramie Energy,_5

Investment in Laramie Energy, LLC - Summarized Financial Information (Detail) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
ASSETS
Current assets	$ 1,032,174				$ 586,592				$ 1,032,174	$ 586,592
Current liabilities	1,034,322				507,201				1,034,322	507,201
Income (loss) from operations	59,531	$ 18,405	$ 48,621	$ 21,423	20,408	$ 4,894	$ 28,983	$ 27,656	147,980	81,941	$ 93,961
Net income (loss)	35,439	$ (83,891)	$ 28,169	$ 61,092	13,886	$ (5,822)	$ 16,178	$ 15,185	40,809	39,427	72,621
Laramie Energy Company
ASSETS
Current assets	23,367				28,569				23,367	28,569
Non-current assets	393,575				788,515				393,575	788,515
Current liabilities	229,687				41,681				229,687	41,681
Non-current liabilities	$ 85,287				$ 293,084				85,287	293,084
Natural gas and oil revenues									193,906	226,974	157,879
Income (loss) from operations									(360,967)	34,206	6,019
Net income (loss)									$ (380,473)	$ 6,347	$ 30,837

Acquisitions - Washington Acqui

Acquisitions - Washington Acquisition (Details) mbpd in Thousands, barrel / d in Thousands, shares in Millions, bbl in Millions	Jan. 11, 2019USD ($)mbpdsharesbbl	Jan. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2019USD ($)barrel / d	Dec. 31, 2019USD ($)barrel / d	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Jan. 09, 2019USD ($)
Business Acquisition [Line Items]
Oil and gas refinery | barrel / d				200	200
Issuance of common stock in connection with acquisition	$ 37,000,000				$ 36,980,000	$ 19,318,000
Acquisition and integration costs					4,704,000	10,319,000	$ 395,000
Income tax benefit (expense)					(69,689,000)	333,000	$ (1,319,000)
Washington Refinery Acquisition
Business Acquisition [Line Items]
Oil and gas refinery | mbpd	42
Oil and gas storage capacity | bbl	2.9
Consideration transferred	$ 326,500,000
Payments to acquire businesses	$ 289,500,000
Issuance of common stock in connection with acquisition (in shares) | shares	2.4
Acquisition and integration costs		$ 5,400,000	$ 4,200,000		2,200,000	$ 2,600,000
Total assets to our refining and logistics segments	$ 672,412,000
Increase in the property, plant, and equipment valuation				$ 2,100,000
Decrease in the deferred tax liability				(3,700,000)
Net decrease in working capital adjustments				(1,800,000)
Adjustment to goodwill				$ (4,000,000)
Revenue					1,200,000,000
Earnings (loss) of acquiree since acquisition date, actual					65,800,000
Income tax benefit (expense)					$ (64,200,000)
Term Loan | Term Loan B Facility
Business Acquisition [Line Items]
Debt instrument, face amount	250,000,000
Term Loan | Par Pacific Term Loan
Business Acquisition [Line Items]
Debt instrument, face amount								$ 45,000,000
Refining | Washington Refinery Acquisition
Business Acquisition [Line Items]
Total assets to our refining and logistics segments	403,900,000
Logistics | Washington Refinery Acquisition
Business Acquisition [Line Items]
Total assets to our refining and logistics segments	$ 268,500,000

Acquisitions - Par West Acquisi

Acquisitions - Par West Acquisition (Details) shares in Thousands, $ in Thousands	Jan. 11, 2019USD ($)	Dec. 19, 2018USD ($)refineryshares	Dec. 31, 2019USD ($)shares	Dec. 31, 2018USD ($)shares
Schedule of Asset Acquisition [Line Items]
Issuance of common stock in connection with acquisition	$ 37,000		$ 36,980	$ 19,318
Common Stock
Schedule of Asset Acquisition [Line Items]
Issuance of common stock in connection with acquisition (in shares) | shares			2,364	1,108
Issuance of common stock in connection with acquisition			$ 23	$ 11
Par West - Asset Acquisition
Schedule of Asset Acquisition [Line Items]
Asset acquisition, consideration transferred		$ 66,900
Asset acquisition, consideration transferred, working capital adjustments		4,300
Payments for asset acquisitions		47,600
Issuance of common stock in connection with acquisition		19,300
Property, plant and equipment, additions		45,200
Asset acquisition, non-hydrocarbon inventory		4,300
Asset acquisition, hydrocarbon inventory		$ 17,400
Number of refineries | refinery		2
Asset acquisition, transaction costs				$ 5,700
Par West - Asset Acquisition | Common Stock
Schedule of Asset Acquisition [Line Items]
Issuance of common stock in connection with acquisition (in shares) | shares		1,100

Acquisitions - Northwest Retail

Acquisitions - Northwest Retail Acquisition (Details) $ in Thousands	Mar. 23, 2018USD ($)gasoline_store_facility	Dec. 31, 2019USD ($)gasoline_store_facility	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Business Acquisition [Line Items]
Convenience store facilities | gasoline_store_facility		34
Goodwill		$ 195,919	$ 153,397	$ 107,187
Acquisition and integration costs		$ 4,704	10,319	$ 395
Northwest Retail
Business Acquisition [Line Items]
Convenience store facilities | gasoline_store_facility	21
Number of leased retail gasoline | gasoline_store_facility	12
Payments to acquire businesses	$ 74,500
Goodwill	46,210
Acquisition and integration costs			$ 600
Retail | Northwest Retail
Business Acquisition [Line Items]
Goodwill	$ 46,200

Acquisitions - Summary of Asset

Acquisitions - Summary of Assets Acquired and Liabilities Assumed (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Jan. 11, 2019	Dec. 31, 2018	Mar. 23, 2018	Dec. 31, 2017
Goodwill	$ 195,919		$ 153,397		$ 107,187
Northwest Retail
Cash				$ 200
Inventories				4,138
Prepaid and other current assets				243
Property, plant and equipment				30,230
Goodwill				46,210
Accounts payable				(759)
Long-term capital lease obligations				(5,244)
Other non-current liabilities				(487)
Total				$ 74,531
Washington Refinery Acquisition
Cash		$ 16,146
Accounts receivable		34,954
Inventories		98,367
Prepaid and other assets		5,320
Property, plant and equipment		412,766
Operating lease assets		62,337
Goodwill		42,522
Total assets		672,412
Obligations under inventory financing agreements		(116,873)
Accounts payable		(55,357)
Current operating lease liabilities		(21,571)
Other current liabilities		(18,411)
Long-term operating lease liabilities		(40,766)
Deferred tax liability		(92,103)
Other non-current liabilities		(804)
Total liabilities		(345,885)
Total		326,527
Refining | Washington Refinery Acquisition
Goodwill		24,700
Total assets		403,900
Logistics | Washington Refinery Acquisition
Goodwill		17,800
Total assets		$ 268,500

Acquisitions - Unaudited Pro Fo

Acquisitions - Unaudited Pro Forma Financial Information (Detail) - Washington Refinery Acquisition - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Revenues	$ 5,429,530	$ 4,709,850
Net loss	$ (4,547)	$ 88,174
Income (loss) per share
Basic (in dollars per share)	$ (0.09)	$ 1.81
Diluted (in dollars per share)	$ (0.09)	$ 1.79

Revenue Recognition (Details)

Revenue Recognition (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Contract receivable	$ 214,500				$ 148,400				$ 214,500	$ 148,400
Deferred revenue	7,905				6,681				7,905	6,681
Revenues	$ 1,399,134	$ 1,401,638	$ 1,409,409	$ 1,191,335	$ 879,112	$ 909,781	$ 856,396	$ 765,439	5,401,516	3,410,728	$ 2,443,066
Refining
Disaggregation of Revenue [Line Items]
Revenues									5,167,942	3,210,067
Logistics
Disaggregation of Revenue [Line Items]
Revenues									199,226	125,743
Retail
Disaggregation of Revenue [Line Items]
Revenues									458,889	441,040
Gasoline | Refining
Disaggregation of Revenue [Line Items]
Revenues									1,416,706	981,090
Gasoline | Logistics
Disaggregation of Revenue [Line Items]
Revenues									0	0
Gasoline | Retail
Disaggregation of Revenue [Line Items]
Revenues									326,304	317,434
Distillates | Refining
Disaggregation of Revenue [Line Items]
Revenues									2,503,981	1,770,381
Distillates | Logistics
Disaggregation of Revenue [Line Items]
Revenues									0	0
Distillates | Retail
Disaggregation of Revenue [Line Items]
Revenues									40,189	39,835
Other Refined Products | Refining
Disaggregation of Revenue [Line Items]
Revenues									1,242,401	458,596
Other Refined Products | Logistics
Disaggregation of Revenue [Line Items]
Revenues									0	0
Other Refined Products | Retail
Disaggregation of Revenue [Line Items]
Revenues									0	0
Merchandise | Refining
Disaggregation of Revenue [Line Items]
Revenues									0	0
Merchandise | Logistics
Disaggregation of Revenue [Line Items]
Revenues									0	0
Merchandise | Retail
Disaggregation of Revenue [Line Items]
Revenues									90,480	83,771
Transportation and terminalling services | Refining
Disaggregation of Revenue [Line Items]
Revenues									0	0
Transportation and terminalling services | Logistics
Disaggregation of Revenue [Line Items]
Revenues									199,226	125,743
Transportation and terminalling services | Retail
Disaggregation of Revenue [Line Items]
Revenues									0	$ 0
Other revenue | Refining
Disaggregation of Revenue [Line Items]
Revenues									4,854
Other revenue | Logistics
Disaggregation of Revenue [Line Items]
Revenues									0
Other revenue | Retail
Disaggregation of Revenue [Line Items]
Revenues									$ 1,916

Inventories (Detail)

Inventories (Detail) - USD ($)	Dec. 31, 2019	Dec. 31, 2018
Crude oil and feedstocks	$ 266,020,000	$ 124,877,000
Refined products and blendstock	286,703,000	162,576,000
Warehouse stock and other	63,149,000	34,612,000
Total	615,872,000	322,065,000
Reserves for the lower of cost or market value of inventory	0	3,800,000
Inventory, LIFO reserve	6,400,000
Titled Inventory
Crude oil and feedstocks	117,717,000	7,000,000
Refined products and blendstock	127,966,000	62,401,000
Warehouse stock and other	63,149,000	34,612,000
Total	308,832,000	104,013,000
Supply and Offtake Agreements
Crude oil and feedstocks	148,303,000	117,877,000
Refined products and blendstock	158,737,000	100,175,000
Warehouse stock and other	0	0
Total	307,040,000	218,052,000
Renewable Identification Numbers “RINs” and Environmental Credits
Warehouse stock and other	$ 19,100,000	$ 5,000,000

Prepaid and Other Current Ass_3

Prepaid and Other Current Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Advances to suppliers	$ 27,635	$ 0
Collateral posted with broker for derivative instruments	10,306	2,759
Prepaid insurance	13,536	7,727
Derivative assets	2,075	5,164
Other	5,604	12,720
Total	$ 59,156	$ 28,370

