Par Pacific (PARR) 10-K 12 Mar 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2017	Mar. 07, 2018	Jun. 30, 2017
Document and Entity Information:
Entity Registrant Name	PAR PACIFIC HOLDINGS, INC.
Entity Central Index Key	821,483
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	FY
Trading Symbol	PARR
Amendment Flag	false
Entity Common Stock, Shares Outstanding		46,327,234
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 449,038,962

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 118,333	$ 47,772
Restricted cash	744	1,246
Trade accounts receivable	121,831	102,384
Inventories	345,357	198,326
Prepaid and other current assets	17,279	53,380
Total current assets	603,544	403,108
Property and equipment
Property, plant, and equipment	529,238	499,867
Proved oil and gas properties, at cost, successful efforts method of accounting	400	1,122
Total property and equipment	529,638	500,989
Less accumulated depreciation and depletion	(79,622)	(49,727)
Property, plant and equipment, net	450,016	451,262
Long-term assets
Investment in Laramie Energy, LLC	127,192	108,823
Intangible assets, net	26,604	29,912
Goodwill	107,187	105,732
Other long-term assets	32,864	46,596
Total assets	1,347,407	1,145,433
Current liabilities
Current maturities of long-term debt	0	20,286
Obligations under inventory financing agreements	363,756	225,135
Accounts payable	52,543	65,190
Advances from customers	9,522	23,774
Accrued taxes	17,687	13,194
Other accrued liabilities	27,444	35,186
Total current liabilities	470,952	382,765
Long-term liabilities
Long-term debt, net of current maturities	384,812	350,110
Common stock warrants	6,808	5,134
Long-term capital lease obligations	1,220	1,780
Other liabilities	35,896	36,735
Total liabilities	899,688	776,524
Commitments and contingencies (Note 14)
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, 2017 and December 31, 2016, 45,776,087 shares and 45,533,913 shares issued at December 31, 2017 and December 31, 2016, respectively	458	455
Additional paid-in capital	593,295	587,057
Accumulated deficit	(148,178)	(220,799)
Accumulated other comprehensive income	2,144	2,196
Total stockholders’ equity	447,719	368,909
Total liabilities and stockholders’ equity	$ 1,347,407	$ 1,145,433

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized	3,000,000	3,000,000
Preferred stock, shares issued	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	45,776,087	45,533,913

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues
Revenues									$ 2,443,066	$ 1,865,045	$ 2,066,337
Operating expenses
Cost of revenues (excluding depreciation)									2,054,627	1,636,339	1,787,368
Operating expense (excluding depreciation)									202,019	166,216	141,621
Depreciation, depletion, and amortization									45,989	31,617	19,918
Impairment expense									0	0	9,639
General and administrative expense (excluding depreciation)									46,078	42,073	44,271
Acquisition and integration expense									395	5,294	2,006
Total operating expenses									2,349,108	1,881,539	2,004,823
Operating income (loss)	$ 21,602	$ 26,716	$ 16,451	$ 29,189	$ 28,325	$ (21,784)	$ (3,313)	$ (19,719)	93,958	(16,494)	61,514
Other income (expense)
Interest expense and financing costs, net									(31,632)	(28,506)	(20,156)
Loss on termination of financing agreements									(8,633)	0	(19,669)
Other income (expense), net									914	(98)	(291)
Change in value of common stock warrants									(1,674)	2,962	(3,664)
Change in value of contingent consideration									0	10,770	(18,450)
Equity earnings (losses) from Laramie Energy, LLC									18,369	(22,381)	(55,983)
Total other income (expense), net									(22,656)	(37,253)	(118,213)
Income (loss) before income taxes									71,302	(53,747)	(56,699)
Income tax benefit									1,319	7,912	16,788
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Income (loss) per share
Basic (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.60	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.58	$ (1.08)	$ (1.06)
Diluted (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.58	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.57	$ (1.08)	$ (1.06)
Weighted-average number of shares outstanding
Basic (in shares)									45,543	42,349	37,678
Diluted (in shares)									45,583	42,349	37,678

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Other comprehensive income (loss):
Reclassification of other post-retirement benefits loss to net income									0	0	1,082
Other post-retirement benefits income (loss)									(52)	2,196	(636)
Total other comprehensive income (loss), net of tax									(52)	2,196	446
Comprehensive income (loss)									$ 72,569	$ (43,639)	$ (39,465)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net Cash Provided by (Used in) Operating Activities [Abstract]
Net loss	$ 72,621,000	$ (45,835,000)	$ (39,911,000)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, depletion, and amortization	45,989,000	31,617,000	19,918,000
Impairment expense	0	0	9,639,000
Loss on termination of financing agreements	8,633,000	0	19,669,000
Gain on termination of other post-retirement benefits	0	0	(5,550,000)
Non-cash interest expense	7,276,000	18,121,000	12,449,000
Change in value of common stock warrants	1,674,000	(2,962,000)	3,664,000
Change in value of contingent consideration	0	(10,770,000)	18,450,000
Deferred taxes	(1,321,000)	(7,935,000)	(16,489,000)
Stock-based compensation	7,204,000	6,625,000	5,165,000
Unrealized (gain) loss on derivative contracts	(989,000)	(15,479,000)	10,896,000
Equity (earnings) losses from Laramie Energy, LLC	(18,369,000)	22,381,000	55,983,000
Net changes in operating assets and liabilities:
Trade accounts receivable	(19,100,000)	(17,162,000)	54,529,000
Collateral posted with broker for derivative transactions	2,499,000	18,212,000	(20,927,000)
Prepaid and other assets	37,645,000	447,000	(35,697,000)
Inventories	(146,533,000)	49,015,000	31,913,000
Deferred turnaround expenditures	0	(32,661,000)	0
Obligations under inventory financing agreements	143,034,000	(5,977,000)	34,845,000
Accounts payable and other accrued liabilities	(33,780,000)	(26,698,000)	(26,188,000)
Contingent consideration	0	(4,830,000)	0
Net cash provided by (used in) operating activities	106,483,000	(23,891,000)	132,358,000
Cash flows from investing activities:
Acquisitions of businesses, net of cash acquired	0	(209,183,000)	(64,331,000)
Capital expenditures	(31,708,000)	(24,833,000)	(22,345,000)
Proceeds from sale of assets	35,000	2,773,000	0
Change in restricted cash	502,000	0	0
Investment in Laramie Energy, LLC	0	(55,000,000)	(27,529,000)
Net cash used in investing activities	(31,171,000)	(286,243,000)	(114,205,000)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs	0	49,044,000	76,056,000
Proceeds from borrowings	616,706,000	354,682,000	208,158,000
Repayments of borrowings	(603,770,000)	(202,165,000)	(227,212,000)
Net borrowings (repayments) on deferred payment arrangement	(2,198,000)	8,027,000	(1,436,000)
Payment of deferred loan costs	(10,064,000)	(6,892,000)	(7,335,000)
Contingent consideration settlements	0	(11,980,000)	0
Proceeds from inventory financing agreements	0	0	271,000,000
Payments for termination of supply and exchange agreements	0	0	(257,811,000)
Payments for early termination of financing agreements	(4,432,000)	0	0
Other financing activities, net	(993,000)	(598,000)	(995,000)
Net cash provided by (used in) financing activities	(4,751,000)	190,118,000	60,425,000
Net increase (decrease) in cash and cash equivalents	70,561,000	(120,016,000)	78,578,000
Cash and cash equivalents at beginning of period	47,772,000	167,788,000	89,210,000
Cash and cash equivalents at end of period	118,333,000	47,772,000	167,788,000
Net cash received (paid) for:
Interest	(23,873,000)	(13,217,000)	(6,891,000)
Taxes		589,000	402,000
Non-cash investing and financing activities:
Accrued capital expenditures	2,926,000	4,907,000	2,102,000
Value of warrants and debt reclassified to equity	0	3,084,000	7,691,000
Capital lease additions	$ 165,000	$ 1,575,000	$ 216,000

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, 2014		37,069
Balance at Dec. 31, 2014	$ 292,159	$ 371	$ 427,287	$ (135,053)	$ (446)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock, net of offering costs of $1.0 million (in shares)		3,500
Issuance of common stock, net of offering costs of $1.0 million	76,056	$ 35	76,021
Exercise of common stock warrants (in shares)		404
Exercise of common stock warrants	7,730	$ 4	7,726
Share-based compensation (in shares)		98
Stock-based compensation	5,165	$ 1	5,164
Purchase of common stock for retirement (in shares)		(61)
Purchase of common stock for retirement	(1,034)	$ (1)	(1,033)
Other comprehensive income (loss)	446				446
Net income (loss)	(39,911)			(39,911)
Balance (in shares) at Dec. 31, 2015		41,010
Balance at Dec. 31, 2015	340,611	$ 410	515,165	(174,964)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock, net of offering costs of $1.0 million (in shares)		4,075
Issuance of common stock, net of offering costs of $1.0 million	49,044	$ 41	49,003
Share-based compensation (in shares)		218
Stock-based compensation	6,625	$ 3	6,622
Equity component of 5.00% Convertible Senior Notes due 2021, net of tax of $8.6 million	13,526		13,526
Conversion of Bridge Notes (in shares)		273
Conversion of Bridge Notes	3,340	$ 2	3,338
Purchase of common stock for retirement (in shares)		(42)
Purchase of common stock for retirement	(598)	$ (1)	(597)
Other comprehensive income (loss)	2,196				2,196
Net income (loss)	(45,835)			(45,835)
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 income (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

CONSOLIDATED STATEMENTS OF CHA8

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Payments of stock issuance costs	$ 1
5% Convertible Senior Notes due 2021 | Convertible Debt
Debt instrument, interest rate	0.50%
Equity component of 5% convertible senior note, net of tax	$ 8.6

Overview

Overview	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Overview	Note 1—Overview Par Pacific Holdings, Inc. and its wholly owned subsidiaries (“Par” or the “Company”) own, manage, and maintain interests in energy and infrastructure businesses. Our strategy is to identify, acquire, and operate energy and infrastructure companies with attractive competitive positions. Currently, we operate in three primary business segments: 1) Refining - Our refinery in Kapolei, Hawaii, produces 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. 2) Retail - Our retail outlets sell gasoline, diesel, and retail merchandise throughout the islands of Oahu, Maui, Hawaii, and Kauai. Our 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 locations. 3) Logistics - 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. In addition, we own and operate a crude oil pipeline gathering system, a refined products pipeline, storage facilities, and loading racks in Wyoming. We also own and operate a jet fuel storage facility and pipeline that serve Ellsworth Air Force Base in South Dakota. We also own a 42.3% equity investment in Laramie Energy, LLC (“ Laramie Energy ”), a joint venture entity operated by Laramie Energy II, LLC (“ Laramie ”) and focused on producing natural gas in Garfield, Mesa, and Rio Blanco Counties, Colorado. Our Corporate and Other reportable segment includes administrative costs, our Texadian operations, and several small non-operated oil and gas interests that were owned by our predecessor.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2—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 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 bankruptcy matters. 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, 2017 and 2016 , we did not have a significant allowance for doubtful accounts. Inventories Commodity inventories are stated at the lower of cost or net realizable value using the first-in, first-out accounting method (“FIFO”). We value merchandise along with spare parts, materials, and supplies at average cost. Beginning in June 2015, our refining segment acquires all of its crude oil utilized at the Hawaii refinery from J. Aron & Company (“J.Aron”) under Supply and Offtake Agreements as described in Note 10—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 are obligated to repurchase the inventory. Prior to the Supply and Offtake Agreements with J. Aron, our refining and distribution segment acquired substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under Supply and Exchange Agreements as described in Note 10—Inventory Financing Agreements . We enter into refined product and crude oil exchange agreements with other oil companies. Exchanges receivable or payable are stated at cost and are presented within Trade accounts receivable and Accounts payable on our consolidated balance sheets. 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 has been an other than temporary decline in the value of the investment. Please read Note 3—Investment in Laramie Energy, LLC . 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 8 to 47 Logistics 3 to 30 Retail 14 to 18 Corporate 3 to 7 Software 3 We record property under capital leases at the lower of the present value of minimum lease payments using our incremental borrowing rate or the fair value of the leased property at the date of lease inception. We depreciate leasehold improvements and property acquired under capital leases over the shorter of the lease term or the economic life of the asset. We review property, plant, and equipment and other long-lived assets 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 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, as well as plugging and abandonment of wells within our natural gas and crude oil 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 facility, 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 2016 , we recognized deferred turnaround costs of approximately $32.7 million . No deferred turnaround costs were recorded during 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 forwards 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 obligation to repurchase crude oil and refined products from J.Aron at the termination of the Supply and Offtake Agreements 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 12—Derivatives and Note 13—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 (“NOLs”) 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 recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2014 , 2015 , and 2016 . However, since we have net operating loss 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 net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions 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. The grant date fair value of restricted stock awards are equal to the market price of our common stock on the date of grant. The fair value of stock options are estimated using the Black-Scholes option-pricing model as of the date of grant. Revenue Recognition We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectibility is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met. Certain transactions are recorded on a net basis and included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. 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. Refining and Retail We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title and risk of loss is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We include transportation fees charged to customers in Revenues in our consolidated statements of operations, while the related transportation costs are included in Cost of revenues (excluding depreciation) . Federal excise and state motor fuel taxes, which are collected from customers and remitted to governmental agencies within our refining and retail segments are excluded from both Revenues and Cost of revenues (excluding depreciation) in our consolidated statements of operations. 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 Renewable Identification Numbers (“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 expense excluded from each line item in our consolidated statements of operations (in thousands): Year Ended December 31, 2017 2016 2015 Cost of revenues $ 6,029 $ 4,604 $ 3,017 Operating expense 22,861 16,340 11,428 General and administrative expense 2,929 2,108 855 Benefit Plans We recognize an asset for the overfunded status or a liability for the underfunded status of our defined benefit pension plan. The funded status is recorded within Other long-term liabilities. Certain changes in the plan's 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 17—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 May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”). The FASB’s objective was to provide a more robust framework to improve comparability of revenue recognition practices across entities by removing most industry and transaction specific guidance, align GAAP with International Financial Reporting Standards, and provide more useful information to financial statement users. This authoritative guidance changes the way entities recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date (“ASU 2015-14”), which defers the effective date of ASU 2014-09 by one year. ASU 2014-09 is now effective for interim and annual periods beginning after December 15, 2017. Further amendments and technical corrections were made to ASU 2014-09 in 2016 and 2017. During 2016, we formally established a working group to assess the amended revenue recognition guidance in Topic 606, including its impact on our business processes, accounting systems, controls, and financial statement disclosures. As part of our evaluation, the working group reviewed existing revenue streams and identified the types of arrangements where differences may arise in revenue recognition upon adoption of the new standard. Our largest revenue stream consists of revenues generated from the sale of refined products, generally at market prices. These revenues are recognized upon delivery of goods to a customer. Our evaluation of this ASU is substantially complete and we currently do not expect the new standard to have a material impact on the amount or timing of revenues recognized for the sale of refined products. In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”). ASU 2016-02 requires lessees to recognize all leases, including operating leases, on the balance sheet as a lease asset or lease liability, unless the lease is a short-term lease. ASU 2016-02 also requires additional disclosures regarding leasing arrangements. In January 2018, the FASB issued ASU No. 2018-01 (“ASU 2018-01”), which clarifies the related transition and accounting for land easements. ASU 2016-02 and ASU No. 2018-01 are effective for interim periods and fiscal years beginning after December 15, 2018, and early application is permitted. We are in the process of determining the method of adoption and the impact this guidance will have on our financial condition, results of operations, and cash flow. In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (“ASU 2016-15”). Additionally, in November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (“ASU 2016-18”). The primary purpose of ASU 2016-15 is to reduce the diversity in practice relating to eight specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies); distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle. ASU 2016-18 requires that an entity include restricted cash and restricted cash equivalents within its statement of cash flows and in the reconciliation to the statement of operations. The guidance in these ASUs is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. The new guidance must be applied using a retrospective transition method. We do not expect the adoption of ASU 2016-15 and ASU 2016-18 to have a material impact on our financial condition, results of operations, or cash flows. In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business (“ASU 2017-01”). This ASU updates the definition of a business combination and provides a framework for determining whether a transaction involves an asset or a business. The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2017, 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 assessments and accounting for future acquisition or disposal transactions. 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 March 2017, the FASB issued ASU 2017-07, Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (“ASU 2017-07”). This ASU requires entities to (1) disaggregate the current-service-cost component from the other components of net benefit cost (the “other components”) and present it with other current compensation costs for related employees in the income statement and (2) present the other components elsewhere in the income statement and outside of income from operations if that subtotal is presented. In addition, the ASU requires entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. ASU 2017-07 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted as of the beginning of any annual period for which an entity’s financial statements (interim or annual) have not been issued or made available for issuance. ASU 2017-07 should be applied retrospectively for the presentation of cost components in the income statement and prospectively for the capitalization of the service cost component in assets. We do not expect the adoption of ASU 2017-07 to have a material impact on our financial condition, results of operations, or cash flows. In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU is to reduce the diversity in practice and cost and complexity in applying the guidance in Topic 718 related to the change to terms or conditions of a share-based payment award. The guidance in ASU 2017-09 is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied prospectively to an award modified on or after the adoption date. We do not expect the adoption of ASU 2017-09 to have a material impact on our financial condition, results of operations, or cash flows. In February 2018, the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income ("ASU 2018-02"). This ASU permits entities to elect 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 ASC 740. The guidance in ASU 2018-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. Management is still evaluating the effects of the available adoption methods and has not yet determined which method will be elected. Accounting Principles Adopted On January 1, 2017, we adopted ASU No. 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements as well as classification in the statement of cash flows. Effective January 1, 2017, our accounting policy is to recognize forfeitures as they occur. The adoption of this ASU did not have a material impact on our financial condition, results of operations, or cash flows. On January 1, 2017, we adopted ASU No. 2016-07, Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting (“ASU 2016-07”). ASU 2016-07 simplifies the equity method of accounting by eliminating the requirement to retrospectively apply the equity method to an investment that subsequently qualifies for such accounting as a result of an increase in the level of ownership interest or degree of influence. The adoption of this ASU did not have any impact on our financial condition, results of operations, or cash flows.

Investment in Laramie Energy

Investment in Laramie Energy	12 Months Ended
	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investment in Laramie Energy	Note 3—Investment in Laramie Energy, LLC We have a 42.3% 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 $230 million . As of December 31, 2017 and 2016 , the balance outstanding on the revolving credit facility was approximately $171.5 million and $117.5 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. On March 9, 2015 , we entered into an amendment to Laramie Energy's Limited Liability Company Agreement and made a cash capital contribution of $13.8 million to Laramie Energy . On May 29, 2015 , we made an additional cash capital contribution of $13.8 million . As a result of our contributions to Laramie Energy , our ownership interest increased from 33.34% to 34.0% . On July 31, 2015 , an unaffiliated third party invested an aggregate of $19 million in Laramie Energy in the form of cash and property. As a result of this transaction, our ownership interest decreased from 34.0% to 32.4% . At December 31, 2015, we conducted an impairment test related to our equity investment in Laramie Energy . As a result of the decline in commodity prices during 2015, we concluded that our equity investment in Laramie Energy was impaired and recognized an other-than-temporary impairment charge of $41.1 million on our consolidated statement of operations for the year ended December 31, 2015. On March 1, 2016 , Laramie Energy acquired and assumed operatorship of certain properties in the Piceance Basin for $152.1 million , subject to customary purchase price adjustments (“Laramie Purchase”). In connection with the Laramie Purchase, we acquired additional membership interests of Laramie Energy for an aggregate cash purchase price of $55.0 million . As a result of this transaction, our ownership interest in Laramie Energy increased from 32.4% to 42.3% . The change in our equity investment in Laramie Energy is as follows (in thousands): Year Ended December 31, 2017 2016 2015 Beginning balance $ 108,823 $ 76,203 $ 104,657 Equity earnings (losses) from Laramie Energy 13,043 (28,198 ) (15,713 ) Accretion of basis difference 5,326 5,818 811 Impairment — — (41,081 ) Investments — 55,000 27,529 Ending balance $ 127,192 $ 108,823 $ 76,203 Summarized financial information for Laramie Energy is as follows (in thousands): December 31, 2017 2016 Current assets $ 18,757 $ 12,199 Non-current assets 720,444 655,022 Current liabilities 42,149 58,067 Non-current liabilities 237,497 186,631 Year Ended December 31, 2017 2016 2015 Natural gas and oil revenues $ 157,879 $ 104,826 $ 42,870 Income (loss) from operations 6,019 (27,325 ) (40,984 ) Net income (loss) 30,837 (61,849 ) (49,159 ) 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. Laramie Energy's net loss for the year ended December 31, 2016 includes $42.7 million and $34.5 million of DD&A expense and unrealized losses on derivative instruments, respectively. Laramie Energy's net loss for the year ended December 31, 2015 includes $24.6 million and $16.6 million of DD&A expense and unrealized gains on derivative instruments, respectively. Additionally, 2015 includes $12.3 million of impairments of unproved properties. At December 31, 2017 and 2016 , our equity in the underlying net assets of Laramie Energy exceeded the carrying value of our investment by approximately $67.2 million and $69.9 million , respectively. This difference arose primarily due to lack of control and marketability discounts and an other-than-temporary impairment of our equity investment in Laramie Energy. We attributed this difference to natural gas and crude oil properties and are amortizing the difference over 15 years based on the estimated timing of production of proved reserves.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Acquisitions	Note 4—Acquisitions Wyoming Refining Company Acquisition On June 14, 2016 , Par Wyoming, LLC, a wholly owned subsidiary of Par, entered into a unit purchase agreement (the “Purchase Agreement”) with Black Elk Refining, LLC to purchase all of the issued and outstanding units representing the membership interests in Hermes Consolidated, LLC (d/b/a Wyoming Refining Company ) and, indirectly, Wyoming Refining Company ’s wholly owned subsidiary, Wyoming Pipeline Company, LLC (collectively, “ Wyoming Refining ”) (the “ WRC Acquisition ”). Wyoming Refining owns and operates a refinery and related logistics assets in Newcastle, Wyoming . On July 14, 2016 , we completed the WRC Acquisition for cash consideration of $209.4 million , including a deposit of $5.0 million paid in June 2016, and assumed debt consisting of term loans of $58.0 million and revolving loans of $10.1 million . The consideration was paid with funds received from the issuance of our 2.50% convertible subordinated bridge notes (the “Bridge Notes”), cash on hand, which included the net proceeds from our June 2016 issuance and sale of an aggregate of $115 million principal amount of 5.00% convertible senior notes due 2021 (the “ 5.00% Convertible Senior Notes ”), and the issuance of a $65 million secured term loan by Par Wyoming Holdings, LLC (the “ Par Wyoming Holdings Credit Agreement ”). Please read Note 11—Debt for further information on the 5.00% Convertible Senior Notes , the Bridge Notes, and the Par Wyoming Holdings Credit Agreement . We accounted for the WRC Acquisition 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 the acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Wyoming Refining and 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 WRC Acquisition is expected to be deductible for income tax reporting purposes. During the three months ended June 30, 2017, the purchase price allocation was adjusted to record an increase of $2.0 million to our Wyoming refinery’s environmental liability as a result of additional information obtained by management regarding estimated remediation costs at certain locations. The purchase price allocation was also adjusted to record an increase to inventory of $0.5 million related to line fill inventory at our refined product pipelines. Goodwill increased $1.5 million as a result of these adjusting entries recorded during the three months ended June 30, 2017. As of June 30, 2017, we finalized the WRC Acquisition purchase price allocation. A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 183 Accounts receivable 16,880 Inventories 28,402 Prepaid and other assets 1,304 Property, plant, and equipment 254,367 Goodwill (1) 66,449 Accounts payable and other current liabilities (57,861 ) Wyoming Refining Senior Secured Revolver (10,100 ) Wyoming Refining Senior Secured Term Loan (58,036 ) Other non-current liabilities (32,222 ) Total $ 209,366 ______________________________________________ (1) We allocated $39.8 million and $26.6 million of goodwill to our refining and logistics segments, respectively. We incurred $0.7 million of acquisition costs related to the WRC Acquisition for the year ended December 31, 2016 . These costs are included in acquisition and integration costs on our consolidated statement of operations. The results of operations of Wyoming Refining were included in our results beginning July 14, 2016 . For the year ended December 31, 2016 , our results of operations included revenues of $174.6 million and net income of $0.7 million related to Wyoming Refining. The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the WRC Acquisition had been completed on January 1, 2015 (in thousands): Year Ended December 31, 2016 2015 Revenues $ 2,026,237 $ 2,369,513 Net income (loss) (51,239 ) (51,582 ) Income (loss) per share Basic $ (1.21 ) $ (1.24 ) Diluted $ (1.21 ) $ (1.24 ) Mid Pac Acquisition On April 1, 2015 , we completed the acquisition of Par Hawaii Inc. (“PHI,” formerly Koko’oha Investments, Inc.), a Hawaii corporation that owns 100% of the outstanding membership interests of Mid Pac Petroleum, LLC (“Mid Pac”). Net cash consideration was $74.4 million , including the working capital settlement of $1 million paid in September 2015. The cash consideration included advance deposits of $15 million , of which $10 million was paid in 2014, prior to closing. In connection with the acquisition, Mid Pac 's pre-existing debt was fully repaid on the closing date for $45.3 million . The acquisition and debt repayment were funded with cash on hand and $55 million of borrowings under a credit agreement with the Bank of Hawaii. We accounted for the acquisition of Mid Pac 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 Mid Pac 's and utilization of our net operating loss carryforwards, as well as other intangible assets that do not qualify for separate recognition. In addition, we recorded certain other identifiable intangible assets including trade names and customer relationships. These intangible assets will be amortized over their estimated useful lives on a straight-line basis, which approximates their consumptive life. Please read Note 9—Goodwill and Intangible Assets for further discussion. None of the goodwill or intangible assets are 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 $ 10,007 Accounts receivable 9,905 Inventories 5,375 Prepaid and other current assets 1,444 Property, plant and equipment 40,997 Land 34,800 Goodwill (1) 26,942 Intangible assets 33,647 Other non-current assets 1,228 Accounts payable and other current liabilities (10,742 ) Deferred tax liability (16,759 ) Other non-current liabilities (7,235 ) Total $ 129,609 ________________________________________________________ (1) We allocated $13.5 million , $2.7 million , and $10.8 million of goodwill to our refining, retail, and logistics reporting units, respectively. We incurred $0.8 million of acquisition costs related to the Mid Pac acquisition for the year ended December 31, 2015. These costs are included in acquisition and integration costs on our consolidated statement of operations. The results of operations of Mid Pac were included in our refining , retail , and logistics segments results beginning April 1, 2015 . For the year ended December 31, 2015, our results of operations included Mid Pac 's revenues of $147.6 million and net income of $10.6 million , respectively. The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the Mid Pac acquisition had been completed on January 1, 2014 (in thousands): Year Ended December 31, 2015 Revenues $ 2,093,587 Net loss (54,941 )

Inventories

Inventories	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventories	Note 5—Inventories Inventories at December 31, 2017 and 2016 consist of the following (in thousands): Titled Inventory Supply and Offtake Agreements (1) Total December 31, 2017 Crude oil and feedstocks $ 93,970 $ 56,014 $ 149,984 Refined products and blendstock 63,505 108,917 172,422 Warehouse stock and other 22,951 — 22,951 Total $ 180,426 $ 164,931 $ 345,357 December 31, 2016 Crude oil and feedstocks $ 11,620 $ 49,682 $ 61,302 Refined products and blendstock 38,916 77,677 116,593 Warehouse stock and other 20,431 — 20,431 Total $ 70,967 $ 127,359 $ 198,326 _________________________________________________________ (1) Please read Note 10—Inventory Financing Agreements for further information. There was no reserve for the lower of cost or net realizable value of inventory as of December 31, 2017 . As of December 31, 2016 , the reserve for the lower of cost or net realizable value of inventory was $ 0.2 million .

