Par Pacific (PARR) 10-K 12 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Mar. 09, 2015	Jun. 30, 2014
Document and Entity Information:
Entity Registrant Name	PAR PETROLEUM CORP/CO
Entity Central Index Key	821483
Current Fiscal Year End Date	-19
Entity Filer Category	Smaller Reporting Company
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	PARR
Amendment Flag	FALSE
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		37,093,918
Entity Public Float			$268,219,000

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$89,210	$38,061
Restricted cash	749	802
Trade accounts receivable	112,968	117,493
Inventories	243,853	380,623
Prepaid and other current assets	14,009	7,522
Total current assets	460,789	544,501
Property and equipment
Property, plant and equipment	123,323	107,623
Proved oil and gas properties, at cost, successful efforts method of accounting	1,122	4,949
Total property and equipment	124,445	112,572
Less accumulated depreciation, depletion and amortization	-11,510	-3,968
Property and equipment, net	112,935	108,604
Long-term assets
Investment in Piceance Energy, LLC	104,657	101,796
Intangible assets, net	7,506	11,170
Goodwill	20,786	20,603
Other long-term assets	34,334	26,539
Total assets	741,007	813,213
Current liabilities
Current maturities of long-term debt	29,100	3,250
Obligations under supply and exchange agreements	197,394	385,519
Accounts payable	33,064	28,870
Other accrued liabilities	50,152	31,956
Accrued settlement claims	1,096	3,793
Total current liabilities	310,806	453,388
Long-term liabilities
Long-term debt, net of current maturities and unamortized discount	107,510	94,030
Common stock warrants	12,123	17,336
Contingent consideration	9,131	11,980
Long-term capital lease obligations	1,295	1,526
Other liabilities	7,983	6,689
Total liabilities	448,848	584,949
Commitments and contingencies (Note 12)
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 and 300,000,000 shares authorized at December 31, 2014 and 2013, respectively, 37,068,886 shares and 30,151,000 shares issued at December 31, 2014 and 2013, respectively	371	301
Additional paid-in capital	427,287	315,975
Accumulated deficit	-135,053	-88,012
Accumulated other comprehensive loss	-446	0
Total stockholders’ equity	292,159	228,264
Total liabilities and stockholders’ equity	$741,007	$813,213

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
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	500,000,000	300,000,000
Common stock, shares issued	37,068,886	30,151,000

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Revenues
Refining, distribution and marketing revenues	$2,912,881	$778,126
Commodity marketing and logistics revenues	189,160	100,149
Natural gas and oil revenues	5,984	7,739
Total operating revenues	3,108,025	886,014
Operating expenses
Cost of revenues	2,937,472	857,066
Operating expense, excluding depreciation, depletion and amortization expense	140,900	27,251
Lease operating expense	5,673	5,676
Depreciation, depletion and amortization	14,897	5,982
Loss (gain) on sale of assets, net	624	-50
Trust litigation and settlements	0	6,206
General and administrative expense	34,304	21,494
Acquisition and integration expense	11,687	9,794
Total operating expenses	3,145,557	933,419
Operating loss	-37,532	-47,405
Other income (expense)
Interest expense and financing costs, net	-19,783	-19,426
Other income (expense), net	-312	758
Change in value of common stock warrants	4,433	-10,159
Change in value of contingent consideration	2,849	0
Equity earnings (losses) from Piceance Energy, LLC	2,849	-2,941
Total other income (expense), net	-9,964	-31,768
Loss before income taxes	-47,496	-79,173
Income tax benefit (expense)	455	0
Net loss	($47,041)	($79,173)
Basic and diluted loss per common share (in usd per share)	($1.44)	($4.01)
Weighted average number of shares outstanding:
Basic (in shares)	32,739	19,740
Diluted (in shares)	32,739	19,740

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS Statement (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
Net loss	($47,041)	($79,173)
Other comprehensive loss:
Other post-retirement benefits and total other comprehensive loss	-446	0
Comprehensive loss	($47,487)	($79,173)

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net loss	($47,041)	($79,173)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation, depletion, amortization and accretion	14,897	5,982
Non-cash interest expense	15,258	16,742
Change in value of common stock warrants	-4,433	10,159
Change in value of contingent consideration	-2,849	0
Lower of cost or market charge	2,444	0
Deferred taxes	-257	179
Loss (gain) on sale of assets, net	624	-50
Stock-based compensation	3,970	1,161
Unrealized gain on derivative contracts	-1,015	0
Equity (earnings) losses from Piceance Energy, LLC	-2,849	2,941
Net changes in operating assets and liabilities:
Trade accounts receivable	5,608	-40,278
Prepaid and other assets	-5,966	-2,569
Inventories	59,085	69,211
Obligations under supply and exchange agreements	-112,884	-38,999
Accounts payable and other accrued liabilities	20,804	19,017
Net cash used in operating activities	-54,604	-35,677
Cash flows from investing activities
Payment of deposit for Koko'oha acquisition	-10,000	0
Capital expenditures	-14,300	-7,768
Proceeds from sale of assets	595	2,850
Purchase of HIE, net of cash acquired, including working capital settlement	-582	-559,279
Investment in Piceance Energy, LLC	-12	-303
Net cash used in investing activities	-24,299	-564,500
Cash flows from financing activities
Proceeds from sale of common stock, net of offering costs	103,949	199,170
Proceeds from borrowings	363,620	159,800
Repayments of borrowings	-331,530	-121,909
Payment of deferred loan costs	-6,045	-2,264
Proceeds from supply and exchange agreements	0	378,238
Proceeds from exercise of common stock warrants	5	18
Restricted cash released	53	19,000
Net cash provided by financing activities	130,052	632,053
Net increase in cash and cash equivalents	51,149	31,876
Cash at beginning of period	38,061	6,185
Cash at end of period	89,210	38,061
Supplemental cash flow information
Interest paid	-4,526	-2,186
Taxes paid	243	0
Non-cash investing and financing activities
Accrued capital expenditures	2,328	0
Stock issued used to settle bankruptcy claims	2,677	2,605
Value of warrants reclassified to equity	$786	$3,741