Property, Plant and Equipment (

Property, Plant and Equipment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Land	$ 188,096	$ 117,559
Buildings and equipment	937,926	512,870
Other	20,961	18,939
Total property, plant, and equipment	1,146,983	649,368
Proved oil and gas properties	0	400
Less accumulated depreciation, depletion, and amortization	(185,040)	(111,507)
Property, plant, and equipment, net	961,943	538,261
Depreciation expense	$ 75,200	$ 39,000	$ 31,800

Asset Retirement Obligations (D

Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation - beginning of period	$ 9,985	$ 9,103	$ 9,042
Obligations acquired	0	487	0
Accretion expense	331	395	369
Liabilities settled during period	(136)	0	(308)
Asset retirement obligation - end of period	$ 10,180	$ 9,985	$ 9,103

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets - Schedule of Goodwill (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Goodwill [Roll Forward]
Balance at beginning of period	$ 153,397	$ 107,187
Acquisition during period	42,522	46,210
Balance at end of period	$ 195,919	$ 153,397

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Schedule of Finite-Lived Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	$ 38,592	$ 38,331
Accumulated amortization of intangible assets	(17,043)	(14,384)
Amortized intangible assets, net	21,549	23,947
Trade names and trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	6,267	6,267
Accumulated amortization of intangible assets	(5,124)	(5,037)
Amortized intangible assets, net	1,143	1,230
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	32,064	32,064
Accumulated amortization of intangible assets	(11,919)	(9,347)
Amortized intangible assets, net	20,145	22,717
Other
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	261	0
Accumulated amortization of intangible assets	0	0
Amortized intangible assets, net	$ 261	$ 0

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization expense	$ 2.7	$ 2.7	$ 3.3
Average useful life	13 years 6 months

Goodwill and Intangible Asset_5

Goodwill and Intangible Assets - Finite-lived Intangible Assets Amortization Expense (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
2020	$ 2,658
2021	2,658
2022	2,658
2023	2,658
2024	1,400
Thereafter	9,517
Amortized intangible assets, net	$ 21,549	$ 23,947

Inventory Financing Agreements

Inventory Financing Agreements - Narrative (Details)	Dec. 05, 2018USD ($)mbpd	Jun. 27, 2018	Jun. 26, 2018USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Jun. 01, 2018USD ($)	Dec. 21, 2017	May 08, 2017	Dec. 01, 2016USD ($)installment	Jun. 01, 2015USD ($)
Supply and exchange agreement expenses				$ 74,839,000	$ 39,768,000	$ 31,632,000
Supply and Offtake Agreements
Commitment period				1 year
Debt instrument, interest rate									7.00%
Amount of deferred payment arrangement	$ 165,000,000		$ 125,000,000
Percentage of receivables and inventory for deferred payment		85.00%	85.00%
Purchase and supply commitment, deferred payment arrangement, aggregate marginal increase	$ 2,500,000
Barrels of crude per day provided by J. Aron | mbpd	150
Supply and exchange agreement expenses				$ 5,900,000	4,500,000	2,300,000
Deferral arrangement fee											$ 1,300,000
Current borrowing capacity				155,500,000	77,400,000
Outstanding amount of deferred payment arrangement				97,500,000	68,400,000
Fee agreement receivable				500,000	2,500,000		$ 2,200,000			$ 14,600,000
Number of fee agreement payments | installment										18
London Interbank Offered Rate (LIBOR) | Supply and Offtake Agreements
Basis spread on variable rate	3.50%
Deferred payment availability fee											0.75%
Inventory Intermediation | Supply and Offtake Agreements
Cost of goods and services sold				$ 35,500,000	$ 21,500,000
Shipping and Handling | Supply and Offtake Agreements
Cost of goods and services sold						$ 13,700,000
7.75% Senior Secured Note due 2025
Debt instrument, interest rate				7.75%
7.75% Senior Secured Note due 2025 | Senior Notes
Debt instrument, interest rate				7.75%				7.75%

Inventory Financing Agreement_2

Inventory Financing Agreements - Washington Refinery Intermediation Agreement (Details) - USD ($) $ in Thousands	Nov. 01, 2019	Jan. 11, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Supply Commitment [Line Items]
Interest expense			$ 74,839	$ 39,768	$ 31,632
Washington Refinery Intermediation Agreement
Supply Commitment [Line Items]
Percentage of receivables and inventory for deferred payment		95.00%
Amount of deferred payment arrangement		$ 90,000
Commitment fee percentage	0.75%	1.50%
Long-term line of credit			63,800
Interest expense			6,400
London Interbank Offered Rate (LIBOR) | Washington Refinery Intermediation Agreement
Supply Commitment [Line Items]
Basis spread on variable rate		3.25%
Letter of Credit | Washington Refinery Intermediation Agreement
Supply Commitment [Line Items]
Line of credit, current			127,200
Inventory Intermediation | Washington Refinery Intermediation Agreement
Supply Commitment [Line Items]
Cost of goods and services sold			$ 3,700

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($)	Dec. 31, 2019	Dec. 31, 2018	Sep. 27, 2018	Dec. 21, 2017	Jun. 30, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 634,737,000	$ 416,466,000
Less: unamortized discount and deferred financing costs	(22,806,000)	(23,826,000)
Total debt, net of unamortized debt discount	611,931,000	392,640,000
Less current maturities	(12,297,000)	(33,000)
Long-term debt, net of current maturities and unamortized discount	$ 599,634,000	392,607,000
5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%				5.00%
7.75% Senior Secured Note due 2025
Debt Instrument [Line Items]
Debt instrument, interest rate	7.75%
Convertible Debt | 5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 48,665,000	115,000,000
Less: unamortized discount and deferred financing costs	$ (3,900,000)
Debt instrument, interest rate	5.00%
Senior Notes | 7.75% Senior Secured Note due 2025
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 300,000,000	300,000,000		$ 300,000,000
Debt instrument, interest rate	7.75%			7.75%
Term Loan | Mid Pac Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 1,433,000	1,466,000
Debt instrument, interest rate			4.375%
Term Loan | Term Loan B Facility
Debt Instrument [Line Items]
Principal amount of long-term debt	240,625,000	0
Term Loan | Retail Property Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	44,014,000	0
Revolving Credit Facility | ABL Revlover
Debt Instrument [Line Items]
Principal amount of long-term debt	0	0
Letters of credit outstanding	200,000	$ 13,500,000
Letters of Credit and Surety Bonds
Debt Instrument [Line Items]
Letters of credit outstanding	$ 3,600,000

Debt - Long-Term Debt Maturitie

Debt - Long-Term Debt Maturities (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Debt Disclosure [Abstract]
2020	$ 14,054
2021	62,785
2022	14,187
2023	14,259
2024	50,080
Thereafter	479,372
Total	$ 634,737	$ 416,466

Debt - 7.75% Senior Secured Not

Debt - 7.75% Senior Secured Notes Due 2025 (Details) - USD ($) $ in Thousands	Dec. 21, 2017	Dec. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Principal amount of long-term debt		$ 634,737	$ 416,466
7.75% Senior Secured Note due 2025
Debt Instrument [Line Items]
Debt instrument, interest rate		7.75%
Senior Notes | 7.75% Senior Secured Note due 2025
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 300,000	$ 300,000	$ 300,000
Long-term debt	$ 289,200
Unamortized discount and debt issuance costs, percentage	1.00%
Debt instrument, interest rate	7.75%	7.75%

Debt - ABL Loan Agreement (Deta

Debt - ABL Loan Agreement (Details) - USD ($)	Jul. 24, 2018	Dec. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Principal amount of long-term debt		$ 634,737,000	$ 416,466,000
Revolving Credit Facility | ABL Credit Facility
Debt Instrument [Line Items]
Line of credit facility, increase (decrease)	$ 10,000,000
Line credit maximum borrowing amount	$ 85,000,000
Revolving Credit Facility | ABL Revlover
Debt Instrument [Line Items]
Principal amount of long-term debt		0	$ 0
Line of credit facility, borrowing base		$ 57,600,000
Effective percentage		4.30%

Debt - ABL Credit Facility Appl

Debt - ABL Credit Facility Applicable Margins (Details) - ABL Revlover	12 Months Ended
	Dec. 31, 2019
Borrowing Base Greater than 50% | Prime Rate
Debt Instrument [Line Items]
Debt instrument margin rate	0.75%
Borrowing Base Greater than 50% | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument margin rate	1.75%
Borrowing Base Greater than 30% and less than or Equal to 50% | Prime Rate
Debt Instrument [Line Items]
Debt instrument margin rate	1.00%
Borrowing Base Greater than 30% and less than or Equal to 50% | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument margin rate	2.00%
Borrowing Base Less Than or Equal to 30% | Prime Rate
Debt Instrument [Line Items]
Debt instrument margin rate	1.25%
Borrowing Base Less Than or Equal to 30% | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument margin rate	2.25%

Debt - Mid Pac Term Loan (Detai

Debt - Mid Pac Term Loan (Details) - USD ($) $ in Thousands	Sep. 27, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Proceeds from issuance of debt		$ 510,906	$ 118,741	$ 616,706
Term Loan | Mid Pac Term Loan
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 1,500
Debt instrument, interest rate	4.375%

Debt - 5% Convertible Senior No

Debt - 5% Convertible Senior Note Due 2021 (Details)	Jun. 27, 2016USD ($)shares	Jun. 21, 2016USD ($)$ / shares	Jun. 30, 2016USD ($)trading_dayday	Dec. 31, 2019USD ($)shares	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Jun. 15, 2016USD ($)
Debt Instrument [Line Items]
Repayments of debt					$ 241,336,000	$ 118,751,000	$ 603,770,000
Principal amount of long-term debt				$ 634,737,000	634,737,000	416,466,000
Unamortized discount (premium) and debt issuance costs				$ 22,806,000	$ 22,806,000	23,826,000
5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Debt instrument, interest rate			5.00%	5.00%	5.00%
Convertible Debt | 5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Aggregate principal amount			$ 115,000,000
Additional principal amount			15,000,000
Proceeds from borrowings			$ 111,600,000
Unamortized discount and debt issuance costs, percentage			3.00%
Debt instrument, interest rate				5.00%	5.00%
Conversion rate	55.5556
Number of equity instruments (in shares) | shares	6,388,894
Conversion price (in dollars per share) | $ / shares		$ 18
Threshold percentage of stock price trigger	140.00%
Threshold trading days | day			20
Threshold consecutive trading days | trading_day			30
Redemption price, percentage	100.00%
Repurchase face amount				$ 66,300,000	$ 66,300,000
Repayments of convertible debt				$ 18,600,000
Issuance of common stock for convertible notes repurchase, net (in shares) | shares				3,200,000
Repurchase of convertible debt				$ 74,300,000
Debt extinguishment and commitment costs					(6,100,000)
Long-term debt, fair value	$ 89,300,000
Carrying amount of equity component	22,200,000			28,700,000	28,700,000
If-converted value in excess of principal					14,200,000
Principal amount of long-term debt				48,665,000	48,665,000	$ 115,000,000
Unamortized discount (premium) and debt issuance costs				3,900,000	3,900,000
Term Loan | Tranche B Term Loan
Debt Instrument [Line Items]
Repayments of debt		$ 5,000,000
Deferred finance costs, net								$ 2,500,000
Long-term Debt | Convertible Debt | 5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Deferred finance costs, net	$ 600,000
Reported Value Measurement | 5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Long-term debt, fair value				$ 44,800,000	$ 44,800,000