Prepaid and Other Current Asset

Prepaid and Other Current Assets	12 Months Ended
	Dec. 31, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid and Other Current Assets	Note 6—Prepaid and Other Current Assets Prepaid and other current assets at December 31, 2017 and 2016 consist of the following (in thousands): December 31, 2017 2016 Advances to suppliers for crude oil purchases $ — $ 38,300 Collateral posted with broker for derivative instruments 215 2,714 Prepaid insurance 7,547 7,504 Derivative assets 4,296 161 Other 5,221 4,701 Total $ 17,279 $ 53,380

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Note 7—Property, Plant and Equipment Major classes of property, plant and equipment consist of the following (in thousands): December 31, 2017 2016 Land $ 79,330 $ 76,437 Buildings and equipment 433,977 412,999 Other 15,931 10,431 Total property, plant and equipment 529,238 499,867 Proved oil and gas properties 400 1,122 Less accumulated depreciation and depletion (79,622 ) (49,727 ) Property, plant and equipment, net $ 450,016 $ 451,262 Depreciation expense was approximately $31.8 million , $23.1 million , and $15.3 million for the years ended December 31, 2017 , 2016 , and 2015 , respectively.

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 8—Asset Retirement Obligations The table below summarizes the changes in our recorded asset retirement obligations (in thousands): Year Ended December 31, 2017 2016 2015 Beginning balance $ 9,042 $ 8,909 $ 2,580 Obligations acquired — — 5,725 Accretion expense 369 362 604 Liabilities settled during period (308 ) (229 ) — Ending balance $ 9,103 $ 9,042 $ 8,909

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	Note 9—Goodwill and Intangible Assets During the years ended December 31, 2017 and 2016 , the change in the carrying amount of goodwill was as follows (in thousands): Balance at January 1, 2016 $ 41,327 Acquisition of Wyoming Refining (1) 64,994 Mid Pac acquisition purchase price allocation adjustment (2) (589 ) Balance at December 31, 2016 105,732 Wyoming Refining acquisition purchase price allocation adjustment (1) 1,455 Balance at December 31, 2017 $ 107,187 ________________________________________________________ (1) Please read Note 4—Acquisitions for further discussion. (2) During 2016, the purchase price allocation was adjusted to record an increase to tax receivables and a decrease to goodwill of $0.6 million . The tax receivable was recorded in connection with a tax refund received by Mid Pac in the first quarter of 2016. Intangible assets consist of the following (in thousands): December 31, 2017 2016 Intangible assets: Railcar leases $ 3,249 $ 3,249 Trade names and trademarks 6,267 6,267 Customer relationships 32,064 32,064 Total intangible assets 41,580 41,580 Accumulated amortization: Railcar leases (3,249 ) (2,599 ) Trade name and trademarks (4,951 ) (4,864 ) Customer relationships (6,776 ) (4,205 ) Total accumulated amortization (14,976 ) (11,668 ) Net: Railcar leases — 650 Trade name and trademarks 1,316 1,403 Customer relationships 25,288 27,859 Total intangible assets, net $ 26,604 $ 29,912 At September 30, 2015, we conducted an impairment test related to goodwill and intangible assets in our Texadian reporting unit. As of result of canceling the charter on the barges used to transport crude from Canada to the U.S. Gulf Coast in the Texadian business and negative cash flows, we concluded that goodwill and the supplier relationships intangible asset were fully impaired at September 30, 2015. We recognized impairment charges for goodwill and intangible assets of $7.0 million and $2.6 million in our consolidated statement of operations for the year ended December 31, 2015, respectively. Amortization expense was approximately $3.3 million , $4.5 million , and $4.4 million for the years ended December 31, 2017 , 2016 , and 2015 , respectively. Our intangible assets related to customer relationships and trade names have an average useful life of 13.6 years . Expected amortization expense for each of the next five years and thereafter is as follows (in thousands): Year Ended Amount 2018 $ 2,658 2019 2,658 2020 2,658 2021 2,658 2022 2,658 Thereafter 13,314 $ 26,604

Inventory Financing Agreements

Inventory Financing Agreements	12 Months Ended
	Dec. 31, 2017
Other Commitments [Abstract]
Inventory Financing Agreements	Note 10—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 refinery (the “Supply and Offtake Agreements”). On May 8, 2017 , we and J. Aron amended the Supply and Offtake Agreements and extended the term through May 31, 2021 with a one -year extension option upon mutual agreement of the parties. As part of this amendment, 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, 2017 , we had no obligations due to J. Aron under this letter of credit 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 as noted below. During the term of the Supply and Offtake Agreements, we and J. Aron 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 94 thousand barrels per day of crude oil to our Hawaii refinery. Additionally, we agreed to sell and J. Aron agreed to buy, at market prices, refined products produced at our Hawaii refinery. 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 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. In connection with the December 21, 2017 amendment and restatement of the Supply and Offtake Agreements, certain collateral (including the mortgage liens on the real property and improvements comprising the Hawaii refinery and on all equipment used to operate the Hawaii refinery, the equity interests in Par Hawaii Refining, LLC ("PHR") held by Par Petroleum, LLC, and certain other items of personal property) was released, and Par Petroleum, LLC issued an unsecured guaranty in favor of J. Aron pursuant to which Par Petroleum, LLC guarantees the payment and performance of certain liabilities of PHR under the Supply and Offtake Agreements. 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, 2017 , 2016 , and 2015 , we incurred approximately $13.7 million , $7.8 million , and $6.9 million in handling fees related to the Supply and Offtake Agreements, respectively, which are included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. For the years ended December 31, 2017 , 2016 , and 2015 , Interest expense and financing costs, net on our consolidated statements of operations includes approximately $2.3 million , $3.2 million , and $1.5 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 $125 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 will bear interest at a rate equal to three-month LIBOR plus 3.75% 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, 2017 , the capacity of the Deferred Payment Arrangement was $83.1 million and we had $41.1 million outstanding. Under the Supply and Offtake Agreements, we pay or receive certain fees from J. Aron based on changes in market prices over time. In September 2015, we entered into an agreement to fix this market fee for the period from October 1, 2015 through November 30, 2016 whereby J. Aron agreed to pay us a total of $18 million to be settled in fourteen equal monthly payments. In February 2016, we fixed the market fee for the remainder of the term of the Supply and Offtake Agreements for an additional $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 aggregate $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, 2017 , the receivable was $7.1 million . The agreements also provide us with the ability to economically hedge price risk on our inventories and crude oil purchases. Please read Note 12—Derivatives for further information. Supply and Exchange Agreements On September 25, 2013, we entered into several agreements with Barclays for the purpose of managing our working capital and the crude oil and refined product inventory at the Hawaii refinery (the “Supply and Exchange Agreements”). Effective July 31, 2014, we supplemented the Supply and Exchange Agreements by entering into the Refined Product Supply Master Confirmation, pursuant to which Barclays provided refined product supply and intermediation arrangements to us. For the year ended December 31, 2015, we incurred approximately $6.9 million in handling fees related to the Supply and Exchange Agreements, which are included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. For the year ended December 31, 2015, Interest expense and financing costs, net on our consolidated statements of operations includes approximately $2.3 million of expenses related to the Supply and Exchange Agreements. Upon execution of the Supply and Offtake Agreements, we terminated the Supply and Exchange Agreements with Barclays, subject to certain obligations to reimburse Barclays for third-party claims. We recognized a loss of $17.4 million on the termination of the agreement which consisted of a loss of $13.3 million for the cash settlement value of the liability which had previously been measured assuming settlement with inventory on hand and a loss of $5.6 million for the acceleration of deferred financing costs. These losses were partially offset by a $1.5 million exit fee received from Barclays. The net loss of $17.4 million related to the termination of the Supply and Exchange Agreements is included in Loss on termination of financing agreements on our consolidated statements of operations for the year ended December 31, 2015. The cash paid to settle the obligation is included in Payments for termination of supply and exchange agreements in our consolidated statements of cash flows for the year ended December 31, 2015.

Debt

Debt	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Debt	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. 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 Loss on termination of financing agreements 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 WRC Acquisition . The proceeds of the Par Wyoming Holdings Term Loan were used to pay a portion of the consideration for the WRC 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 Loss on termination of financing agreements 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 WRC 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 WRC 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 WRC 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 Loss on termination of financing agreements on our consolidated statement of operations for the year ended December 31, 2017. 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 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 are 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 12—Derivatives for further information on embedded derivatives. 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, 2017 , the if-converted value was $8.2 million in excess of the outstanding principal amount of the 5.00% Convertible Senior Notes . As of December 31, 2017 , the outstanding principal amount of the 5.00% Convertible Senior Notes was $115.0 million , the unamortized discount and deferred financing cost was $19.5 million and the carrying amount of the liability component was $95.5 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 . 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 Loss on termination of financing agreements on our consolidated statement of operations for the year ended December 31, 2017. Bridge Notes On July 14, 2016 , we issued approximately $52.6 million in aggregate principal amount of bridge notes in a private offering pursuant to the terms of a note purchase agreement (the “Bridge Notes”) entered into among the purchasers of the Bridge Notes and us. On September 22, 2016 , we completed a registered pro-rata subscription rights offering of approximately 4 million shares of our common stock (the “Rights Offering”). The Rights Offering resulted in gross proceeds, before expenses, of approximately $49.9 million . We used the net proceeds from the Rights Offering to repay all accrued and unpaid interest and a portion of the outstanding principal amount on the Bridge Notes. The remaining $3.1 million aggregate principal amount and $0.3 million unpaid interest of the Bridge Notes was mandatorily converted into 272,733 shares of our common stock based on a conversion price of $12.25 per share. In connection with our repayment of the Bridge Notes, we expensed $3.0 million of financing costs, which are included within Interest expense and financing costs, net on our consolidated statements of operations for the year ended December 31, 2016 . 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 and Highbridge International, LLC, who are also our significant stockholders. Proceeds from the Term Loan were used to fund a deposit per the Mid Pac merger agreement, 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 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”), 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 20—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 a loss on termination 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 instruments are customary cross default provisions that require the repayment of amounts outstanding on demand should an event of default occur and not be cured within the permitted grace period, if any. As of December 31, 2017 , we are 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 SEC on September 2, 2016 and declared effective on September 16, 2016 (“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 are subject to restrictions on their ability to distribute funds to us, whether by cash dividends, loans, or advances." id="sjs-B4">Note 11—Debt The following table summarizes our outstanding debt as of December 31, 2017 and 2016 (in thousands): December 31, 2017 2016 Hawaii Retail Credit Facilities $ — $ 95,319 5.00% Convertible Senior Notes due 2021 115,000 115,000 7.75% Senior Secured Notes due 2025 300,000 — Term Loan — 60,361 Par Wyoming Holdings Term Loan — 67,325 Wyoming Refining Senior Secured Term Loan — 55,715 Wyoming Refining Senior Secured Revolver — 6,700 Principal amount of long-term debt 415,000 400,420 Less: unamortized discount and deferred financing costs (30,188 ) (30,024 ) Total debt, net of unamortized discount and deferred financing costs 384,812 370,396 Less: current maturities — (20,286 ) Long-term debt, net of current maturities $ 384,812 $ 350,110 Annual maturities of our long-term debt for the next five years and thereafter are as follows (in thousands): Year Ended Amount Due 2018 $ — 2019 — 2020 — 2021 115,000 2022 — Thereafter 300,000 Total $ 415,000 Our debt is subject to various affirmative and negative covenants. As of December 31, 2017 , we were in compliance with all debt covenants. Under the ABL Credit Facility and the indenture governing the 7.75% Senior Secured Notes , 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 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 and collateral under the Supply and Offtake Agreements. 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 , PHI, Mid Pac, HIE Retail, LLC, and WRC (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 in the maximum principal amount at any time outstanding of $75 million , subject to a borrowing base, which provides for revolving loans and for the issuance of letters of credit (the “ ABL Revolver ”). The ABL Revolver was undrawn and had a borrowing base of approximately $48.7 million at December 31, 2017 . 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. 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 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. 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 Loss on termination of financing agreements 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 WRC Acquisition . The proceeds of the Par Wyoming Holdings Term Loan were used to pay a portion of the consideration for the WRC 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 Loss on termination of financing agreements 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 WRC 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 WRC 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 WRC 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 Loss on termination of financing agreements on our consolidated statement of operations for the year ended December 31, 2017. 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 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 are 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 12—Derivatives for further information on embedded derivatives. 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, 2017 , the if-converted value was $8.2 million in excess of the outstanding principal amount of the 5.00% Convertible Senior Notes . As of December 31, 2017 , the outstanding principal amount of the 5.00% Convertible Senior Notes was $115.0 million , the unamortized discount and deferred financing cost was $19.5 million and the carrying amount of the liability component was $95.5 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 . 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 Loss on termination of financing agreements on our consolidated statement of operations for the year ended December 31, 2017. Bridge Notes On July 14, 2016 , we issued approximately $52.6 million in aggregate principal amount of bridge notes in a private offering pursuant to the terms of a note purchase agreement (the “Bridge Notes”) entered into among the purchasers of the Bridge Notes and us. On September 22, 2016 , we completed a registered pro-rata subscription rights offering of approximately 4 million shares of our common stock (the “Rights Offering”). The Rights Offering resulted in gross proceeds, before expenses, of approximately $49.9 million . We used the net proceeds from the Rights Offering to repay all accrued and unpaid interest and a portion of the outstanding principal amount on the Bridge Notes. The remaining $3.1 million aggregate principal amount and $0.3 million unpaid interest of the Bridge Notes was mandatorily converted into 272,733 shares of our common stock based on a conversion price of $12.25 per share. In connection with our repayment of the Bridge Notes, we expensed $3.0 million of financing costs, which are included within Interest expense and financing costs, net on our consolidated statements of operations for the year ended December 31, 2016 . 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 and Highbridge International, LLC, who are also our significant stockholders. Proceeds from the Term Loan were used to fund a deposit per the Mid Pac merger agreement, 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 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”), 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 20—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 a loss on termination 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 instruments are customary cross default provisions that require the repayment of amounts outstanding on demand should an event of default occur and not be cured within the permitted grace period, if any. As of December 31, 2017 , we are 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 SEC on September 2, 2016 and declared effective on September 16, 2016 (“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 are 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, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Note 12—Derivatives Commodity Derivatives We utilize crude oil commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, future 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. We have determined that this obligation contains an embedded derivative, similar to forward purchase contracts of crude oil and refined products. As such, we have accounted for this embedded derivative at fair value with changes in the fair value recorded in Cost of revenues (excluding depreciation) on our consolidated statements of operations. We are also required under the Supply and Offtake Agreements to hedge the time spread between the period of crude oil cargo pricing and the month of delivery. We utilize OTC swaps to accomplish this. We have entered into forward purchase contracts for crude oil and forward 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 13—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. At December 31, 2017 , our open commodity derivative contracts represented: • futures sales contracts of 200 thousand barrels that economically hedge our crude oil and refined product inventory; • OTC swap purchases of 321 thousand barrels that economically hedge our crude oil and refined products month-end target inventory under our Supply and Offtake Agreements; • net OTC swaps and futures sales contracts of 140 thousand barrels that economically hedge our sales of refined products; and • option collars of 60 thousand barrels per month and OTC swaps of 15 thousand barrels per month through December 2018 that economically hedge our internally consumed fuel. Interest Rate Derivatives We are exposed to interest rate volatility in the Supply and Offtake Agreements. We utilize interest rate swaps to manage our interest rate risk. As of December 31, 2017 , we had locked in an average fixed rate of 1.1% in exchange for a floating interest rate indexed to the three-month LIBOR on an aggregate notional amount of $200.0 million . The interest rate swaps mature in February 2019 and March 2021. 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 11—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, 2017 , 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, 2017 and 2016 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2017 2016 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,814 $ — Commodity derivatives (1) Other long-term assets — 2,748 Commodity derivatives Other accrued liabilities (39 ) (595 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements (19,564 ) (20,000 ) Interest rate derivatives Prepaid and other current assets 1,482 161 Interest rate derivatives Other long-term assets 2,328 3,377 Interest rate derivatives Other accrued liabilities — (94 ) _________________________________________________________ (1) Does not include cash collateral of $0.2 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of December 31, 2017 and 2016 , 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 2017 2016 2015 Commodity derivatives Cost of revenues (excluding depreciation) $ (4,517 ) $ (1,338 ) $ 14,367 J. Aron repurchase obligation derivative Cost of revenues (excluding depreciation) 436 (29,810 ) 12,654 Interest rate derivatives Interest expense and financing costs, net 489 2,729 —

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 13—Fair Value Measurements Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis Purchase Price Allocation of Wyoming Refining The fair values of the assets acquired and liabilities assumed as a result of the Wyoming Refining acquisition were estimated as of July 14, 2016 , the date of the acquisition, using valuation techniques described in notes (1) through (5) described below. Valuation Fair Value Technique (in thousands) Net working capital $ (11,092 ) (1) Property, plant, and equipment 254,367 (2) Goodwill 66,449 (3) Long-term debt (68,136 ) (4) Other non-current liabilities (32,222 ) (5) Total $ 209,366 (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. (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 debt was recorded at carrying value. The carrying value of long-term debt approximated fair value due to its floating interest rate. (5) Other non-current liabilities include environmental liabilities and the underfunded status of the Wyoming Refining defined benefit plan. 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. Environmental liabilities are based on management’s best estimates of probable future costs using current available information. We consider this to be a Level 3 fair value measurement. Purchase Price Allocation of Mid Pac The fair values of the assets acquired and liabilities assumed as a result of the Mid Pac acquisition were estimated as of April 1, 2015 , the date of the acquisition, using valuation techniques described in notes (1) through (7) described below. Valuation Fair Value Technique (in thousands) Net working capital $ 15,989 (1) Property, plant, and equipment 40,997 (2) Land 34,800 (3) Goodwill 26,942 (4) Intangible assets 33,647 (5) Other non-current assets 1,228 (7) Deferred tax liability (16,759 ) (6) Other non-current liabilities (7,235 ) (7) Total $ 129,609 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of the 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. We consider this to be a Level 3 fair value measurement. (3) 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. (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 fair value of customer relationships was estimated using the Excess Earnings Method. Significant inputs used in this model include estimated revenue attributable to the customer relationship and estimated attrition rates. The fair value of the trade names and trademarks was estimated using the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. We consider this to be a Level 3 fair value measurement. (6) The deferred tax liability was determined based on the differences between the tax bases of the assets acquired and liabilities assumed and the values of those assets and liabilities recognized on our consolidated balance sheets as of the date of acquisition. (7) Other non-current assets and liabilities were recorded at their estimated net present value. We consider this to be a Level 3 fair value measurement. Investment in Laramie Energy At December 31, 2015, we conducted an impairment test related to our equity investment in Laramie Energy . As a result of the decline in commodity prices during 2015, we concluded that our equity investment in Laramie Energy was impaired and recognized an other-than-temporary impairment charge of $41.1 million on our consolidated statement of operations for the year ended December 31, 2015. We primarily used a market approach to determine the fair value of our equity investment in Laramie Energy as of December 31, 2015. We used the income approach to corroborate our fair value measurement of Laramie Energy under the market approach. We consider this to be a Level 2 fair value measurement. During 2017 and 2016 , there was no impairment recorded in connection with our investment in Laramie Energy. Assets and Liabilities Measured at Fair Value on a Recurring Basis Common stock warrants As of December 31, 2017 and 2016 , 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, 2017 , the warrants had a weighted-average exercise price of $0.09 and a remaining term of 4.67 years. The estimated fair value of the common stock warrants was $19.21 and $14.49 per share as of December 31, 2017 and 2016 , 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 crude oil commodity derivative contracts to manage our price exposure in our inventory positions, future purchases of crude oil, future sales of refined products, and cost of crude oil consumed in the refining process. We utilize interest rate swaps to manage our interest rate risk. Please read Note 12—Derivatives for further information on derivatives. We are obligated to repurchase the crude oil and refined products from J. Aron at the termination of the Supply and Offtake Agreements. We have determined that this obligation contains an embedded derivative, similar to forward purchase contracts of crude oil and refined products. As such, we have accounted for this embedded derivative 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, 2017 and 2016 , 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 commodity 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 obligation derivative requires that we make estimates of the prices and differentials assuming settlement at the end of the reporting period. Estimates of the J. Aron 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; therefore it is classified as a Level 3 instrument. We do not have other commodity derivatives classified as Level 3 at December 31, 2017 or 2016 . Please read Note 12—Derivatives for further information on derivatives. Contingent consideration The cash consideration for our acquisition of PHR was subject to an earnout provision. As of December 31, 2016, the earn-out measurement period was complete and our estimated liability no longer relies on forecasts and simulations. Prior to December 31, 2016, the liability was remeasured at the end of each reporting period using an estimate based on actual results to date and a Monte Carlo simulation analysis for future periods. Significant inputs used in the valuation model included estimated future gross margin, annual gross margin volatility, and a present value factor. We considered this to be a Level 3 fair value measurement. See Note 14—Commitments and Contingencies for further discussion. Financial Statement Impact Fair value amounts by hierarchy level as of December 31, 2017 and 2016 are presented gross in the tables below (in thousands): December 31, 2017 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 557 $ 21,907 $ — $ 22,464 $ (19,650 ) $ 2,814 Interest rate derivatives — 3,810 — 3,810 — 3,810 Total $ 557 $ 25,717 $ — $ 26,274 $ (19,650 ) $ 6,624 Liabilities Common stock warrants $ — $ — $ (6,808 ) $ (6,808 ) $ — $ (6,808 ) Commodity derivatives (596 ) (19,093 ) — (19,689 ) 19,650 (39 ) J. Aron repurchase obligation derivative — — (19,564 ) (19,564 ) — (19,564 ) Total $ (596 ) $ (19,093 ) $ (26,372 ) $ (46,061 ) $ 19,650 $ (26,411 ) December 31, 2016 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 190 $ 26,095 $ — $ 26,285 $ (23,537 ) $ 2,748 Interest rate derivatives — 3,602 — 3,602 (64 ) 3,538 Total $ 190 $ 29,697 $ — $ 29,887 $ (23,601 ) $ 6,286 Liabilities Common stock warrants $ — $ — $ (5,134 ) $ (5,134 ) $ — $ (5,134 ) Commodity derivatives (54 ) (24,078 ) — (24,132 ) 23,537 (595 ) J.Aron repurchase obligation derivative — — (20,000 ) (20,000 ) — (20,000 ) Interest rate derivatives — (158 ) — (158 ) 64 (94 ) Total $ (54 ) $ (24,236 ) $ (25,134 ) $ (49,424 ) $ 23,601 $ (25,823 ) _________________________________________________________ (1) Does not include cash collateral of $7.2 million and $9.7 million as of December 31, 2017 and 2016 , respectively included 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, 2017 2016 2015 Beginning balance $ (25,134 ) $ (25,867 ) $ (21,254 ) Settlements — 16,810 7,691 Acquired — — (2,844 ) Total unrealized income (loss) included in earnings (1,238 ) (16,077 ) (9,460 ) Ending balance $ (26,372 ) $ (25,134 ) $ (25,867 ) The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2017 and 2016 is as follows (in thousands): Carrying Value Fair Value (1) December 31, 2017 5.00% Convertible Senior Notes due 2021 (3) $ 95,486 $ 149,007 7.75% Senior Secured Notes due 2025 289,326 300,423 Common stock warrants 6,808 6,808 December 31, 2016 Hawaii Retail Credit Agreement (2) $ 93,853 $ 93,853 5.00% Convertible Senior Notes due 2021 (3) 91,029 122,229 Term Loan 57,426 62,367 Par Wyoming Holdings Term Loan (2) 65,908 65,908 Wyoming Refining Senior Secured Term Loan (2) 55,480 55,480 Wyoming Refining Senior Secured Revolver (2) 6,700 6,700 Common stock warrants 5,134 5,134 _________________________________________________________ (1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy with the exception of the fair value measurements of the 5.00% Convertible Senior Notes and the 7.75% Senior Secured Notes , which are considered Level 2 measurements as discussed below. (2) Fair value approximated carrying value due to the debt's floating rate interest which approximates current market value. (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. We estimated the fair value of the Term Loan using a discounted cash flow analysis and an estimate of the current yield of 11.06% as of December 31, 2016 by reference to market interest rates for term debt of comparable companies. 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, 2017 . 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 was determined using a market approach based on quoted prices. Because the 7.75% Senior Secured Notes may not be actively traded, the inputs used to measure the fair value are classified as Level 2 inputs within the fair value hierarchy. The fair value of all non-derivative financial instruments included in current assets, including cash and cash equivalents, restricted cash, and trade accounts receivable, current liabilities, and accounts payable approximate their carrying value due to their short term nature.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 14—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 Earnout 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”), 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. The cash consideration for the acquisition is 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 has disputed our calculation of the 2015 and 2016 earn-out amounts and has asserted that it is 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. If we and Tesoro are unable to agree on the calculation of the 2015 and 2016 earn-out amounts, the dispute will be resolved in accordance with the dispute resolution provisions set forth in the membership interest purchase agreement to determine the amounts owed, if any. The Company disputes that any additional amounts are due and intends to vigorously defend itself in connection with the resolution of Tesoro’s claims. The parties have agreed to attend non-binding mediation on March 22, 2018. Mid Pac Earnout and Indemnity Dispute Pursuant to a Stock Purchase Agreement dated August 3, 2011 and amended October 25, 2011 (the “SPA”), Mid Pac purchased all the issued and outstanding stock of Inter Island Petroleum, Inc. (“Inter Island”) from Brian J. and Wendy Barbata (collectively, the “Barbatas”). The SPA provides for an earn-out payment to be made to the Barbatas in an amount equal to four times the amount by which the average of Inter Island’s earnings before interest, taxes, depreciation, and amortization during the relevant earn-out period exceeds $3.5 million . The earn-out payment is capped at a maximum of $4.5 million . Mid Pac contends that there are no amounts owed to the Barbatas for the earn-out period, while the Barbatas contend they are entitled to $4.5 million . Mid Pac intends to vigorously oppose any such claims. Any claims by the Barbatas may be offset by Mid Pac ’s claims for indemnification under the SPA. By letters dated December 31, 2013 and April 25, 2014, Mid Pac has asserted indemnification claims against the Barbatas exceeding $1 million with respect to environmental losses arising from certain terminals operated by Inter Island and its subsidiaries. The Barbatas have disputed such claims. Arbitration for the earn-out and indemnification claims is scheduled to commence on November 27, 2018. United Steelworkers Union Dispute A portion of our employees at the Hawaii 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 has been scheduled for the week of October 1, 2018. PHR denies the USW’s allegations and intends to vigorously defend itself in connection with such claim in the grievance/arbitration process and any subsequent proceeding before the NLRB. Environmental Matters Like other petroleum refiners and exploration and production companies, our operations are subject to extensive and periodically-changing federal and state environmental 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. Wyoming refinery Our Wyoming refinery is subject to a number of consent decrees, orders, and settlement agreements involving the U.S. Environmental Protection Agency (“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 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, 2017 , we have accrued $18.2 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 5 years , with the remainder being 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 preliminary 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 appears to be declining 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 . Moreover, in November 2016, the Pipeline and Hazardous Materials Safety Administration (“PHMSA”) conducted an integrated inspection of the products pipeline acquired in the WRC Acquisition. As a result of compliance violations identified during the inspection, the Wyoming refinery was assessed a civil penalty of $279 thousand in December 2017, which was paid in January 2018. 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. On September 29, 2015, the EPA announced a final rule updating standards that control toxic air emissions from petroleum refineries, addressing, among other things, flaring operations, fenceline air quality monitoring, and additional emission reductions from storage tanks and delayed coking units. Affected existing sources will be required to comply with the new requirements no later than 2018, with certain refiners required to comply earlier depending on the relevant provision and refinery construction date. We do not anticipate that compliance with this rule will have a material impact on our financial condition, results of operations, or cash flows. 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. Although delayed, the Hawaii Department of Health has issued regulations that would 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). Those rules are pending final approval by the Hawaii State Government. The Hawaii refinery’s capacity to reduce fuel use and GHG emissions is limited. However, the state’s pending regulation allows, and the Hawaii refinery expects to be able to demonstrate, that additional reductions are not cost-effective or necessary in light of the state’s current GHG inventory and future year projections. The pending 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 with the state’s Renewable Portfolio Standards. Fuel Standards In 2007, the U.S. Congress passed the Energy Independence and Security Act of 2007 (the “EISA”) that, among other things, sets 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 a second Renewable Fuel Standard (the “RFS2”). In August 2012, the EPA and National Highway Traffic Safety Administration jointly adopted regulations that establish an average industry fuel economy of 54.5 miles per gallon by model year 2025. The RFS2 requires an increasing amount of renewable fuel usage, up to 36 billion gallons by 2022. In the near term, the RFS2 will be satisfied primarily with fuel ethanol blended into gasoline. The RFS2 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 credits 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 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 January 2011, the EPA issued a second waiver for the use of E15 in vehicles model years 2001- 2006. 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. Consequently, unless either the state or federal regulations are revised, RINs will be required to fulfill the federal mandate for renewable fuels. In March 2014, the EPA published a final Tier 3 gasoline standard that lowers the allowable sulfur level in gasoline to 10 parts per million (“ppm”) and also lowers the allowable benzene, aromatics, and olefins content of gasoline, with the most recent rulemaking addressing certain technical corrections and clarifications effective June 21, 2016. The effective date for the new standard was January 1, 2017, however, approved small volume refineries have until January 1, 2020 to meet the standard. Our Hawaii refinery is required to comply with Tier 3 gasoline standards within 30 months of June 21, 2016, the date our Hawaii refinery was disqualified from small volume refinery status. On March 19, 2015, the EPA confirmed the small volume refinery status of our Wyoming refinery. There will be compliance costs and uncertainties regarding how we will comply with the various requirements contained in the EISA and other fuel-related regulations. Along with credit and trading options, potential capital upgrades for the Hawaii and Wyoming refineries are being evaluated. We may also 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 our Hawaii refinery. As a result of the Consent Decree, PHR expanded its planned 2016 Hawaii 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. Although the turnaround was completed during the third quarter of 2016, work related to the Consent Decree is ongoing. This work subjects us to risks associated with engineering, procurement, and construction of improvements and repairs to our facilities and related penalties and fines to the extent applicable deadlines under the Consent Decree are not satisfied, as well as risks related to the performance of equipment required by, or affected by, the Consent Decree. Each of these risks could have a material adverse effect on our business, financial condition, or results of operations. We estimate the cost of compliance with the Consent Decree to be approximately $30.0 million . However, 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, 2017 , Tesoro has reimbursed us for $12.1 million of our total capital expenditures of $12.9 million incurred in connection with the Consent Decree. Net capital expenditures and reimbursements related to the Consent Decree for the year ended December 31, 2017 and 2016 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 $1.0 million and a cap of $15.0 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 the Debtors hold against third parties. As of December 31, 2017 , 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. See Note 21—Subsequent Events for further discussion. Capital Leases Within our retail segment, we have capital lease obligations related primarily to the leases of five retail stations with generally two years remaining on the current term and four five-year renewal options . Minimum annual lease payments including interest, for capital leases are as follows (in thousands): 2018 $ 863 2019 703 2020 167 2021 56 2022 — Thereafter — Total minimum lease payments 1,789 Less amount representing interest 86 Total minimum rental payments $ 1,703 Operating Leases We have 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. The majority of the future lease payments relate to retail stations and facilities used in the storage, transportation, and sale of crude oil and refined products. We have operating leases for most of our retail stations with an average of 5 years remaining and generally containing renewal options and escalation clauses. Leases for facilities used in the storage, transportation, and sale of crude oil and refined products have various expiration dates extending to 2078 . Minimum annual lease payments for operating leases to which we are legally obligated and having initial or remaining non-cancelable lease terms in excess of one year are as follows (in thousands): 2018 $ 16,453 2019 12,305 2020 8,649 2021 7,332 2022 6,275 Thereafter 29,668 Total minimum rental payments $ 80,682 Rent expense for the years ended December 31, 2017 , 2016 , and 2015 was approximately $41.2 million , $39.6 million , and $17.7 million , respectively. Major Customers For the year ended December 31, 2017 , we had one customer in our refining segment that accounted for 10% of our consolidated revenue. No other customer accounted for more than 10% of our consolidated revenues during the years ended December 31, 2017 , 2016 , and 2015 .