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2012	$100,757	$150	$109,446	($8,839)
Balance (in shares) at Dec. 31, 2012		15,008
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock issued in a private transaction, net of offering cost (in shares)		14,388
Stock issued in a private transaction, net of offering cost	199,170	144	199,026
Bankruptcy claim settlements (in shares)		209
Bankruptcy claim settlements	2,605	2	2,603
Exercise of common stock warrants (in shares)		184
Exercise of common stock warrants		2	3,739
Value of warrants reclassified to equity	3,741
Share-based compensation (in shares)		362
Share-based compensation	1,164	3	1,161
Other comprehensive loss	0
Net loss	-79,173		0	-79,173
Balance at Dec. 31, 2013	228,264	301	315,975	-88,012
Balance (in shares) at Dec. 31, 2013		30,151
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reverse stock split	0	1	-1
Stock issued in a private transaction, net of offering cost (in shares)		6,525
Stock issued in a private transaction, net of offering cost	103,949	65	103,884
Bankruptcy claim settlements (in shares)		146
Bankruptcy claim settlements	2,677	1	2,676
Exercise of common stock warrants (in shares)		51
Exercise of common stock warrants			785
Value of warrants reclassified to equity	786
Share-based compensation (in shares)		196
Share-based compensation	3,970	2	3,968
Other comprehensive loss	-446				-446
Net loss	-47,041
Balance at Dec. 31, 2014	$292,159	$371	$427,287	($135,053)	($446)
Balance (in shares) at Dec. 31, 2014		37,069

CONSOLIDATED_STATEMENTS_OF_CHA1

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Statement of Stockholders' Equity [Abstract]
Payments of Stock Issuance Costs	$237	$830

Overview

Overview	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Overview	Note 1—Overview
	We are a diversified energy company based in Houston, Texas. Currently, we operate in three segments: (i) refining, distribution and marketing, (ii) natural gas and oil production, and (iii) commodity marketing and logistics.
	Our refining, distribution, and marketing segment consists of a refinery in Kapolei, Hawaii, refined products terminals, pipelines, a single-point mooring, and retail outlets which distribute gasoline and diesel fuel throughout Hawaii. The refinery produces ultra-low sulfur diesel, gasoline, jet fuel, marine fuel, and other associated refined products primarily for consumption in Hawaii. The refining, distribution, and marketing segment was established through the acquisition of Hawaii Independent Energy, LLC ("HIE") on September 25, 2013.
	Our natural gas and oil assets are non-operated and are concentrated in our 33.34% ownership of Piceance Energy, LLC ("Piceance Energy"), a joint venture entity operated by Laramie Energy II, LLC ("Laramie") and focused on producing natural gas in Garfield and Mesa Counties, Colorado. In addition, we own non-operated interests in Colorado and offshore California, and an overriding royalty interest in New Mexico. Our interests are heavily weighted towards natural gas and natural gas liquids.
	Our commodity marketing and logistics segment focuses on sourcing, marketing, transporting, and distributing crude oil and refined products. Our logistics capability consists of historical pipeline shipping status, a railcar fleet, and expertise in contracted chartering of tows and barges, with the capability of moving crude oil from landlocked locations in the Western U.S. and Canada to the refining hubs in the Midwest, Gulf Coast, and East Coast regions of the U.S.
	As a result of the HIE acquisition, our results of operations for any period after September 30, 2013 will not be comparable to any prior period. We anticipate our results of operations, capital and liquidity position, and the overall success of our business will depend, in large part, on the results of our refinery segment. The differences, or spread, between crude oil prices and the prices we receive for finished products (known as the “crack spread”), both of which are largely beyond our control, will be the primary driver of the refinery segment results of operations and, therefore, of our profitability.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
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 Petroleum Corporation and its subsidiaries. All inter-company 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 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. Significant estimates include the fair value of assets and liabilities, natural gas and oil reserves, income taxes and the valuation allowances related to deferred tax assets, derivatives, asset retirement obligations, and contingencies and litigation accruals.
	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 and cash held at commercial banks to support letter of credit facilities.
	Allowance for Doubtful Accounts
	We establish provisions for losses on trade receivables if it becomes probable 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, 2014 and 2013, we had no significant allowance for doubtful accounts.
	Inventories
	Commodity inventories are stated at the lower of cost or market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.
	Our refining, distribution, and marketing segment acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 9—Supply and Exchange Agreements. The crude oil remains in the legal title of Barclays 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, Barclays takes title to the refined products stored in our storage tanks until sold to our retail locations or to third parties. We record the inventory owned by Barclays on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties.
	Investment in Piceance Energy, LLC
	We account for our Investment in Piceance 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 Piceance 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
	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 improve 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
	We account for our natural gas and oil exploration and development activities using the successful efforts method of accounting. Under such method, costs of productive exploratory wells, development dry holes, and productive wells and undeveloped leases are capitalized. Natural gas and oil lease acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological or geophysical expenses, and delay rentals for natural gas and oil leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, then evaluated quarterly and charged to expense if and when the well is determined not to have found reserves in commercial quantities. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of producing properties.
	Unproved properties are assessed quarterly on a property-by-property basis and any impairment in value is charged to expense. If the unproved properties are determined to be productive, the related costs are transferred to proved oil and natural gas properties and are depleted. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain or loss until all costs have been recovered.
	Depreciation, depletion, and amortization ("DD&A") of capitalized acquisition, exploration, and development costs is computed using the units-of-production method by individual fields (common reservoirs) using proved producing natural gas and oil reserves as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based on total proved natural gas and oil reserves as the related reserves are produced.
	Our natural gas and oil assets are reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.
	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, distribution, and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and 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 DD&A on our consolidated statement of operations and the related capitalized cost is depreciated over the asset’s useful life. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments 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.
	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 two-step quantitative test is required. If required, we will review 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 indicator exists and an estimate of the impairment loss is calculated.
	Our intangible assets include relationships with suppliers and shippers, favorable railcar leases, trade names, and trademarks. These intangible assets will be 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 environmental expenses are recorded in operating expenses in our consolidated statements of operations.
	Derivatives and Other Financial instruments
	We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange-traded futures contracts, collar agreements, swaps, or options. The purpose of the transactions is to provide a measure of stability to our cash flows in an environment of volatile commodity prices.
	Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and will not net settle. Should we not designate a contract as a normal purchase or normal sale, the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. As of December 31, 2014 and 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements.
	In addition, from time to time 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. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.
	Please read Note 10—Debt and Note 11—Fair Value Measurements for information regarding our common stock warrants which are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were accounted for as embedded derivatives.
	Accrued Settlement Claims
	We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy. Please read Note 12—Commitments and Contingencies for further information.
	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 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 2011, 2012, and 2013. 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 over the period the employee provides service, generally the vesting period, and include such costs in General and administrative expense in the consolidated statements of operations. The fair value of equity instruments issued to employees is measured on the grant date and recognized over the service period on a straight-line basis.
	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 collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met.
	Certain transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another and are recorded on a net basis and included in Cost of revenues on our consolidated statements of operations.
	Refining, Distribution and Marketing. 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.
	Federal excise and state motor fuel taxes, which are collected from customers and remitted to governmental agencies within our refining, marketing, and distribution segment are excluded from both Revenues and Cost of revenues in our consolidated statements of operations.
	Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2014 and 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.
	Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of railcars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the purchaser, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.
	Other Post-retirement Benefits - Medical
	We recognize an asset for the overfunded status or a liability for the underfunded status of its post-retirement benefit plan. The funded status is recorded within Other long-term liabilities. Changes in the plan's funded status are recognized in Other comprehensive 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 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. We use data from peers as well as external sources in the determination of the volatility and risk free rates used in our fair value calculations. A sensitivity analysis is performed as well to determine the impact of inputs on the ending fair value estimate.
Loss Per Share
Basic loss per share (“EPS”) is computed by dividing net loss by the sum of the weighted average number of common shares outstanding and the weighted average number of shares issuable under the warrants. Please read Note 15—Loss Per Share for further information. The warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation of basic EPS as these shares are not considered earned until vesting occurs.
Foreign Currency Transactions
We may, on occasion, enter into transactions denominated in currencies other than the U. S. dollar, 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 No. 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. ASU No. 2014-09 is effective for interim and annual periods beginning after December 15, 2016 and early adoption is not permitted. We are in the process of determining the impact this guidance will have on our financial condition, results of operations and cash flows.
In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 is intended to define management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern and to provide related footnote disclosures. The amendments in this ASU are effective for interim and annual periods beginning after December 15, 2016 and early adoption is permitted. We do not expect the adoption of ASU 2014-15 to have a material impact on our financial condition, results of operations and cash flows.
In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis ("ASU 2015-02"). ASU 2015-02 changes the consolidation analysis required under U.S.generally accepted accounting principles. ASU 2015-02 eliminates the presumption that a general partner should consolidate a limited partnership and modifies the evaluation of whether limited partnerships are Variable Interest Entities ("VIEs") or voting interest entities. Under the amended guidance, limited partners would be required to consolidate a partnership if the limited partner retains certain powers and obligations. The amendments in this ASU are effective for annual periods beginning after December 15, 2016, and interim periods beginning after December 15, 2017. Early adoption is permitted, but the guidance must be applied as of the beginning of the annual period containing the adoption date. We are in the process of determining the impact this guidance will have on our financial condition, results of operations and cash flows.