Debt - Term Loan B Facility (De

Debt - Term Loan B Facility (Details) - USD ($)	Jan. 11, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Proceeds from borrowings		$ 510,906,000	$ 118,741,000	$ 616,706,000
Term Loan | Term Loan B Facility
Debt Instrument [Line Items]
Debt instrument, face amount	$ 250,000,000
Proceeds from borrowings	232,000,000
Effective percentage		9.10%
Periodic payment, principal amount	$ 3,100,000
Term Loan | Term Loan B Facility | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate	6.75%
Term Loan | Term Loan B Facility | Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate	5.75%

Debt - Par Pacific Term Loan Ag

Debt - Par Pacific Term Loan Agreement (Details) - Term Loan - Par Pacific Term Loan - USD ($)	Jan. 09, 2019	Dec. 31, 2019
Debt Instrument [Line Items]
Debt instrument, face amount	$ 45,000,000
Effective percentage		1.30%
Debt extinguishment and commitment costs		$ 100,000
London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate	3.50%

Debt - Retail Property Term Loa

Debt - Retail Property Term Loan (Details) - Retail Property Term Loan	Mar. 29, 2019USD ($)retail_property	Dec. 31, 2019
Debt Instrument [Line Items]
Retail properties with mortgage liens | retail_property	21
Term Loan
Debt Instrument [Line Items]
Debt instrument, face amount | $	$ 45,000,000
Debt covenant, loan-to-appraisal value of portfolio properties, ratio	75.00%
Debt covenant, minimum annual debt yield	9.00%
Effective percentage		3.80%
Debt instrument, term	20 years
Term Loan | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate	1.50%

Debt - J. Aron Forward Sale (De

Debt - J. Aron Forward Sale (Details) - Supply and Offtake Agreements - USD ($) $ in Millions	Dec. 21, 2017	May 08, 2017
Debt Instrument [Line Items]
Purchase and supply commitment, forward sale amount		$ 30
Debt instrument, interest rate		7.00%
Cost associated with termination of debt	$ 0.3

Debt - Par Wyoming Holdings Cre

Debt - Par Wyoming Holdings Credit Agreement (Details) - Wyoming Refining Company - USD ($)	Dec. 21, 2017	Jul. 14, 2016
Secured Debt
Debt Instrument [Line Items]
Basis spread on variable rate		9.50%
Basis spread on variable rate, paid in kind		13.00%
Secured Debt
Debt Instrument [Line Items]
Debt instrument, face amount		$ 65,000,000
Cost associated with termination of debt	$ 5,200,000

Debt - Wyoming Refining Credit

Debt - Wyoming Refining Credit Facilities (Details) - USD ($)	Dec. 21, 2017	Jul. 14, 2016
Revolving Credit Facility | Wyoming Refining Senior Secured Revolver
Debt Instrument [Line Items]
Line credit maximum borrowing amount		$ 30,000,000
Cost associated with termination of debt	$ 100,000
Term Loan | Wyoming Refining Senior Secured Term Loan
Debt Instrument [Line Items]
Periodic payment, principal amount		$ 2,300,000
Term Loan | Wyoming Refining Company | Wyoming Refining Senior Secured Term Loan | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate		3.00%

Debt - Hawaii Retail Credit Fac

Debt - Hawaii Retail Credit Facilities (Details) - USD ($)	Dec. 21, 2017	Dec. 31, 2017	Dec. 21, 2017	Dec. 17, 2015
Hawaii Retail Credit Agreement
Debt Instrument [Line Items]
Interest rate during period		4.00%
Hawaii Retail Credit Agreement | Term Loan
Debt Instrument [Line Items]
Line credit maximum borrowing amount				$ 110,000,000
Annual principal payment	$ 2,750,000		$ 2,750,000
Hawaii Retail Credit Agreement | Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Line credit maximum borrowing amount				$ 5,000,000
Cost associated with termination of debt	$ 1,200,000
Base Rate | Minimum | Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument margin rate			1.50%
Base Rate | Maximum | Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument margin rate			2.25%
Eurodollar | Minimum | Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument margin rate			2.50%
Eurodollar | Maximum | Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument margin rate			3.25%

Debt - Term Loan (Details)

Debt - Term Loan (Details) - USD ($)	Jun. 21, 2016	Jul. 11, 2014	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 15, 2016
Debt Instrument [Line Items]
Repayments of debt			$ 241,336,000	$ 118,751,000	$ 603,770,000
Secured Debt
Debt Instrument [Line Items]
Original issue discount		5.00%
Secured Debt | Term Loan
Debt Instrument [Line Items]
Line credit maximum borrowing amount		$ 50,000,000
Bridge Loan | Secured Debt
Debt Instrument [Line Items]
Line credit maximum borrowing amount		$ 75,000,000
Minimum | Secured Debt
Debt Instrument [Line Items]
Interest rate during period		10.00%
Maximum | Secured Debt
Debt Instrument [Line Items]
Interest rate during period		12.00%
2.5% Convertible Senior Note | Convertible Debt
Debt Instrument [Line Items]
Debt instrument, interest rate			2.50%
Tranche B Term Loan | Term Loan
Debt Instrument [Line Items]
Deferred finance costs, net						$ 2,500,000
Repayments of debt	$ 5,000,000
Delayed Draw Term Loan and Bridge Loan Agreement
Debt Instrument [Line Items]
Financing costs expensed					$ 1,800,000
Whitebox Advisors, LLC | Tranche B Term Loan | Term Loan
Debt Instrument [Line Items]
Deferred finance costs, net						$ 1,300,000
Repayments of debt	$ 3,300,000

Debt - Guarantors (Details)

Debt - Guarantors (Details)	Feb. 06, 2019USD ($)
Debt Disclosure [Abstract]
Initial offering price	$ 750,000,000

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) bbl in Thousands	1 Months Ended	12 Months Ended
	Feb. 28, 2018USD ($)	Dec. 31, 2019$ / bblbbl	Jun. 30, 2016USD ($)
Credit Derivatives [Line Items]
Derivative contracts, barrels		260
Derivative, average fixed interest rate		3.91%
Option Collars
Credit Derivatives [Line Items]
Derivative contracts, barrels		75
Commodity derivatives
Credit Derivatives [Line Items]
Derivative contracts, barrels		260
Interest Rate Swap
Credit Derivatives [Line Items]
Notional amount | $	$ 100,000,000
Termination of derivative gain (loss) | $	$ 3,700,000
Long
Credit Derivatives [Line Items]
Derivative contracts, barrels		3,360
Long | Commodity derivatives
Credit Derivatives [Line Items]
Derivative contracts, barrels		3,360
Short
Credit Derivatives [Line Items]
Derivative contracts, barrels		3,100
Short | Commodity derivatives
Credit Derivatives [Line Items]
Derivative contracts, barrels		3,100
5% Convertible Senior Notes due 2021
Credit Derivatives [Line Items]
Debt instrument, interest rate		5.00%	5.00%
5% Convertible Senior Notes due 2021 | Convertible Debt
Credit Derivatives [Line Items]
Aggregate principal amount | $			$ 115,000,000
Debt instrument, interest rate		5.00%
Minimum | Option Collars
Credit Derivatives [Line Items]
Derivative, average price risk option strike price | $ / bbl		48.77
Maximum | Option Collars
Credit Derivatives [Line Items]
Derivative, average price risk option strike price | $ / bbl		65

Derivatives - Schedule of Deriv

Derivatives - Schedule of Derivatives Fair Value Amounts (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	$ 10,300	$ 2,700
Other Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	9,500	8,300
Commodity Contract | Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	2,075	4,973
Commodity Contract | Other accrued liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(5,534)	(700)
Interest rate derivatives | Prepaid and other current assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	0	191
Interest rate derivatives | Other accrued liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(314)	0
Interest rate derivatives | Other liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(1,113)	0
Over the Counter | J. Aron repurchase obligation derivative | Obligations under inventory financing agreements
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	173	4,085
Over the Counter | MLC terminal obligation derivative | Obligations under inventory financing agreements
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	$ (14,717)	$ 0

Derivatives - Schedule of Pre-T

Derivatives - Schedule of Pre-Tax Gain (Loss) Recognized in the Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Commodity derivatives | Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives gain (loss)	$ (1,547)	$ (3,420)	$ (4,517)
J. Aron repurchase obligation derivative | Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives gain (loss)	(3,912)	23,649	436
MLC terminal obligation derivative | Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives gain (loss)	(19,326)	0	0
Interest rate derivatives | Interest Expense
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives gain (loss)	$ (1,506)
Interest rate derivatives | Interest Income
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives gain (loss)		$ 1,309	$ 489

Fair Value Measurements - Asset

Fair Value Measurements - Assets Acquired and Liabilities Assumed (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Jan. 11, 2019	Dec. 31, 2018	Mar. 23, 2018	Dec. 31, 2017
Goodwill	$ 195,919		$ 153,397		$ 107,187
Washington Refinery Acquisition
Net working capital		$ (35,854)
Property, plant and equipment		412,766
Operating lease assets		62,337
Goodwill		42,522
Long-term operating lease liabilities		(40,766)
Deferred tax liability		(92,103)
Other non-current liabilities		(804)
Total		$ 326,527
Operating lease, discount rate		9.60%
Northwest Retail
Net working capital				$ 3,822
Property, plant and equipment				30,230
Goodwill				46,210
Long-term capital lease obligations				(5,244)
Other non-current liabilities				(487)
Total				$ 74,531

Fair Value Measurements - Commo

Fair Value Measurements - Common Stock Warrants (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Investment warrants, exercise price (in dollars per share)	$ 0.09	$ 0.09
Warrants And rights outstanding term	2 years 8 months 1 day	3 years 8 months 1 day
Fair value of common stock warrants (in dollars per share)	$ 23.16	$ 14.13
Warrant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock warrants outstanding (in shares)	354,350	354,350
Laramie Energy Company
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity method investments, fair value				$ 51,800
Equity method investment, aggregate cost				$ 133,300
Impairment charge	$ 81,515	$ 0	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details)	Dec. 31, 2019	Jun. 30, 2016
5% Convertible Senior Notes due 2021
Schedule of Equity Method Investments [Line Items]
Debt instrument, interest rate	5.00%	5.00%
7.75% Senior Secured Note due 2025
Schedule of Equity Method Investments [Line Items]
Debt instrument, interest rate	7.75%