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Stockholders' Equity	Note 15—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. On September 22, 2016 , we issued approximately 4 million shares of our common stock to certain pre-existing investors and other investors in the Rights Offering at a purchase price of $12.25 per share. The gross proceeds from the Rights Offering were approximately $49.9 million , before deducting expenses of approximately $0.9 million , for net proceeds of approximately $49.0 million . The net proceeds from the Rights Offering were used to repay all accrued and unpaid interest and a portion of the outstanding principal amount on the Bridge Notes. On November 25, 2015 , we issued an aggregate of 3.4 million shares of our common stock to certain pre-existing investors and other investors in a registered direct offering (the “Offering”) at a purchase price of $22.00 per share. The total gross proceeds from the Offering were approximately $74.8 million , before deducting expenses of approximately $1.0 million , for net proceeds of approximately $73.8 million . 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. In connection with the issuance by the Company of its 2.50% convertible subordinated bridge notes (the “Bridge Notes”), the Company entered into a registration rights agreement (the “Bridge Notes Registration Rights Agreement”), dated as of July 14, 2016 with the purchasers of the Bridge Notes. The Bridge Notes Registration Rights Agreement required the Company to file with the SEC a shelf registration statement covering resales of the shares of common stock, if any, issuable upon conversion of the Bridge Notes, (ii) to use its commercially reasonable efforts to cause such shelf registration statement to be declared effective by the SEC no later than (A) the earlier of December 14, 2016 or 60 days after the filing deadline for the shelf registration statement or (B) if earlier, five business days after the date on which the SEC informs the Company that it will not review the shelf registration statement, and (iii) to use its commercially reasonable efforts to keep such shelf registration statement effective until the earlier of (A) the date on which all of such shares have been sold, (B) the date on which such shares may be sold without volume restrictions under Rule 144 of the Securities Act of 1933, as amended, or (C) the third anniversary of the effective date of such shelf registration statement. If the Company does not fulfill its obligations under the Bridge Notes Registration Rights Agreement with respect to the filing deadline, effectiveness deadline, or effectiveness period of a registration statement, it will be required to pay the holders of the Bridge Notes liquidated damages in an amount in cash equal to 1.00% of such holder’s “Allocated Purchase Price,” which is the amount effectively paid by such holder for the Common Stock acquired upon conversion of the Bridge Notes, per calendar month or portion thereof prior to the cure of such event of default. The maximum payment of liquidated damages to any such holder associated with all events of default will not exceed 5.00% of such holder’s Allocated Purchase Price. 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, 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. The maximum number of shares that may be granted under the LTIP is 4.0 million shares of common stock. At December 31, 2017 , 0.8 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; the Compensation Committee of the Board shall be entitled to specify with respect to any restricted stock unit award that upon the payment of a dividend by the Company, the Company will hold in escrow an amount in cash equal to the dividend that would have been paid on the restricted stock units had they been converted into the same number of shares of common stock and held by the recipient on that date. Upon adjustment and vesting of the restricted stock unit, any cash payment due with respect to such dividends shall be made to the recipient. 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. These awards generally vest ratably over a four-year period. 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, 2017 2016 2015 Restricted Stock Awards $ 4,263 $ 2,975 $ 3,692 Restricted Stock Units $ 502 $ 1,255 $ — Stock Option Awards $ 2,439 $ 2,352 $ 1,477 Restricted Stock Awards and Restricted Stock Units The following table summarizes our restricted stock activity, including performance restricted stock units, (in thousands, except per share amounts): Shares Weighted- Unvested balance at December 31, 2016 436 $ 17.83 Granted 323 $ 15.25 Vested (207 ) $ 18.77 Forfeited (9 ) $ 16.44 Unvested balance at December 31, 2017 543 $ 16.23 The total fair value of restricted stock and restricted stock units that vested during the years ended December 31, 2017 , 2016 , and 2015 was $4.0 million , $3.6 million , and $4.5 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, 2017 , 2016 , and 2015 was $15.25 , $17.32 , and $18.24 , respectively. As of December 31, 2017 , 2016 , and 2015 , there was approximately $5.7 million , $6.2 million , and $7.1 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 2.39 years, 2.50 years, and 2.91 years, respectively. During the year ended December 31, 2017 , we granted 45 thousand performance restricted stock units to executive officers. These performance restricted stock units had a fair value of approximately $0.7 million and are subject to certain annual performance targets as defined by our Board of Directors. As of December 31, 2017 , there were approximately $0.4 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 2.16 years. 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 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 2017 , 2016 , and 2015 are presented below. 2017 2016 2015 Expected life from date of grant (years) 5.3 4.4 6.4 Expected volatility 42.0% 39.8% 35.0% Expected dividend yield —% —% —% Risk-free interest rate 1.97% 1.16% 1.81% The following table summarizes our stock option activity (in thousands, except per share amounts): Number of Options Weighted-Average Weighted-Average Aggregate Outstanding balance at December 31, 2016 1,743 $ 20.13 6.2 $ — Issued 239 15.03 Exercised — — Forfeited / canceled (3 ) 15.15 Outstanding balance at December 31, 2017 1,979 $ 19.52 5.5 $ 1,431 Exercisable, end of year 1,094 $ 19.51 4.3 $ 1,329 The estimated weighted-average grant-date fair value per share of options granted during the year ended December 31, 2017 , 2016 , and 2015 was $5.81 , $3.79 , and $8.36 , respectively. As of December 31, 2017 and 2016 , there were approximately $3.5 million and $4.5 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 1.74 and 2.84 years, respectively.

Benefit Plans

Benefit Plans	12 Months Ended
	Dec. 31, 2017
Compensation and Retirement Disclosure [Abstract]
Benefit Plans	Note 16—Benefit Plans Defined Contribution Plan We maintain two defined contribution plans for our employees. All eligible employees may participate in one of these plans, either immediately or after one year of service, depending on the plan. We match employee contributions up to a maximum of 6% of the employee's eligible compensation. Vesting percentages associated with the employer contributions range from 0% to 100% , depending on the plan and the number of years of service. For the years ended December 31, 2017 , 2016 , and 2015 , we made contributions to the plans totaling approximately $3.6 million , $3.2 million , and $1.4 million , respectively. Defined Benefit Plan We maintain a defined benefit pension plan (the “Benefit Plan”) covering substantially all our Wyoming Refining employees. Benefits 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. 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 Benefit Plan was amended (the “Plan Amendment”) to freeze all future benefit accruals for salaried plan participants. The Plan Amendment reduced the projected benefit obligation by $3.1 million as of December 31, 2016. The curtailment gain of $3.1 million was recognized as reduction of Operating expense (excluding depreciation) in our consolidated statement of operations for the year ended December 31, 2016. The changes in the projected benefit obligation and the fair value of plan assets of our Benefit Plan for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 were as follows (in thousands): 2017 2016 Changes in projected benefit obligation: Projected benefit obligation as of the beginning of the period $ 28,914 $ 34,319 Service cost 614 668 Interest cost 1,192 598 Plan amendment — (3,067 ) Actuarial (gain) loss 1,091 (2,436 ) Benefits paid (934 ) (1,168 ) Projected benefit obligation as of December 31 $ 30,877 $ 28,914 Changes in fair value of plan assets: Fair value of plan assets as of the beginning of the period $ 21,345 $ 22,067 Actual return on plan assets 3,050 446 Employer contributions — — Benefits paid (934 ) (1,168 ) Fair value of plan assets as of December 31 $ 23,461 $ 21,345 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, 2017 and 2016 was as follows: 2017 2016 Projected benefit obligation $ 30,877 $ 28,914 Fair value of plan assets 23,461 21,345 Underfunded status $ 7,416 $ 7,569 Gross amounts recognized in accumulated other comprehensive income: (1) Net actuarial gain $ 2,965 $ 2,196 ____________________________________________________ (1) As of December 31, 2017 , we had no amounts recorded in accumulated other comprehensive income that are expected to be amortized into net periodic benefit cost in 2018 . Weighted-average assumptions used to measure our projected benefit obligation as of December 31, 2017 and 2016 and net periodic benefit costs for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 are as follows: 2017 2016 Projected benefit obligation: Discount rate (1) 3.65 % 4.20 % Rate of compensation increase 3.00 % 4.30 % Net periodic benefit costs: Discount rate (1) 4.20 % 3.80 % Expected long-term rate of return (2) 6.25 % 7.00 % Rate of compensation increase 4.30 % 4.03 % _________________________________________________________ (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 (credit) for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 includes the following components: 2017 2016 Components of net periodic benefit cost (credit): Service cost $ 614 $ 668 Interest cost 1,192 598 Expected return on plan assets (1,189 ) (686 ) Plan amendment effect — (3,067 ) Net periodic benefit cost (credit) $ 617 $ (2,487 ) The weighted-average asset allocation at December 31, 2017 is as follows: Target Actual Asset category: Equity securities 60 % 59 % Debt securities 30 % 32 % Real estate 10 % 9 % 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 Plan assets are invested in pooled separate accounts administered by the Benefit Plan custodian. The underlying assets in the pooled separate accounts are invested in equity securities, debt securities, and real estate. The pooled separate accounts are valued based upon the fair market value of the underlying investments and are deemed to be Level 2. We do not intend to make any contributions to the pension plan during 2018 . 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 2018 $ 1,090 2019 1,140 2020 1,240 2021 1,310 2022 1,270 Thereafter 7,800 $ 13,850 Other Post-Retirement Benefits - Medical Prior to December 31, 2015, we sponsored a post-retirement medical plan to provide health care coverage continuation from the date of retirement to age 65 for qualifying employees. Employees hired before 2006 were generally eligible to participate in the plan after five years of service and reaching the age of 55 and would have paid 20% of the monthly insurance premium. Employees hired after 2006 were generally eligible to participate in the plan after five years of service and reaching the age of 55 and were required to pay 100% of the monthly insurance premium; however, after 10 years of service, they were only required to pay 50% of the monthly insurance premium. On December 31, 2015, we terminated our post-retirement medical plan and extinguished the remaining benefit obligation of $6.6 million . The plan termination gain of $5.6 million is included as a reduction of Operating expense (excluding depreciation) on our consolidated statement of operations for the year ended December 31, 2015. The changes in the benefit obligation of our post-retirement medical plan as of and for the year ended December 31, 2015 were as follows (in thousands): Year Ended December 31, 2015 Benefit obligation at the beginning of year $ 5,414 Service cost 370 Interest cost 212 Plan amendments — Plan termination (6,632 ) Actuarial loss (gain) 636 Projected benefit obligation at end of year $ — The post-retirement medical plan was an unfunded plan and therefore had no plan assets as of or during the year ended December 31, 2015. The weighted-average discount rate used to determine net periodic benefit costs for the year ended December 31, 2015 was 3.5% .

Income (Loss) Per Share

Income (Loss) Per Share	12 Months Ended
	Dec. 31, 2017
Earnings Per Share [Abstract]
Income (loss) per Share	Note 17—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, 347 thousand shares, and 344 thousand shares for the years ended December 31, 2017 , 2016 , and 2015 , respectively. 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 loss per share (in thousands, except per share amounts): Year Ended December 31, 2017 2016 2015 Net income (loss) $ 72,621 $ (45,835 ) $ (39,911 ) Less: Undistributed income allocated to participating securities (1) 878 — — Net income (loss) attributable to common stockholders 71,743 (45,835 ) (39,911 ) Plus: Net income effect of convertible securities — — — Numerator for diluted income (loss) per common share $ 71,743 $ (45,835 ) $ (39,911 ) Basic weighted-average common stock shares outstanding 45,543 42,349 37,678 Add dilutive effects of common stock equivalents (2) 40 — — Diluted weighted-average common stock shares outstanding 45,583 42,349 37,678 Basic income (loss) per common share $ 1.58 $ (1.08 ) $ (1.06 ) Diluted income (loss) per common share $ 1.57 $ (1.08 ) $ (1.06 ) ________________________________________________________ (1) Participating securities includes restricted stock that has been issued but has not yet vested. (2) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per share for the years ended December 31, 2016 and 2015 . For the year ended December 31, 2017 , our calculation of dilutive shares outstanding excluded 65 thousand shares of unvested restricted stock, 1.3 million stock options, and 6.4 million outstanding common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on the date of issuance. For the year ended December 31, 2016 , our calculation of dilutive shares outstanding excluded 451 thousand shares of unvested restricted stock, 1.3 million stock options, and 6.4 million outstanding common stock equivalents assuming our 5.00% Convertible Senior Notes had been converted on the date of issuance. For the year ended December 31, 2015 , our calculation of dilutive shares outstanding excluded 535 thousand shares of unvested restricted stock and 632 thousand stock options. As discussed in Note 11—Debt , we have the option of settling the 5.00% Convertible Senior Notes issued in June 2016 in cash or shares of common stock, or any combination thereof, upon conversion. For the year ended December 31, 2017 , diluted income (loss) per share was determined using the if-converted method. We have a net loss for the year ended December 31, 2016 ; therefore, there is no impact for the conversion of the 5.00% Convertible Senior Notes on diluted EPS as the effect would be anti-dilutive.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Note 18—Income Taxes We have approximately $1.6 billion in net operating loss carryforwards (“NOL carryforwards”); however, we currently have a valuation allowance against this and substantially all of our other deferred taxed 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. Management considers the scheduled reversal of deferred tax liabilities, projected future results of operations, and tax planning strategies in making this assessment. Based upon the level of historical taxable income, significant book losses during the prior periods, and projections for future results of operations over the periods in which the deferred tax assets are deductible, among other factors, management concluded that we did not meet the “more likely than not” requirement in order to recognize deferred tax assets and therefore, a valuation allowance has been recorded for substantially all of our net deferred tax assets at December 31, 2017 and 2016 . 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. This exception under Code Section 382(l)(5) provides for substantially less restrictive limitations on our NOL carryforwards; however, the NOL carryforwards would have been eliminated if we had experienced another ownership change within the two year period following our Bankruptcy. 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. During the years ended December 31, 2017 , 2016 , and 2015 , no adjustments were recognized for uncertain tax benefits. 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. On December 22, 2017, the Tax Cuts and Jobs Act (“U.S. tax reform”) was signed into law. U.S. tax reform 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. As a result of the change in rate, we remeasured our net deferred tax assets and the associated valuation allowance by $207.7 million . 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 U.S. tax reform. The current year AMT credit of $0.8 million was also recorded as a long-term receivable rather than a deferred tax asset. During 2016, we recorded a benefit for the release of $8.6 million of our valuation allowance to offset future temporary differences associated with the 5.00% Convertible Senior Notes . During 2015, we recorded a benefit for the release of $16.8 million of our valuation allowance as we expect to be able to utilize a portion of our NOL carryforwards to offset future taxable income of Mid Pac. During 2018 and thereafter, we will continue to assess the realizability of our deferred tax assets based on consideration of actual and projected operating results and tax planning strategies. Should actual operating results improve, the amount of the deferred tax asset considered more likely than not to be realizable could be increased. Income (loss) before income taxes related to our foreign operations was a loss of $1.4 million , and $0.9 million for the years ended December 31, 2016 and 2015 , respectively. We had no income (loss) from foreign operations for the year ended December 31, 2017 . Income tax expense (benefit) consisted of the following (in thousands): Year Ended December 31, 2017 2016 2015 Current: U.S.—Federal $ — $ — $ — U.S.—State 2 23 — Foreign — — (299 ) Deferred: U.S.—Federal (1,321 ) (7,046 ) (14,685 ) U.S.—State — (889 ) (1,804 ) Foreign — — — Total $ (1,319 ) $ (7,912 ) $ (16,788 ) Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate of 35% to pretax income as a result of the following: Year Ended December 31, 2017 2016 2015 Federal statutory rate 35.0 % 35.0 % 35.0 % State income taxes, net of federal benefit — % 1.6 % 3.2 % Expiration of capital loss carryover — % (17.6 )% (25.5 )% Change in valuation allowance related to current activity (30.1 )% 9.2 % 25.3 % Change in valuation allowance related to change in tax rate (291.2 )% — % — % Change in tax rate 291.2 % — % — % Permanent items 1.1 % (5.7 )% (7.6 )% Provision to return adjustments and other (7.9 )% (7.8 )% (0.8 )% Actual income tax rate (1.9 )% 14.7 % 29.6 % Deferred tax assets (liabilities) are comprised of the following (in thousands): December 31, 2017 2016 Deferred tax assets: Net operating loss $ 388,317 $ 611,631 Property and equipment 9,862 23,203 Other 10,263 10,868 Total deferred tax assets 408,442 645,702 Valuation allowance (383,253 ) (613,866 ) Net deferred tax assets 25,189 31,836 Deferred tax liabilities: Investment in Laramie Energy 18,140 20,600 Convertible notes 3,193 6,866 Intangible assets 3,978 2,671 Other 863 2,337 Total deferred tax liabilities 26,174 32,474 Total deferred tax liability, net $ (985 ) $ (638 ) We have NOL carryforwards as of December 31, 2017 of $1.6 billion for federal income tax purposes. If not utilized, the NOL carryforwards will expire during 2027 through 2036 . As noted above, we also have AMT Credit Carryovers of $1.6 million which are refundable under the U.S. tax reform legislation effective tax year 2018. During 2016, we amended our federal income tax returns for 2012, 2013, and 2014 to properly reflect amortization deductions with respect to certain development costs related to our investment in Laramie Energy that should have been claimed in those years. The impact of the corrected returns was an increase to the deferred tax asset related to our net operating loss and a corresponding decrease in the deferred tax asset related to our investment in Laramie Energy of approximately $59 million .

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Segment Information	Note 19—Segment Information We report the results for the following four business segments: (i) Refining , (ii) Retail , (iii) Logistics , and (iv) Corporate and Other. Beginning in the third quarter of 2016, the results of operations of Wyoming Refining are included in our refining and logistics segments. We have recast the segment information for the years ended December 31, 2016 and 2015 to reflect the elimination of the Texadian segment as a reportable segment beginning in the first quarter of 2017. As of December 31, 2017, Texadian had ceased its business operations other than the disposal of certain assets and liquidation of inventory. Our Corporate and Other reportable segment now includes administrative costs, our Texadian operations, and several small non-operated oil and gas interests that were owned by our predecessor. Summarized financial information concerning reportable segments consists of the following (in thousands): 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) 141,068 15,010 45,941 — 202,019 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) $ 86,013 $ 33,993 $ 24,700 $ (50,748 ) $ 93,958 Interest expense and financing costs, net (31,632 ) Loss on termination of financing agreements (8,633 ) Other income, net 914 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 . For the year ended December 31, 2016 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 1,702,463 $ 102,779 $ 290,402 $ (230,599 ) $ 1,865,045 Cost of revenues (excluding depreciation) 1,580,014 65,439 220,545 (229,659 ) 1,636,339 Operating expense (excluding depreciation) 112,724 11,239 41,291 962 166,216 Depreciation, depletion, and amortization 17,565 4,679 6,372 3,001 31,617 General and administrative expense (excluding depreciation) — — — 42,073 42,073 Acquisition and integration costs — — — 5,294 5,294 Operating income (loss) $ (7,840 ) $ 21,422 $ 22,194 $ (52,270 ) $ (16,494 ) Interest expense and financing costs, net (28,506 ) Other expense, net (98 ) Change in value of common stock warrants 2,962 Change in value of contingent consideration 10,770 Equity losses from Laramie Energy, LLC (22,381 ) Loss before income taxes (53,747 ) Income tax benefit 7,912 Net loss $ (45,835 ) Total assets $ 772,438 $ 120,443 $ 122,570 $ 129,982 $ 1,145,433 Goodwill 53,037 36,145 16,550 — 105,732 Capital expenditures 15,106 1,344 4,375 4,008 24,833 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $271.9 million for the year ended December 31, 2016 . For the year ended December 31, 2015 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 1,895,662 $ 82,671 $ 283,507 $ (195,503 ) $ 2,066,337 Cost of revenues (excluding depreciation) 1,718,729 48,660 215,194 (195,215 ) 1,787,368 Operating expense (excluding depreciation) 95,588 5,433 35,317 5,283 141,621 Depreciation, depletion, and amortization 9,522 3,117 5,421 1,858 19,918 Impairment expense — — — 9,639 9,639 General and administrative expense (excluding depreciation) — — — 44,271 44,271 Acquisition and integration costs — — — 2,006 2,006 Operating income (loss) $ 71,823 $ 25,461 $ 27,575 $ (63,345 ) $ 61,514 Interest expense and financing costs, net (20,156 ) Loss on termination of financing agreements (19,669 ) Other expense, net (291 ) Change in value of common stock warrants (3,664 ) Change in value of contingent consideration (18,450 ) Equity losses from Laramie Energy, LLC (55,983 ) Loss before income taxes (56,699 ) Income tax benefit 16,788 Net loss $ (39,911 ) Total assets $ 516,482 $ 53,158 $ 115,544 $ 207,077 $ 892,261 Goodwill 13,765 11,012 16,550 — 41,327 Capital expenditures 8,573 6,089 3,643 4,040 22,345 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $330.0 million for the year ended December 31, 2015 .

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Note 20—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, 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 11—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 EGI, an affiliate of Zell Credit Opportunities Fund, LP (“ZCOF”), which own 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 significant costs incurred related to this agreement during the years ended December 31, 2017 , 2016 , or 2015 . Bridge Notes Commitment and Issuance On June 14, 2016 , we entered into a Bridge Notes commitment letter (the “Bridge Notes Commitment Letter”) with entities affiliated with EGI and Highbridge pursuant to which such parties committed to purchase an aggregate of up to $52.6 million of Bridge Notes. We paid a fee, in the amount of 5.0% of their respective commitments, to each of the entities affiliated with EGI and Highbridge who had committed to purchasing Bridge Notes pursuant to the Bridge Notes Commitment Letter. This fee was deducted from the proceeds received at the Bridge Notes closing in July 2016. On September 22, 2016 , we repaid $49 million of the outstanding interest and principal on the Bridge Notes and converted the remaining outstanding principal amount on the Bridge Notes into 272,733 shares of our common stock.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Note 21—Subsequent Events 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 for cash consideration of approximately $70 million plus the agreed value of inventory at closing (the " CHS Acquisition "). The closing of the CHS Acquisition is subject to certain customary closing conditions and is expected to close in the first quarter of 2018. As part of the CHS Acquisition , Par and CHS Inc. will enter into a multi-year branded petroleum marketing agreement for the continued supply of Cenex-branded refined products to the acquired convenience stores. In addition, the parties also will enter into a multi-year supply agreement pursuant to which Par will supply refined products to CHS Inc. within the Rocky Mountain and Pacific Northwest markets. 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 Recovery Trustee, 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 reserves owed on account of the remaining claims of the U.S. Government and Noble Energy, Inc. 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 $23.5 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. As a result of this transaction, our ownership interest in Laramie Energy decreased from 42.3% to 39.14% .