Equity_Method_Investments_Disc

Equity Method Investments Disclosure	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Investment in Piceance Energy	Note 3—Investment in Piceance Energy
	We have a 33.34% ownership interest in Piceance Energy, LLC ("Piceance Energy"), a joint venture operated by Laramie Energy II, LLC ("Laramie") and focused on producing natural gas in Garfield and Mesa Counties, Colorado. Piceance Energy has a $400 million revolving credit facility secured by a lien on its natural gas and oil properties and related assets with a borrowing base currently set at $125 million. As of December 31, 2014 and 2013, the balance outstanding on the revolving credit facility was approximately $98 million and $90.2 million, respectively. We are guarantors of Piceance Energy’s credit facility, with recourse limited to the pledge of our equity interest of our wholly-owned subsidiary, Par Piceance Energy Equity. Under the terms of its credit facility, Piceance Energy is generally prohibited from making future cash distributions to its owners, including us.
	The change in our equity investment in Piceance Energy is as follows (in thousands):
		Year Ended December 31,
		2014		2013
	Beginning balance	$	101,796	$	104,434
	Equity earnings (loss) from Piceance Energy	2,278		(3,516		)
	Accretion of basis difference	571		575
	Investments	12		303
	Ending balance	$	104,657	$	101,796
	Summarized financial information for Piceance Energy is as follows (in thousands):
		December 31,
		2014		2013
	Current assets	$	13,168	$	5,901
	Non-current assets	468,379		454,402
	Current liabilities	17,103		13,040
	Non-current liabilities	107,087		96,738
		Year Ended December 31,
		2014		2013
		100%		100%
	Natural gas and oil revenues	$	80,471	$	61,091
	Income (loss) from operations	3,768		(6,765		)
	Net income (loss)	6,831		(10,546		)
	The net income for year ended December 31, 2014 includes $32.8 million and $9.8 million of DD&A expense and unrealized gains on derivative instruments, respectively. The net loss for the year ended December 31, 2013 includes $26.6 million and $1.1 million of DD&A expense and unrealized losses on derivative instruments, respectively.
	At December 31, 2014 and 2013, our equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment by approximately $14.7 million and $15.3 million, respectively. This difference arose due to lack of control and marketability discounts. We attributed this difference to natural gas and oil properties and are amortizing the difference over 15 years based on the estimate of proved reserves at the date Piceance Energy was formed.