Fair Value Measurements - Deriv

Fair Value Measurements - Derivative Assets and Liabilities Measured at Fair Value on a Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Liabilities
Common stock warrants	$ (8,206)	$ (5,007)
Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		5,595
Derivative asset, fair value, gross liability		(431)
Derivative asset		5,164
Liabilities
Fair value of derivative liability	(34,306)	(2,053)
Derivative liability, fair value, gross asset	4,595	431
Derivative liability	(29,711)	(1,622)
Cash collateral	19,800	10,900
Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		191
Derivative asset, fair value, gross liability		0
Derivative asset		191
Liabilities
Fair value of derivative liability	(1,427)
Derivative liability, fair value, gross asset	0
Derivative liability	(1,427)
Fair Value, Inputs, Level 1 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		170
Liabilities
Fair value of derivative liability	(10,129)	(870)
Fair Value, Inputs, Level 1 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		0
Liabilities
Fair value of derivative liability	0
Fair Value, Inputs, Level 2 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		5,425
Liabilities
Fair value of derivative liability	(1,427)	(261)
Fair Value, Inputs, Level 2 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		191
Liabilities
Fair value of derivative liability	(1,427)
Fair Value, Inputs, Level 3 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		0
Liabilities
Fair value of derivative liability	(22,750)	(922)
Fair Value, Inputs, Level 3 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset		0
Liabilities
Fair value of derivative liability	0
Exchange Traded | Commodity derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	6,670	5,404
Derivative asset, fair value, gross liability	(4,595)	(431)
Derivative asset	2,075	4,973
Liabilities
Fair value of derivative liability	(10,129)	(1,131)
Derivative liability, fair value, gross asset	4,595	431
Derivative liability	(5,534)	(700)
Exchange Traded | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	173	4,085
Derivative liability, fair value, gross asset	0	0
Derivative liability	173	4,085
Exchange Traded | MLC terminal obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	(14,717)
Derivative liability, fair value, gross asset	0
Derivative liability	(14,717)
Exchange Traded | Fair Value, Inputs, Level 1 | Commodity derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	4,595	170
Liabilities
Fair value of derivative liability	(10,129)	(870)
Exchange Traded | Fair Value, Inputs, Level 1 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	0	0
Exchange Traded | Fair Value, Inputs, Level 1 | MLC terminal obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	0
Exchange Traded | Fair Value, Inputs, Level 2 | Commodity derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	2,075	5,234
Liabilities
Fair value of derivative liability	0	(261)
Exchange Traded | Fair Value, Inputs, Level 2 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	0	0
Exchange Traded | Fair Value, Inputs, Level 2 | MLC terminal obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	0
Exchange Traded | Fair Value, Inputs, Level 3 | Commodity derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	0	0
Liabilities
Fair value of derivative liability	0	0
Exchange Traded | Fair Value, Inputs, Level 3 | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	173	4,085
Exchange Traded | Fair Value, Inputs, Level 3 | MLC terminal obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	(14,717)
Over the Counter | Fair Value, Measurements, Recurring
Liabilities
Common stock warrants	(8,206)	(5,007)
Derivative liability, fair value, gross asset	0	0
Derivative liability	(8,206)	(5,007)
Over the Counter | Fair Value, Inputs, Level 1 | Fair Value, Measurements, Recurring
Liabilities
Common stock warrants	0	0
Over the Counter | Fair Value, Inputs, Level 2 | Fair Value, Measurements, Recurring
Liabilities
Common stock warrants	0	0
Over the Counter | Fair Value, Inputs, Level 3 | Fair Value, Measurements, Recurring
Liabilities
Common stock warrants	$ (8,206)	$ (5,007)

Fair Value Measurements - Der_2

Fair Value Measurements - Derivative Instruments Measured at Fair Value (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, at beginning of period	$ (922)	$ (26,372)	$ (25,134)
Settlements	13,263	0	0
Acquired	(8,654)	0	0
Unrealized and realized income (loss) included in earnings	(26,437)	25,450	(1,238)
Balance, at end of period	$ (22,750)	$ (922)	$ (26,372)

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Value and Fair Value of Long-Term Debt and Other Financial Instruments (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Reported Value Measurement | 5% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 44,800
Fair Value, Inputs, Level 2 | Reported Value Measurement | 5% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	44,783	$ 100,411
Fair Value, Inputs, Level 2 | Reported Value Measurement | 7.75% Senior Secured Note due 2025
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	292,015	290,763
Fair Value, Inputs, Level 2 | Reported Value Measurement | Term Loan B Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	230,474
Fair Value, Inputs, Level 2 | Estimate of Fair Value Measurement | 5% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	66,477	121,488
Fair Value, Inputs, Level 2 | Estimate of Fair Value Measurement | 7.75% Senior Secured Note due 2025
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	309,375	270,000
Fair Value, Inputs, Level 2 | Estimate of Fair Value Measurement | Term Loan B Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	240,625
Fair Value, Inputs, Level 3 | Reported Value Measurement | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	8,206	5,007
Fair Value, Inputs, Level 3 | Reported Value Measurement | Mid Pac Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,433	1,466
Fair Value, Inputs, Level 3 | Reported Value Measurement | Retail Property Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	43,226
Fair Value, Inputs, Level 3 | Estimate of Fair Value Measurement | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	8,206	5,007
Fair Value, Inputs, Level 3 | Estimate of Fair Value Measurement | Mid Pac Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	1,433	$ 1,466
Fair Value, Inputs, Level 3 | Estimate of Fair Value Measurement | Retail Property Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 43,226

Leases (Details)

Leases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)lease	Dec. 31, 2018USD ($)retail_property	Dec. 31, 2017USD ($)
Lessee, Lease, Description [Line Items]
Operating lease undiscounted amount	$ 9
Finance lease undiscounted amount	$ 1.2
Number of operating leases, not yet commenced | lease	3
Number of finance leases, not yet commenced | lease	3
Number of retail stations under capital leases | retail_property		17
Operating lease, average remaining lease term		8 years
Rent expense		$ 41.6	$ 41.2
Minimum
Lessee, Lease, Description [Line Items]
Renewal term	1 year
Capital lease, renewal term		1 year
Maximum
Lessee, Lease, Description [Line Items]
Renewal term	30 years
Capital lease, renewal term		15 years

Leases - Leased Assets and Liab

Leases - Leased Assets and Liabilities (Details) $ in Thousands	Dec. 31, 2019USD ($)
Finance
Right-of-use asset, gross	$ 11,552
Accumulated amortization	(4,447)
Total finance	7,105
Operating
Operating lease assets	420,073
Total leased assets	427,178
Current
Finance	1,784
Operating	79,999
Long-term
Finance	6,227
Operating	340,909
Present value of lease liabilities	$ 428,919
Weighted-average remaining lease term (in years)
Finance	5 years 8 months 8 days
Operating	10 years 3 months 3 days
Weighted-average discount rate
Finance	6.68%
Operating	7.88%

Leases - Lease Cost (Details)

Leases - Lease Cost (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Finance lease cost
Amortization of finance lease assets	$ 1,896
Interest on lease liabilities	521
Operating lease cost	100,384
Variable lease cost	11,663
Short-term lease cost	1,874
Net lease cost	$ 116,338

Leases - Cash Flow (Details)

Leases - Cash Flow (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Cash paid for amounts included in the measurement of liabilities
Financing cash flows from finance leases	$ 2,167
Operating cash flows from finance leases	507
Operating cash flows from operating leases	99,713
Non-cash supplemental amounts
ROU assets obtained in exchange for new finance lease liabilities	963
ROU assets obtained in exchange for new operating lease liabilities	$ 79,382

Leases - Maturity Schedule (Det

Leases - Maturity Schedule (Details) $ in Thousands	Dec. 31, 2019USD ($)
Finance leases
2020	$ 2,247
2021	1,593
2022	1,376
2023	1,345
2024	1,058
Thereafter	2,004
Total lease payments	9,623
Less amount representing interest	(1,612)
Present value of lease liabilities	8,011
Operating leases
2020	109,727
2021	69,091
2022	66,859
2023	53,088
2024	43,337
Thereafter	240,988
Total lease payments	583,090
Less amount representing interest	(162,182)
Present value of lease liabilities	420,908
Total
2020	111,974
2021	70,684
2022	68,235
2023	54,433
2024	44,395
Thereafter	242,992
Total lease payments	592,713
Less amount representing interest	(163,794)
Present value of lease liabilities	$ 428,919

Leases - Maturity Schedule Prio

Leases - Maturity Schedule Prior to the Adoption of ASC 842 (Details) $ in Thousands	Dec. 31, 2018USD ($)
Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	$ 2,723
2020	2,264
2021	1,757
2022	1,512
2023	1,148
Thereafter	2,600
Total minimum rental payments	12,004
Less amount representing interest	(1,865)
Present value of minimum rental payments	10,139
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	62,589
2020	62,132
2021	39,821
2022	38,402
2022	38,827
Thereafter	191,717
Total minimum rental payments	$ 433,488

Commitments and Contingencies C

Commitments and Contingencies Commitment and Contingencies - Narrative (Details)	Mar. 22, 2018USD ($)	Dec. 31, 2019USD ($)refineryclaim	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2019USD ($)refineryclaim	Jun. 17, 2013USD ($)
Long-term Purchase Commitment [Line Items]
Renewable identification numbers (RINs) benefit		$ 5,300,000
Number of owned and operated refineries | refinery		4					4
Site contingency reimbursement							$ 12,200,000
Bankruptcy claims number of claims to be settled | claim		2					2
Bankruptcy claims amount of claims to be settled		$ 22,400,000					$ 22,400,000
Settlement liabilities, current		500,000					500,000
Maximum bankruptcy claims remaining		$ 22,400,000					$ 22,400,000
Predecessor working ownership percentage		3.40%					3.40%
Allowed claims, settlement ratio			0.0544
One Major Customer | Customer Concentration Risk | Revenue from Contract with Customer Benchmark
Long-term Purchase Commitment [Line Items]
Concentration risk, percentage				10.00%
Wyoming Refinery One
Long-term Purchase Commitment [Line Items]
Accrual for environmental loss contingencies		$ 16,500,000					$ 16,500,000
Environmental costs recognized, period for recognition of one third costs		5 years
Environmental costs recognized, period for recognition		30 years
Wyoming Refinery Two | Waste Water Treatment System
Long-term Purchase Commitment [Line Items]
Accrual for environmental loss contingencies		$ 11,600,000					11,600,000
Wyoming Refinery
Long-term Purchase Commitment [Line Items]
Loss contingency, range of possible loss, portion not accrued		100,000					100,000
Maximum | Tesoro Corporation
Long-term Purchase Commitment [Line Items]
Contingent consideration, liability								$ 40,000,000
Tesoro Corporation
Long-term Purchase Commitment [Line Items]
Contingent consideration, liability								$ 20,000,000
Loss contingency, damages paid	$ 10,500,000				$ 16,800,000
Loss contingency, damages sought					$ 8,300,000	$ 4,300,000
Tesoro Corporation | Indemnification Agreement
Long-term Purchase Commitment [Line Items]
Guarantor obligations, deductible		1,000,000					1,000,000
Guarantor obligations, maximum exposure, undiscounted		$ 15,000,000					$ 15,000,000