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Note 22—Quarterly Financial Data (Unaudited) Summarized quarterly data for the years ended December 31, 2017 and 2016 consist of the following (in thousands, except per share amounts): Year Ended December 31, 2017 Q1 Q2 Q3 Q4 Revenues $ 605,253 $ 564,245 $ 610,506 $ 663,062 Operating income (loss) 29,189 16,451 26,716 21,602 Net income (loss) 27,786 7,006 18,824 19,005 Net income (loss) per share Basic $ 0.60 $ 0.15 $ 0.41 $ 0.41 Diluted $ 0.58 $ 0.15 $ 0.41 $ 0.41 Year Ended December 31, 2016 Q1 Q2 Q3 Q4 Revenues $ 377,812 $ 413,793 $ 510,305 $ 563,136 Operating income (loss) (19,719 ) (3,313 ) (21,784 ) 28,325 Net income (loss) (18,673 ) (13,088 ) (27,761 ) 13,687 Net income (loss) per share Basic $ (0.46 ) $ (0.32 ) $ (0.67 ) $ 0.30 Diluted $ (0.46 ) $ (0.32 ) $ (0.67 ) $ 0.30

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures	12 Months Ended
	Dec. 31, 2017
Extractive Industries [Abstract]
Supplemental Oil and Gas Disclosures	Note 23—Supplemental Oil and Gas Disclosures (Unaudited) Capitalized costs related to oil and gas activities are as follows (in thousands): December 31, 2017 2016 Company: Unproved properties $ — $ — Proved properties 400 1,122 400 1,122 Accumulated depreciation and depletion (275 ) (930 ) Total $ 125 $ 192 Company’s share of Laramie Energy: Unproved properties $ 13,728 $ 14,416 Proved properties 382,789 334,085 396,517 348,501 Accumulated depreciation, depletion, and amortization (111,119 ) (91,454 ) Total $ 285,398 $ 257,047 Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands): Year Ended December 31, 2017 2016 2015 Company: Development costs—other $ — $ — $ — Total $ — $ — $ — Company’s share of Laramie Energy: Acquisition costs $ — $ 65,324 $ — Development costs—other 49,273 12,805 21,747 Total $ 49,273 $ 78,129 $ 21,747 For the years ended December 31, 2017 , 2016 , and 2015 , 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, 2017 , 2016 , and 2015 that were being evaluated. 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, 2017 2016 2015 Company: Revenue Oil and gas revenues $ 288 $ 190 $ 2,019 Expenses Production costs 29 147 5,283 Depletion and amortization 66 69 42 Exploration — — — Abandoned and impaired properties — — — Results of operations of oil and gas producing activities $ 193 $ (26 ) $ (3,306 ) Company’s share of Laramie Energy: Revenue Oil and gas revenues $ 66,783 $ 43,607 $ 14,217 Expenses Production costs 32,606 27,750 11,047 Impairment of unproved properties — — 3,977 Depletion, depreciation, and amortization 21,277 17,534 8,226 Results of operations of oil and gas producing activities $ 12,900 $ (1,677 ) $ (9,033 ) Total results of operations of oil and gas producing activities $ 13,093 $ (1,703 ) $ (12,339 )

Oil and Gas Reserve Information

Oil and Gas Reserve Information	12 Months Ended
	Dec. 31, 2017
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, 2017 , 2016 , and 2015 , 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, 2017 , 2016 , and 2015 is as follows: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) Company: Balance at January 1, 2015 601 77 17 1,165 Revisions of quantity estimate (330 ) (35 ) (15 ) (630 ) Extensions and discoveries — — — — Production (83 ) (36 ) (2 ) (311 ) Balance at December 31, 2015 (2) 188 6 — 224 Revisions of quantity estimate 196 3 8 262 Extensions and discoveries — — — — Production (54 ) (2 ) — (66 ) Balance at December 31, 2016 (3) 330 7 8 420 Revisions of quantity estimate 109 2 3 139 Extensions and discoveries — — — — Production (47 ) (2 ) — (59 ) Balance at December 31, 2017 (4) 392 7 11 500 Company’s share of Laramie Energy: Balance at January 1, 2015, as revised (5) 192,015 684 5,444 228,788 Revisions of quantity estimate (86,092 ) (295 ) (2,281 ) (101,553 ) Extensions and discoveries 32,041 131 1,007 38,869 Acquisitions and divestures (5,945 ) (20 ) (171 ) (7,091 ) Production (4,745 ) (20 ) (149 ) (5,759 ) Balance at December 31, 2015, as revised (2) (5) 127,274 480 3,850 153,254 Revisions of quantity estimate 28,195 53 526 31,672 Extensions and discoveries 638 1 19 758 Acquisitions and divestures 168,887 492 4,701 200,045 Production (15,192 ) (59 ) (552 ) (18,858 ) Balance at December 31, 2016, as revised (3) (5) 309,802 967 8,544 366,871 Revisions of quantity estimate 1,344 211 (434 ) 3 Extensions and discoveries (4) — — — — Acquisitions and divestures — — — — Production (18,104 ) (71 ) (608 ) (22,178 ) Balance at December 31, 2017 (4) 293,042 1,107 7,502 344,696 Total at December 31, 2017 293,434 1,114 7,513 345,196 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) During 2015 , the Company's estimated proved reserves, inclusive of the Company's share of Laramie Energy's estimated proved reserves, decreased by 76,475 MMcfe or approximately 33% . Revisions of quantity estimates related to our share of Laramie Energy's estimated proved reserves resulted in a decrease of 101,553 MMcfe from the beginning of year reserves. These revisions of quantity estimate are primarily associated with wells becoming uneconomic during 2015. (3) During 2016 , the Company's estimated proved reserves, inclusive of the Company's share of Laramie Energy's estimated proved reserves, increased by 213,813 MMcfe or approximately 139% . Acquisitions and divestitures related to our share of Laramie Energy's estimated proved reserves resulted in an increase of 200,045 MMcfe from the beginning of year reserves. This increase was primarily due to Laramie Energy's acquisition of properties in the Piceance Basin for $152.1 million in March 2016 . Please read Note 3—Investment in Laramie Energy, LLC for more information. The increase of 31,672 MMcfe in Revisions of quantity estimate related to our share of Laramie Energy's estimated proved reserves is primarily due to wells that became economic as a result of increased operator efficiency and cost reductions. (4) 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. Beginning in 2017, Par has decided to base its determination of Laramie Energy proved undeveloped reserves on only a two year drilling and three year completion time horizon, which has resulted in negative revisions to our proved reserves of 17,216 MMcfe during 2017. The Company's share of Laramie Energy's revisions of quantity estimate also includes 30,362 MMcfe of positive revisions associated with 44 probable locations that were converted to proved developed reserves during 2017. These 44 locations converted to proved reserves during 2017 were not considered extensions because they were drilled in proved areas that are slightly offset to other proved locations. The remaining decrease 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. (5) We have revised our previously disclosed proved reserves quantities as of December 31, 2016, 2015, and 2014 to remove certain proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016, 2015, and 2014. Par’s share of Laramie Energy's proved undeveloped reserves from the removed proved undeveloped locations was 19,307 MMcfe, 7,587 MMcfe, and 23,786 MMcfe, representing 5% , 5% , and 9% of total proved reserves as of December 31, 2016, 2015, and 2014, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods. Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) December 31, 2015 Proved developed reserves Company 188 6 — 224 Company's share of Laramie Energy 65,499 248 1,931 78,573 Total 65,687 254 1,931 78,797 Proved undeveloped reserves Company — — — — Company's share of Laramie Energy (2) 61,775 232 1,919 74,681 Total 61,775 232 1,919 74,681 December 31, 2016 Proved developed reserves Company 330 7 8 420 Company's share of Laramie Energy 159,500 516 4,349 188,690 Total 159,830 523 4,357 189,110 Proved undeveloped reserves Company — — — — Company's share of Laramie Energy (2) 150,302 451 4,195 178,181 Total 150,302 451 4,195 178,181 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 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) We have revised our previously disclosed proved undeveloped reserves quantities as of December 31, 2016 and 2015 to remove certain proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016 and 2015. Par’s share of Laramie Energy's proved undeveloped reserves from the removed proved undeveloped locations was 19,307 MMcfe and 7,587 MMcfe as of December 31, 2016 and 2015, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods. Price per MMbtu (2) WTI per Bbl Base pricing, before adjustments for contractual December 31, 2015 $ 2.39 $ 50.28 December 31, 2016 2.29 42.75 December 31, 2017 2.68 51.34 ______________________________________________ (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. (2) The CIG index was used for pricing during 2015. In 2017 and 2016 , pricing is based on the Northwest spot price index. 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, 2017 2016 2015 (in thousands) Company: Future net cash flows $ 1,802 $ 1,154 $ 690 Future costs Production 902 713 345 Development and abandonment — 2 25 Income taxes (1) — — — Future net cash flows 900 439 320 10% discount factor (328 ) (154 ) (128 ) Discounted future net cash flows $ 572 $ 285 $ 192 Company’s share of Laramie Energy: (2) Future net cash flows $ 1,026,005 $ 905,607 $ 405,365 Future costs Production 491,748 462,684 238,129 Development and abandonment 109,248 136,224 67,443 Income taxes (1) — — — Future net cash flows 425,009 306,699 99,793 10% discount factor (209,188 ) (165,557 ) (60,188 ) Discounted future net cash flows $ 215,821 $ 141,142 $ 39,605 Total discounted future net cash flows $ 216,393 $ 141,427 $ 39,797 _______________________________________________ (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. (2) We have revised our previously disclosed discounted future net cash flows as of December 31, 2016 and 2015 to reflect the removal of Laramie Energy's proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016 and 2015. Par’s share of Laramie Energy's discounted future net cash flows from the removed locations was $1.8 million and $0.4 million , representing 1% and 1% of total discounted future net cash flows as of December 31, 2016 and 2015, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods. The principal sources of changes in the standardized measure of discounted net cash flows for the years ended December 31, 2017 , 2016 , and 2015 are as follows (in thousands): Company Company's Share Total Balance at January 1, 2015 (1) $ 1,766 $ 160,671 $ 162,437 Sales of oil and gas production during the period, net of production costs (479 ) (5,753 ) (6,232 ) Acquisitions and divestitures — (4,789 ) (4,789 ) Net change in prices and production costs (679 ) (153,564 ) (154,243 ) Changes in estimated future development costs 8 788 796 Extensions, discoveries, and improved recovery — 9,273 9,273 Revisions of previous quantity estimates, estimated timing of development and other (601 ) 911 310 Previously estimated development and abandonment costs incurred during the period — 15,008 15,008 Accretion of discount 177 17,060 17,237 Balance at December 31, 2015 (1) 192 39,605 39,797 Sales of oil and gas production during the period, net of production costs (62 ) (7,979 ) (8,041 ) Acquisitions and divestitures — 81,066 81,066 Net change in prices and production costs (20 ) 2,994 2,974 Changes in estimated future development costs 14 (8,575 ) (8,561 ) Extensions, discoveries, and improved recovery — 231 231 Revisions of previous quantity estimates, estimated timing of development and other 142 16,995 17,137 Previously estimated development and abandonment costs incurred during the period — 12,805 12,805 Accretion of discount 19 4,000 4,019 Balance at December 31, 2016 (1) 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 _______________________________________________ (1) We have revised our previously disclosed discounted future net cash flows as of December 31, 2016, 2015, and 2014 to reflect the removal of Laramie Energy's proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016, 2015, and 2014. Par’s share of Laramie Energy's discounted future net cash flows from the removed locations was $1.8 million , $0.4 million , and $9.9 million , representing 1% , 1% , and 6% of total discounted future net cash flows as of December 31, 2016, 2015, and 2014, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods.

Condended Financial Information

Condended Financial Information of Registrant	12 Months Ended
	Dec. 31, 2017
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Financial Information of Parent Company Only Disclosure [Text Block]	SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT PAR PACIFIC HOLDINGS, INC. (PARENT ONLY) BALANCE SHEETS (in thousands, except share amounts) December 31, 2017 December 31, 2016 ASSETS Current assets Cash and cash equivalents $ 65,615 $ 10,361 Restricted cash 744 746 Prepaid and other current assets 11,768 9,200 Due from subsidiaries 8,113 66,900 Total current assets 86,240 87,207 Property and equipment Property, plant, and equipment 15,773 10,259 Less accumulated depreciation and depletion (6,226 ) (3,485 ) Property and equipment, net 9,547 6,774 Long-term assets Investment in subsidiaries 552,748 513,693 Other long-term assets 1,976 1,976 Total assets $ 650,511 $ 609,650 LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities Accounts payable $ 4,510 $ 4,529 Other accrued liabilities 12,913 8,141 Due to subsidiaries 82,524 73,529 Total current liabilities 99,947 86,199 Long-term liabilities Long-term debt 95,486 148,456 Common stock warrants 6,808 5,134 Long-term capital lease obligations 551 952 Total liabilities 202,792 240,741 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, 2017 and December 31, 2016, 45,776,087 shares and 45,533,913 shares issued at December 31, 2017 and December 31, 2016, respectively 458 455 Additional paid-in capital 593,295 587,057 Accumulated deficit (148,178 ) (220,799 ) Accumulated other comprehensive income 2,144 2,196 Total stockholders’ equity 447,719 368,909 Total liabilities and stockholders’ equity $ 650,511 $ 609,650 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, 2017 2016 2015 Operating expenses Depreciation and amortization $ 2,871 $ 2,205 $ 963 General and administrative expense (excluding depreciation) 18,922 15,618 16,558 Acquisition and integration expense 192 4,781 1,776 Total operating expenses 21,985 22,604 19,297 Operating loss (21,985 ) (22,604 ) (19,297 ) Other income (expense) Interest expense and financing costs, net (13,709 ) (18,246 ) (13,028 ) Loss on termination of financing agreements (1,804 ) — — Interest income from subsidiaries — 583 1,000 Other income (expense), net 631 67 215 Change in value of common stock warrants (1,674 ) 2,962 (3,664 ) Equity in earnings (losses) of subsidiaries 111,162 (17,170 ) (5,137 ) Total other income (expense), net 94,606 (31,804 ) (20,614 ) Income (loss) before income taxes 72,621 (54,408 ) (39,911 ) Income tax benefit — 8,573 — Net income (loss) $ 72,621 $ (45,835 ) $ (39,911 ) This statement should be read in conjunction with the notes to consolidated financial statements. STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (in thousands) Year Ended December 31, 2017 2016 2015 Net income (loss) $ 72,621 $ (45,835 ) $ (39,911 ) Other comprehensive income (loss): (1) Reclassification of other post-retirement benefits loss to net income — — 1,082 Other post-retirement benefits income (loss), net of tax $ (52 ) 2,196 (636 ) Total other comprehensive income (loss) (52 ) 2,196 446 Comprehensive income (loss) $ 72,569 $ (43,639 ) $ (39,465 ) ____________________________________________________ (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, 2017 2016 2015 Cash flows from operating activities: Net income (loss) $ 72,621 $ (45,835 ) $ (39,911 ) Adjustments to reconcile net loss to cash provided by (used in) operating activities: Depreciation and amortization 2,871 2,205 962 Non-cash interest expense 5,617 13,722 6,860 Non-cash interest income from subsidiary — (583 ) (1,000 ) Change in value of common stock warrants 1,674 (2,962 ) 3,644 Deferred taxes — (8,573 ) — Stock-based compensation 7,204 2,226 3,202 Equity in losses (income) of subsidiaries (111,162 ) 17,170 5,137 Loss on termination of financing agreements 1,804 — — Net changes in operating assets and liabilities: Prepaid and other assets (2,568 ) 25 (8,466 ) Accounts payable and other accrued liabilities 3,088 381 3,674 Net cash used in operating activities (18,851 ) (22,224 ) (25,898 ) Cash flows from investing activities: Investments in subsidiaries (2,072 ) (264,163 ) (89,603 ) Distributions from subsidiaries 70,645 9,047 68,418 Note receivable from subsidiary — 10,000 — Change in restricted cash 2 — — Capital expenditures (5,366 ) (4,321 ) (4,461 ) Due to (from) subsidiaries 80,762 (23,947 ) 27,627 Net cash provided by (used in) investing activities 143,971 (273,384 ) 1,981 Cash flows from financing activities: Proceeds from sale of common stock, net of offering costs — 49,044 76,056 Proceeds from borrowings — 172,282 7,378 Repayments of borrowings (68,873 ) (63,062 ) (37,214 ) Payment of deferred loan costs — (6,298 ) (307 ) Due to (from) subsidiaries — 63,578 — Other financing activities, net (993 ) (598 ) (1,087 ) Net cash provided by (used in) financing activities (69,866 ) 214,946 44,826 Net increase (decrease) in cash and cash equivalents 55,254 (80,662 ) 20,909 Cash and cash equivalents at beginning of period 10,361 91,023 70,114 Cash and cash equivalents at end of period $ 65,615 $ 10,361 $ 91,023 Supplemental cash flow information: Cash received (paid) for: Interest $ (7,856 ) $ (4,557 ) $ (4,709 ) Taxes (1,478 ) — 51 Non-cash investing and financing activities: Accrued capital expenditures $ 370 $ 361 $ 417 Value of warrants and debt reclassified to equity — 3,084 7,691 Capital leases 165 1,575 216 This statement should be read in conjunction with the notes to consolidated financial statements.

Summary of Significant Accoun34

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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 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 bankruptcy matters.
Allowance for Doubtful Accounts	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.
Inventories	Inventories Commodity inventories are stated at the lower of cost or net realizable value using the first-in, first-out accounting method (“FIFO”). We value merchandise along with spare parts, materials, and supplies at average cost. Beginning in June 2015, our refining segment acquires all of its crude oil utilized at the Hawaii refinery from J. Aron & Company (“J.Aron”) under Supply and Offtake Agreements as described in Note 10—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 are obligated to repurchase the inventory.
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 in the consolidated statements of operations. The investment is reviewed for impairment when events or changes in circumstances indicate that there has been an other than temporary decline in the value of the investment.
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 8 to 47 Logistics 3 to 30 Retail 14 to 18 Corporate 3 to 7 Software 3 We record property under capital leases at the lower of the present value of minimum lease payments using our incremental borrowing rate or the fair value of the leased property at the date of lease inception. We depreciate leasehold improvements and property acquired under capital leases over the shorter of the lease term or the economic life of the asset. We review property, plant, and equipment and other long-lived assets 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.
Natural Gas and Oil Properties
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, as well as plugging and abandonment of wells within our natural gas and crude oil 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 facility, 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 2016 , we recognized deferred turnaround costs of approximately $32.7 million . No deferred turnaround costs were recorded during 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 forwards 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 obligation to repurchase crude oil and refined products from J.Aron at the termination of the Supply and Offtake Agreements 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 (“NOLs”) 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 recognize the impact of an uncertain tax position only if it is more likely than not of being sustained upon examination by the relevant taxing authority based on the technical merits of the position. As a general rule, our open years for Internal Revenue Service (“IRS”) examination purposes are 2014 , 2015 , and 2016 . However, since we have net operating loss 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 net operating loss deduction is claimed, the IRS may examine the year in which the net operating loss was generated and adjust it accordingly for purposes of assessing additional tax in the year the net operating loss deductions 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) in the consolidated statements of operations. The grant date fair value of restricted stock awards are equal to the market price of our common stock on the date of grant. The fair value of stock options are estimated using the Black-Scholes option-pricing model as of the date of grant.
Revenue Recognition	Revenue Recognition We recognize revenue when it is realized or realizable and earned. Revenue is realized or realizable and earned when persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed or determinable, and collectibility is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met. Certain transactions are recorded on a net basis and included in Cost of revenues (excluding depreciation) on our consolidated statements of operations. 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. Refining and Retail We recognize revenues upon delivery of goods or services to a customer. For goods, this is the point at which title and risk of loss is transferred and when payment has either been received or collection is reasonably assured. Revenues for services are recorded when the services have been provided. We include transportation fees charged to customers in Revenues in our consolidated statements of operations, while the related transportation costs are included in Cost of revenues (excluding depreciation) . Federal excise and state motor fuel taxes, which are collected from customers and remitted to governmental agencies within our refining and retail segments are excluded from both Revenues and Cost of revenues (excluding depreciation) in our consolidated statements of operations. 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 Renewable Identification Numbers (“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 plan. The funded status is recorded within Other long-term liabilities. Certain changes in the plan's 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 17—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 Not Yet Adopted	Accounting Principles Not Yet Adopted In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”). The FASB’s objective was to provide a more robust framework to improve comparability of revenue recognition practices across entities by removing most industry and transaction specific guidance, align GAAP with International Financial Reporting Standards, and provide more useful information to financial statement users. This authoritative guidance changes the way entities recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date (“ASU 2015-14”), which defers the effective date of ASU 2014-09 by one year. ASU 2014-09 is now effective for interim and annual periods beginning after December 15, 2017. Further amendments and technical corrections were made to ASU 2014-09 in 2016 and 2017. During 2016, we formally established a working group to assess the amended revenue recognition guidance in Topic 606, including its impact on our business processes, accounting systems, controls, and financial statement disclosures. As part of our evaluation, the working group reviewed existing revenue streams and identified the types of arrangements where differences may arise in revenue recognition upon adoption of the new standard. Our largest revenue stream consists of revenues generated from the sale of refined products, generally at market prices. These revenues are recognized upon delivery of goods to a customer. Our evaluation of this ASU is substantially complete and we currently do not expect the new standard to have a material impact on the amount or timing of revenues recognized for the sale of refined products. In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”). ASU 2016-02 requires lessees to recognize all leases, including operating leases, on the balance sheet as a lease asset or lease liability, unless the lease is a short-term lease. ASU 2016-02 also requires additional disclosures regarding leasing arrangements. In January 2018, the FASB issued ASU No. 2018-01 (“ASU 2018-01”), which clarifies the related transition and accounting for land easements. ASU 2016-02 and ASU No. 2018-01 are effective for interim periods and fiscal years beginning after December 15, 2018, and early application is permitted. We are in the process of determining the method of adoption and the impact this guidance will have on our financial condition, results of operations, and cash flow. In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (“ASU 2016-15”). Additionally, in November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (“ASU 2016-18”). The primary purpose of ASU 2016-15 is to reduce the diversity in practice relating to eight specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies); distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle. ASU 2016-18 requires that an entity include restricted cash and restricted cash equivalents within its statement of cash flows and in the reconciliation to the statement of operations. The guidance in these ASUs is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. The new guidance must be applied using a retrospective transition method. We do not expect the adoption of ASU 2016-15 and ASU 2016-18 to have a material impact on our financial condition, results of operations, or cash flows. In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business (“ASU 2017-01”). This ASU updates the definition of a business combination and provides a framework for determining whether a transaction involves an asset or a business. The guidance in this ASU is effective for fiscal years and interim periods beginning after December 15, 2017, 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 assessments and accounting for future acquisition or disposal transactions. 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 March 2017, the FASB issued ASU 2017-07, Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (“ASU 2017-07”). This ASU requires entities to (1) disaggregate the current-service-cost component from the other components of net benefit cost (the “other components”) and present it with other current compensation costs for related employees in the income statement and (2) present the other components elsewhere in the income statement and outside of income from operations if that subtotal is presented. In addition, the ASU requires entities to disclose the income statement lines that contain the other components if they are not presented on appropriately described separate lines. ASU 2017-07 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted as of the beginning of any annual period for which an entity’s financial statements (interim or annual) have not been issued or made available for issuance. ASU 2017-07 should be applied retrospectively for the presentation of cost components in the income statement and prospectively for the capitalization of the service cost component in assets. We do not expect the adoption of ASU 2017-07 to have a material impact on our financial condition, results of operations, or cash flows. In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting (“ASU 2017-09”). The primary purpose of this ASU is to reduce the diversity in practice and cost and complexity in applying the guidance in Topic 718 related to the change to terms or conditions of a share-based payment award. The guidance in ASU 2017-09 is effective for fiscal years and interim periods beginning after December 15, 2017, with early adoption permitted. This ASU should be applied prospectively to an award modified on or after the adoption date. We do not expect the adoption of ASU 2017-09 to have a material impact on our financial condition, results of operations, or cash flows. In February 2018, the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income ("ASU 2018-02"). This ASU permits entities to elect 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 ASC 740. The guidance in ASU 2018-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. Management is still evaluating the effects of the available adoption methods and has not yet determined which method will be elected. Accounting Principles Adopted On January 1, 2017, we adopted ASU No. 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements as well as classification in the statement of cash flows. Effective January 1, 2017, our accounting policy is to recognize forfeitures as they occur. The adoption of this ASU did not have a material impact on our financial condition, results of operations, or cash flows. On January 1, 2017, we adopted ASU No. 2016-07, Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting (“ASU 2016-07”). ASU 2016-07 simplifies the equity method of accounting by eliminating the requirement to retrospectively apply the equity method to an investment that subsequently qualifies for such accounting as a result of an increase in the level of ownership interest or degree of influence. The adoption of this ASU did not have any impact on our financial condition, results of operations, or cash flows.

Summary of Significant Accoun35

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
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 8 to 47 Logistics 3 to 30 Retail 14 to 18 Corporate 3 to 7 Software 3
Summary of Depreciation Expense	The following table summarizes depreciation expense excluded from each line item in our consolidated statements of operations (in thousands): Year Ended December 31, 2017 2016 2015 Cost of revenues $ 6,029 $ 4,604 $ 3,017 Operating expense 22,861 16,340 11,428 General and administrative expense 2,929 2,108 855

Investment in Laramie Energy (T

Investment in Laramie Energy (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 2015 Beginning balance $ 108,823 $ 76,203 $ 104,657 Equity earnings (losses) from Laramie Energy 13,043 (28,198 ) (15,713 ) Accretion of basis difference 5,326 5,818 811 Impairment — — (41,081 ) Investments — 55,000 27,529 Ending balance $ 127,192 $ 108,823 $ 76,203
Equity Method Investees Financial Information	Summarized financial information for Laramie Energy is as follows (in thousands): December 31, 2017 2016 Current assets $ 18,757 $ 12,199 Non-current assets 720,444 655,022 Current liabilities 42,149 58,067 Non-current liabilities 237,497 186,631 Year Ended December 31, 2017 2016 2015 Natural gas and oil revenues $ 157,879 $ 104,826 $ 42,870 Income (loss) from operations 6,019 (27,325 ) (40,984 ) Net income (loss) 30,837 (61,849 ) (49,159 )

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2017
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 $ 10,007 Accounts receivable 9,905 Inventories 5,375 Prepaid and other current assets 1,444 Property, plant and equipment 40,997 Land 34,800 Goodwill (1) 26,942 Intangible assets 33,647 Other non-current assets 1,228 Accounts payable and other current liabilities (10,742 ) Deferred tax liability (16,759 ) Other non-current liabilities (7,235 ) Total $ 129,609 ________________________________________________________ (1) We allocated $13.5 million , $2.7 million , and $10.8 million of goodwill to our refining, retail, and logistics reporting units, respectively. A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands): Cash $ 183 Accounts receivable 16,880 Inventories 28,402 Prepaid and other assets 1,304 Property, plant, and equipment 254,367 Goodwill (1) 66,449 Accounts payable and other current liabilities (57,861 ) Wyoming Refining Senior Secured Revolver (10,100 ) Wyoming Refining Senior Secured Term Loan (58,036 ) Other non-current liabilities (32,222 ) Total $ 209,366 ______________________________________________ (1) We allocated $39.8 million and $26.6 million of goodwill to our refining and logistics segments, respectively.
Business Acquisition, Pro Forma Information	The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the WRC Acquisition had been completed on January 1, 2015 (in thousands): Year Ended December 31, 2016 2015 Revenues $ 2,026,237 $ 2,369,513 Net income (loss) (51,239 ) (51,582 ) Income (loss) per share Basic $ (1.21 ) $ (1.24 ) Diluted $ (1.21 ) $ (1.24 ) The following unaudited pro forma financial information presents our consolidated revenues and net income (loss) as if the Mid Pac acquisition had been completed on January 1, 2014 (in thousands): Year Ended December 31, 2015 Revenues $ 2,093,587 Net loss (54,941 )

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	Inventories at December 31, 2017 and 2016 consist of the following (in thousands): Titled Inventory Supply and Offtake Agreements (1) Total December 31, 2017 Crude oil and feedstocks $ 93,970 $ 56,014 $ 149,984 Refined products and blendstock 63,505 108,917 172,422 Warehouse stock and other 22,951 — 22,951 Total $ 180,426 $ 164,931 $ 345,357 December 31, 2016 Crude oil and feedstocks $ 11,620 $ 49,682 $ 61,302 Refined products and blendstock 38,916 77,677 116,593 Warehouse stock and other 20,431 — 20,431 Total $ 70,967 $ 127,359 $ 198,326 _________________________________________________________ (1) Please read Note 10—Inventory Financing Agreements for further information.