Business_Combination_Disclosur

Business Combination Disclosure	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Acquisitions	Note 4—Acquisitions
	We made our acquisitions in furtherance of our growth strategy that focuses on the acquisition of income producing businesses in order to monetize our net operating loss carryforwards.
	Mid Pac Plan of Merger
	On June 2, 2014, we and our subsidiary entered into an agreement and plan of merger with Koko’oha Investments, Inc., a Hawaii corporation (“Koko’oha”). Koko’oha owns 100% of the outstanding membership interests of Mid Pac Petroleum, LLC, a Delaware limited liability company (“Mid Pac”), which is the exclusive licensee of the “76” brand in the State of Hawaii and the owner/operator of several terminals and retail gasoline stations across Hawaii. Pursuant to the merger agreement, we expect to acquire 100% of Koko’oha and Mid Pac for $107 million, less estimated long-term liabilities, plus estimated merchandise and product inventory, subject to other adjustments as set forth in the merger agreement. Through a series of amendments to the merger agreement with Koko'oha, the date by which we or Koko'oha can terminate the merger agreement for failure to consummate the merger has been extended to March 31, 2015.
	We believe we have satisfied the Federal Trade Commission's concerns under the Hart-Scott-Rodino Act and anticipate entering into a consent decree in mid-March. We expect to close the acquisition in April of 2015.
	In connection with and due upon signing the Mid Pac merger agreement, we funded a $10 million deposit against the purchase price, which was funded through proceeds from the Term Loan and is included in Other long-term assets on our consolidated balance sheets. Please read Note 10—Debt for further information. We are obligated to deposit an additional $5 million against the purchase price within three days of the expiration of the waiting period under the HSR Act. If the merger agreement is terminated due to a breach of representations and obligations by us, we forfeit the deposits. If the merger agreement is terminated due to mutual consent, government order or closing does not occur on or before March 31, 2015, the deposits will be refunded to us. If the merger agreement is terminated due to Mid Pac's breach of representations and warranties, the deposits will be returned to us and Mid Pac will be obligated to pay us an additional $5 million if the termination occurs prior to the expiration or early termination of the waiting period under the HSR Act or $7.5 million if it occurs after. In 2014, we incurred $6.4 million in costs related to the Mid Pac acquisition.
	Hawaii Independent Energy
	On September 25, 2013, one of our subsidiaries completed the acquisition of Tesoro Hawaii which owned and operated a petroleum refinery in Kapolei, Hawaii, certain pipeline assets, floating pipeline mooring equipment, refined products terminals, and retail assets selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii. Following the acquisition, Tesoro Hawaii was renamed Hawaii Independent Energy, LLC (“HIE”). The purchase price was $75 million, paid in cash plus net working capital and inventories at closing plus certain contingent earnout payments of up to $40 million. As a part of the purchase price, we also funded approximately $24.3 million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing. The purchase price was paid with a portion of the net proceeds from the private placement common stock sale (please read Note 13—Stockholders' Equity), amounts received pursuant to the Supply and Exchange Agreements (please read Note 9—Supply and Exchange Agreements) and the ABL Facility (please read Note 10—Debt).
	The contingent earnout payments, if any, are to be paid annually following each of the three calendar years beginning January 1, 2014 through the year ending December 31, 2016, in an amount equal to 20% of the consolidated annual gross margin of HIE in excess of $165 million during such calendar years, with an annual cap of $20 million. In the event that the refinery ceases operations or we dispose of any facility used in the acquired business, our obligation to make earnout payments could be modified and/or accelerated. There were no earnout payments due based on the results for the year ended December 31, 2014.
	We accounted for the acquisition of HIE 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 HIE’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 trademarks. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.
	During 2014, we finalized the HIE acquisition purchase price allocation. The primary purchase price allocation adjustments related to the finalization of the post-retirement medical plan, working capital settlements, and allocating value to underground storage tanks installed by Tesoro Corporation in conjunction with the Environmental Agreement. Please read Note 14—Benefit Plans and Note 12—Commitments and Contingencies for additional information. We believe these adjustments did not have a material impact on prior periods.
	A summary of the final estimated fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Inventory	$	418,750
	Trade accounts receivable	59,553
	Prepaid and other current assets	2,497
	Property, plant and equipment	59,670
	Land	39,800
	Goodwill	13,796
	Intangible assets	4,596
	Accounts payable and other current liabilities	(18,542		)
	Contingent consideration liability	(11,980		)
	Other non-current liabilities	(7,561		)
	Total	$	560,579
	The acquisition was partially funded from proceeds totaling approximately $378.2 million from the Supply and Exchange Agreements. Please read Note 9—Supply and Exchange Agreements for further information. None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs of approximately $7 million are included in Acquisition and integration expense on our consolidated statement of operations for the year ended December 31, 2013.
	The unaudited pro forma financial information for the year ended December 31, 2013 presented below assumes that the HIE acquisitions occurred as of January 1, 2013 (in thousands):
	Revenues	$	2,987
	Net income	$	(122	)
	Revenue and earnings for HIE subsequent to the acquisition are included in the refining, marketing, and distribution segment in Note 17—Segment Information.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventories	Note 5—Inventories
	Inventories at December 31, 2014 and 2013 consist of the following (in thousands):
		December 31, 2014
		Titled Inventory		Supply and Exchange Agreements		Total
	Crude oil and feedstocks	$	—	$	62,594	$	62,594
	Refined products and blend stock	47,922		118,375		166,297
	Warehouse stock and other	14,962		—		14,962
	Total	$	62,884	$	180,969	$	243,853
		December 31, 2013
		Titled Inventory		Supply and Exchange Agreements		Total
	Crude oil and feedstocks	$	—	$	137,706	$	137,706
	Refined products and blend stock	67,532		161,554		229,086
	Warehouse stock and other	13,831		—		13,831
	Total	$	81,363	$	299,260	$	380,623
	The reserves for the lower of cost or market value of inventory was $2.4 million as of December 31, 2014. There was no reserve as of December 31, 2013.

Property_Plant_and_Equipment_D

Property, Plant and Equipment Disclosure	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Note 6—Property, Plant and Equipment
	Major classes of property, plant and equipment consist of the following (in thousands):
		December 31,
		2014			2013
	Land	$	39,800		$	39,800
	Buildings and equipment	81,488			65,878
	Other	2,035			1,945
	Total property, plant and equipment	123,323			107,623
	Proved oil and gas properties	1,122			4,949
	Less accumulated depreciation, depletion and amortization	(11,510		)	(3,968		)
	Property, plant and equipment, net	$	112,935		$	108,604

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 7—Asset Retirement Obligations
	The table below summarizes the changes in our asset retirement obligations (in thousands):
		Year Ended December 31,
		2014			2013
	Asset retirement obligation – beginning of period	$	3,172		$	512
	Obligation acquired	—			2,601
	Accretion expense	239			59
	Change in estimate	(831		)	—
	Asset retirement obligation – end of period	$	2,580		$	3,172

Intangible_assets

Intangible assets	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets	Note 8—Intangible Assets
	Intangible assets consist of the following (in thousands):
		December 31,
		2014			2013
	Intangible assets:
	Supplier relationships	$	3,360		$	3,360
	Railcar leases	3,249			3,249
	Historical shipper status	2,200			2,200
	Trade names and trademarks	4,689			4,689
	Total intangible assets	$	13,498		$	13,498
	Accumulated amortization:
	Supplier relationships	$	(516	)	$	(258	)
	Railcar leases	(1,301		)	(650		)
	Historical shipper status	(2,200		)	(1,100		)
	Trade name and trademarks	(1,975		)	(320		)
	Total accumulated amortization	$	(5,992	)	$	(2,328	)
	Net:
	Supplier relationships	$	2,844		$	3,102
	Railcar leases	1,948			2,599
	Historical shipper status	—			1,100
	Trade name and trademarks	2,714			4,369
	Total intangible assets, net	$	7,506		$	11,170
	Amortization expense was approximately $3.7 million and $2.3 million for the years ended December 31, 2014 and 2013, respectively. Expected amortization expense for each of the next five years and thereafter is as follows (in thousands):
	Year Ended		Amount
	2015		$	2,518
	2016		2,012
	2017		908
	2018		258
	2019		258
	Thereafter		1,552
			$	7,506
	During the year ended December 31, 2014, the changes in the carrying amount of goodwill were as follows (in thousands):
	Balance at beginning of period	$	20,603
	HIE acquisition purchase price allocation adjustments (1)	183
	Balance at end of period	$	20,786
	________________________________________________________
	(1) Please read Note 4—Acquisitions for further discussion of these adjustments.