Stockholders' Equity - Registra

Stockholders' Equity - Registration Rights Agreement (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Maximum amount of repurchase rights agreement	$ 50
Effectiveness penalty percentage	0.25%
Purchase price allocation percentage	0.75%
5% Convertible Senior Notes due 2021 | Convertible Debt
Debt Instrument [Line Items]
Interest rate on the 90th day following registration statement	0.25%
Interest rate on the 91st day following the registration statement	0.50%
Registration statement liquidation damages limit	0.50%

Stockholders' Equity - Incentiv

Stockholders' Equity - Incentive Plan (Details) - USD ($)	Jun. 12, 2014	Dec. 31, 2019	May 08, 2018
Class of Stock [Line Items]
Number of shares authorized (in shares)			6,000,000
Available future grants and awards (in shares)		1,800,000
Award vesting period		4 years
Restricted Stock
Class of Stock [Line Items]
Award vesting period		4 years
Restricted Stock Units (RSUs)
Class of Stock [Line Items]
Award vesting period		3 years
Stock Purchase Plan | Employee Stock
Class of Stock [Line Items]
Maximum stock purchase per employee	$ 1,000,000
Stock purchase plan restricted sale of stock period	2 years
Percent of common stock granted in proportion to common stock purchased	20.00%
Vesting percentage of restricted stock granted in relation to shares purchased under the Stock Purchase Plan	50.00%
Vesting period of restricted stock granted in relation to shares purchased under the Stock Purchase Plan	2 years
Term for stock option purchase in relation to Stock Purchase Plan	5 years
Vesting period of stock options purchased in relation to shares purchased under the Stock Purchase Plan	2 years
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	50.00%
Non-Employee Chairman | Stock Purchase Plan | Employee Stock
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	50.00%
Non-Employee Board Member | Stock Purchase Plan | Employee Stock
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	35.00%
Minimum | Executive Officer | Stock Purchase Plan | Employee Stock
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	50.00%
Maximum | Executive Officer | Stock Purchase Plan | Employee Stock
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	70.00%

Stockholders' Equity - Summary

Stockholders' Equity - Summary of Compensation Costs (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Restricted Stock
Class of Stock [Line Items]
Compensation expense	$ 3,490	$ 3,483	$ 4,263
Restricted Stock Units (RSUs)
Class of Stock [Line Items]
Compensation expense	1,269	835	502
Employee Stock Option
Class of Stock [Line Items]
Compensation expense	$ 1,454	$ 1,878	$ 2,439

Stockholders' Equity - Employee

Stockholders' Equity - Employee Stock Purchase Plan (Details) - USD ($) $ in Thousands	Feb. 27, 2018	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for grant (in shares)		1,800,000
ESPP | Employee Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Purchase price of common stock, percent	85.00%
Maximum purchase value during offering period, per employee	$ 15
ESPP | Employee Stock Purchase Plan | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of purchase value during offering period, per employee	0.00%
ESPP | Employee Stock Purchase Plan | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of purchase value during offering period, per employee	10.00%
ESPP | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining number of shares authorized to be repurchase (in shares)		432,000
Share-based compensation expense		$ 200
Discount from market price, offering date		15.00%
Number of shares issued to employees (in shares)		68,000
ESPP | Common Stock | Employee Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for grant (in shares)	500,000

Stockholders' Equity - Summar_2

Stockholders' Equity - Summary of Restricted Stock Activity (Detail) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Restricted Stock
Shares
Non vested balance, beginning of period (in shares)	526
Granted (in shares)	295
Vested (in shares)	(213)
Forfeited (in shares)	(70)
Non vested balance, end of period (in shares)	538	526
Weighted- Average Grant Date Fair Value
Non vested balance, beginning of period (USD per share)	$ 17.29
Granted (USD per share)	17.43	$ 17.47	$ 15.49
Vested (USD per share)	17.31
Forfeited (USD per share)	16.64
Non vested balance, end of period (USD per share)	$ 16.95	$ 17.29
Performance Restricted Stock Units
Shares
Non vested balance, beginning of period (in shares)	101
Granted (in shares)	48
Vested (in shares)	0
Forfeited (in shares)	(3)
Non vested balance, end of period (in shares)	146	101
Weighted- Average Grant Date Fair Value
Non vested balance, beginning of period (USD per share)	$ 16.14
Granted (USD per share)	17
Vested (USD per share)	0
Forfeited (USD per share)	17.34
Non vested balance, end of period (USD per share)	$ 16.33	$ 16.14

Stockholders' Equity - Narrativ

Stockholders' Equity - Narrative Restricted Stock Awards and Stock Option Grants (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Class of Stock [Line Items]
Weighted average exercise price (USD per share)	$ 19.31	$ 19.27
Deferred and Matching Restricted Stock Units
Class of Stock [Line Items]
Stock issued during period, MSPP (in shares)	0
Restricted Stock
Class of Stock [Line Items]
Options vested in period, fair value	$ 3.7	$ 3.3	$ 4
Grants in period, weighted average grant date fair value (USD per share)	$ 17.43	$ 17.47	$ 15.49
Compensation not yet recognized,share-based awards other than options	$ 6.3	$ 5.8
Compensation cost not yet recognized, period for recognition	1 year 8 months 8 days	2 years 5 months 15 days
Performance Restricted Stock Units
Class of Stock [Line Items]
Grants in period, weighted average grant date fair value (USD per share)		$ 17.34	$ 14.60
Compensation not yet recognized,share-based awards other than options	$ 0.9	$ 0.9
Compensation cost not yet recognized, period for recognition	1 year 8 months 26 days	1 year 10 months 13 days
Total unrecognized compensation costs related to stock option awards (in years)	$ 0.8	$ 0.8	$ 0.7
Employee Stock Option
Class of Stock [Line Items]
Compensation cost not yet recognized, period for recognition	1 year 8 months 8 days	2 years 3 months 25 days
Weighted average exercise price (USD per share)	$ 5.98	$ 6.30	$ 5.81
Total unrecognized compensation costs related to stock option awards	$ 2.7	$ 3.4

Stockholders' Equity - Weighted

Stockholders' Equity - Weighted Average Assumptions Stock Options Granted (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Equity [Abstract]
Expected life from date of grant (years)	5 years 3 months 18 days	5 years 3 months 18 days	5 years 3 months 18 days
Expected volatility	34.30%	36.20%	42.00%
Risk-free interest rate	2.46%	2.50%	1.97%

Stockholders' Equity - Stock Op

Stockholders' Equity - Stock Option Activity Schedule (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Number of Options
Outstanding, Beginning of year (in shares)	2,231
Issued (in shares)	300
Exercise (in shares)	(483)
Forfeited / canceled (in shares)	(18)
Outstanding, End of year (in shares)	2,030	2,231
Exercisable, end of year (in shares)	1,275
Weighted-Average Exercise Price
Outstanding, beginning of year (USD per share)	$ 19.27
Issued (USD per share)	17
Exercised (USD per share)	17.78
Forfeited / canceled (USD per share)	17
Outstanding, end of year (USD per share)	19.31	$ 19.27
Exercisable, weighted average exercise price (USD per share)	$ 20.25
Weighted-Average Remaining Contractual Term in Years
Outstanding, weighted average remaining contractual term	4 years 8 months 12 days	4 years 9 months 18 days
Options exercisable, weighted average remaining contractual term	3 years 7 months 6 days
Aggregate Intrinsic Value
Outstanding at January 1	$ 0
Outstanding at December 31	7,981	$ 0
Exercisable at year end	$ 3,816
Employee Stock Option
Weighted-Average Exercise Price
Outstanding, beginning of year (USD per share)	$ 6.30	$ 5.81
Outstanding, end of year (USD per share)	$ 5.98	$ 6.30

Benefit Plans - Narrative (Deta

Benefit Plans - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Requisite service period	30 days
Minimum participant age	21 years
Employer matching contribution, percent of match	6.00%
Employers matching contribution, vesting percentage	100.00%
Total plan contributions	$ 5,600,000	$ 4,000,000	$ 3,600,000
Period with five consecutive years of highest average compensation	10 years
U.S. Oil plan
Defined Benefit Plan Disclosure [Line Items]
Expected future employer contributions, next fiscal year	$ 500,000
Wyoming Refining plan
Defined Benefit Plan Disclosure [Line Items]
Expected future employer contributions, next fiscal year	$ 0

Benefit Plans - Changes in Proj

Benefit Plans - Changes in Projected Benefit Obligations and Fair Value of Plan Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Changes in projected benefit obligation:
Projected benefit obligation as of the beginning of the period	$ 27,539	$ 30,877
Acquired	16,831	0
Service cost	910	548	$ 614
Interest cost	1,794	1,107	1,192
Actuarial (gain) loss	6,688	(2,917)
Benefits paid	(1,620)	(2,076)
Projected benefit obligation as of the end of the period	52,142	27,539	30,877
Changes in fair value of plan assets:
Fair value of plan assets as of the beginning of the period	20,254	23,461
Acquired	16,027	0
Actual return (loss) on plan assets	6,405	(1,131)
Employer contributions	1,800	0
Benefits paid	(1,620)	(2,076)
Fair value of plan assets as of the end of the period	$ 42,866	$ 20,254	$ 23,461

Benefit Plans - Unfunded Status

Benefit Plans - Unfunded Status (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Retirement Benefits [Abstract]
Projected benefit obligation	$ 52,142	$ 27,539	$ 30,877
Fair value of plan assets	42,866	20,254	$ 23,461
Underfunded status	9,276	7,285
Other post-retirement benefits income (loss)	(2,622)	$ 3,494
Expected amortization, next fiscal year	$ 200

Benefit Plans - Key Assumptions

Benefit Plans - Key Assumptions for Projected Benefit Obligation and Net Periodic Benefit Cost (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Wyoming Refining plan
Projected benefit obligation:
Discount rate	3.30%	4.20%	3.65%
Rate of compensation increase	3.00%	3.00%	3.00%
Net periodic benefit costs:
Discount rate	4.20%	3.65%	4.20%
Expected long-term rate of return	6.50%	6.50%	6.25%
Rate of compensation increase	3.00%	3.00%	4.30%
U.S. Oil plan
Projected benefit obligation:
Discount rate	3.10%	0.00%	0.00%
Rate of compensation increase	3.00%	0.00%	0.00%
Net periodic benefit costs:
Discount rate	4.10%	0.00%	0.00%
Expected long-term rate of return	6.00%	0.00%	0.00%
Rate of compensation increase	3.00%	0.00%	0.00%