Prepaid and Other Current Ass39

Prepaid and Other Current Assets (Tables)	12 Months Ended
	Dec. 31, 2017
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Current Assets	Prepaid and other current assets at December 31, 2017 and 2016 consist of the following (in thousands): December 31, 2017 2016 Advances to suppliers for crude oil purchases $ — $ 38,300 Collateral posted with broker for derivative instruments 215 2,714 Prepaid insurance 7,547 7,504 Derivative assets 4,296 161 Other 5,221 4,701 Total $ 17,279 $ 53,380

Property, Plant and Equipment D

Property, Plant and Equipment Disclosure (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Major classes of property, plant and equipment consist of the following (in thousands): December 31, 2017 2016 Land $ 79,330 $ 76,437 Buildings and equipment 433,977 412,999 Other 15,931 10,431 Total property, plant and equipment 529,238 499,867 Proved oil and gas properties 400 1,122 Less accumulated depreciation and depletion (79,622 ) (49,727 ) Property, plant and equipment, net $ 450,016 $ 451,262

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 2015 Beginning balance $ 9,042 $ 8,909 $ 2,580 Obligations acquired — — 5,725 Accretion expense 369 362 604 Liabilities settled during period (308 ) (229 ) — Ending balance $ 9,103 $ 9,042 $ 8,909

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	During the years ended December 31, 2017 and 2016 , the change in the carrying amount of goodwill was as follows (in thousands): Balance at January 1, 2016 $ 41,327 Acquisition of Wyoming Refining (1) 64,994 Mid Pac acquisition purchase price allocation adjustment (2) (589 ) Balance at December 31, 2016 105,732 Wyoming Refining acquisition purchase price allocation adjustment (1) 1,455 Balance at December 31, 2017 $ 107,187 ________________________________________________________ (1) Please read Note 4—Acquisitions for further discussion. (2) During 2016, the purchase price allocation was adjusted to record an increase to tax receivables and a decrease to goodwill of $0.6 million . The tax receivable was recorded in connection with a tax refund received by Mid Pac in the first quarter of 2016.
Schedule of Finite-Lived Intangible Assets	Intangible assets consist of the following (in thousands): December 31, 2017 2016 Intangible assets: Railcar leases $ 3,249 $ 3,249 Trade names and trademarks 6,267 6,267 Customer relationships 32,064 32,064 Total intangible assets 41,580 41,580 Accumulated amortization: Railcar leases (3,249 ) (2,599 ) Trade name and trademarks (4,951 ) (4,864 ) Customer relationships (6,776 ) (4,205 ) Total accumulated amortization (14,976 ) (11,668 ) Net: Railcar leases — 650 Trade name and trademarks 1,316 1,403 Customer relationships 25,288 27,859 Total intangible assets, net $ 26,604 $ 29,912
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 2018 $ 2,658 2019 2,658 2020 2,658 2021 2,658 2022 2,658 Thereafter 13,314 $ 26,604

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Schedule of Debt	The following table summarizes our outstanding debt as of December 31, 2017 and 2016 (in thousands): December 31, 2017 2016 Hawaii Retail Credit Facilities $ — $ 95,319 5.00% Convertible Senior Notes due 2021 115,000 115,000 7.75% Senior Secured Notes due 2025 300,000 — Term Loan — 60,361 Par Wyoming Holdings Term Loan — 67,325 Wyoming Refining Senior Secured Term Loan — 55,715 Wyoming Refining Senior Secured Revolver — 6,700 Principal amount of long-term debt 415,000 400,420 Less: unamortized discount and deferred financing costs (30,188 ) (30,024 ) Total debt, net of unamortized discount and deferred financing costs 384,812 370,396 Less: current maturities — (20,286 ) Long-term debt, net of current maturities $ 384,812 $ 350,110
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 2018 $ — 2019 — 2020 — 2021 115,000 2022 — Thereafter 300,000 Total $ 415,000
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, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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, 2017 and 2016 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2017 2016 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,814 $ — Commodity derivatives (1) Other long-term assets — 2,748 Commodity derivatives Other accrued liabilities (39 ) (595 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements (19,564 ) (20,000 ) Interest rate derivatives Prepaid and other current assets 1,482 161 Interest rate derivatives Other long-term assets 2,328 3,377 Interest rate derivatives Other accrued liabilities — (94 ) _________________________________________________________ (1) Does not include cash collateral of $0.2 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of December 31, 2017 and 2016 , respectively. Fair value amounts by hierarchy level as of December 31, 2017 and 2016 are presented gross in the tables below (in thousands): December 31, 2017 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 557 $ 21,907 $ — $ 22,464 $ (19,650 ) $ 2,814 Interest rate derivatives — 3,810 — 3,810 — 3,810 Total $ 557 $ 25,717 $ — $ 26,274 $ (19,650 ) $ 6,624 Liabilities Common stock warrants $ — $ — $ (6,808 ) $ (6,808 ) $ — $ (6,808 ) Commodity derivatives (596 ) (19,093 ) — (19,689 ) 19,650 (39 ) J. Aron repurchase obligation derivative — — (19,564 ) (19,564 ) — (19,564 ) Total $ (596 ) $ (19,093 ) $ (26,372 ) $ (46,061 ) $ 19,650 $ (26,411 ) December 31, 2016 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 190 $ 26,095 $ — $ 26,285 $ (23,537 ) $ 2,748 Interest rate derivatives — 3,602 — 3,602 (64 ) 3,538 Total $ 190 $ 29,697 $ — $ 29,887 $ (23,601 ) $ 6,286 Liabilities Common stock warrants $ — $ — $ (5,134 ) $ (5,134 ) $ — $ (5,134 ) Commodity derivatives (54 ) (24,078 ) — (24,132 ) 23,537 (595 ) J.Aron repurchase obligation derivative — — (20,000 ) (20,000 ) — (20,000 ) Interest rate derivatives — (158 ) — (158 ) 64 (94 ) Total $ (54 ) $ (24,236 ) $ (25,134 ) $ (49,424 ) $ 23,601 $ (25,823 ) _________________________________________________________ (1) Does not include cash collateral of $7.2 million and $9.7 million as of December 31, 2017 and 2016 , respectively included 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 2017 2016 2015 Commodity derivatives Cost of revenues (excluding depreciation) $ (4,517 ) $ (1,338 ) $ 14,367 J. Aron repurchase obligation derivative Cost of revenues (excluding depreciation) 436 (29,810 ) 12,654 Interest rate derivatives Interest expense and financing costs, net 489 2,729 —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements, Nonrecurring	The fair values of the assets acquired and liabilities assumed as a result of the Wyoming Refining acquisition were estimated as of July 14, 2016 , the date of the acquisition, using valuation techniques described in notes (1) through (5) described below. Valuation Fair Value Technique (in thousands) Net working capital $ (11,092 ) (1) Property, plant, and equipment 254,367 (2) Goodwill 66,449 (3) Long-term debt (68,136 ) (4) Other non-current liabilities (32,222 ) (5) Total $ 209,366 (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. (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 debt was recorded at carrying value. The carrying value of long-term debt approximated fair value due to its floating interest rate. (5) Other non-current liabilities include environmental liabilities and the underfunded status of the Wyoming Refining defined benefit plan. 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. Environmental liabilities are based on management’s best estimates of probable future costs using current available information. We consider this to be a Level 3 fair value measurement. The fair values of the assets acquired and liabilities assumed as a result of the Mid Pac acquisition were estimated as of April 1, 2015 , the date of the acquisition, using valuation techniques described in notes (1) through (7) described below. Valuation Fair Value Technique (in thousands) Net working capital $ 15,989 (1) Property, plant, and equipment 40,997 (2) Land 34,800 (3) Goodwill 26,942 (4) Intangible assets 33,647 (5) Other non-current assets 1,228 (7) Deferred tax liability (16,759 ) (6) Other non-current liabilities (7,235 ) (7) Total $ 129,609 (1) Current assets acquired and liabilities assumed were recorded at their net realizable value. (2) The fair value of the 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. We consider this to be a Level 3 fair value measurement. (3) 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. (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 fair value of customer relationships was estimated using the Excess Earnings Method. Significant inputs used in this model include estimated revenue attributable to the customer relationship and estimated attrition rates. The fair value of the trade names and trademarks was estimated using the Relief from Royalty Method. Significant inputs used in this model include estimated revenue attributable to the trade names and trademarks and a royalty rate. We consider this to be a Level 3 fair value measurement. (6) The deferred tax liability was determined based on the differences between the tax bases of the assets acquired and liabilities assumed and the values of those assets and liabilities recognized on our consolidated balance sheets as of the date of acquisition. (7) Other non-current assets and liabilities were recorded at their estimated net present value. We consider this to be a Level 3 fair value measurement.
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, 2017 and 2016 and their placement within our consolidated balance sheets. December 31, Balance Sheet Location 2017 2016 Asset (Liability) Commodity derivatives (1) Prepaid and other current assets $ 2,814 $ — Commodity derivatives (1) Other long-term assets — 2,748 Commodity derivatives Other accrued liabilities (39 ) (595 ) J. Aron repurchase obligation derivative Obligations under inventory financing agreements (19,564 ) (20,000 ) Interest rate derivatives Prepaid and other current assets 1,482 161 Interest rate derivatives Other long-term assets 2,328 3,377 Interest rate derivatives Other accrued liabilities — (94 ) _________________________________________________________ (1) Does not include cash collateral of $0.2 million and $2.7 million recorded in Prepaid and other current assets and $7.0 million and $7.0 million in Other long-term assets as of December 31, 2017 and 2016 , respectively. Fair value amounts by hierarchy level as of December 31, 2017 and 2016 are presented gross in the tables below (in thousands): December 31, 2017 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 557 $ 21,907 $ — $ 22,464 $ (19,650 ) $ 2,814 Interest rate derivatives — 3,810 — 3,810 — 3,810 Total $ 557 $ 25,717 $ — $ 26,274 $ (19,650 ) $ 6,624 Liabilities Common stock warrants $ — $ — $ (6,808 ) $ (6,808 ) $ — $ (6,808 ) Commodity derivatives (596 ) (19,093 ) — (19,689 ) 19,650 (39 ) J. Aron repurchase obligation derivative — — (19,564 ) (19,564 ) — (19,564 ) Total $ (596 ) $ (19,093 ) $ (26,372 ) $ (46,061 ) $ 19,650 $ (26,411 ) December 31, 2016 Level 1 Level 2 Level 3 Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet (1) Assets Commodity derivatives $ 190 $ 26,095 $ — $ 26,285 $ (23,537 ) $ 2,748 Interest rate derivatives — 3,602 — 3,602 (64 ) 3,538 Total $ 190 $ 29,697 $ — $ 29,887 $ (23,601 ) $ 6,286 Liabilities Common stock warrants $ — $ — $ (5,134 ) $ (5,134 ) $ — $ (5,134 ) Commodity derivatives (54 ) (24,078 ) — (24,132 ) 23,537 (595 ) J.Aron repurchase obligation derivative — — (20,000 ) (20,000 ) — (20,000 ) Interest rate derivatives — (158 ) — (158 ) 64 (94 ) Total $ (54 ) $ (24,236 ) $ (25,134 ) $ (49,424 ) $ 23,601 $ (25,823 ) _________________________________________________________ (1) Does not include cash collateral of $7.2 million and $9.7 million as of December 31, 2017 and 2016 , respectively included 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, 2017 2016 2015 Beginning balance $ (25,134 ) $ (25,867 ) $ (21,254 ) Settlements — 16,810 7,691 Acquired — — (2,844 ) Total unrealized income (loss) included in earnings (1,238 ) (16,077 ) (9,460 ) Ending balance $ (26,372 ) $ (25,134 ) $ (25,867 )
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, 2017 and 2016 is as follows (in thousands): Carrying Value Fair Value (1) December 31, 2017 5.00% Convertible Senior Notes due 2021 (3) $ 95,486 $ 149,007 7.75% Senior Secured Notes due 2025 289,326 300,423 Common stock warrants 6,808 6,808 December 31, 2016 Hawaii Retail Credit Agreement (2) $ 93,853 $ 93,853 5.00% Convertible Senior Notes due 2021 (3) 91,029 122,229 Term Loan 57,426 62,367 Par Wyoming Holdings Term Loan (2) 65,908 65,908 Wyoming Refining Senior Secured Term Loan (2) 55,480 55,480 Wyoming Refining Senior Secured Revolver (2) 6,700 6,700 Common stock warrants 5,134 5,134 _________________________________________________________ (1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy with the exception of the fair value measurements of the 5.00% Convertible Senior Notes and the 7.75% Senior Secured Notes , which are considered Level 2 measurements as discussed below. (2) Fair value approximated carrying value due to the debt's floating rate interest which approximates current market value. (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.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Lease Payments for Capital Leases	Minimum annual lease payments including interest, for capital leases are as follows (in thousands): 2018 $ 863 2019 703 2020 167 2021 56 2022 — Thereafter — Total minimum lease payments 1,789 Less amount representing interest 86 Total minimum rental payments $ 1,703
Schedule of Future Minimum Rental Payments for Operating Leases	Minimum annual lease payments for operating leases to which we are legally obligated and having initial or remaining non-cancelable lease terms in excess of one year are as follows (in thousands): 2018 $ 16,453 2019 12,305 2020 8,649 2021 7,332 2022 6,275 Thereafter 29,668 Total minimum rental payments $ 80,682

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
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, 2017 2016 2015 Restricted Stock Awards $ 4,263 $ 2,975 $ 3,692 Restricted Stock Units $ 502 $ 1,255 $ — Stock Option Awards $ 2,439 $ 2,352 $ 1,477
Schedule Of Equity Incentive Plan Disclosures	The following table summarizes our restricted stock activity, including performance restricted stock units, (in thousands, except per share amounts): Shares Weighted- Unvested balance at December 31, 2016 436 $ 17.83 Granted 323 $ 15.25 Vested (207 ) $ 18.77 Forfeited (9 ) $ 16.44 Unvested balance at December 31, 2017 543 $ 16.23
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 2017 , 2016 , and 2015 are presented below. 2017 2016 2015 Expected life from date of grant (years) 5.3 4.4 6.4 Expected volatility 42.0% 39.8% 35.0% Expected dividend yield —% —% —% Risk-free interest rate 1.97% 1.16% 1.81%
Schedule of Share-based Compensation, Stock Options, Activity	The following table summarizes our stock option activity (in thousands, except per share amounts): Number of Options Weighted-Average Weighted-Average Aggregate Outstanding balance at December 31, 2016 1,743 $ 20.13 6.2 $ — Issued 239 15.03 Exercised — — Forfeited / canceled (3 ) 15.15 Outstanding balance at December 31, 2017 1,979 $ 19.52 5.5 $ 1,431 Exercisable, end of year 1,094 $ 19.51 4.3 $ 1,329

Benefit Plans (Tables)

Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2017
Compensation and Retirement Disclosure [Abstract]
Schedule of Defined Benefit Plans Disclosures	The changes in the projected benefit obligation and the fair value of plan assets of our Benefit Plan for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 were as follows (in thousands): 2017 2016 Changes in projected benefit obligation: Projected benefit obligation as of the beginning of the period $ 28,914 $ 34,319 Service cost 614 668 Interest cost 1,192 598 Plan amendment — (3,067 ) Actuarial (gain) loss 1,091 (2,436 ) Benefits paid (934 ) (1,168 ) Projected benefit obligation as of December 31 $ 30,877 $ 28,914 Changes in fair value of plan assets: Fair value of plan assets as of the beginning of the period $ 21,345 $ 22,067 Actual return on plan assets 3,050 446 Employer contributions — — Benefits paid (934 ) (1,168 ) Fair value of plan assets as of December 31 $ 23,461 $ 21,345
Schedule of Accumulated and Projected Benefit Obligations	The reconciliation of the underfunded status of our Benefit Plans of December 31, 2017 and 2016 was as follows: 2017 2016 Projected benefit obligation $ 30,877 $ 28,914 Fair value of plan assets 23,461 21,345 Underfunded status $ 7,416 $ 7,569 Gross amounts recognized in accumulated other comprehensive income: (1) Net actuarial gain $ 2,965 $ 2,196 ____________________________________________________ (1) As of December 31, 2017 , we had no amounts recorded in accumulated other comprehensive income that are expected to be amortized into net periodic benefit cost in 2018 .
Schedule of Assumptions Used	Weighted-average assumptions used to measure our projected benefit obligation as of December 31, 2017 and 2016 and net periodic benefit costs for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 are as follows: 2017 2016 Projected benefit obligation: Discount rate (1) 3.65 % 4.20 % Rate of compensation increase 3.00 % 4.30 % Net periodic benefit costs: Discount rate (1) 4.20 % 3.80 % Expected long-term rate of return (2) 6.25 % 7.00 % Rate of compensation increase 4.30 % 4.03 % _________________________________________________________ (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 (credit) for the year ended December 31, 2017 and the period from July 14, 2016 to December 31, 2016 includes the following components: 2017 2016 Components of net periodic benefit cost (credit): Service cost $ 614 $ 668 Interest cost 1,192 598 Expected return on plan assets (1,189 ) (686 ) Plan amendment effect — (3,067 ) Net periodic benefit cost (credit) $ 617 $ (2,487 )
Schedule of Allocation of Plan Assets	The weighted-average asset allocation at December 31, 2017 is as follows: Target Actual Asset category: Equity securities 60 % 59 % Debt securities 30 % 32 % Real estate 10 % 9 % 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 2018 $ 1,090 2019 1,140 2020 1,240 2021 1,310 2022 1,270 Thereafter 7,800 $ 13,850
Schedule of Benefit Obligations in Excess of Fair Value of Plan Assets	The changes in the benefit obligation of our post-retirement medical plan as of and for the year ended December 31, 2015 were as follows (in thousands): Year Ended December 31, 2015 Benefit obligation at the beginning of year $ 5,414 Service cost 370 Interest cost 212 Plan amendments — Plan termination (6,632 ) Actuarial loss (gain) 636 Projected benefit obligation at end of year $ —

Income (Loss) Per Share (Tables

Income (Loss) Per Share (Tables)	12 Months Ended
	Dec. 31, 2017
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 loss per share (in thousands, except per share amounts): Year Ended December 31, 2017 2016 2015 Net income (loss) $ 72,621 $ (45,835 ) $ (39,911 ) Less: Undistributed income allocated to participating securities (1) 878 — — Net income (loss) attributable to common stockholders 71,743 (45,835 ) (39,911 ) Plus: Net income effect of convertible securities — — — Numerator for diluted income (loss) per common share $ 71,743 $ (45,835 ) $ (39,911 ) Basic weighted-average common stock shares outstanding 45,543 42,349 37,678 Add dilutive effects of common stock equivalents (2) 40 — — Diluted weighted-average common stock shares outstanding 45,583 42,349 37,678 Basic income (loss) per common share $ 1.58 $ (1.08 ) $ (1.06 ) Diluted income (loss) per common share $ 1.57 $ (1.08 ) $ (1.06 ) ________________________________________________________ (1) Participating securities includes restricted stock that has been issued but has not yet vested. (2) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted loss per share for the years ended December 31, 2016 and 2015 .

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 2015 Current: U.S.—Federal $ — $ — $ — U.S.—State 2 23 — Foreign — — (299 ) Deferred: U.S.—Federal (1,321 ) (7,046 ) (14,685 ) U.S.—State — (889 ) (1,804 ) Foreign — — — Total $ (1,319 ) $ (7,912 ) $ (16,788 )
Schedule of Effective Income Tax Rate Reconciliation	Income tax expense was different from the amounts computed by applying U.S. Federal income tax rate of 35% to pretax income as a result of the following: Year Ended December 31, 2017 2016 2015 Federal statutory rate 35.0 % 35.0 % 35.0 % State income taxes, net of federal benefit — % 1.6 % 3.2 % Expiration of capital loss carryover — % (17.6 )% (25.5 )% Change in valuation allowance related to current activity (30.1 )% 9.2 % 25.3 % Change in valuation allowance related to change in tax rate (291.2 )% — % — % Change in tax rate 291.2 % — % — % Permanent items 1.1 % (5.7 )% (7.6 )% Provision to return adjustments and other (7.9 )% (7.8 )% (0.8 )% Actual income tax rate (1.9 )% 14.7 % 29.6 %
Schedule of Deferred Tax Assets and Liabilities	Deferred tax assets (liabilities) are comprised of the following (in thousands): December 31, 2017 2016 Deferred tax assets: Net operating loss $ 388,317 $ 611,631 Property and equipment 9,862 23,203 Other 10,263 10,868 Total deferred tax assets 408,442 645,702 Valuation allowance (383,253 ) (613,866 ) Net deferred tax assets 25,189 31,836 Deferred tax liabilities: Investment in Laramie Energy 18,140 20,600 Convertible notes 3,193 6,866 Intangible assets 3,978 2,671 Other 863 2,337 Total deferred tax liabilities 26,174 32,474 Total deferred tax liability, net $ (985 ) $ (638 )

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2017
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, 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) 141,068 15,010 45,941 — 202,019 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) $ 86,013 $ 33,993 $ 24,700 $ (50,748 ) $ 93,958 Interest expense and financing costs, net (31,632 ) Loss on termination of financing agreements (8,633 ) Other income, net 914 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 . For the year ended December 31, 2016 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 1,702,463 $ 102,779 $ 290,402 $ (230,599 ) $ 1,865,045 Cost of revenues (excluding depreciation) 1,580,014 65,439 220,545 (229,659 ) 1,636,339 Operating expense (excluding depreciation) 112,724 11,239 41,291 962 166,216 Depreciation, depletion, and amortization 17,565 4,679 6,372 3,001 31,617 General and administrative expense (excluding depreciation) — — — 42,073 42,073 Acquisition and integration costs — — — 5,294 5,294 Operating income (loss) $ (7,840 ) $ 21,422 $ 22,194 $ (52,270 ) $ (16,494 ) Interest expense and financing costs, net (28,506 ) Other expense, net (98 ) Change in value of common stock warrants 2,962 Change in value of contingent consideration 10,770 Equity losses from Laramie Energy, LLC (22,381 ) Loss before income taxes (53,747 ) Income tax benefit 7,912 Net loss $ (45,835 ) Total assets $ 772,438 $ 120,443 $ 122,570 $ 129,982 $ 1,145,433 Goodwill 53,037 36,145 16,550 — 105,732 Capital expenditures 15,106 1,344 4,375 4,008 24,833 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $271.9 million for the year ended December 31, 2016 . For the year ended December 31, 2015 Refining Logistics Retail Corporate, Eliminations, and Other (1) Total Revenues $ 1,895,662 $ 82,671 $ 283,507 $ (195,503 ) $ 2,066,337 Cost of revenues (excluding depreciation) 1,718,729 48,660 215,194 (195,215 ) 1,787,368 Operating expense (excluding depreciation) 95,588 5,433 35,317 5,283 141,621 Depreciation, depletion, and amortization 9,522 3,117 5,421 1,858 19,918 Impairment expense — — — 9,639 9,639 General and administrative expense (excluding depreciation) — — — 44,271 44,271 Acquisition and integration costs — — — 2,006 2,006 Operating income (loss) $ 71,823 $ 25,461 $ 27,575 $ (63,345 ) $ 61,514 Interest expense and financing costs, net (20,156 ) Loss on termination of financing agreements (19,669 ) Other expense, net (291 ) Change in value of common stock warrants (3,664 ) Change in value of contingent consideration (18,450 ) Equity losses from Laramie Energy, LLC (55,983 ) Loss before income taxes (56,699 ) Income tax benefit 16,788 Net loss $ (39,911 ) Total assets $ 516,482 $ 53,158 $ 115,544 $ 207,077 $ 892,261 Goodwill 13,765 11,012 16,550 — 41,327 Capital expenditures 8,573 6,089 3,643 4,040 22,345 ________________________________________________________ (1) Includes eliminations of intersegment revenues and cost of revenues of $330.0 million for the year ended December 31, 2015 .