Supply_and_Exchange_Agreements

Supply and Exchange Agreements	12 Months Ended
	Dec. 31, 2014
Other Commitments [Abstract]
Supply and Exchange Agreements	Note 9—Supply and Exchange Agreements
	HIE entered into several agreements with Barclays Bank PLC ("Barclays"), referred to collectively as the Supply and Exchange Agreements, on September 25, 2013 in connection with the acquisition of HIE. HIE entered into the Supply and Exchange Agreements for the purpose of managing its working capital and the crude oil and refined product inventory at the refinery. Effective July 31, 2014, HIE supplemented the Supply and Exchange Agreements by entering into the Refined Product Supply Master Confirmation, pursuant to which Barclays may provide refined product supply and intermediation arrangements to HIE.
	Pursuant to the Supply and Exchange Agreements, Barclays holds title to all of the crude oil in the tanks at the refinery and holds title to a majority of our refined product inventory in our tanks at the refinery. Barclays also prepaid us for certain inventory held at locations outside of our refinery. We hold title to the inventory during the refining process. Barclays sells the crude oil to us as it is discharged out of the refinery's tanks. We exchange refined product owned by Barclays stored in our tanks for equal volumes of refined product produced by our refinery when we execute third-party sales of refined product. We currently market and sell the refined product independently to third parties. The Supply and Exchange Agreements have an initial term of three years with two one-year renewal options.
	We record the inventory owned by Barclays on our behalf because we maintain the risk of loss until the refined products are sold to third parties. Because we do not hold legal title to the crude oil inventory until it enters the refinery, we record a liability in an amount equal to the carrying value of the crude oil inventory.
	In accordance with the terms of the Supply and Exchange Agreements, the volume of refined products purchased by Barclays in connection with the acquisition of HIE is known as the “Block Volume”. To the extent we have refined product inventory equal to or in excess of the Block Volume at period-end, we record a liability, valued at the carrying value of the related inventory, for only the Block Volume. To the extent we have refined product inventory less than the Block Volume at period-end, we record a liability for the refined product inventory on hand at its carrying value, plus a liability for the shortfall in volumes valued at current market prices. The liability related to the Supply and Exchange Agreements is included in Obligations under supply and exchange agreements on our consolidated balance sheets.
	For the years ended December 31, 2014 and 2013, we incurred approximately $16.5 million and $3.7 million in handling fees related to the Supply and Exchange Agreements, respectively, which is included in Cost of revenues on our consolidated statements of operations. For the years ended December 31, 2014 and 2013, Interest expense and financing costs, net, on our statements of operations includes approximately $4.2 million and $1.1 million of expenses related to the Supply and Exchange Agreements, respectively.