Benefit Plans - Net Periodic Be

Benefit Plans - Net Periodic Benefit Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Components of net periodic benefit cost:
Service cost	$ 910	$ 548	$ 614
Interest cost	1,794	1,107	1,192
Expected return on plan assets	(1,972)	(1,258)	(1,189)
Amortization of net loss	95	0	0
Amortization of prior service cost	3	0	0
Net periodic benefit cost	$ 830	$ 397	$ 617

Benefit Plans - Asset Allocatio

Benefit Plans - Asset Allocation (Details)	Dec. 31, 2019
U.S. Oil plan
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	100.00%
Actual plan asset allocations	100.00%
U.S. Oil plan | Equity securities
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocations	62.00%
U.S. Oil plan | Debt securities
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocations	38.00%
U.S. Oil plan | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocations	0.00%
Wyoming Refining plan
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	100.00%
Actual plan asset allocations	100.00%
Wyoming Refining plan | Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	54.00%
Actual plan asset allocations	56.00%
Wyoming Refining plan | Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	35.00%
Actual plan asset allocations	32.00%
Wyoming Refining plan | Real estate
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	11.00%
Actual plan asset allocations	12.00%
Minimum | U.S. Oil plan | Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	40.00%
Minimum | U.S. Oil plan | Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	20.00%
Minimum | U.S. Oil plan | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	0.00%
Maximum | U.S. Oil plan | Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	80.00%
Maximum | U.S. Oil plan | Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	60.00%
Maximum | U.S. Oil plan | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	30.00%

Benefit Plans - Project Benefit

Benefit Plans - Project Benefit Payment Obligations (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Retirement Benefits [Abstract]
Fair value assumptions, expected term	10 years
2020	$ 2,215
2021	2,007
2022	2,082
2023	2,203
2024	2,234
Thereafter	13,095
Total	$ 23,836

Income (Loss) Per Share - Narra

Income (Loss) Per Share - Narrative (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 30, 2016
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	182	68	65
Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	1,600	1,300	1,300
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	5,100	6,400	6,400
Warrant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average number of shares issuable under the common stock warrants (in shares)	354	354	354
5% Convertible Senior Notes due 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Debt instrument, interest rate	5.00%			5.00%
Convertible Debt | 5% Convertible Senior Notes due 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Debt instrument, interest rate	5.00%

Income (Loss) Per Share - Commu

Income (Loss) Per Share - Commutation of Basic and Diluted Loss per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Earnings Per Share [Abstract]
Net income (loss)	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Undistributed income allocated to participating securities									438	556	878
Net income attributable to common stockholders									40,371	38,871	71,743
Plus: Net income effect of convertible securities									0	0	0
Numerator for diluted income per common share									$ 40,371	$ 38,871	$ 71,743
Basic weighted-average common stock shares outstanding (in shares)									50,352	45,726	45,543
Add dilutive effects of common stock equivalents (in shares)									118	29	40
Diluted weighted-average common stock shares outstanding (in shares)									50,470	45,755	45,583
Basic (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.23	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.58
Diluted (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.14	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.57

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Contingency [Line Items]
Net operating loss carryovers	$ 1,400,000,000
Income tax benefit	69,689,000	$ (333,000)	$ 1,319,000
Unrecognized tax benefits, period increase (decrease)	0	0	0
Tax Cuts and Jobs Act of 2017, income tax benefit		$ 700,000	800,000
Tax Cuts and Jobs Act of 2017, measurement period adjustment			$ 207,700,000
Alternative minimum tax credit carryovers	800,000
Washington Refinery Acquisition
Income Tax Contingency [Line Items]
Income tax benefit	$ 64,200,000

Income Taxes - Taxes Expense (B

Income Taxes - Taxes Expense (Benefit) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current:
U.S.—Federal	$ (3,203)	$ (328)	$ 0
U.S.—State	400	0	2
Deferred:
U.S.—Federal	(58,461)	426	(1,321)
U.S.—State	(8,425)	235	0
Total	$ (69,689)	$ 333	$ (1,319)

Income Taxes - Income Tax Rate

Income Taxes - Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Federal statutory rate	21.00%	21.00%	35.00%
State income taxes, net of federal benefit	(1.10%)	0.60%	0.00%
Change in valuation allowance related to current activity	227.10%	(21.30%)	(30.10%)
Change in valuation allowance related to change in tax rate	0.00%	0.00%	(291.20%)
Change in tax rate	0	0	2.912
Permanent items	(4.30%)	1.30%	1.10%
Provision to return adjustments and other	(1.40%)	(0.80%)	(7.90%)
Actual income tax rate	241.30%	0.80%	(1.90%)

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Asset (Liabilities) (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred tax assets:
Net operating loss	$ 373,717	$ 396,033
Property, plant, and equipment	0	8,323
Intangible assets	0	444
Other	19,560	17,886
Total deferred tax assets	393,277	422,686
Valuation allowance	(330,251)	(394,196)
Net deferred tax assets	63,026	28,490
Deferred tax liabilities:
Inventory	5,738	0
Property and equipment	64,281	0
Investment in Laramie Energy	11,609	26,981
Convertible notes	2,285	2,658
Intangible assets	750	0
Other	4,904	496
Total deferred tax liabilities	89,567	30,135
Total deferred tax liability, net	$ (26,541)	$ (1,645)

Segment Information (Detail)

Segment Information (Detail) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)segment	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Segment Reporting [Abstract]
Number of business segments | segment									4
Revenues	$ 1,399,134	$ 1,401,638	$ 1,409,409	$ 1,191,335	$ 879,112	$ 909,781	$ 856,396	$ 765,439	$ 5,401,516	$ 3,410,728	$ 2,443,066
Cost of revenues (excluding depreciation)									4,803,589	3,003,116	2,054,627
Operating expense (excluding depreciation)									312,899	215,284	202,016
Depreciation, depletion, and amortization									86,121	52,642	45,989
General and administrative expense (excluding depreciation)									46,223	47,426	46,078
Acquisition and integration costs									4,704	10,319	395
Operating income	59,531	18,405	48,621	21,423	20,408	4,894	28,983	27,656	147,980	81,941	93,961
Interest expense and financing costs, net									(74,839)	(39,768)	(31,632)
Debt extinguishment and commitment costs									(11,587)	(4,224)	(8,633)
Other income, net									2,516	1,046	911
Change in value of common stock warrants									(3,199)	1,801	(1,674)
Change in value of contingent consideration									0	10,500	0
Equity earnings (losses) from Laramie Energy, LLC									(89,751)	9,464	18,369
Income (loss) before income taxes									(28,880)	39,760	71,302
Income tax benefit (expense)									69,689	(333)	1,319
Net Income	35,439	$ (83,891)	$ 28,169	$ 61,092	13,886	$ (5,822)	$ 16,178	$ 15,185	40,809	39,427	72,621
Total assets	2,700,560				1,460,734				2,700,560	1,460,734	1,347,407
Goodwill	195,919				153,397				195,919	153,397	107,187
Capital expenditures									83,920	48,439	31,708
Refining
Revenues									5,167,942	3,210,067
Logistics
Revenues									199,226	125,743
Retail
Revenues									458,889	441,040
Operating Segments | Refining
Revenues									5,167,942	3,210,067	2,319,638
Cost of revenues (excluding depreciation)									4,783,747	2,957,995	2,062,804
Operating expense (excluding depreciation)									234,582	146,320	141,065
Depreciation, depletion, and amortization									55,832	32,483	29,753
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration costs									0	0	0
Operating income									93,781	73,269	86,016
Total assets	1,907,318				968,623				1,907,318	968,623	949,588
Goodwill	77,927				53,264				77,927	53,264	53,264
Capital expenditures									34,492	25,601	10,433
Operating Segments | Logistics
Revenues									199,226	125,743	121,470
Cost of revenues (excluding depreciation)									112,124	77,712	66,301
Operating expense (excluding depreciation)									11,010	7,782	15,010
Depreciation, depletion, and amortization									17,017	6,860	6,166
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration costs									0	0	0
Operating income									59,075	33,389	33,993
Total assets	494,209				130,138				494,209	130,138	118,304
Goodwill	55,232				37,373				55,232	37,373	37,373
Capital expenditures									40,730	13,055	8,836
Operating Segments | Retail
Revenues									458,889	441,040	326,076
Cost of revenues (excluding depreciation)									332,302	333,664	249,097
Operating expense (excluding depreciation)									67,307	61,182	45,941
Depreciation, depletion, and amortization									10,035	8,962	6,338
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration costs									0	0	0
Operating income									49,245	37,232	24,700
Total assets	232,150				201,848				232,150	201,848	128,966
Goodwill	62,760				62,760				62,760	62,760	16,550
Capital expenditures									6,869	6,101	7,073
Corporate Reconciling Items And Eliminations
Revenues									(424,541)	(366,122)	(324,118)
Cost of revenues (excluding depreciation)									(424,584)	(366,255)	(323,575)
Operating expense (excluding depreciation)									0	0	0
Depreciation, depletion, and amortization									3,237	4,337	3,732
General and administrative expense (excluding depreciation)									46,223	47,426	46,078
Acquisition and integration costs									4,704	10,319	395
Operating income									(54,121)	(61,949)	(50,748)
Total assets	66,883				160,125				66,883	160,125	150,549
Goodwill	$ 0				$ 0				0	0	0
Capital expenditures									1,829	3,682	5,366
Gross Profit									$ (424,500)	$ (365,500)	$ (325,200)

Related Party Transaction (Deta

Related Party Transaction (Detail) - USD ($)	Jun. 21, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jun. 30, 2016	Jun. 15, 2016
Related Party Transaction [Line Items]
Repayments of debt		$ 241,336,000	$ 118,751,000	$ 603,770,000
Percentage ownership of par common stock		10.00%
Investor
Related Party Transaction [Line Items]
Travel and out of pocket expenses		$ 50,000
Initial term of service agreements		1 year
Renewal term for service agreements		1 year
Termination period between extension date		60 days
Equity Group Investments | Investor
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party		$ 0	$ 0	$ 0
Tranche B Term Loan | Term Loan
Related Party Transaction [Line Items]
Deferred finance costs, net							$ 2,500,000
Repayments of debt	$ 5,000,000
Tranche B Term Loan | Term Loan | Investor
Related Party Transaction [Line Items]
Deferred finance costs, net							2,500,000
Tranche B Term Loan | Term Loan | Whitebox Advisors, LLC
Related Party Transaction [Line Items]
Deferred finance costs, net							$ 1,300,000
Repayments of debt	$ 3,300,000
5% Convertible Senior Notes due 2021
Related Party Transaction [Line Items]
Debt instrument, interest rate		5.00%				5.00%
5% Convertible Senior Notes due 2021 | Convertible Debt
Related Party Transaction [Line Items]
Debt instrument, interest rate		5.00%
Aggregate principal amount						$ 115,000,000
5% Convertible Senior Notes due 2021 | Convertible Debt | Whitebox Advisors, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Aggregate principal amount					$ 47,500,000
Line credit maximum borrowing amount						32,500,000
5% Convertible Senior Notes due 2021 | Convertible Debt | Highbridge | Affiliated Entity
Related Party Transaction [Line Items]
Aggregate principal amount					$ 40,400,000
Senior Unsecured Convertible Notes due 2021 | Convertible Debt | Whitebox Advisors, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Line credit maximum borrowing amount						$ 100,000,000