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Summarized quarterly data for the years ended December 31, 2017 and 2016 consist of the following (in thousands, except per share amounts): Year Ended December 31, 2017 Q1 Q2 Q3 Q4 Revenues $ 605,253 $ 564,245 $ 610,506 $ 663,062 Operating income (loss) 29,189 16,451 26,716 21,602 Net income (loss) 27,786 7,006 18,824 19,005 Net income (loss) per share Basic $ 0.60 $ 0.15 $ 0.41 $ 0.41 Diluted $ 0.58 $ 0.15 $ 0.41 $ 0.41 Year Ended December 31, 2016 Q1 Q2 Q3 Q4 Revenues $ 377,812 $ 413,793 $ 510,305 $ 563,136 Operating income (loss) (19,719 ) (3,313 ) (21,784 ) 28,325 Net income (loss) (18,673 ) (13,088 ) (27,761 ) 13,687 Net income (loss) per share Basic $ (0.46 ) $ (0.32 ) $ (0.67 ) $ 0.30 Diluted $ (0.46 ) $ (0.32 ) $ (0.67 ) $ 0.30

Disclosures About Capitalized C

Disclosures About Capitalized Costs, Costs Incurred (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
Extractive Industries [Abstract]
Oil And Gas Property Successful Effort Method	Capitalized costs related to oil and gas activities are as follows (in thousands): December 31, 2017 2016 Company: Unproved properties $ — $ — Proved properties 400 1,122 400 1,122 Accumulated depreciation and depletion (275 ) (930 ) Total $ 125 $ 192 Company’s share of Laramie Energy: Unproved properties $ 13,728 $ 14,416 Proved properties 382,789 334,085 396,517 348,501 Accumulated depreciation, depletion, and amortization (111,119 ) (91,454 ) Total $ 285,398 $ 257,047
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands): Year Ended December 31, 2017 2016 2015 Company: Development costs—other $ — $ — $ — Total $ — $ — $ — Company’s share of Laramie Energy: Acquisition costs $ — $ 65,324 $ — Development costs—other 49,273 12,805 21,747 Total $ 49,273 $ 78,129 $ 21,747
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, 2017 2016 2015 Company: Revenue Oil and gas revenues $ 288 $ 190 $ 2,019 Expenses Production costs 29 147 5,283 Depletion and amortization 66 69 42 Exploration — — — Abandoned and impaired properties — — — Results of operations of oil and gas producing activities $ 193 $ (26 ) $ (3,306 ) Company’s share of Laramie Energy: Revenue Oil and gas revenues $ 66,783 $ 43,607 $ 14,217 Expenses Production costs 32,606 27,750 11,047 Impairment of unproved properties — — 3,977 Depletion, depreciation, and amortization 21,277 17,534 8,226 Results of operations of oil and gas producing activities $ 12,900 $ (1,677 ) $ (9,033 ) Total results of operations of oil and gas producing activities $ 13,093 $ (1,703 ) $ (12,339 )

Information Regarding Proved Oi

Information Regarding Proved Oil and Gas Reserves (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 , 2016 , and 2015 is as follows: Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) Company: Balance at January 1, 2015 601 77 17 1,165 Revisions of quantity estimate (330 ) (35 ) (15 ) (630 ) Extensions and discoveries — — — — Production (83 ) (36 ) (2 ) (311 ) Balance at December 31, 2015 (2) 188 6 — 224 Revisions of quantity estimate 196 3 8 262 Extensions and discoveries — — — — Production (54 ) (2 ) — (66 ) Balance at December 31, 2016 (3) 330 7 8 420 Revisions of quantity estimate 109 2 3 139 Extensions and discoveries — — — — Production (47 ) (2 ) — (59 ) Balance at December 31, 2017 (4) 392 7 11 500 Company’s share of Laramie Energy: Balance at January 1, 2015, as revised (5) 192,015 684 5,444 228,788 Revisions of quantity estimate (86,092 ) (295 ) (2,281 ) (101,553 ) Extensions and discoveries 32,041 131 1,007 38,869 Acquisitions and divestures (5,945 ) (20 ) (171 ) (7,091 ) Production (4,745 ) (20 ) (149 ) (5,759 ) Balance at December 31, 2015, as revised (2) (5) 127,274 480 3,850 153,254 Revisions of quantity estimate 28,195 53 526 31,672 Extensions and discoveries 638 1 19 758 Acquisitions and divestures 168,887 492 4,701 200,045 Production (15,192 ) (59 ) (552 ) (18,858 ) Balance at December 31, 2016, as revised (3) (5) 309,802 967 8,544 366,871 Revisions of quantity estimate 1,344 211 (434 ) 3 Extensions and discoveries (4) — — — — Acquisitions and divestures — — — — Production (18,104 ) (71 ) (608 ) (22,178 ) Balance at December 31, 2017 (4) 293,042 1,107 7,502 344,696 Total at December 31, 2017 293,434 1,114 7,513 345,196 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) During 2015 , the Company's estimated proved reserves, inclusive of the Company's share of Laramie Energy's estimated proved reserves, decreased by 76,475 MMcfe or approximately 33% . Revisions of quantity estimates related to our share of Laramie Energy's estimated proved reserves resulted in a decrease of 101,553 MMcfe from the beginning of year reserves. These revisions of quantity estimate are primarily associated with wells becoming uneconomic during 2015. (3) During 2016 , the Company's estimated proved reserves, inclusive of the Company's share of Laramie Energy's estimated proved reserves, increased by 213,813 MMcfe or approximately 139% . Acquisitions and divestitures related to our share of Laramie Energy's estimated proved reserves resulted in an increase of 200,045 MMcfe from the beginning of year reserves. This increase was primarily due to Laramie Energy's acquisition of properties in the Piceance Basin for $152.1 million in March 2016 . Please read Note 3—Investment in Laramie Energy, LLC for more information. The increase of 31,672 MMcfe in Revisions of quantity estimate related to our share of Laramie Energy's estimated proved reserves is primarily due to wells that became economic as a result of increased operator efficiency and cost reductions. (4) 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. Beginning in 2017, Par has decided to base its determination of Laramie Energy proved undeveloped reserves on only a two year drilling and three year completion time horizon, which has resulted in negative revisions to our proved reserves of 17,216 MMcfe during 2017. The Company's share of Laramie Energy's revisions of quantity estimate also includes 30,362 MMcfe of positive revisions associated with 44 probable locations that were converted to proved developed reserves during 2017. These 44 locations converted to proved reserves during 2017 were not considered extensions because they were drilled in proved areas that are slightly offset to other proved locations. The remaining decrease 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. (5) We have revised our previously disclosed proved reserves quantities as of December 31, 2016, 2015, and 2014 to remove certain proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016, 2015, and 2014. Par’s share of Laramie Energy's proved undeveloped reserves from the removed proved undeveloped locations was 19,307 MMcfe, 7,587 MMcfe, and 23,786 MMcfe, representing 5% , 5% , and 9% of total proved reserves as of December 31, 2016, 2015, and 2014, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods. Gas Oil NGLS Total (MMcf) (Mbbl) (Mbbl) (MMcfe) (1) December 31, 2015 Proved developed reserves Company 188 6 — 224 Company's share of Laramie Energy 65,499 248 1,931 78,573 Total 65,687 254 1,931 78,797 Proved undeveloped reserves Company — — — — Company's share of Laramie Energy (2) 61,775 232 1,919 74,681 Total 61,775 232 1,919 74,681 December 31, 2016 Proved developed reserves Company 330 7 8 420 Company's share of Laramie Energy 159,500 516 4,349 188,690 Total 159,830 523 4,357 189,110 Proved undeveloped reserves Company — — — — Company's share of Laramie Energy (2) 150,302 451 4,195 178,181 Total 150,302 451 4,195 178,181 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 __________________________________________________ (1) MMcfe is based on a ratio of 6 Mcf to 1 barrel. (2) We have revised our previously disclosed proved undeveloped reserves quantities as of December 31, 2016 and 2015 to remove certain proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016 and 2015. Par’s share of Laramie Energy's proved undeveloped reserves from the removed proved undeveloped locations was 19,307 MMcfe and 7,587 MMcfe as of December 31, 2016 and 2015, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods. Price per MMbtu (2) WTI per Bbl Base pricing, before adjustments for contractual December 31, 2015 $ 2.39 $ 50.28 December 31, 2016 2.29 42.75 December 31, 2017 2.68 51.34 ______________________________________________ (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. (2) The CIG index was used for pricing during 2015. In 2017 and 2016 , pricing is based on the Northwest spot price index.
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, 2017 2016 2015 (in thousands) Company: Future net cash flows $ 1,802 $ 1,154 $ 690 Future costs Production 902 713 345 Development and abandonment — 2 25 Income taxes (1) — — — Future net cash flows 900 439 320 10% discount factor (328 ) (154 ) (128 ) Discounted future net cash flows $ 572 $ 285 $ 192 Company’s share of Laramie Energy: (2) Future net cash flows $ 1,026,005 $ 905,607 $ 405,365 Future costs Production 491,748 462,684 238,129 Development and abandonment 109,248 136,224 67,443 Income taxes (1) — — — Future net cash flows 425,009 306,699 99,793 10% discount factor (209,188 ) (165,557 ) (60,188 ) Discounted future net cash flows $ 215,821 $ 141,142 $ 39,605 Total discounted future net cash flows $ 216,393 $ 141,427 $ 39,797 _______________________________________________ (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. (2) We have revised our previously disclosed discounted future net cash flows as of December 31, 2016 and 2015 to reflect the removal of Laramie Energy's proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016 and 2015. Par’s share of Laramie Energy's discounted future net cash flows from the removed locations was $1.8 million and $0.4 million , representing 1% and 1% of total discounted future net cash flows as of December 31, 2016 and 2015, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods.
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, 2017 , 2016 , and 2015 are as follows (in thousands): Company Company's Share Total Balance at January 1, 2015 (1) $ 1,766 $ 160,671 $ 162,437 Sales of oil and gas production during the period, net of production costs (479 ) (5,753 ) (6,232 ) Acquisitions and divestitures — (4,789 ) (4,789 ) Net change in prices and production costs (679 ) (153,564 ) (154,243 ) Changes in estimated future development costs 8 788 796 Extensions, discoveries, and improved recovery — 9,273 9,273 Revisions of previous quantity estimates, estimated timing of development and other (601 ) 911 310 Previously estimated development and abandonment costs incurred during the period — 15,008 15,008 Accretion of discount 177 17,060 17,237 Balance at December 31, 2015 (1) 192 39,605 39,797 Sales of oil and gas production during the period, net of production costs (62 ) (7,979 ) (8,041 ) Acquisitions and divestitures — 81,066 81,066 Net change in prices and production costs (20 ) 2,994 2,974 Changes in estimated future development costs 14 (8,575 ) (8,561 ) Extensions, discoveries, and improved recovery — 231 231 Revisions of previous quantity estimates, estimated timing of development and other 142 16,995 17,137 Previously estimated development and abandonment costs incurred during the period — 12,805 12,805 Accretion of discount 19 4,000 4,019 Balance at December 31, 2016 (1) 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 _______________________________________________ (1) We have revised our previously disclosed discounted future net cash flows as of December 31, 2016, 2015, and 2014 to reflect the removal of Laramie Energy's proved undeveloped locations scheduled for completion more than 5 years from initial booking that were classified as proved undeveloped reserves as of December 31, 2016, 2015, and 2014. Par’s share of Laramie Energy's discounted future net cash flows from the removed locations was $1.8 million , $0.4 million , and $9.9 million , representing 1% , 1% , and 6% of total discounted future net cash flows as of December 31, 2016, 2015, and 2014, respectively. These prior period revisions are not material to our consolidated financial statements for the respective periods.

Overview - Additional Informati

Overview - Additional Information (Detail) - segment	12 Months Ended
	Dec. 31, 2017	Mar. 01, 2016	Feb. 29, 2016	Jul. 31, 2015	Jul. 30, 2015	May 29, 2015	May 28, 2015
Operating segments	3
Laramie Energy Company
Ownership of Laramie Energy, LLC	42.30%	42.30%	32.40%	32.40%	34.00%	34.00%	33.34%

Summary of Significant Accoun56

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Amortization period of planned major maintenance activities, minimum		3 years
Amortization period of planned major maintenance activities, maximum		5 years
Deferred turnaround expenditures	$ 32,700,000	$ 0	$ 32,661,000	$ 0
Cost of revenues		6,029,000	4,604,000	3,017,000
Operating expense		22,861,000	16,340,000	11,428,000
General and administrative expense		$ 2,929,000	$ 2,108,000	$ 855,000
Refining Equipment | Minimum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life		8 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		14 years
Retail Site | Maximum
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life		18 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
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life		3 years

Investment in Laramie Energy -

Investment in Laramie Energy - Additional Information (Detail) - USD ($)	Mar. 01, 2016	Jul. 31, 2015	May 29, 2015	Mar. 09, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 29, 2016	Jul. 30, 2015	May 28, 2015
Schedule of Equity Method Investments [Line Items]
Investment in Laramie Energy, LLC					$ 0	$ 55,000,000	$ 27,529,000
Depreciation, depletion, and amortization					45,989,000	31,617,000	19,918,000
Unrealized gain (loss) on derivative contracts					$ 989,000	15,479,000	(10,896,000)
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Ownership of Laramie Energy, LLC	42.30%	32.40%	34.00%		42.30%			32.40%	34.00%	33.34%
Investment in Laramie Energy, LLC			$ 13,800,000	$ 13,800,000
Other than temporary impairment charge					$ 0	0	(41,081,000)
Aggregate cash purchase price	$ 55,000,000				0	55,000,000	27,529,000
Depreciation, depletion, and amortization					50,300,000	42,700,000	24,600,000
Unrealized gain (loss) on derivative contracts					46,200,000	(34,500,000)	16,600,000
Impairment of unproved properties							$ 12,300,000
Amount of equity in underlying assets exceeding carrying value					$ 67,200,000	69,900,000
Amortization of natural gas and oil properties					15 years
Unaffiliated Third Party | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Investment in Laramie Energy, LLC		$ 19,000,000
Piceance Basin | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Investment in Laramie Energy, LLC	$ 152,100,000
Revolving Credit Facility | Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Line credit maximum borrowing amount					$ 400,000,000
Asset borrowing base currently at					230,000,000
Balance outstanding on the revolving credit facility					$ 171,500,000	$ 117,500,000

Investment in Laramie Energy 58

Investment in Laramie Energy - Change in Equity Investment (Detail) - USD ($) $ in Thousands	Mar. 01, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance		$ 108,823
Equity earnings (losses) from Laramie Energy, LLC		18,369	$ (22,381)	$ (55,983)
Ending balance		127,192	108,823
Laramie Energy Company
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance		108,823	76,203	104,657
Equity earnings (losses) from Laramie Energy, LLC		13,043	(28,198)	(15,713)
Accretion of basis difference		5,326	5,818	811
Impairment		0	0	(41,081)
Investments	$ 55,000	0	55,000	27,529
Ending balance		$ 127,192	$ 108,823	$ 76,203

Investment in Laramie Energy 59

Investment in Laramie Energy - Summarized Financial Information (Detail) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
ASSETS
Current assets	$ 603,544				$ 403,108				$ 603,544	$ 403,108
Current liabilities	470,952				382,765				470,952	382,765
Income (loss) from operations	21,602	$ 26,716	$ 16,451	$ 29,189	28,325	$ (21,784)	$ (3,313)	$ (19,719)	93,958	(16,494)	$ 61,514
Net income (loss)	19,005	$ 18,824	$ 7,006	$ 27,786	13,687	$ (27,761)	$ (13,088)	$ (18,673)	72,621	(45,835)	(39,911)
Laramie Energy Company
ASSETS
Current assets	18,757				12,199				18,757	12,199
Non-current assets	720,444				655,022				720,444	655,022
Current liabilities	42,149				58,067				42,149	58,067
Non-current liabilities	$ 237,497				$ 186,631				237,497	186,631
Natural gas and oil revenues									157,879	104,826	42,870
Income (loss) from operations									6,019	(27,325)	(40,984)
Net income (loss)									$ 30,837	$ (61,849)	$ (49,159)

Acquisitions - Wyoming Refining

Acquisitions - Wyoming Refining Company Acquisition (Details) - USD ($)	Jul. 14, 2016	Jun. 30, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Apr. 01, 2015
Business Acquisition [Line Items]
Adjustment to goodwill												$ (600,000)
Goodwill			$ 107,187,000				$ 105,732,000				$ 107,187,000	105,732,000	$ 41,327,000
Acquisition and integration expense											395,000	5,294,000	2,006,000
Revenues											2,443,066,000	1,865,045,000	2,066,337,000
Net loss			$ 19,005,000	$ 18,824,000	$ 7,006,000	$ 27,786,000	$ 13,687,000	$ (27,761,000)	$ (13,088,000)	$ (18,673,000)	72,621,000	(45,835,000)	$ (39,911,000)
Wyoming Refining Company
Business Acquisition [Line Items]
Payments to acquire businesses	$ 209,400,000
Adjustment to WRC environmental liability (other non-current liabilities)					2,000,000
Adjustment to inventory					500,000
Adjustment to goodwill					$ 1,500,000						$ 1,455,000
Goodwill	66,449,000
Acquisition and integration expense												700,000
Revenues												174,600,000
Net loss												$ 700,000
Other Long Term Assets | Wyoming Refining Company
Business Acquisition [Line Items]
Deposit to acquire businesses		$ 5,000,000
5% Convertible Senior Notes due 2021
Business Acquisition [Line Items]
Debt instrument, interest rate		5.00%	5.00%						5.00%		5.00%
Convertible Debt | Convertible Subordinated Bridge Notes
Business Acquisition [Line Items]
Debt instrument, interest rate			2.50%								2.50%
Convertible Debt | 5% Convertible Senior Notes due 2021
Business Acquisition [Line Items]
Debt instrument, interest rate			5.00%				0.50%				5.00%	0.50%
Debt instrument, face amount		$ 115,000,000							$ 115,000,000
Secured Debt | Wyoming Refining Company
Business Acquisition [Line Items]
Wyoming Refining Senior Secured Debt	(58,036,000)
Refining
Business Acquisition [Line Items]
Goodwill														$ 13,500,000
Refining | Wyoming Refining Company
Business Acquisition [Line Items]
Goodwill	39,800,000
Logistics
Business Acquisition [Line Items]
Goodwill														$ 10,800,000
Logistics | Wyoming Refining Company
Business Acquisition [Line Items]
Goodwill	26,600,000
Revolving Credit Facility | Wyoming Refining Senior Secured Revolver | Wyoming Refining Company
Business Acquisition [Line Items]
Wyoming Refining Senior Secured Debt	(10,100,000)
Secured Debt | Wyoming Refining Company
Business Acquisition [Line Items]
Debt instrument, face amount	$ 65,000,000

Acquisitions - Summary of Asset

Acquisitions - Summary of Assets Acquired and Liabilities Assumed (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Jul. 14, 2016	Dec. 31, 2015	Apr. 01, 2015
Goodwill	$ 107,187	$ 105,732		$ 41,327
Wyoming Refining Company
Cash			$ 183
Accounts receivable			16,880
Inventories			28,402
Prepaid and other assets			1,304
Property, plant and equipment			254,367
Goodwill			66,449
Accounts payable and other current liabilities			(57,861)
Other non-current liabilities			(32,222)
Total			209,366
Wyoming Refining Company | Secured Debt
Wyoming Refining Senior Secured Debt			(58,036)
Mid Pac Petroleum, LLC
Cash					$ 10,007
Accounts receivable					9,905
Inventories					5,375
Prepaid and other current assets					1,444
Property, plant and equipment					40,997
Land					34,800
Goodwill					26,942
Intangible assets					33,647
Other non-current assets					1,228
Accounts payable and other current liabilities					(10,742)
Deferred tax liability				$ (16,800)	(16,759)
Other non-current liabilities					(7,235)
Total					$ 129,609
Wyoming Refining Senior Secured Revolver | Wyoming Refining Company | Revolving Credit Facility
Wyoming Refining Senior Secured Debt			$ (10,100)

Acquisitions - Unaudited Pro Fo

Acquisitions - Unaudited Pro Forma Financial Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Wyoming Refining Company
Business Acquisition [Line Items]
Revenues	$ 2,026,237	$ 2,369,513
Net loss	$ (51,239)	$ (51,582)
Earnings Per Share [Abstract]
Basic (in dollars per share)	$ (1.21)	$ (1.24)
Diluted (in dollars per share)	$ (1.21)	$ (1.24)
Mid Pac Petroleum, LLC
Business Acquisition [Line Items]
Revenues		$ 2,093,587
Net loss		$ (54,941)

Acquisitions - Mid Pac Acquisit

Acquisitions - Mid Pac Acquisition (Detail) - USD ($) $ in Thousands	Apr. 01, 2015	Sep. 30, 2015	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Business Acquisition [Line Items]
Long-term debt			$ 384,812				$ 370,396				$ 384,812	$ 370,396
Goodwill			107,187				105,732				107,187	105,732	$ 41,327
Acquisition related costs											395	5,294	2,006
Revenues											2,443,066	1,865,045	2,066,337
Net income (loss)			$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	(39,911)
Mid Pac Petroleum, LLC
Business Acquisition [Line Items]
Cash consideration	$ 74,400
Working capital settlement amount		$ 1,000
Advanced deposit	15,000													$ 10,000
Goodwill	26,942
Acquisition related costs													800
Revenues													147,600
Net income (loss)													$ 10,600
Mid Pac Petroleum, LLC | Mid Pac Petroleum, LLC
Business Acquisition [Line Items]
Long-term debt	45,300
Mid Pac Credit Agreement | Mid Pac Petroleum, LLC
Business Acquisition [Line Items]
Long-term debt	$ 55,000
Par Hawaii Inc. | Mid Pac Petroleum, LLC
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Refining
Business Acquisition [Line Items]
Goodwill	$ 13,500
Retail
Business Acquisition [Line Items]
Goodwill	2,700
Logistics
Business Acquisition [Line Items]
Goodwill	$ 10,800

Inventories (Detail)

Inventories (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Crude oil and feedstocks	$ 149,984	$ 61,302
Refined products and blendstock	172,422	116,593
Warehouse stock and other	22,951	20,431
Total	345,357	198,326
Reserves for the lower of cost or market value of inventory	0	200
Titled Inventory
Crude oil and feedstocks	93,970	11,620
Refined products and blendstock	63,505	38,916
Warehouse stock and other	22,951	20,431
Total	180,426	70,967
Supply and Offtake Agreements
Crude oil and feedstocks	56,014	49,682
Refined products and blendstock	108,917	77,677
Warehouse stock and other	0	0
Total	$ 164,931	$ 127,359

Prepaid and Other Current Ass65

Prepaid and Other Current Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Advances to suppliers for crude oil purchases	$ 0	$ 38,300
Collateral posted with broker for derivative instruments	215	2,714
Prepaid insurance	7,547	7,504
Derivative assets	4,296	161
Other	5,221	4,701
Total	$ 17,279	$ 53,380

Property, Plant and Equipment (

Property, Plant and Equipment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Land	$ 79,330	$ 76,437
Buildings and equipment	433,977	412,999
Other	15,931	10,431
Total property, plant and equipment	529,238	499,867
Proved oil and gas properties	400	1,122
Less accumulated depreciation and depletion	(79,622)	(49,727)
Property, plant and equipment, net	450,016	451,262
Depreciation and depletion expense	$ 31,800	$ 23,100	$ 15,300

Asset Retirement Obligations (D

Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation - beginning of period	$ 9,042	$ 8,909	$ 2,580
Obligations acquired	0	0	5,725
Accretion expense	369	362	604
Liabilities settled during period	(308)	(229)	0
Asset retirement obligation - end of period	$ 9,103	$ 9,042	$ 8,909

Goodwill and Intangible Asset68

Goodwill and Intangible Assets - Schedule of Goodwill (Detail) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Goodwill [Roll Forward]
Balance at beginning of period		$ 105,732	$ 41,327
Acquisition during period			64,994
Adjustment to goodwill			(600)
Balance at end of period		107,187	105,732
Mid Pac Petroleum, LLC
Goodwill [Roll Forward]
Adjustment to goodwill			$ (589)
Wyoming Refining Company
Goodwill [Roll Forward]
Adjustment to goodwill	$ 1,500	$ 1,455

Goodwill and Intangible Asset69

Goodwill and Intangible Assets - Schedule of Finite-Lived Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	$ 41,580	$ 41,580
Accumulated amortization of intangible assets	(14,976)	(11,668)
Amortized intangible assets, Net	26,604	29,912
Railcar Leases
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	3,249	3,249
Accumulated amortization of intangible assets	(3,249)	(2,599)
Amortized intangible assets, Net	0	650
Trade names and trademarks
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	6,267	6,267
Accumulated amortization of intangible assets	(4,951)	(4,864)
Amortized intangible assets, Net	1,316	1,403
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	32,064	32,064
Accumulated amortization of intangible assets	(6,776)	(4,205)
Amortized intangible assets, Net	$ 25,288	$ 27,859

Goodwill and Intangible Asset70

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Goodwill [Line Items]
Amortization expense	$ 3.3	$ 4.5	$ 4.4
Supplier relationships | Texadian
Goodwill [Line Items]
Goodwill, impairment loss			7
Impairment of intangible assets			$ 2.6
Mid Pac Petroleum, LLC
Goodwill [Line Items]
Average useful life	13 years 7 months

Goodwill and Intangible Asset71

Goodwill and Intangible Assets - Finite-lived Intangible Assets Amortization Expense (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
2,018	$ 2,658
2,019	2,658
2,020	2,658
2,021	2,658
2,022	2,658
Thereafter	13,314
Amortized intangible assets, Net	$ 26,604	$ 29,912

Inventory Financing Agreements(

Inventory Financing Agreements(Textual) (Detail) barrel / d in Thousands	May 08, 2017	Jun. 01, 2015USD ($)barrel / d	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)payment	May 31, 2021USD ($)	Dec. 21, 2017	Feb. 29, 2016USD ($)installment
Supply and exchange agreement expenses			$ 31,632,000	$ 28,506,000	$ 20,156,000
Supply and Offtake Agreements
Commitment period	1 year
Barrels of crude per day provided by J. Aron | barrel / d		94
Debt instrument, interest rate	7.00%
Handling fees			13,700,000	7,800,000	6,900,000
Supply and exchange agreement expenses			2,300,000	$ 3,200,000	1,500,000
Amount of deferred payment arrangement		$ 125,000,000
Percentage of receivables and inventory for deferred payment		85.00%
Deferral arrangement fee		$ 1,300,000
Current borrowing capacity			83,100,000
Outstanding amount of deferred payment arrangement			41,100,000
Fee agreement receivable			$ 7,100,000		$ 18,000,000			$ 14,600,000
Number of fee agreement payments					14			18
Supply and Exchange Agreements
Handling fees					$ 6,900,000
Supply and exchange agreement expenses					2,300,000
Loss on termination of financing agreements					17,400,000
Price variance loss commitment					13,300,000
Accelerated deferred financing costs					5,600,000
Exit fee received					$ 1,500,000
London Interbank Offered Rate (LIBOR) | Supply and Offtake Agreements
Margin on LIBOR rate		3.75%
Deferred payment availability fee		0.75%
Scenario, Forecast | Supply and Offtake Agreements
Fee agreement receivable						$ 2,200,000
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%

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 21, 2017	Dec. 31, 2016	Jun. 30, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 415,000		$ 400,420
Less: unamortized discount and deferred financing costs	(30,188)		(30,024)
Total debt, net of unamortized debt discount	384,812		370,396
Less current maturities	0		(20,286)
Long-term debt, net of current maturities and unamortized discount	384,812		350,110
Hawaii Retail Credit Agreement
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 0		95,319
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%
Tranche B Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 0		60,361
Par Wyoming Holdings Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	0		67,325
Wyoming Refining Senior Secured Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt	0		55,715
Wyoming Refining Senior Secured Revolver
Debt Instrument [Line Items]
Principal amount of long-term debt	0		6,700
Convertible Debt | 5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Principal amount of long-term debt	115,000		$ 115,000
Less: unamortized discount and deferred financing costs	$ (19,500)
Debt instrument, interest rate	5.00%		0.50%
Senior Notes | 7.75% Senior Secured Note due 2025
Debt Instrument [Line Items]
Principal amount of long-term debt	$ 300,000	$ 300,000	$ 0
Debt instrument, interest rate	7.75%	7.75%

Debt - Long-Term Debt Maturitie

Debt - Long-Term Debt Maturities (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
2,018	$ 0
2,019	0
2,020	0
2,021	115,000
2,022	0
Thereafter	300,000
Total debt, net of unamortized debt discount	$ 415,000	$ 400,420

Debt - 7.75% Senior Secured Not

Debt - 7.75% Senior Secured Notes Due 2025 (Details) - USD ($) $ in Thousands	Dec. 21, 2017	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Principal amount of long-term debt		$ 415,000	$ 400,420
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	$ 0
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 ($)	12 Months Ended
	Dec. 31, 2017	Dec. 21, 2017
Revolving Credit Facility | ABL Credit Facility
Debt Instrument [Line Items]
Line credit maximum borrowing amount		$ 75,000,000
Revolving Credit Facility | ABL Revlover
Debt Instrument [Line Items]
Line of credit facility, borrowing base	$ 48,700,000
Borrowing Base Greater than 50% | London Interbank Offered Rate (LIBOR) | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	1.75%
Borrowing Base Greater than 50% | Prime Rate | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	0.75%
Borrowing Base Greater than 30% and less than or Equal to 50% | London Interbank Offered Rate (LIBOR) | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	2.00%
Borrowing Base Greater than 30% and less than or Equal to 50% | Prime Rate | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	1.00%
Borrowing Base Less Than or Equal to 30% | London Interbank Offered Rate (LIBOR) | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	2.25%
Borrowing Base Less Than or Equal to 30% | Prime Rate | ABL Revlover
Debt Instrument [Line Items]
Debt instrument margin rate	1.25%

Debt - J. Aron Forward Sale (De

Debt - J. Aron Forward Sale (Details) - USD ($) $ in Thousands	Dec. 21, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	May 08, 2017
Debt Instrument [Line Items]
Cost associated with termination of debt		$ 8,633	$ 0	$ 19,669
Supply and Offtake Agreements
Debt Instrument [Line Items]
Purchase And supply commitment, forward sale amount					$ 30,000
Debt instrument, interest rate					7.00%
Cost associated with termination of debt	$ 300

Debt - Par Wyoming Holdings Cre

Debt - Par Wyoming Holdings Credit Agreement (Details) - USD ($)	Dec. 21, 2017	Jul. 14, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Cost associated with termination of debt			$ 8,633,000	$ 0	$ 19,669,000
Wyoming Refining Company | 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 | Wyoming Refining Company
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	Apr. 30, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Cost associated with termination of debt			$ 8,633,000	$ 0	$ 19,669,000
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 - 5% Convertible Senior No