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	Note 10—Debt
	Our debt is as follows (in thousands):
		December 31,
		2014				2013
	Term Loan	$	87,360			$	19,480
	ABL Facility	—				51,800
	Retail Credit Agreement	22,750				26,000
	Texadian Uncommitted Credit Agreement	26,500				—
	Total debt, net of unamortized debt discount	136,610				97,280
	Less current maturities	(29,100		)		(3,250		)
	Long-term debt, net of current maturities and unamortized discount	$	107,510			$	94,030
	Annual maturities of our long-term debt for the next five years and thereafter are as follows (in thousands):
	Year		Amount Due
	2015		$	29,100
	2016		39,371
	2017		2,600
	2018		53,189
	2019		2,600
	Thereafter		9,750
			$	136,610
	Term Loan
	During 2012 and 2013, we borrowed $13 million and $17 million, respectively, pursuant to the Delayed Draw Term Loan Credit Agreement ("Loan Agreement"). The lenders under the Loan Agreement included ZCOF Par Petroleum Holdings, L.L.C. and Highbridge International, LLC, who are also our stockholders. In November 2013, we repaid in full and terminated all of our obligations under the Loan Agreement, other than the New Tranche B Loans described below and expensed $6.1 million of financing costs associated with the termination of the Loan Agreement.
	On December 28, 2012, we amended the Loan Agreement and borrowed an additional $35 million ("Tranche B Loan"). On June 24, 2013, we refinanced and replaced the Tranche B Loan and borrowed $65 million (“New Tranche B Loans”). We repaid a portion of the New Tranche B Loans with proceeds from a private placement. Please read Note 13—Stockholders' Equity for further information.
	The New Tranche B Loans are secured by a lien on substantially all of our assets and our subsidiaries, excluding Texadian, Texadian Energy Canada Limited (“Texadian Canada”), certain of our immaterial subsidiaries, and Hawaii Pacific Energy and its subsidiaries. All our obligations under the New Tranche B Loans are unconditionally guaranteed by the Guarantors.
	On May 30, 2014, we entered into a Twelfth Amendment to the Loan Agreement (collectively with the New Tranche B Loans, the "Twelfth Amendment"), pursuant to which we borrowed an additional $13.2 million which was primarily used to fund the deposit due upon signing the merger agreement with Koko'oha. Please read Note 4—Acquisitions.
	Borrowings under the Twelfth Amendment bore interest (a) from May 30, 2014 to September 1, 2014 at a rate equal to 12% per annum payable in kind and (b) on and after September 1, 2014 at a rate equal to 14.75% per annum payable, at our election, either in cash or in kind. We also agreed to pay a nonrefundable amendment fee of approximately $506 thousand as well as an original issue discount of approximately $630 thousand. The Twelfth Amendment lenders agreed to waive the exit fee related to the existing New Tranche B Loans of which we had accrued approximately $97 thousand as of the date of the Twelfth Amendment. Except as discussed above, the Twelfth Amendment did not change any other terms or conditions of the New Tranche B Loans.
	On July 11, 2014, we and certain subsidiaries entered into a Delayed Draw Term Loan and Bridge Loan Credit Agreement ("Credit Agreement") to provide us with a term loan of up to $50 million ("Term Loan") and a bridge loan of up to $75 million ("Bridge Loan"). The Term Loan amended and restated the Twelfth Amendment, reduced the interest rate, and may be used to fund the additional deposit per the Mid Pac merger agreement, for transaction costs and for working capital and general corporate purposes. The Term Loan matures on July 11, 2018 and bears interest at either 10% per annum if paid in cash or 12% per annum if paid in kind, at our election, and has an original issue discount of 5%. During July 2014, we borrowed $15.5 million to fund transaction costs, provide working capital, and for general corporate purposes.
	On July 28, 2014, we entered into a First Amendment to the Credit Agreement pursuant to which we expanded the Term Loan and borrowed an additional $35 million ("Advance"), which resulted in net proceeds to us of approximately $32 million. The Advance was to be repaid upon the receipt of net equity proceeds from the Rights Offering. Please read Note 13—Stockholders' Equity for more information. Except for the repayment terms, all other terms and conditions remained unchanged. We used the proceeds for working capital and general corporate purposes.
	On September 3, 2014, we terminated all of the Bridge Loan commitments under the Credit Agreement. On September 10, 2014, we entered into a Second Amendment to the Credit Agreement whereby we extended the repayment date of the Advance to March 31, 2015. All other terms and conditions remained unchanged. We expensed approximately $1.8 million of financing costs associated with the termination of the Bridge Loan. On March 11, 2015, we entered into a Third Amendment to the Credit Agreement whereby we extended the repayment date of the Advance to March 31, 2016; therefore, the Advance has been classified as long-term debt as of December 31, 2014. All other terms and conditions remain unchanged.
	Certain lenders to the Credit Agreement are our stockholders. Please read Note 18—Related Party Transactions for more information.
	ABL Facility
	On September 25, 2013 and in connection with the acquisition of HIE, HIE and its subsidiary (“ABL Borrowers”) and Hawaii Pacific Energy entered into an asset-based senior secured revolving credit facility (“ABL Facility”) of up to $125 million, of which up to $50 million of availability under the ABL Facility may be used for the issuances of letters of credit. The ABL Facility is secured by a lien on substantially all of HIE’s assets. The ABL Borrowers borrowed $15 million on September 25, 2013 under the ABL Facility to fund the acquisition of HIE and to provide working capital to the ABL Borrowers. The proceeds from future amounts borrowed pursuant to the ABL Facility were used for general corporate purposes and to fund the working capital of the ABL Borrowers. As of December 31, 2014, the total capacity of the ABL Facility was $79.5 million and we had $2.4 million of letters of credit outstanding.
	Outstanding balances on the ABL Facility bear interest at the base rate specified below (“Base Rate”) plus a margin (based on a sliding scale of 1.00% to 1.50% depending on the borrowing base usage) or the adjusted LIBOR specified below (“Adjusted LIBOR”) plus a margin (based on a sliding scale of 2.00% to 2.50% depending on the borrowing base usage). The margin was 1.25% for Base Rate loans and 2.25% for Adjusted LIBOR loans during 2013. The Base Rate is equal to the highest of (i) the prime lending rate of the ABL Agent, (ii) the Federal Funds Rate plus 0.5% per annum, and (iii) the Adjusted LIBOR for a LIBOR loan denominated in dollars with a one-month interest period commencing on such day plus 1.00%. The effective weighted-average interest rate for 2014 was 2.95%.
	The ABL Borrowers agreed to pay commitment fees for the ABL Facility equal to 0.375% if the borrowing base usage is greater than 50%; and 0.500% if the borrowing base usage is less than or equal to 50%. Outstanding letters of credit will be charged a participation fee at a per annum rate equal to the margin applicable to Adjusted LIBOR loans, a facing fee, and customary administrative fees.
	All loans and other obligations outstanding under the ABL Facility are payable in full on September 25, 2017.
	The ABL Borrowers and Hawaii Pacific Energy are required to comply with various affirmative and negative covenants affecting its business and operations, including compliance with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization, as adjusted, to total fixed charges of 1.0 to 1.0.
	Retail Credit Agreement
	On November 14, 2013, HIE Retail, LLC (“HIE Retail”), our subsidiary, entered into a Credit Agreement (“Retail Credit Agreement”) in the form of a senior secured term loan of up to $30 million (“Retail Term Loan”) and a senior secured revolving line of credit of up to $5 million (“Retail Revolver”). Loans made under the Retail Credit Agreement are secured by a first priority security interest in substantially all of the assets of HIE Retail consisting primarily of 31 distribution outlets, selling fuel products and merchandise on the islands of Oahu, Maui and Hawaii.
	The Retail Credit Agreement requires HIE Retail to comply with various financial covenants that are measured on a quarterly basis commencing with the fiscal quarter ending March 31, 2014 and are calculated on a trailing four-quarter basis. Such covenants require HIE Retail to maintain a maximum Leverage Ratio (as defined in the Retail Credit Agreement) of 5.50 to 1.00 in 2014 and ratably adjusts to 4.75:1 in 2018. HIE Retail is also required to maintain a Fixed Charge Coverage Ratio of 1.15:1.00.
	Retail Term Loan
	Principal on the Retail Term Loan will be repaid in quarterly principal payments over the term through November 14, 2020.
	The Retail Term Loan bears interest, at HIE Retail’s election, at a rate equal to (i) 30, 90 and 180 day LIBOR plus the Applicable Margin (as specified below) for LIBOR Loans (as defined in the Retail Credit Agreement), or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Applicable Margin and is payable quarterly. The effective interest rate for 2014 on the outstanding loan was 2.6%.