Quarterly Financial Data (Una_3

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 1,399,134	$ 1,401,638	$ 1,409,409	$ 1,191,335	$ 879,112	$ 909,781	$ 856,396	$ 765,439	$ 5,401,516	$ 3,410,728	$ 2,443,066
Operating income	59,531	18,405	48,621	21,423	20,408	4,894	28,983	27,656	147,980	81,941	93,961
Net income (loss)	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Net income (loss) per share
Basic (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.23	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.58
Diluted (USD per share)	$ 0.68	$ (1.65)	$ 0.56	$ 1.14	$ 0.30	$ (0.13)	$ 0.35	$ 0.33	$ 0.80	$ 0.85	$ 1.57

Supplemental Oil and Gas Disc_3

Supplemental Oil and Gas Disclosures (Unaudited) Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Oil and Gas, Present Activity [Line Items]
Proved properties	$ 0	$ 400
Company's Share of Laramie Energy
Oil and Gas, Present Activity [Line Items]
Unproved properties	14,722	16,379
Proved properties	211,083	473,763
Oil and gas property, successful effort method, gross, total	225,805	490,142
Accumulated depreciation and depletion	(63,791)	(150,075)
Oil and gas property, successful efforts method	$ 162,014	$ 340,067

Supplemental Oil and Gas Disc_4

Supplemental Oil and Gas Disclosures (Unaudited) Costs Incurred (Details) - Company's Share of Laramie Energy - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Acquisition costs	$ 0	$ 0	$ 0
Development costs—other	32,748	50,867	49,273
Total	$ 32,748	$ 50,867	$ 49,273

Supplemental Oil and Gas Disc_5

Supplemental Oil and Gas Disclosures (Unaudited) Summary of Operations (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue
Revenues	$ 1,399,134	$ 1,401,638	$ 1,409,409	$ 1,191,335	$ 879,112	$ 909,781	$ 856,396	$ 765,439	$ 5,401,516	$ 3,410,728	$ 2,443,066
Expenses
Results of operations of oil and gas producing activities									(153,722)	23,811	13,093
Company
Expenses
Production costs									87	191	29
Depletion and amortization									6	17	66
Results of operations of oil and gas producing activities									63	(157)	193
Company's Share of Laramie Energy
Expenses
Production costs									41,446	42,706	32,606
Impairment of proved properties									163,401	0	0
Depletion and amortization									38,011	26,819	21,277
Results of operations of oil and gas producing activities									(153,785)	23,968	12,900
Oil and Gas | Company
Revenue
Revenues									156	51	288
Oil and Gas | Company's Share of Laramie Energy
Revenue
Revenues									$ 89,073	$ 93,493	$ 66,783

Oil and Gas Reserve Informati_3

Oil and Gas Reserve Information (Details) Mcf in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2019$ / WTIperBbl$ / CIGperMbtuMcfMBbls	Dec. 31, 2018$ / WTIperBbl$ / CIGperMbtuMcfMBbls	Dec. 31, 2017$ / WTIperBbl$ / CIGperMbtuMcfMBbls
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	276,611
Downward revision of proved undeveloped reserves	57,212
Downward revision due to decreases in natural gas prices	54,520,000
Proved developed reserve	276,611	318,210	206,446
Proved undeveloped reserve	0	105,668	138,750
Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance	119	500	420
Revisions of quantity estimate	270	(341)	139
Extensions and discoveries	0	0	0
Acquisitions and divestitures	(48)
Production	(26)	(40)	(59)
Ending Balance	315	119	500
Increase (decrease) in estimated proved reserves	(147,267)	78,682	22,095
Increase in estimated proved reserves, percentage	(35.00%)	23.00%	(6.00%)
Proved developed reserve		119	500
Proved undeveloped reserve	0	0	0
Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance	423,759	344,696	366,871
Revisions of quantity estimate	(111,732)	85,875	3
Extensions and discoveries	0	0	0
Acquisitions and divestitures	0	23,609	0
Production	(35,731)	(30,421)	(22,178)
Ending Balance	276,296	423,759	344,696
Increase (decrease) in estimated proved reserves	(35,731)
Additions of proved undeveloped reserves		60,679,000
Positive revisions from converted proved developed reserves		11,614,000
Positive revisions due to performance revisions		13,582,000
Proved developed reserve	276,296	318,091	205,946
Proved undeveloped reserve	0	105,668	138,750
Natural Gas
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	238,451
Proved developed reserve	238,451	256,452	174,856
Proved undeveloped reserve	0	81,428	118,578
Natural Gas | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance	89	392	330
Revisions of quantity estimate	222	(269)	109
Extensions and discoveries	0	0	0
Acquisitions and divestitures	(30)
Production	(20)	(34)	(47)
Ending Balance	261	89	392
Proved developed reserve		89	392
Proved undeveloped reserve	0	0	0
Base pricing, before adjustments for contractual differentials | $ / CIGperMbtu	2.04	2.47	2.68
Natural Gas | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance	337,791	293,042	309,802
Revisions of quantity estimate	(69,924)	47,871	1,344
Extensions and discoveries	0	0	0
Acquisitions and divestitures	0	22,391	0
Production	(29,677)	(25,513)	(18,104)
Ending Balance	238,190	337,791	293,042
Proved developed reserve	238,190	256,363	174,464
Proved undeveloped reserve	0	81,428	118,578
Oil
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance | MBbls	939
Proved developed reserve | MBbls	939	1,424	665
Proved undeveloped reserve | MBbls	0	325	449
Oil | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls	4	7	7
Revisions of quantity estimate | MBbls	1	(2)	2
Extensions and discoveries | MBbls	0	0	0
Acquisitions and divestitures | MBbls	(3)
Production | MBbls	(1)	(1)	(2)
Ending Balance | MBbls	1	4	7
Proved developed reserve | MBbls		4	7
Proved undeveloped reserve | MBbls	0	0	0
Base pricing, before adjustments for contractual differentials | $ / WTIperBbl	55.85	65.56	51.34
Oil | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls	1,745	1,107	967
Revisions of quantity estimate | MBbls	(681)	732	211
Extensions and discoveries | MBbls	0	0	0
Acquisitions and divestitures | MBbls	0	12	0
Production | MBbls	(126)	(106)	(71)
Ending Balance | MBbls	938	1,745	1,107
Proved developed reserve | MBbls	938	1,420	658
Proved undeveloped reserve | MBbls	0	325	449
Natural Gas Liquids
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance | MBbls	5,421
Proved developed reserve | MBbls	5,421	8,869	4,600
Proved undeveloped reserve | MBbls	0	3,715	2,913
Natural Gas Liquids | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls	1	11	8
Revisions of quantity estimate | MBbls	7	(10)	3
Extensions and discoveries | MBbls	0	0	0
Acquisitions and divestitures | MBbls	0
Production | MBbls	0	0	0
Ending Balance | MBbls	8	1	11
Proved developed reserve | MBbls		1	11
Proved undeveloped reserve | MBbls	0	0	0
Natural Gas Liquids | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls	12,583	7,502	8,544
Revisions of quantity estimate | MBbls	(6,287)	5,602	(434)
Extensions and discoveries | MBbls	0	0	0
Acquisitions and divestitures | MBbls	0	191	0
Production | MBbls	(883)	(712)	(608)
Ending Balance | MBbls	5,413	12,583	7,502
Proved developed reserve | MBbls	5,413	8,868	4,589
Proved undeveloped reserve | MBbls	0	3,715	2,913

Oil and Gas Reserve Informati_4

Oil and Gas Reserve Information - Summary of Proved Developed and Undeveloped Reserves (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Discounted future net cash flows	$ 140,016	$ 319,232	$ 216,393	$ 141,427
Company
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future net cash flows	833	398	1,802
Production	509	123	902
Development and abandonment	37	35	0
Income taxes	0	0	0
Future net cash flows	287	240	900
10% discount factor	(106)	(110)	(328)
Discounted future net cash flows	181	130	572	285
Company's Share of Laramie Energy
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future net cash flows	669,271	1,283,890	1,026,005
Production	398,193	583,112	491,748
Development and abandonment	25,277	93,546	109,248
Income taxes	0	0	0
Future net cash flows	245,801	607,232	425,009
10% discount factor	(105,966)	(288,130)	(209,188)
Discounted future net cash flows	$ 139,835	$ 319,102	$ 215,821	$ 141,142

Oil and Gas Reserve Informati_5

Oil and Gas Reserve Information - Discounted Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	$ 319,232	$ 216,393	$ 141,427
Sales of oil and gas production during the period, net of production costs	(59,148)	(47,292)	(29,939)
Acquisitions and divestitures	(143)	35,182
Net change in prices and production costs	(114,219)	(1,345)	35,537
Revisions of previous quantity estimates, estimated timing of development and other	(64,073)	53,919	38,038
Previously estimated development and abandonment costs incurred during the period	26,444	40,736	17,187
Accretion of discount	31,923	21,639	14,143
End of period	140,016	319,232	216,393
Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	130	572	285
Sales of oil and gas production during the period, net of production costs	(55)	(127)	(28)
Acquisitions and divestitures	(143)	0
Net change in prices and production costs	(24)	20	(60)
Revisions of previous quantity estimates, estimated timing of development and other	260	(392)	346
Previously estimated development and abandonment costs incurred during the period	0	0	0
Accretion of discount	13	57	29
End of period	181	130	572
Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	319,102	215,821	141,142
Sales of oil and gas production during the period, net of production costs	(59,093)	(47,165)	(29,911)
Acquisitions and divestitures	0	35,182
Net change in prices and production costs	(114,195)	(1,365)	35,597
Revisions of previous quantity estimates, estimated timing of development and other	(64,333)	54,311	37,692
Previously estimated development and abandonment costs incurred during the period	26,444	40,736	17,187
Accretion of discount	31,910	21,582	14,114
End of period	$ 139,835	$ 319,102	$ 215,821