Debt - 5% Convertible Senior Note Due 2021 (Details)	Jun. 27, 2016USD ($)shares	Jun. 21, 2016USD ($)$ / shares	Jun. 30, 2016USD ($)day	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 15, 2016USD ($)
Debt Instrument [Line Items]
Proceeds from borrowings				$ 616,706,000	$ 354,682,000	$ 208,158,000
Principal amount of long-term debt				415,000,000	400,420,000
Unamortized discount (premium) and debt issuance costs				$ 30,188,000	30,024,000
5% Convertible Senior Notes due 2021
Debt Instrument [Line Items]
Debt instrument, interest rate			5.00%	5.00%
Tranche B Term Loan
Debt Instrument [Line Items]
Principal amount of long-term debt				$ 0	$ 60,361,000
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
Debt instrument, interest rate				5.00%	0.50%
Conversion rate	55.5556
Number of equity instruments | shares	6,388,894
Conversion price | $ / shares		$ 18
Threshold percentage of stock price trigger	140.00%
Threshold trading days | day			20
Threshold consecutive trading days			30 days
Redemption price, percentage	100.00%
Long-term debt, fair value	$ 89,300,000
Carrying amount of equity component	22,200,000
If-converted value in excess of principal				$ 8,200,000
Principal amount of long-term debt				115,000,000	$ 115,000,000
Unamortized discount (premium) and debt issuance costs				19,500,000
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				$ 95,486,000	$ 91,029,000

Debt - Hawaii Retail Credit Fac

Debt - Hawaii Retail Credit Facilities (Details) - USD ($)	Dec. 21, 2017	Dec. 31, 2017	Dec. 21, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 17, 2015
Debt Instrument [Line Items]
Cost associated with termination of debt		$ 8,633,000		$ 0	$ 19,669,000
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
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 - Bridge Notes (Details)

Debt - Bridge Notes (Details) - USD ($) $ / shares in Units, $ in Thousands	Sep. 22, 2016	Dec. 31, 2016	Dec. 31, 2015	Jul. 14, 2016
Debt Instrument [Line Items]
Issuance of common stock, net of offering costs		$ 49,044	$ 76,056
Bridge Loan
Debt Instrument [Line Items]
Debt instrument, face amount	$ 3,100			$ 52,600
Accrued interest, increase	300
Deferred finance costs, net	$ 3,000
Bridge Loan | Rights Offering
Debt Instrument [Line Items]
Shares subscribed but unissued	4,000,000
Issuance of common stock, net of offering costs	$ 49,900
Common Stock | Bridge Loan | Rights Offering
Debt Instrument [Line Items]
Conversion of Bridge Notes (in shares)	272,733
Conversion price	$ 12.25

Debt - Term Loan (Details)

Debt - Term Loan (Details) - USD ($)	Jun. 21, 2016	Jul. 11, 2014	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Sep. 22, 2016	Jun. 15, 2016
Debt Instrument [Line Items]
Financing costs expensed			$ 8,633,000	$ 0	$ 19,669,000
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
Debt Instrument [Line Items]
Deferred finance costs, net						$ 3,000,000
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%
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)	Sep. 02, 2016USD ($)
Debt Disclosure [Abstract]
Initial offering price	$ 750,000,000

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) bbl in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)bbl	Dec. 31, 2016	Jun. 30, 2016USD ($)
Options Collar | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	60
Options Collars and Swaps | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	15
Interest Rate Swap
Credit Derivatives [Line Items]
Fixed interest rate	1.10%
Notional amount | $	$ 200,000,000
Long | Commodity Contract | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	200
Long | Energy Related Derivative | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	321
Long | Options Collars and Swaps | Over the Counter
Credit Derivatives [Line Items]
Derivative contracts, barrels	140
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%	0.50%

Derivatives - Schedule of Deriv

Derivatives - Schedule of Derivatives Fair Value Amounts (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Prepaid Expenses and Other Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	$ 200	$ 2,700
Other Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Cash collateral	7,000	7,000
Commodity Contract | Prepaid Expenses and Other Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	2,814	0
Commodity Contract | Other Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	0	2,748
Commodity Contract | Other Accrued Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	(39)	(595)
Interest rate derivatives | Prepaid Expenses and Other Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	1,482	161
Interest rate derivatives | Other Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	2,328	3,377
Interest rate derivatives | Other Accrued Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	0	(94)
Over the Counter | J. Aron repurchase obligation derivative | Obligations under Inventory Financing Agreements
Derivative Instruments, Gain (Loss) [Line Items]
Asset (Liability)	$ (19,564)	$ (20,000)

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Commodity derivatives | Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Cost of revenues	$ (4,517)	$ (1,338)	$ 14,367
J. Aron repurchase obligation derivative | Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Cost of revenues	436	(29,810)	12,654
Interest rate derivatives | Interest Expense
Derivative Instruments, Gain (Loss) [Line Items]
Cost of revenues	$ 489	$ 2,729	$ 0

Fair Value Measurements - Asset

Fair Value Measurements - Assets Acquired and Liabilities Assumed (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Jul. 14, 2016	Dec. 31, 2015	Apr. 01, 2015
Goodwill	$ 107,187	$ 105,732		$ 41,327
Deferred tax liability	$ (985)	$ (638)
Wyoming Refining Company
Net working capital			$ (11,092)
Goodwill			66,449
Long-term debt			(68,136)
Other non-current liabilities			(32,222)
Total			209,366
Wyoming Refining Company | Property, Plant and Equipment
Property, plant and equipment			$ 254,367
Mid Pac Petroleum, LLC
Net working capital					$ 15,989
Goodwill					26,942
Intangible assets					33,647
Other non-current assets					1,228
Deferred tax liability					(16,759)
Other non-current liabilities					(7,235)
Total					129,609
Mid Pac Petroleum, LLC | Property, Plant and Equipment
Property, plant and equipment					40,997
Mid Pac Petroleum, LLC | Land
Property, plant and equipment					$ 34,800

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2016
Laramie Energy Company
Schedule of Equity Method Investments [Line Items]
Other than temporary impairment charge	$ 0	$ 0	$ 41,081
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 - Commo

Fair Value Measurements - Common Stock Warrants (Detail) - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average exercise price	$ 0.09
Term (years)	4 years 8 months
Fair value of common stock warrants	$ 19.21	$ 14.49
Warrant
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock warrants outstanding (in shares)	354,350	354,350

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, 2017	Dec. 31, 2016
Liabilities
Common stock warrants	$ (6,808)	$ (5,134)
Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	26,274	29,887
Derivative asset, fair value, gross liability	(19,650)	(23,601)
Derivative asset	6,624	6,286
Liabilities
Fair value of derivative liability	(46,061)	(49,424)
Derivative liability, fair value, gross asset	19,650	23,601
Derivative liability	(26,411)	(25,823)
Cash collateral	7,200	9,700
Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	3,810	3,602
Derivative asset, fair value, gross liability	0	(64)
Derivative asset	3,810	3,538
Liabilities
Fair value of derivative liability		(158)
Derivative liability, fair value, gross asset		64
Derivative liability		(94)
Fair Value, Inputs, Level 1 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	557	190
Liabilities
Fair value of derivative liability	(596)	(54)
Fair Value, Inputs, Level 1 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	0	0
Liabilities
Fair value of derivative liability		0
Fair Value, Inputs, Level 2 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	25,717	29,697
Liabilities
Fair value of derivative liability	(19,093)	(24,236)
Fair Value, Inputs, Level 2 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	3,810	3,602
Liabilities
Fair value of derivative liability		(158)
Fair Value, Inputs, Level 3 | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	0	0
Liabilities
Fair value of derivative liability	(26,372)	(25,134)
Fair Value, Inputs, Level 3 | Interest rate derivatives | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	0	0
Liabilities
Fair value of derivative liability		0
Exchange Traded | Future | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	22,464	26,285
Derivative asset, fair value, gross liability	(19,650)	(23,537)
Derivative asset	2,814	2,748
Liabilities
Fair value of derivative liability	(19,689)	(24,132)
Derivative liability, fair value, gross asset	19,650	23,537
Derivative liability	(39)	(595)
Exchange Traded | J. Aron repurchase obligation derivative | Fair Value, Measurements, Recurring
Liabilities
Fair value of derivative liability	(19,564)	(20,000)
Derivative liability, fair value, gross asset	0	0
Derivative liability	(19,564)	(20,000)
Exchange Traded | Fair Value, Inputs, Level 1 | Future | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	557	190
Liabilities
Fair value of derivative liability	(596)	(54)
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 2 | Future | Fair Value, Measurements, Recurring
Assets
Fair value of derivative asset	21,907	26,095
Liabilities
Fair value of derivative liability	(19,093)	(24,078)
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 3 | Future | 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	(19,564)	(20,000)
Over the Counter | Fair Value, Measurements, Recurring
Liabilities
Common stock warrants	(6,808)	(5,134)
Derivative liability, fair value, gross asset	0	0
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	$ (6,808)	$ (5,134)

Fair Value Measurements - Der92

Fair Value Measurements - Derivative Instruments Measured at Fair Value (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, at beginning of period	$ (25,134)	$ (25,867)	$ (21,254)
Settlements	0	16,810	7,691
Acquired	0	0	(2,844)
Total unrealized income (loss) included in earnings	(1,238)	(16,077)	(9,460)
Balance, at end of period	$ (26,372)	$ (25,134)	$ (25,867)

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, 2017	Dec. 31, 2016
Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt fair value		11.06%
Reported Value Measurement | Tranche B Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		$ 57,426
Reported Value Measurement | Wyoming Refining Senior Secured Revolver
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		6,700
Reported Value Measurement | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	$ 6,808	5,134
Reported Value Measurement | 5% Convertible Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	95,486	91,029
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	289,326
Reported Value Measurement | Hawaii Retail Credit Agreement
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		93,853
Reported Value Measurement | Par Wyoming Holdings Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		65,908
Reported Value Measurement | Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		55,480
Estimate of Fair Value Measurement | Tranche B Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		62,367
Estimate of Fair Value Measurement | Wyoming Refining Senior Secured Revolver
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		6,700
Estimate of Fair Value Measurement | Warrant
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Warrants not settleable in cash, fair value	6,808	5,134
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	149,007	122,229
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	$ 300,423
Estimate of Fair Value Measurement | Hawaii Retail Credit Agreement
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		93,853
Estimate of Fair Value Measurement | Par Wyoming Holdings Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		65,908
Estimate of Fair Value Measurement | Wyoming Refining Senior Secured Term Loan
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value		$ 55,480

Commitments and Contingencies C

Commitments and Contingencies Commitment and Contingencies - Narrative (Details)	12 Months Ended			17 Months Ended
	Dec. 31, 2017USD ($)claim	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2017USD ($)claim	Jun. 17, 2013USD ($)
Long-term Purchase Commitment [Line Items]
Loss contingency, damages sought	$ 4,500,000
Multiplier for earnout payment before EBITDA	4			4
Minimum EBITDA benchmark for earnout	$ 3,500,000			$ 3,500,000
Maximum earnout payment amount	$ 4,500,000			4,500,000
Site contingency reimbursement				12,100,000
Site contingencies capital expenditures				$ 12,900,000
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
Clear Air Act Violation
Long-term Purchase Commitment [Line Items]
Site contingency, loss exposure not accrued, best estimate	$ 30,000,000
Pending Litigation
Long-term Purchase Commitment [Line Items]
Claim amount for environmental losses	1,000,000			$ 1,000,000
Wyoming Refinery One
Long-term Purchase Commitment [Line Items]
Environmental costs recognized, capitalized	$ 18,200,000			18,200,000
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]
Environmental costs recognized, capitalized	$ 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
Loss contingency, loss in period	279,400
Tesoro Corporation
Long-term Purchase Commitment [Line Items]
Contingent consideration, liability					$ 20,000,000
Loss contingency, damages paid		$ 16,800,000
Loss contingency, damages sought		$ 8,300,000	$ 4,300,000
Maximum | Tesoro Corporation
Long-term Purchase Commitment [Line Items]
Contingent consideration, liability					$ 40,000,000
Indemnification Agreement | Tesoros
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

Commitments and Contingencies -

Commitments and Contingencies - Capital Leases and Operating Leases Narrative (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Capital leases term of contract	2 years
Remaining term on operating lease	5 years
Rent expense	$ 41.2	$ 39.6	$ 17.7

Commitments and Contingencies96

Commitments and Contingencies - Capital Lease Payment Schedule (Detail) $ in Thousands	Dec. 31, 2017USD ($)
Commitments and Contingencies Disclosure [Abstract]
2,018	$ 863
2,019	703
2,020	167
2,020	56
2,022	0
Thereafter	0
Total minimum lease payments	1,789
Less amount representing interest	86
Total minimum rental payments	$ 1,703

Commitments and Contingencies97

Commitments and Contingencies - Operating Lease Payment Schedule (Detail) $ in Thousands	Dec. 31, 2017USD ($)
Commitments and Contingencies Disclosure [Abstract]
2,018	$ 16,453
2,019	12,305
2,020	8,649
2,021	7,332
2,022	6,275
Thereafter	29,668
Total minimum rental payments	$ 80,682

Stockholders' Equity - Common S

Stockholders' Equity - Common Stock (Details) - USD ($) $ / shares in Units, $ in Thousands	Sep. 22, 2016	Nov. 25, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class of Stock [Line Items]
Common stock, shares authorized (in shares)			500,000,000	500,000,000
Issuance of common stock, net of offering costs				$ 49,044	$ 76,056
Proceeds from sale of common stock, net of offering costs			$ 0	49,044	76,056
Payments of stock issuance costs				$ 1,000	$ 1,000
Private Placement
Class of Stock [Line Items]
Common stock, shares authorized (in shares)		3,400,000
Proceeds from sale of common stock, net of offering costs		$ 74,800
Proceeds from issuance of common stock, net		$ 73,800
Bridge Loan | Rights Offering
Class of Stock [Line Items]
Shares subscribed but unissued	4,000,000
Issuance of common stock, net of offering costs	$ 49,900
Proceeds from issuance of common stock, net	$ 49,000
Common Stock | Private Placement
Class of Stock [Line Items]
Price per share (in dollars per share)		$ 22
Payments of stock issuance costs		$ 1,000
Common Stock | Bridge Loan | Rights Offering
Class of Stock [Line Items]
Price per share (in dollars per share)	$ 12.25
Payments of stock issuance costs	$ 900

Stockholders' Equity - Registra

Stockholders' Equity - Registration Rights Agreement (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Jun. 30, 2016
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
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%		5.00%
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%
Debt instrument, interest rate	5.00%	0.50%
2.5% Convertible Senior Note [Member] | Convertible Debt
Debt Instrument [Line Items]
Registration statement liquidation damages limit	5.00%
Debt instrument, interest rate	2.50%
Liquidation damages percent	1.00%

Stockholders' Equity - Incentiv

Stockholders' Equity - Incentive Plan (Details) - USD ($)	Jun. 12, 2014	Dec. 31, 2017	Dec. 20, 2012
Class of Stock [Line Items]
Number of shares authorized			4,000,000
Available future grants and awards (in shares)		800,000
Award vesting period		4 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 percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan	50.00%
Vesting period of stock options purchased in relation to shares purchased under the Stock Purchase Plan	2 years
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Stock
Class of Stock [Line Items]
Compensation expense	$ 4,263	$ 2,975	$ 3,692
Restricted Stock Units (RSUs)
Class of Stock [Line Items]
Compensation expense	502	1,255	0
Employee Stock Option
Class of Stock [Line Items]
Compensation expense	$ 2,439	$ 2,352	$ 1,477

Stockholders' Equity - Summa102

Stockholders' Equity - Summary of Restricted Stock Activity (Detail) - Restricted Stock - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock Awards, Shares
Non vested balance, beginning of period (in shares)	436
Granted (in shares)	323
Vested (in shares)	(207)
Forfeited (in shares)	(9)
Non vested balance, end of period (in shares)	543	436
Stock Awards, Weighted-Average Grant Date Fair Value
Non vested balance, beginning of period (USD per share)	$ 17.83
Granted (USD per share)	15.25	$ 17.32	$ 18.24
Vested (USD per share)	18.77
Forfeitured (USD per share)	16.44
Non vested balance, end of period (USD per share)	$ 16.23	$ 17.83

Stockholders' Equity - Narrativ

Stockholders' Equity - Narrative Restricted Stock Awards and Stock Option Grants (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class of Stock [Line Items]
Weighted average exercise price (in dollars per share)	$ 19.52	$ 20.13
Restricted Stock
Class of Stock [Line Items]
Options vested in period, fair value	$ 4	$ 3.6	$ 4.5
Grants in period, weighted average grant date fair value (USD per share)	$ 15.25	$ 17.32	$ 18.24
Compensation not yet recognized,share-based awards other than options	$ 5.7	$ 6.2	$ 7.1
Compensation cost not yet recognized, period for recognition	2 years 4 months 20 days	2 years 6 months	2 years 10 months 28 days
Granted (in shares)	323
Performance Restricted Stock Units
Class of Stock [Line Items]
Compensation not yet recognized,share-based awards other than options	$ 0.4
Compensation cost not yet recognized, period for recognition	2 years 1 month 27 days
Granted (in shares)	45
Stock issued during period, value, restricted stock award, gross	$ 0.7
Employee Stock Option
Class of Stock [Line Items]
Compensation cost not yet recognized, period for recognition	1 year 8 months 26 days	2 years 10 months 2 days
Weighted average exercise price (in dollars per share)	$ 5.81	$ 3.79	$ 8.36
Compensation not yet recognized, stock options	$ 3.5	$ 4.5

Stockholders' Equity - Weighted

Stockholders' Equity - Weighted Average Assumptions Stock Options Granted (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Equity [Abstract]
Expected life from date of grant (years)	5 years 3 months	4 years 5 months	6 years 5 months
Expected volatility	42.00%	39.80%	35.00%
Expected dividend yield	0.00%	0.00%	0.00%
Risk-free interest rate	1.97%	1.16%	1.81%

Stockholders' Equity - Stock Op

Stockholders' Equity - Stock Option Activity Schedule (Detail) - USD ($) $ / shares in Units, shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Number of Options
Outstanding, Beginning of year (in shares)	1,743
Issued (in shares)	239
Exercised (in shares)	0
Forfeited / canceled (in shares)	(3)
Outstanding, End of year (in shares)	1,979	1,743
Exercisable, end of year (in shares)	1,094
Weighted-Average Exercise Price
Outstanding, beginning of year (USD per share)	$ 20.13
Issued (USD per share)	15.03
Exercised (USD per share)	0
Forfeited / canceled (USD per share)	15.15
Outstanding, end of year (USD per share)	19.52	$ 20.13
Exercisable, weighted average exercise price (USD per share)	$ 19.51
Weighted-Average Remaining Contractual Term in Years
Outstanding, weighted average remaining contractual term	5 years 5 months 15 days	6 years 2 months
Options exercisable, weighted average remaining contractual term	4 years 3 months 18 days
Aggregate Intrinsic Value
Outstanding at January 1	$ 0
Outstanding at December 31	1,431,000	$ 0
Exercisable at year end	$ 1,329,000
Employee Stock Option
Weighted-Average Exercise Price
Outstanding, beginning of year (USD per share)	$ 3.79	$ 8.36
Outstanding, end of year (USD per share)	$ 5.81	$ 3.79

Benefit Plans - Narrative (Deta

Benefit Plans - Narrative (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Contribution Pension Plan Disclosure [Abstract]
Employer matching contribution, percent of match		6.00%
Total plan contributions		$ 3,600	$ 3,200	$ 1,400
Plan amendments	$ 3,067	$ 0
Recognized Net gain (loss) due curtailments			$ 3,100
Minimum
Defined Contribution Pension Plan Disclosure [Abstract]
Employers matching contribution, vesting percentage		0.00%
Maximum
Defined Contribution Pension Plan Disclosure [Abstract]
Employers matching contribution, vesting percentage		100.00%

Benefit Plans - Changes in Proj

Benefit Plans - Changes in Projected Benefit Obligations and Fair Value of Plan Assets (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit obligation at the beginning of year	$ 34,319	$ 28,914
Service cost	668	614
Interest cost	598	1,192
Plan amendments	(3,067)	0
Actuarial (gain) loss	(2,436)	1,091
Benefits paid	(1,168)	(934)
Projected benefit obligation at end of year	28,914	30,877
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets as of the beginning of the period	22,067	21,345
Actual return on plan assets	446	3,050
Employer contributions	0	0
Benefits paid	(1,168)	(934)
Fair value of plan assets as of December 31	$ 21,345	$ 23,461

Benefit Plans - Unfunded Status

Benefit Plans - Unfunded Status (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Jul. 13, 2016
Compensation and Retirement Disclosure [Abstract]
Projected benefit obligation	$ 30,877	$ 28,914	$ 34,319
Fair value of plan assets	23,461	21,345	$ 22,067
Underfunded status	7,416	7,569
Other post-retirement benefits income (loss)	$ 2,965	$ 2,196

Benefit Plans - Key Assumptions

Benefit Plans - Key Assumptions for Projected Benefit Obligation and Net Periodic Benefit Cost (Details)	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2015
Projected benefit obligation:
Discount rate	4.20%	3.65%
Rate of compensation increase	4.30%	3.00%
Net periodic benefit costs:
Discount rate	3.80%	4.20%	3.50%
Expected long-term rate of return	7.00%	6.25%
Rate of compensation increase	4.03%	4.30%

Benefit Plans - Net Periodic Be

Benefit Plans - Net Periodic Benefit Cost (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017
Components of net periodic benefit cost:
Service cost	$ 668	$ 614
Interest cost	598	1,192
Expected return on plan assets	(686)	(1,189)
Plan amendment effect	(3,067)	0
Net periodic benefit cost	$ (2,487)	$ 617

Benefit Plans - Asset Allocatio

Benefit Plans - Asset Allocation (Details)	12 Months Ended
	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	100.00%
Actual plan asset allocations	100.00%
Equity securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	60.00%
Actual plan asset allocations	59.00%
Debt securities
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	30.00%
Actual plan asset allocations	32.00%
Real estate
Defined Benefit Plan Disclosure [Line Items]
Target plan asset allocations	10.00%
Actual plan asset allocations	9.00%

Benefit Plans - Project Benefit

Benefit Plans - Project Benefit Payment Obligations (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)
Compensation and Retirement Disclosure [Abstract]
2,018	$ 1,090
2,019	1,140
2,020	1,240
2,021	1,310
2,022	1,270
Thereafter	7,800
Total	$ 13,850
Fair value assumptions, expected term	10 years

Benefit Plans - Other Post-Reti

Benefit Plans - Other Post-Retirement Benefits (Details) $ in Thousands	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2015USD ($)age
Schedule of Defined Benefit Plans and Defined Contribution Plans Disclosures [Line Items]
Post-retirement medical, maximum age of coverage | age			65
Post-retirement medical, minimum service requirement			5 years
Post-retirement medical, minimum age of coverage | age			55
Post-retirement medical, post 55, pre 2006 employee percentage of monthly insurance			20.00%
Post-retirement medical, post 55, post 2006 employee percentage of monthly insurance			100.00%
Post-retirement medical, post 2006 reduction in premium service requirement			10 years
Post-retirement medical, post 55 with post 2006 reduction in premium service requirement percentage of monthly insurance			50.00%
Weighted-average discount rates used to determine the benefit obligations	4.20%	3.65%
Weighted average discount rate use to determine net periodic benefit costs	3.80%	4.20%	3.50%
Postretirement Medical Plan
Schedule of Defined Benefit Plans and Defined Contribution Plans Disclosures [Line Items]
Plan termination | $			$ 6,632
Defined benefit gain on plan termination | $			$ (5,600)

Benefit Plans - Changes in Bene

Benefit Plans - Changes in Benefit Obligations (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2015
Change in benefit obligation:
Benefit obligation at the beginning of year	$ 34,319	$ 28,914
Service cost	668	614
Interest cost	598	1,192
Plan amendments	3,067	0
Actuarial loss (gain)	2,436	(1,091)
Projected benefit obligation at end of year	$ 28,914	$ 30,877
Postretirement Medical Plan
Change in benefit obligation:
Benefit obligation at the beginning of year			$ 5,414
Service cost			370
Interest cost			212
Plan amendments			0
Plan termination			(6,632)
Actuarial loss (gain)			636
Projected benefit obligation at end of year			$ 0

Income (Loss) Per Share - Narra

Income (Loss) Per Share - Narrative (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	65	451	535
Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	1,300	1,300	632
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities (in shares)	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	347	344

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Undistributed income allocated to participating securities									878	0	0
Net income (loss) attributable to common stockholders									71,743	(45,835)	(39,911)
Plus: Net income effect of convertible securities									0	0	0
Numerator for diluted income (loss) per common share									$ 71,743	$ (45,835)	$ (39,911)
Basic weighted-average common stock shares outstanding (in shares)									45,543	42,349	37,678
Add dilutive effects of common stock equivalents (in shares)									40	0	0
Diluted weighted-average common stock shares outstanding (in shares)									45,583	42,349	37,678
Basic (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.60	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.58	$ (1.08)	$ (1.06)
Diluted (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.58	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.57	$ (1.08)	$ (1.06)

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Apr. 01, 2015
Income Taxes [Line Items]
Net operating loss carryovers	$ 1,600,000
Tax Cuts and Jobs Act of 2017, change in tax rate, deferred tax asset, provisional income tax expense (benefit)	207,700
Tax Cuts and Jobs Act of 2017, provisional income tax benefit	800
Deferred tax asset, increase (decrease)		$ 59,000
Income (loss) before income taxes, foreign	0	1,400	$ 900
Alternative minimum tax credit carryovers	$ 1,600
Minimum
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2,027
Maximum
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2,036
Mid Pac Petroleum, LLC
Income Taxes [Line Items]
Deferred tax liability			$ 16,800	$ 16,759
5% Convertible Senior Notes due 2021
Income Taxes [Line Items]
Deferred tax asset, increase (decrease)		$ 8,600

Income Taxes - Taxes Expense (B

Income Taxes - Taxes Expense (Benefit) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current:
U.S.—Federal	$ 0	$ 0	$ 0
U.S.—State	2	23	0
Foreign	0	0	(299)
Deferred:
U.S.—Federal	(1,321)	(7,046)	(14,685)
U.S.—State	0	(889)	(1,804)
Foreign	0	0	0
Total	$ (1,319)	$ (7,912)	$ (16,788)

Income Taxes - Income Tax Rate

Income Taxes - Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Federal statutory rate	35.00%	35.00%	35.00%
State income taxes, net of federal benefit	0.00%	1.60%	3.20%
Expiration of capital loss carryover	0.00%	(17.60%)	(25.50%)
Change in valuation allowance related to current activity	(30.10%)	9.20%	25.30%
Change in valuation allowance related to change in tax rate	(291.20%)	0.00%	0.00%
Change in tax rate	291.20%	0.00%	0.00%
Permanent items	1.10%	(5.70%)	(7.60%)
Provision to return adjustments and other	(7.90%)	(7.80%)	(0.80%)
Actual income tax rate	(1.90%)	14.70%	29.60%

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Asset (Liabilities) (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred tax assets:
Net operating loss	$ 388,317	$ 611,631
Property and equipment	9,862	23,203
Other	10,263	10,868
Total deferred tax assets	408,442	645,702
Valuation allowance	(383,253)	(613,866)
Net deferred tax assets	25,189	31,836
Deferred tax liabilities:
Investment in Laramie Energy	18,140	20,600
Convertible notes	3,193	6,866
Intangible assets	3,978	2,671
Other	863	2,337
Total deferred tax liabilities	26,174	32,474
Total deferred tax liabilities	$ (985)	$ (638)

Segment Information (Detail)