	The Applicable Margin for each fiscal quarter is the applicable rate per annum set forth below, such amount to be determined as of the last day of the immediately preceding fiscal quarter.
	Level		Leverage Ratio		Applicable Margin for			Applicable Margin for Base
					LIBOR Loans			Rate Loans
	1		<4.00x		2	%		—	%
	2		4.00x-5.00x		2.25	%		0.25	%
	3		>5.00x		2.5	%		0.5	%
	Fifty percent of annual Excess Cash Flow (as defined in the Retail Credit Agreement) will be applied to the outstanding principal balance of the Term Loan beginning with Excess Cash Flow for fiscal year 2014 to the extent the leverage ratio is equal to or greater than 4.50:1.00.
	Retail Revolver
	The Retail Revolver and any letters of credit issued under the Retail Revolver mature on November 14, 2016.
	Advances under the Retail Revolver will bear interest, at HIE Retail’s election, at a rate equal to (a) 30, 90 and 180 day LIBOR plus the Revolver Applicable Margin (as defined below) for LIBOR Loans, or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Revolver Applicable Margin.
	HIE Retail agreed to pay a fee (“Unused Fee”), based on the leverage ratio on the last date of the immediately preceding quarter as set forth below, based on the unused portion of the Revolver and calculated on the average of the unused amount for the quarter. The Unused Fee is payable quarterly in arrears.
	The Retail Revolver Applicable Margin and the Unused Fee, for each quarter is determined, on the last date of the immediately preceding fiscal quarter:
								Revolver		Revolver
								Applicable Margin for		Applicable Margin for
	Level		Leverage Ratio		Unused Fee			LIBOR Loans		Base Rate Loans
	1		<4.00x		0.25	%		1.75	%	-0.25	%
	2		4.00x-5.00x		0.375	%		2	%	—	%
	3		>5.00x		0.5	%		2.25	%	0.25	%
	Commitment fees for Standby Letters of Credit issued under the Revolver are due quarterly in arrears and will be equal to 2.00% per annum on the letter of credit amount payable. As of December 31, 2014, there were no balances or letters of credit outstanding under the Retail Revolver.
	Texadian Uncommitted Credit Agreement
	On June 12, 2013, Texadian, and its wholly-owned subsidiary Texadian Canada, entered into an Uncommitted Credit Agreement to provide for loans and letters of credit, on an uncommitted and absolutely discretionary basis, in an aggregate amount at any one time outstanding not to exceed $50 million. Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian’s assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian. Texadian agreed to pay certain fees with respect to the loans and letters of credit made available to it under the Uncommitted Credit Agreement, including an up-front fee, an origination fee, a minimum compensation fee, a collateral audit fee, and fees with respect to letters of credit. The Uncommitted Credit Agreement requires Texadian to comply with various affirmative and negative covenants affecting its business, and Texadian must comply with certain financial maintenance covenants, including among other things, covenants regarding the minimum net working capital and minimum tangible net worth of Texadian. The Uncommitted Credit Facility does not permit, at any time, Texadian’s consolidated leverage ratio to be greater than 5.00 to 1.00 or its consolidated gross asset coverage to be equal to or less than zero. As of December 31, 2014, we had $27.6 million of letters of credit outstanding related to this agreement.
	On October 10, 2014, the maturity date of the Uncommitted Credit Agreement was extended to May 15, 2015 and the availability was temporarily increased to $85 million. The temporary increase in availability was extended to January 6, 2015 on December 19, 2014.
On February 20, 2015, Texadian, and its wholly-owned subsidiary Texadian Canada, amended and restated the uncommitted credit agreement. The amendment increased the uncommitted loans and letters of credit capacity to $200 million and matures in February 2016.
Cross Default Provisions
Included within each of the our debt agreements 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, 2014 we are in compliance with all of our credit agreements.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 11—Fair Value Measurements
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Purchase Price Allocation of HIE. The final fair values of the assets acquired and liabilities assumed as a result of the HIE acquisition were estimated as of the date of the acquisition and finalized during the quarter ended September 30, 2014 using valuation techniques described in notes (a) through (g) described below.
						Valuation
		Fair Value				Technique
		(in thousands)
	Net working capital	$	462,258			(a)
	Property, plant and equipment	59,670				(b)
	Land	39,800				(c)
	Goodwill	13,796				(d)
	Intangible assets	4,596				(e)
	Contingent consideration liability	(11,980		)		(f)
	Other non-current liabilities	(7,561		)		(g)
	Total	$	560,579
	(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
	(b)	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 external obsolescence. We consider this to be a Level 3 fair value measurement.
	(c)	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.
	(d)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
	(e)	The fair value of the trade names and trademarks was estimated using a form of the income approach, 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. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.
	(f)	The fair value of the liability for contingent consideration was estimated using Monte Carlo simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.
	(g)	Other non-current assets and liabilities are recorded at their estimated net present value.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Common stock warrants. We estimate the fair value of our outstanding common stock warrants using a Monte Carlo simulation analysis, which is considered to be a Level 3 fair value measurement. Significant inputs used in the Monte Carlo simulation analysis include:
		December 31,
		2014		2013
	Stock price	$16.25		$22.30
	Weighted average exercise price	$0.10		$0.10
	Term (years)	7.67		8.67
	Risk-free rate	2.01%		2.78%
	Expected volatility	50.20%		52.90%
	The expected volatility is based on the 10-year historical volatilities of comparable public companies. Based on the Monte Carlo simulation analysis, the estimated fair value of the common stock warrants was $16.17 and $21.64 per share as of December 31, 2014 and 2013, respectively. Since the common stock warrants were in the money upon issuance, we do not believe that changes in the inputs to the Monte Carlo simulation analysis will have a significant impact to the value of the common stock warrants other than changes in the value of our common stock. Increases in the value of our common stock will increase the value of the common stock warrants. Likewise, a decrease in the value of our common stock will result in a decrease in the value of the common stock warrants.
	Debt prepayment derivative. A previous loan agreement contained a contingent prepayment feature that we accounted for as a derivative. At June 30, 2013, we reduced the carrying value of the debt prepayment derivative to zero because we did not believe there was any probability of us repaying the loan prior to maturity. This was considered a Level 3 fair value measurement. In November 2013, we repaid in full and terminated all of our obligations, including any repayment premiums, under this loan agreement thus extinguishing the liability.
	Derivative instruments. From time to time, we enter into certain exchange traded oil contracts that do not qualify for or for which we do not elect the normal purchase or normal sale exception. Changes in the fair value of these contracts are recorded in earnings. The fair value of our commodity derivatives is measured using the closing market price at the end of the reporting period obtained from the New York Mercantile Exchange and from third-party broker quotes and pricing providers.
	Contingent consideration. The cash consideration for our acquisition of HIE may be increased pursuant to an earn out provision. The liability is remeasured at the end of each reporting period using a Monte Carlo simulation analysis. Significant inputs used in the valuation model include estimated future gross margin, annual gross margin volatility and a present value factor. We consider this to be a Level 3 fair value measurement.
	Financial Statement Impact
	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 and 2013 and their placement within our consolidated balance sheet consist of the following (in thousands):
				December 31,
		Balance Sheet Location		2014				2013
				Asset (Liability)
	Common stock warrants	Common stock warrants		$	(12,123	)		$	(17,336	)
	Contingent consideration liability	Contingent consideration liability		(9,131		)		(11,980		)
	Exchange-traded futures	Prepaid and other current assets		1,015				—
	The following table summarizes the pre-tax gain (loss) recognized in our consolidated statement 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		2014				2013
	Common stock warrants	Change in value of common stock warrants		$	4,433			$	(10,159	)
	Contingent consideration liability	Change in value of contingent consideration		2,849				—
	Debt repayment derivative	Interest expense and financing costs, net		—				45
	Derivatives - exchange traded futures	Cost of revenues		8,228				104