Condensed Financial Informati_2

Condensed Financial Information of Registrant Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 126,015	$ 75,076
Restricted cash	2,413	743
Total cash, cash equivalents, and restricted cash	128,428	75,819	$ 119,077	$ 49,018
Prepaid and other current assets	59,156	28,370
Total current assets	1,032,174	586,592
Property, plant, and equipment
Property, plant, and equipment	1,146,983	649,768
Less accumulated depreciation, depletion, and amortization	(185,040)	(111,507)
Property, plant, and equipment, net	961,943	538,261
Long-term assets
Operating lease assets	420,073
Other long-term assets	21,997	21,881
Total assets	2,700,560	1,460,734	1,347,407
Current liabilities
Accounts payable	162,402	54,787
Operating lease liabilities	79,999
Other accrued liabilities	84,744	54,562
Total current liabilities	1,034,322	507,201
Long-term liabilities
Long-term debt, net of current maturities	599,634	392,607
Common stock warrants	8,206	5,007
Finance lease liabilities	6,227
Finance lease liabilities		6,123
Operating lease liabilities	340,909
Other liabilities	63,020	37,467
Total liabilities	2,052,318	948,405
Stockholders’ equity
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued	0	0
Common stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2019 and December 31, 2018, 53,254,151 shares and 46,983,924 shares issued at December 31, 2019 and December 31, 2018, respectively	533	470
Additional paid-in capital	715,069	617,937
Accumulated deficit	(67,942)	(108,751)
Accumulated other comprehensive income	582	2,673
Total stockholders’ equity	648,242	512,329	447,719	368,909
Total liabilities and stockholders’ equity	2,700,560	1,460,734
Parent Company
Current assets
Cash and cash equivalents	6,309	28,701
Restricted cash	743	743
Total cash, cash equivalents, and restricted cash	7,052	29,444	$ 66,359	$ 11,107
Prepaid and other current assets	12,325	11,711
Due from subsidiaries	180,686	43,928
Total current assets	200,063	85,083
Property, plant, and equipment
Property, plant, and equipment	20,961	18,939
Less accumulated depreciation, depletion, and amortization	(12,117)	(9,034)
Property, plant, and equipment, net	8,844	9,905
Long-term assets
Operating lease assets	4,276
Investment in subsidiaries	636,742	638,975
Other long-term assets	1,128	3,334
Total assets	851,053	737,297
Current liabilities
Accounts payable	2,597	8,312
Operating lease liabilities	698
Other accrued liabilities	14,591	12,349
Due to subsidiaries	125,778	96,963
Total current liabilities	143,664	117,624
Long-term liabilities
Long-term debt, net of current maturities	44,783	100,411
Common stock warrants	8,206	5,007
Finance lease liabilities	223
Finance lease liabilities		475
Operating lease liabilities	5,629
Other liabilities	306	1,451
Total liabilities	202,811	224,968
Stockholders’ equity
Preferred stock, $0.01 par value: 3,000,000 shares authorized, none issued	0	0
Common stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2019 and December 31, 2018, 53,254,151 shares and 46,983,924 shares issued at December 31, 2019 and December 31, 2018, respectively	533	470
Additional paid-in capital	715,069	617,937
Accumulated deficit	(67,942)	(108,751)
Accumulated other comprehensive income	582	2,673
Total stockholders’ equity	648,242	512,329
Total liabilities and stockholders’ equity	$ 851,053	$ 737,297

Condensed Financial Informati_3

Condensed Financial Information of Registrant Balance Sheet (Parenthetical) (Details) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Condensed Balance Sheet Statements, Captions [Line Items]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	3,000,000	3,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	53,254,151	46,983,924
Parent Company
Condensed Balance Sheet Statements, Captions [Line Items]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	3,000,000	3,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	53,254,151	46,983,924

Condensed Financial Informati_4

Condensed Financial Information of Registrant Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating expenses
Depreciation and amortization									$ 86,121	$ 52,642	$ 45,989
General and administrative expense (excluding depreciation)									46,223	47,426	46,078
Acquisition and integration costs									4,704	10,319	395
Total operating expenses									5,253,536	3,328,787	2,349,105
Operating loss	$ 59,531	$ 18,405	$ 48,621	$ 21,423	$ 20,408	$ 4,894	$ 28,983	$ 27,656	147,980	81,941	93,961
Other income (expense)
Interest expense and financing costs, net									(74,839)	(39,768)	(31,632)
Other income (expense), net									2,516	1,046	911
Change in value of common stock warrants									(3,199)	1,801	(1,674)
Equity in earnings (losses) from subsidiaries									(89,751)	9,464	18,369
Total other expense, net									(176,860)	(42,181)	(22,659)
Income (loss) before income taxes									(28,880)	39,760	71,302
Income tax benefit (expense)									69,689	(333)	1,319
Net Income	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	40,809	39,427	72,621
Parent Company
Operating expenses
Depreciation and amortization									2,969	4,092	2,871
General and administrative expense (excluding depreciation)									20,017	20,721	18,922
Acquisition and integration costs									28	10,118	192
Total operating expenses									23,014	34,931	21,985
Operating loss									(23,014)	(34,931)	(21,985)
Other income (expense)
Interest expense and financing costs, net									(9,952)	(10,867)	(13,709)
Debt extinguishment and commitment costs									(6,091)	0	(1,804)
Other income (expense), net									2,303	1,155	631
Change in value of common stock warrants									(3,199)	1,801	(1,674)
Equity in earnings (losses) from subsidiaries									81,097	81,942	111,162
Total other expense, net									64,158	74,031	94,606
Income (loss) before income taxes									41,144	39,100	72,621
Income tax benefit (expense)									(335)	327	0
Net Income									$ 40,809	$ 39,427	$ 72,621

Condensed Financial Informati_5

Condensed Financial Information of Registrant Other Comprehensive Income (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Statement of Income Captions [Line Items]
Net income (loss)		$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Other comprehensive income (loss):
Other post-retirement benefits income (loss), net of tax										(2,091)	529	(52)
Total other comprehensive income (loss), net of tax										(2,091)	529	(52)
Comprehensive income										38,718	39,956	72,569
Parent Company
Condensed Statement of Income Captions [Line Items]
Net income (loss)										40,809	39,427	72,621
Other comprehensive income (loss):
Other post-retirement benefits income (loss), net of tax	[1]									(2,091)	529	(52)
Total other comprehensive income (loss), net of tax	[1]									(2,091)	529	(52)
Comprehensive income	[1]									$ 38,718	$ 39,956	$ 72,569
[1]	Other comprehensive income (loss) relates to benefit plans at our subsidiaries.

Condensed Financial Informati_6

Condensed Financial Information of Registrant Statements of Cash Flow (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash flows from operating activities:
Net income (loss)	$ 35,439	$ (83,891)	$ 28,169	$ 61,092	$ 13,886	$ (5,822)	$ 16,178	$ 15,185	$ 40,809	$ 39,427	$ 72,621
Adjustments to reconcile net income to cash used in operating activities:
Depreciation, depletion, and amortization									86,121	52,642	45,989
Non-cash interest expense									9,118	7,127	7,276
Change in value of common stock warrants									3,199	(1,801)	1,674
Stock-based compensation									6,437	6,196	7,204
Equity in losses (income) of subsidiaries									89,751	(9,464)	(18,369)
Net changes in operating assets and liabilities:
Prepaid and other assets									(24,121)	(5,521)	37,645
Accounts payable, other accrued liabilities, and operating lease assets and liabilities									68,969	19,885	(33,780)
Net cash provided by operating activities									105,630	90,620	106,483
Cash flows from investing activities:
Capital expenditures									(83,920)	(48,439)	(31,708)
Other investing activities									864	816	35
Net cash used in investing activities									(353,229)	(175,821)	(31,673)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs									0	19,318	0
Proceeds from borrowings									510,906	118,741	616,706
Repayments of borrowings									(241,336)	(118,751)	(603,770)
Payment of deferred loan costs									(13,450)	(379)	(10,064)
Exercise of stock options									8,171	0	0
Payments for debt extinguishment and commitment costs									(8,087)	(3,390)	(4,432)
Other financing activities, net									582	(860)	(993)
Net cash provided by (used in) financing activities									300,208	41,943	(4,751)
Net increase (decrease) in cash, cash equivalents, and restricted cash									52,609	(43,258)	70,059
Cash, cash equivalents, and restricted cash at beginning of period				75,819				119,077	75,819	119,077	49,018
Cash, cash equivalents, and restricted cash at end of period	128,428				75,819				128,428	75,819	119,077
Net cash received (paid) for:
Interest									(58,250)	(28,186)	(23,873)
Taxes									(136)	(49)	(1,478)
Non-cash investing and financing activities:
Accrued capital expenditures									6,386	6,199	2,926
ROU assets obtained in exchange for new finance lease liabilities									963
ROU assets obtained in exchange for new finance lease liabilities										1,678	165
ROU assets obtained in exchange for new operating lease liabilities									79,382
Common stock issued for business combination									36,980	0	0
Non-cash contribution to subsidiary for business combination									(36,980)
Common stock issued to repurchase convertible notes									74,290	0	0
Parent Company
Cash flows from operating activities:
Net income (loss)									40,809	39,427	72,621
Adjustments to reconcile net income to cash used in operating activities:
Depreciation, depletion, and amortization									2,969	4,092	2,871
Non-cash interest expense									4,600	4,925	5,617
Change in value of common stock warrants									3,199	(1,801)	1,674
Stock-based compensation									6,437	6,196	7,204
Equity in losses (income) of subsidiaries									(81,097)	(81,942)	(111,162)
Debt extinguishment and commitment costs									6,091	0	1,804
Net changes in operating assets and liabilities:
Prepaid and other assets									1,592	(2,604)	(2,568)
Accounts payable, other accrued liabilities, and operating lease assets and liabilities									(8,441)	5,601	3,088
Net cash provided by operating activities									(23,841)	(26,106)	(18,851)
Cash flows from investing activities:
Investments in subsidiaries									0	0	(2,072)
Distributions from subsidiaries									16,673	0	70,645
Capital expenditures									(1,829)	(3,682)	(5,366)
Due to (from) subsidiaries									(6,519)	(25,102)	80,762
Other investing activities									31	0	0
Net cash used in investing activities									8,356	(28,784)	143,969
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs									0	19,318	0
Proceeds from borrowings									63,406	10,770	0
Repayments of borrowings									(76,323)	(11,253)	(68,873)
Payment of deferred loan costs									(252)	0	0
Exercise of stock options									8,171	0	0
Payments for debt extinguishment and commitment costs									(1,899)	0	0
Other financing activities, net									(10)	(860)	(993)
Net cash provided by (used in) financing activities									(6,907)	17,975	(69,866)
Net increase (decrease) in cash, cash equivalents, and restricted cash									(22,392)	(36,915)	55,252
Cash, cash equivalents, and restricted cash at beginning of period				$ 29,444				$ 66,359	29,444	66,359	11,107
Cash, cash equivalents, and restricted cash at end of period	$ 7,052				$ 29,444				7,052	29,444	66,359
Net cash received (paid) for:
Interest									(5,357)	(5,750)	(7,856)
Taxes									(220)	(49)	(1,478)
Non-cash investing and financing activities:
Accrued capital expenditures									497	714	370
ROU assets obtained in exchange for new finance lease liabilities									198
ROU assets obtained in exchange for new finance lease liabilities										539	165
ROU assets obtained in exchange for new operating lease liabilities									134
Common stock issued for business combination									36,980	0	0
Common stock issued to repurchase convertible notes									$ 74,290	$ 0	$ 0