Segment Information (Detail) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2017USD ($)segment	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Apr. 01, 2015USD ($)
Segment Reporting [Abstract]
Number of businsess segment | segment									4
Revenues									$ 2,443,066	$ 1,865,045	$ 2,066,337
Cost of revenues (excluding depreciation)									2,054,627	1,636,339	1,787,368
Operating expense (excluding depreciation)									202,019	166,216	141,621
Depreciation, depletion, and amortization									45,989	31,617	19,918
Impairment expense									0	0	9,639
General and administrative expense (excluding depreciation)									46,078	42,073	44,271
Acquisition and integration expense									395	5,294	2,006
Operating income (loss)	$ 21,602	$ 26,716	$ 16,451	$ 29,189	$ 28,325	$ (21,784)	$ (3,313)	$ (19,719)	93,958	(16,494)	61,514
Interest Expense									(31,632)	(28,506)	(20,156)
Loss on termination of financing agreements									(8,633)	0	(19,669)
Other income, net									914	(98)	(291)
Change in value of common stock warrants									(1,674)	2,962	(3,664)
Change in value of contingent consideration									0	10,770	(18,450)
Equity earnings (losses) from Laramie Energy, LLC									18,369	(22,381)	(55,983)
Income (loss) before income taxes									71,302	(53,747)	(56,699)
Income tax benefit									1,319	7,912	16,788
Net income (loss)	19,005	$ 18,824	$ 7,006	$ 27,786	13,687	$ (27,761)	$ (13,088)	$ (18,673)	72,621	(45,835)	(39,911)
Assets	1,347,407				1,145,433				1,347,407	1,145,433	892,261
Goodwill	107,187				105,732				107,187	105,732	41,327
Payments to Acquire Property, Plant, and Equipment									31,708	24,833	22,345
Refining
Goodwill												$ 13,500
Logistics
Goodwill												10,800
Retail
Goodwill												$ 2,700
Operating Segments | Refining
Revenues									2,319,638	1,702,463	1,895,662
Cost of revenues (excluding depreciation)									2,062,804	1,580,014	1,718,729
Operating expense (excluding depreciation)									141,068	112,724	95,588
Depreciation, depletion, and amortization									29,753	17,565	9,522
Impairment expense											0
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration expense									0	0	0
Operating income (loss)									86,013	(7,840)	71,823
Assets	949,588				772,438				949,588	772,438	516,482
Goodwill	53,264				53,037				53,264	53,037	13,765
Payments to Acquire Property, Plant, and Equipment									10,433	15,106	8,573
Operating Segments | Logistics
Revenues									121,470	102,779	82,671
Cost of revenues (excluding depreciation)									66,301	65,439	48,660
Operating expense (excluding depreciation)									15,010	11,239	5,433
Depreciation, depletion, and amortization									6,166	4,679	3,117
Impairment expense											0
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration expense									0	0	0
Operating income (loss)									33,993	21,422	25,461
Assets	118,304				120,443				118,304	120,443	53,158
Goodwill	37,373				36,145				37,373	36,145	11,012
Payments to Acquire Property, Plant, and Equipment									8,836	1,344	6,089
Operating Segments | Retail
Revenues									326,076	290,402	283,507
Cost of revenues (excluding depreciation)									249,097	220,545	215,194
Operating expense (excluding depreciation)									45,941	41,291	35,317
Depreciation, depletion, and amortization									6,338	6,372	5,421
Impairment expense											0
General and administrative expense (excluding depreciation)									0	0	0
Acquisition and integration expense									0	0	0
Operating income (loss)									24,700	22,194	27,575
Assets	128,966				122,570				128,966	122,570	115,544
Goodwill	16,550				16,550				16,550	16,550	16,550
Payments to Acquire Property, Plant, and Equipment									7,073	4,375	3,643
Intersegment Eliminations
Gross Profit									(325,200)	(271,900)	(330,000)
Intersegment Eliminations | Corporate, Eliminations and Other
Revenues									(324,118)	(230,599)	(195,503)
Cost of revenues (excluding depreciation)									(323,575)	(229,659)	(195,215)
Operating expense (excluding depreciation)									0	962	5,283
Depreciation, depletion, and amortization									3,732	3,001	1,858
Impairment expense											9,639
General and administrative expense (excluding depreciation)									46,078	42,073	44,271
Acquisition and integration expense									395	5,294	2,006
Operating income (loss)									(50,748)	(52,270)	(63,345)
Assets	150,549				129,982				150,549	129,982	207,077
Goodwill	$ 0				$ 0				0	0	0
Payments to Acquire Property, Plant, and Equipment									$ 5,366	$ 4,008	$ 4,040

Related Party Transaction (Text

Related Party Transaction (Textual) (Detail) - USD ($)	Sep. 22, 2016	Jun. 21, 2016	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016	Jul. 14, 2016	Jun. 30, 2016	Jun. 15, 2016	Jun. 14, 2016
Related Party Transaction [Line Items]
Percentage ownership of Par common stock			10.00%
Bridge Loan
Related Party Transaction [Line Items]
Deferred finance costs, net	$ 3,000,000
Aggregate principal amount	3,100,000					$ 52,600,000
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
Rights Offering | Bridge Loan
Related Party Transaction [Line Items]
Repayments of debt	$ 49,000,000
Common Stock | Rights Offering | Bridge Loan
Related Party Transaction [Line Items]
Conversion of stock, shares converted (in shares)	272,733
EGI | Affiliated Entity | Bridge Loan
Related Party Transaction [Line Items]
Line credit maximum borrowing amount									$ 52,632,000
Debt instrument, interest rate									5.00%
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]
Aggregate principal amount							$ 115,000,000
Debt instrument, interest rate			5.00%		0.50%
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

Subsequent Events - Narrative (

Subsequent Events - Narrative (Details) - USD ($) $ in Thousands

Feb. 28, 2018

Jan. 09, 2018

Jul. 31, 2015

May 29, 2015

Mar. 09, 2015

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Mar. 01, 2016

Feb. 29, 2016

Jul. 30, 2015

May 28, 2015

Subsequent Event [Line Items]

Investment in Laramie Energy, LLC

$ 0

$ 55,000

$ 27,529

CHS Acquisition | Subsequent Event

Subsequent Event [Line Items]

Payments to acquire businesses

$ 70,000

Laramie Energy Company

Subsequent Event [Line Items]

Investment in Laramie Energy, LLC

$ 13,800

$ 13,800

Ownership of Laramie Energy, LLC

32.40%

34.00%

42.30%

42.30%

32.40%

34.00%

33.34%

Laramie Energy Company | Subsequent Event

Subsequent Event [Line Items]

Ownership of Laramie Energy, LLC

39.14%

Laramie Energy Company | Unaffiliated Third Party

Subsequent Event [Line Items]

Investment in Laramie Energy, LLC

$ 19,000

Laramie Energy Company | Unaffiliated Third Party | Subsequent Event

Subsequent Event [Line Items]

Investment in Laramie Energy, LLC

$ 23,500

Equity method investments, fair value

$ 28,100

Shares issued (in shares)

70,227

Quarterly Financial Data (Detai

Quarterly Financial Data (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 663,062	$ 610,506	$ 564,245	$ 605,253	$ 563,136	$ 510,305	$ 413,793	$ 377,812
Operating income (loss)	21,602	26,716	16,451	29,189	28,325	(21,784)	(3,313)	(19,719)	$ 93,958	$ (16,494)	$ 61,514
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Net income (loss) per share
Basic (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.60	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.58	$ (1.08)	$ (1.06)
Diluted (USD per share)	$ 0.41	$ 0.41	$ 0.15	$ 0.58	$ 0.30	$ (0.67)	$ (0.32)	$ (0.46)	$ 1.57	$ (1.08)	$ (1.06)

Disclosures About Capitalize125

Disclosures About Capitalized Costs, Costs Incurred (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Company:
Proved properties	$ 400	$ 1,122
Company
Company:
Unproved properties	0	0
Proved properties	400	1,122
Oil and Gas Property, Successful Effort Method, Gross, Total	400	1,122
Accumulated depreciation and depletion	(275)	(930)
Oil and gas property, successful efforts method	125	192
Company's Share of Laramie Energy
Company:
Unproved properties	13,728	14,416
Proved properties	382,789	334,085
Oil and Gas Property, Successful Effort Method, Gross, Total	396,517	348,501
Accumulated depreciation and depletion	(111,119)	(91,454)
Oil and gas property, successful efforts method	$ 285,398	$ 257,047

Disclosures About Capitalize126

Disclosures About Capitalized Costs, Costs Incurred (Details 1) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Company
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Development costs—other	$ 0	$ 0	$ 0
Total	0	0	0
Company's Share of Laramie Energy
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Acquisition costs	0	65,324	0
Development costs—other	49,273	12,805	21,747
Total	$ 49,273	$ 78,129	$ 21,747

Disclosures About Capitalize127

Disclosures About Capitalized Costs, Costs Incurred (Details 2) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Company
Revenue
Oil and gas revenues	$ 288	$ 190	$ 2,019
Expenses
Production costs	29	147	5,283
Depletion and amortization	66	69	42
Exploration	0	0	0
Abandoned and impaired properties	0	0	0
Impairment of unproved properties	0	0	0
Results of operations of oil and gas producing activities	193	(26)	(3,306)
Company's Share of Laramie Energy
Revenue
Oil and gas revenues	66,783	43,607	14,217
Expenses
Production costs	32,606	27,750	11,047
Depletion and amortization	21,277	17,534	8,226
Abandoned and impaired properties	0	0	3,977
Impairment of unproved properties	0	0	3,977
Results of operations of oil and gas producing activities	12,900	(1,677)	(9,033)
Total results of operations of oil and gas producing activities	$ 13,093	$ (1,703)	$ (12,339)

Information Regarding Proved128

Information Regarding Proved Oil and Gas Reserves (Details) Mcf in Thousands, MBbls in Thousands, $ in Thousands	Mar. 01, 2016USD ($)	May 29, 2015USD ($)	Mar. 09, 2015USD ($)	Dec. 31, 2017USD ($)$ / WTIperBbl$ / CIGperMbtuMcfMBbls	Dec. 31, 2016USD ($)$ / WTIperBbl$ / CIGperMbtuMcfMBbls	Dec. 31, 2015USD ($)$ / WTIperBbl$ / CIGperMbtuMcfMBbls	Dec. 31, 2014McfMBbls
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance				345,196
Investment in Laramie Energy, LLC | $				$ 0	$ 55,000	$ 27,529
Proved developed reserve				206,446	189,110	78,797
Proved undeveloped reserve				138,750	178,181	74,681
Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance				420	224	1,165
Revisions of quantity estimate				(139)	(262)	630
Extensions and discoveries				0	0	0
Production				(59)	(66)	(311)
Ending Balance					420	224	1,165
Increase in estimated proved reserves				22,095	(213,813)	(76,475)
Increase in estimated proved reserves, percentage				6.00%	139.30%	33.30%
Proved developed reserve				500	420	224
Proved undeveloped reserve				0	0	0
Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance				366,871	153,254	228,788
Revisions of quantity estimate				(3)	(31,672)	101,553
Extensions and discoveries				0	758	38,869
Acquisitions and divestitures				0	200,045	(7,091)
Production				(22,178)	(18,858)	(5,759)
Ending Balance				344,696	366,871	153,254	228,788
Increase in estimated proved reserves				22,178	(200,045)	(101,553)
Proved developed reserve				205,946	188,690	78,573
Proved undeveloped reserve				138,750	178,181	74,681
Natural Gas
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance				293,434
Proved developed reserve				174,856	159,830	65,687
Proved undeveloped reserve				118,578	150,302	61,775
Natural Gas | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance				330	188	601
Revisions of quantity estimate				(109)	(196)	330
Extensions and discoveries				0	0	0
Production				(47)	(54)	(83)
Ending Balance					330	188	601
Proved developed reserve				392	330	188
Proved undeveloped reserve				0	0	0
Base Pricing, before adjustments for contractual differentials | $ / CIGperMbtu				2.68	2.29	2.39
Natural Gas | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance				309,802	127,274	192,015
Revisions of quantity estimate				(1,344)	(28,195)	86,092
Extensions and discoveries				0	638	32,041
Acquisitions and divestitures				0	168,887	(5,945)
Production				(18,104)	(15,192)	(4,745)
Ending Balance				293,042	309,802	127,274	192,015
Proved developed reserve				174,464	159,500	65,499
Proved undeveloped reserve				118,578	150,302	61,775
Oil
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance | MBbls				1,114
Proved developed reserve | MBbls				665	523	254
Proved undeveloped reserve | MBbls				449	451	232
Oil | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls				7	6	77
Revisions of quantity estimate | MBbls				(2)	(3)	35
Extensions and discoveries | MBbls				0	0	0
Production | MBbls				(2)	(2)	(36)
Ending Balance | MBbls					7	6	77
Proved developed reserve | MBbls				7	7	6
Proved undeveloped reserve | MBbls				0	0	0
Base Pricing, before adjustments for contractual differentials | $ / WTIperBbl				51.34	42.75	50.28
Oil | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls				967	480	684
Revisions of quantity estimate | MBbls				(211)	(53)	295
Extensions and discoveries | MBbls				0	1	131
Acquisitions and divestitures | MBbls				0	492	(20)
Production | MBbls				(71)	(59)	(20)
Ending Balance | MBbls				1,107	967	480	684
Proved developed reserve | MBbls				658	516	248
Proved undeveloped reserve | MBbls				449	451	232
Natural Gas Liquids
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance | MBbls				7,513
Proved developed reserve | MBbls				4,600	4,357	1,931
Proved undeveloped reserve | MBbls				2,913	4,195	1,919
Natural Gas Liquids | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls				8	0	17
Revisions of quantity estimate | MBbls				(3)	(8)	15
Extensions and discoveries | MBbls				0	0	0
Production | MBbls				0	0	(2)
Ending Balance | MBbls					8	0	17
Proved developed reserve | MBbls				11	8	0
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 Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Starting Balance | MBbls				8,544	3,850	5,444
Revisions of quantity estimate | MBbls				434	(526)	2,281
Extensions and discoveries | MBbls				0	19	1,007
Acquisitions and divestitures | MBbls				0	4,701	(171)
Production | MBbls				(608)	(552)	(149)
Ending Balance | MBbls				7,502	8,544	3,850	5,444
Proved developed reserve | MBbls				4,589	4,349	1,931
Proved undeveloped reserve | MBbls				2,913	4,195	1,919
Laramie Energy Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Investment in Laramie Energy, LLC | $		$ 13,800	$ 13,800
Laramie Energy Company | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Increase in estimated proved reserves				30
Laramie Energy Company | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Revisions of quantity estimate				17,216
Laramie Energy Company | Piceance Basin
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Investment in Laramie Energy, LLC | $	$ 152,100
Restatement Adjustment | Natural Gas | Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Revisions of quantity estimate					(19,307)	(7,587)	(23,786)
Revision of estimate percentage					5.00%	5.00%	9.00%

Information Regarding Proved129

Information Regarding Proved Oil and Gas Reserves (Details 1) Mcf in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)Mcf	Dec. 31, 2016USD ($)Mcf	Dec. 31, 2015USD ($)Mcf	Dec. 31, 2014USD ($)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Discounted future net cash flows	$ 216,393	$ 141,427	$ 39,797	$ 162,437
Company
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Proved Developed and Undeveloped Reserves, Net, Period Increase (Decrease) | Mcf	(22,095)	213,813	76,475
Future net cash flows	$ 1,802	$ 1,154	$ 690
Production	902	713	345
Development and abandonment	0	2	25
Income taxes	0	0	0
Future net cash flows	900	439	320
10% discount factor	(328)	(154)	(128)
Discounted future net cash flows	$ 572	$ 285	$ 192	1,766
Company's Share of Laramie Energy
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Proved Developed and Undeveloped Reserves, Net, Period Increase (Decrease) | Mcf	(22,178)	200,045	101,553
Future net cash flows	$ 1,026,005	$ 905,607	$ 405,365
Production	491,748	462,684	238,129
Development and abandonment	109,248	136,224	67,443
Income taxes	0	0	0
Future net cash flows	425,009	306,699	99,793
10% discount factor	(209,188)	(165,557)	(60,188)
Discounted future net cash flows	$ 215,821	141,142	39,605	$ 160,671
Restatement Adjustment | Company's Share of Laramie Energy
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future net cash flows		$ 1,800	$ 400
Future cash flow estimate revision percentage		1.00%	1.00%
Laramie [Member] | Company
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Proved Developed and Undeveloped Reserves, Net, Period Increase (Decrease) | Mcf	(30)

Information Regarding Proved130

Information Regarding Proved Oil and Gas Reserves (Details 2) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	$ 141,427	$ 39,797	$ 162,437
Sales of oil and gas production during the period, net of production costs	(29,939)	(8,041)	(6,232)
Acquisitions and divestitures		81,066	(4,789)
Net change in prices and production costs	35,537	2,974	(154,243)
Changes in estimated future development costs		(8,561)	796
Extensions, discoveries and improved recovery		231	9,273
Revisions of previous quantity estimates, estimated timing of development and other	38,038	17,137	310
Previously estimated development and abandonment costs incurred during the period	17,187	12,805	15,008
Accretion of discount	14,143	4,019	17,237
End of period	216,393	141,427	39,797	$ 162,437
Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	285	192	1,766
Sales of oil and gas production during the period, net of production costs	(28)	(62)	(479)
Acquisitions and divestitures		0	0
Net change in prices and production costs	(60)	(20)	(679)
Changes in estimated future development costs		14	8
Extensions, discoveries and improved recovery		0	0
Revisions of previous quantity estimates, estimated timing of development and other	346	142	(601)
Previously estimated development and abandonment costs incurred during the period	0	0	0
Accretion of discount	29	19	177
End of period	572	285	192	1,766
Company's Share of Laramie Energy
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	141,142	39,605	160,671
Sales of oil and gas production during the period, net of production costs	(29,911)	(7,979)	(5,753)
Acquisitions and divestitures		81,066	(4,789)
Net change in prices and production costs	35,597	2,994	(153,564)
Changes in estimated future development costs		(8,575)	788
Extensions, discoveries and improved recovery		231	9,273
Revisions of previous quantity estimates, estimated timing of development and other	37,692	16,995	911
Previously estimated development and abandonment costs incurred during the period	17,187	12,805	15,008
Accretion of discount	14,114	4,000	17,060
End of period	$ 215,821	141,142	39,605	160,671
Restatement Adjustment | Company
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Revisions of previous quantity estimates, estimated timing of development and other		$ 1,800	$ 400	$ 9,900
Revisions of previous quantity estimates, percentage		1.00%	1.00%	6.00%

Condended Financial Informat131

Condended Financial Information of Registrant Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 118,333	$ 47,772	$ 167,788	$ 89,210
Restricted cash	744	1,246
Prepaid and other current assets	17,279	53,380
Total current assets	603,544	403,108
Property and equipment
Total property and equipment	529,638	500,989
Less accumulated depreciation and depletion	(79,622)	(49,727)
Property, plant and equipment, net	450,016	451,262
Long-term assets
Other long-term assets	32,864	46,596
Total assets	1,347,407	1,145,433	892,261
Current liabilities
Accounts payable	52,543	65,190
Other accrued liabilities	27,444	35,186
Total current liabilities	470,952	382,765
Long-term liabilities
Long-term debt, net of current maturities	384,812	350,110
Common stock warrants	6,808	5,134
Long-term capital lease obligations	1,220	1,780
Total liabilities	899,688	776,524
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, 2017 and December 31, 2016, 45,776,087 shares and 45,533,913 shares issued at December 31, 2017 and December 31, 2016, respectively	458	455
Additional paid-in capital	593,295	587,057
Accumulated deficit	(148,178)	(220,799)
Accumulated other comprehensive income	2,144	2,196
Total stockholders’ equity	447,719	368,909
Total liabilities and stockholders’ equity	1,347,407	1,145,433
Parent Company
Current assets
Cash and cash equivalents	65,615	10,361	$ 91,023	$ 70,114
Restricted cash	744	746
Prepaid and other current assets	11,768	9,200
Due from subsidiaries	8,113	66,900
Total current assets	86,240	87,207
Property and equipment
Total property and equipment	15,773	10,259
Less accumulated depreciation and depletion	(6,226)	(3,485)
Property, plant and equipment, net	9,547	6,774
Long-term assets
Investment in subsidiaries	552,748	513,693
Other long-term assets	1,976	1,976
Total assets	650,511	609,650
Current liabilities
Accounts payable	4,510	4,529
Other accrued liabilities	12,913	8,141
Due to subsidiaries	82,524	73,529
Total current liabilities	99,947	86,199
Long-term liabilities
Long-term debt, net of current maturities	95,486	148,456
Common stock warrants	6,808	5,134
Long-term capital lease obligations	551	952
Total liabilities	202,792	240,741
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, 2017 and December 31, 2016, 45,776,087 shares and 45,533,913 shares issued at December 31, 2017 and December 31, 2016, respectively	458	455
Additional paid-in capital	593,295	587,057
Accumulated deficit	(148,178)	(220,799)
Accumulated other comprehensive income	2,144	2,196
Total stockholders’ equity	447,719	368,909
Total liabilities and stockholders’ equity	$ 650,511	$ 609,650

Condended Financial Informat132

Condended Financial Information of Registrant Balance Sheet (Parenthetical) (Details) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Condensed Balance Sheet Statements, Captions [Line Items]
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized	3,000,000	3,000,000
Preferred stock, shares issued	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	45,776,087	45,533,913
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	3,000,000	3,000,000
Preferred stock, shares issued	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	45,776,087	45,533,913

Condended Financial Informat133

Condended Financial Information of Registrant Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating expenses
Depreciation and amortization									$ 45,989	$ 31,617	$ 19,918
General and administrative expense (excluding depreciation)									46,078	42,073	44,271
Acquisition and integration expense									395	5,294	2,006
Total operating expenses									2,349,108	1,881,539	2,004,823
Operating income (loss)	$ 21,602	$ 26,716	$ 16,451	$ 29,189	$ 28,325	$ (21,784)	$ (3,313)	$ (19,719)	93,958	(16,494)	61,514
Other income (expense)
Interest expense and financing costs, net									(31,632)	(28,506)	(20,156)
Loss on termination of financing agreements									(8,633)	0	(19,669)
Other income (expense), net									914	(98)	(291)
Change in value of common stock warrants									(1,674)	2,962	(3,664)
Equity earnings (losses) of subsidiaries									18,369	(22,381)	(55,983)
Total other income (expense), net									(22,656)	(37,253)	(118,213)
Income (loss) before income taxes									71,302	(53,747)	(56,699)
Income tax benefit									1,319	7,912	16,788
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	72,621	(45,835)	(39,911)
Parent Company
Operating expenses
Depreciation and amortization									2,871	2,205	962
General and administrative expense (excluding depreciation)									18,922	15,618	16,558
Acquisition and integration expense									192	4,781	1,776
Total operating expenses									21,985	22,604	19,297
Operating income (loss)									(21,985)	(22,604)	(19,297)
Other income (expense)
Interest expense and financing costs, net									(13,709)	(18,246)	(13,028)
Loss on termination of financing agreements									(1,804)	0	0
Interest income from subsidiaries									0	583	1,000
Other income (expense), net									631	67	215
Change in value of common stock warrants									(1,674)	2,962	(3,644)
Equity earnings (losses) of subsidiaries									111,162	(17,170)	(5,137)
Total other income (expense), net									94,606	(31,804)	(20,614)
Income (loss) before income taxes									72,621	(54,408)	(39,911)
Income tax benefit									0	8,573	0
Net income (loss)									$ 72,621	$ (45,835)	$ (39,911)

Condended Financial Informat134

Condended Financial Information of Registrant Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Statement of Income Captions [Line Items]
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Other comprehensive income (loss):
Reclassification of other post-retirement benefits loss to net income									0	0	1,082
Other post-retirement benefits income (loss)									(52)	2,196	(636)
Total other comprehensive income (loss), net of tax									(52)	2,196	446
Comprehensive income (loss)									72,569	(43,639)	(39,465)
Parent Company
Condensed Statement of Income Captions [Line Items]
Net income (loss)									72,621	(45,835)	(39,911)
Other comprehensive income (loss):
Reclassification of other post-retirement benefits loss to net income									0	0	1,082
Other post-retirement benefits income (loss)									(52)	2,196	(636)
Total other comprehensive income (loss), net of tax									(52)	2,196	446
Comprehensive income (loss)									$ 72,569	$ (43,639)	$ (39,465)

Condended Financial Informat135

Condended Financial Information of Registrant Statements of Cash Flow (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities:
Net income (loss)	$ 19,005	$ 18,824	$ 7,006	$ 27,786	$ 13,687	$ (27,761)	$ (13,088)	$ (18,673)	$ 72,621	$ (45,835)	$ (39,911)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, depletion, and amortization									45,989	31,617	19,918
Non-cash interest expense									7,276	18,121	12,449
Change in value of common stock warrants									1,674	(2,962)	3,664
Deferred taxes									(1,321)	(7,935)	(16,489)
Stock-based compensation									7,204	6,625	5,165
Equity in losses (income) of subsidiaries									(18,369)	22,381	55,983
Loss on termination of financing agreements									8,633	0	19,669
Net changes in operating assets and liabilities:
Prepaid and other assets									37,645	447	(35,697)
Accounts payable and other accrued liabilities									(33,780)	(26,698)	(26,188)
Net cash provided by (used in) operating activities									106,483	(23,891)	132,358
Cash flows from investing activities:
Change in restricted cash									502	0	0
Capital expenditures									(31,708)	(24,833)	(22,345)
Net cash used in investing activities									(31,171)	(286,243)	(114,205)
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs									0	49,044	76,056
Proceeds from borrowings									616,706	354,682	208,158
Repayments of borrowings									(603,770)	(202,165)	(227,212)
Payment of deferred loan costs									(10,064)	(6,892)	(7,335)
Other financing activities, net									(993)	(598)	(995)
Net cash provided by (used in) financing activities									(4,751)	190,118	60,425
Net increase (decrease) in cash and cash equivalents									70,561	(120,016)	78,578
Cash and cash equivalents at beginning of period				47,772				167,788	47,772	167,788	89,210
Cash and cash equivalents at end of period	118,333				47,772				118,333	47,772	167,788
Net cash received (paid) for:
Interest									(23,873)	(13,217)	(6,891)
Taxes										(589)	(402)
Non-cash investing and financing activities:
Accrued capital expenditures									2,926	4,907	2,102
Value of warrants and debt reclassified to equity									0	3,084	7,691
Capital lease additions									165	1,575	216
Parent Company
Cash flows from operating activities:
Net income (loss)									72,621	(45,835)	(39,911)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, depletion, and amortization									2,871	2,205	962
Non-cash interest expense									5,617	13,722	6,860
Non-cash interest income from subsidiary									0	(583)	(1,000)
Change in value of common stock warrants									1,674	(2,962)	3,644
Deferred taxes									0	(8,573)	0
Stock-based compensation									7,204	2,226	3,202
Equity in losses (income) of subsidiaries									(111,162)	17,170	5,137
Loss on termination of financing agreements									1,804	0	0
Net changes in operating assets and liabilities:
Prepaid and other assets									(2,568)	25	(8,466)
Accounts payable and other accrued liabilities									3,088	381	3,674
Net cash provided by (used in) operating activities									(18,851)	(22,224)	(25,898)
Cash flows from investing activities:
Investments in subsidiaries									(2,072)	(264,163)	(89,603)
Distributions from subsidiaries									70,645	9,047	68,418
Note receivable from subsidiary									0	10,000	0
Change in restricted cash									2	0	0
Capital expenditures									(5,366)	(4,321)	(4,461)
Due to (from) subsidiaries									80,762	(23,947)	27,627
Net cash used in investing activities									143,971	(273,384)	1,981
Cash flows from financing activities:
Proceeds from sale of common stock, net of offering costs									0	49,044	76,056
Proceeds from borrowings									0	172,282	7,378
Repayments of borrowings									(68,873)	(63,062)	(37,214)
Payment of deferred loan costs									0	(6,298)	(307)
Due to (from) subsidiaries									0	63,578	0
Other financing activities, net									(993)	(598)	(1,087)
Net cash provided by (used in) financing activities									(69,866)	214,946	44,826
Net increase (decrease) in cash and cash equivalents									55,254	(80,662)	20,909
Cash and cash equivalents at beginning of period				$ 10,361				$ 91,023	10,361	91,023	70,114
Cash and cash equivalents at end of period	$ 65,615				$ 10,361				65,615	10,361	91,023
Net cash received (paid) for:
Interest									(7,856)	(4,557)	(4,709)
Taxes									(1,478)	0	51
Non-cash investing and financing activities:
Accrued capital expenditures									370	361	417
Value of warrants and debt reclassified to equity									0	3,084	7,691
Capital lease additions									$ 165	$ 1,575	$ 216