	Commodities - physical forward contracts	Cost of revenues		—				306
	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 and 2013 and their level within the fair value hierarchy is as follows (in thousands):
		December 31, 2014
		Fair Value				Level 1				Level 2		Level 3
	Common stock warrants	$	(12,123	)		$	—			$	—	$	(12,123	)
	Contingent consideration liability	(9,131		)		—				—		(9,131		)
	Derivatives - exchange traded futures	1,015				1,015				—		—
		December 31, 2013
		Fair Value				Level 1				Level 2		Level 3
	Common stock warrants	$	(17,336	)		$	—			$	—	$	(17,336	)
	Contingent consideration liability	(11,980		)		—				—		(11,980		)
	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,
			2014				2013
	Balance, at beginning of period		$	(29,316	)		$	(10,945	)
Settlements		780				3,723
Acquired		—				(11,980		)
Total unrealized income (loss) included in earnings		7,282				(10,114		)
Balance, at end of period		$	(21,254	)		$	(29,316	)
The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2014 and 2013 is as follows (in thousands):
	31-Dec-14
	Carrying Value				Fair Value (1)
Term Loan	$	87,360			$	87,068
ABL Facility (2)	—				—
HIE Retail Credit Agreement (2)	22,750				22,750
Texadian Uncommitted Credit Agreement	26,500				26,500
Common stock warrants	12,123				12,123
Contingent consideration liability	9,131				9,131
	31-Dec-13
	Carrying Value				Fair Value (1)
Term Loan	$	19,480			18,800
ABL Facility (2)	51,800				51,800
HIE Retail Credit Agreement (2)	26,000				26,000
Common stock warrants	17,336				17,336
Contingent consideration liability	11,980				11,980
_________________________________________________________
(1) The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.
(2) Fair value approximates carrying value due to the floating rate interest.
We estimate our long-term debt’s fair value using a discounted cash flow analysis and an estimate of the current yield of 14.11% and 15.28% as of December 31, 2014 and 2013, respectively, by reference to market interest rates for term debt of comparable companies.
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, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 12—Commitments and Contingencies
	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. 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.
	Regulation of Greenhouse Gases. The United States Environmental Protection Agency (“EPA”) has begun regulating greenhouse gases ("GHG") under the Clean Air Act Amendments of 1990 (“Clean Air Act”). 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 Clean Air Act 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 cost of the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity.
	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 (“DOH”) has issued regulations that would require each major facility to reduce CO2 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 Government of Hawaii. The refinery’s capacity to reduce fuel use and GHG emissions is limited. However, the state’s pending regulation allows, and the refinery should 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) which have already dramatically reduced greenhouse emissions or are on schedule to reduce CO2 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 (“EISA”) which, among other things, set a target fuel economy standard of 35 miles per gallon for the combined fleet of cars and light trucks in the United States 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 Clean Air Act 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, which need to be addressed before E15 can be marketed on a large scale for use in traditional gasoline engines. Since April 2006, the State of Hawaii has required that a minimum of 9.2% ethanol be blended into at least 85% of the gasoline pool, but the regulation also limited the amount of ethanol to no more than 10%. Consequently, unless either the state or federal regulations are revised, qualified Renewable Identification Numbers (“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 ppm and also lowers the allowable benzene, aromatics and olefins content of gasoline. The effective date for the new standard, January 1, 2017, gives refiners nationwide little time to engineer, permit and implement substantial modifications. Along with credit and trading options, potential capital upgrades for the refinery are being evaluated.
	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. We may experience a decrease in demand for refined petroleum products due to an increase in combined fleet mileage or due to refined petroleum products being replaced by renewable fuels.
	Environmental Agreement
	On September 25, 2013 (“Closing Date”), Hawaii Pacific Energy (a wholly-owned subsidiary of Par created for purposes of the HIE acquisition), Tesoro and HIE entered into an Environmental Agreement (“Environmental Agreement”), which allocated responsibility for known and contingent environmental liabilities related to the acquisition of HIE, including the Consent Decree as described below.
	Consent Decree. Tesoro is currently negotiating a consent decree with the EPA and the United States Department of Justice concerning alleged violations of the federal Clean Air Act related to the ownership and operation of multiple facilities owned or formerly owned by Tesoro and its affiliates (“Consent Decree”), including the Hawaii refinery. It is anticipated that the Consent Decree will be finalized sometime during the first half of 2015 and will require certain capital improvements to our refinery to reduce emissions of air pollutants.
	We estimate the cost of compliance with the final decree could be $20 million to $25 million. However, Tesoro is responsible under the Environmental Agreement for reimbursing HIE for all reasonable third-party capital expenditures incurred for the construction, installation and commissioning of such capital projects and for the payment of any fines or penalties imposed on HIE arising from the Consent Decree to the extent related to acts or omission of Tesoro or HIE prior to the Closing Date. Tesoro’s obligation to reimburse HIE for such fines and penalties is not subject to a monetary limitation; however, the obligation relating to fines and penalties terminates on the third anniversary of the Closing Date.
	Tank Replacements. Tesoro replaced, at its expense, the existing underground storage tanks at six retail locations. The tank replacements were completed at five of the stations during 2014. The sixth location was completed during the first quarter of 2015.
	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 Closing Date, any fine, penalty or other cost assessed by a governmental authority in connection with violations of environmental laws by HIE prior to the Closing Date, certain groundwater remediation work, the replacement of underground storage tanks located at certain retail sites, fines or penalties imposed on HIE by the Consent Decree related to acts or omissions of Tesoro prior to the Closing Date and to claims and losses related to the Pearl City Superfund Site.
	Tesoro’s indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a deductible of $1 million and a cap of $15 million for certain of Tesoro’s indemnification obligations related to certain pre-existing conditions as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions.
	Recovery Trusts
	We emerged from the reorganization of Delta Petroleum 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.
	We are the beneficiary of the General Trust, subject to the terms of the respective trust agreement and the Plan. Since the Emergence Date, the General Trust has filed various claims and causes of action against third parties before the Bankruptcy Court, which actions are ongoing. Upon liquidation of the various claims and causes of action held by the General Trust, the proceeds, less certain administrative reserves and expenses, will be transferred to us. It is unknown at this time what proceeds, if any, we will realize from the General Trust’s litigation efforts.
	The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. 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.
	As of December 31, 2014 and 2013, 27 and 28 claims totaling approximately $26.5 million and $40.2 million remain to be resolved by the trustee for the General Trust and we have reserved approximately $1.1 million and $3.8 million representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end, respectively. During the year ended December 31, 2014, the trustee for the General Trust settled one claim from U.S. Bank of $3.7 million. In October 2014, we issued 146 thousand shares of common stock to settle this claim. During the year ended December 31, 2013, the trustee for the General Trust settled 59 claims of $26.9 million for approximately $5.4 million in cash and 209 thousand shares of common stock.
	A summary of claims is as follows (in thousands, except number of filed claims):
		For The Year Ended December 31, 2014
									Remaining Filed
		Settled Claims							Claims
						Consideration
		Count		Amount		Cash		Stock	Count	Amount
	U.S. Government Claims	—		$	—	$	—	—	2	$	22,364
	Other Various Claims	1		3,702		—		146	25	4,158
	Total	1		$	3,702	$	—	146	27	$	26,522
		For The Year Ended December 31, 2013
									Remaining Filed
		Settled Claims							Claims
						Consideration
		Count		Amount		Cash		Stock	Count	Amount
	U.S. Government Claims	1		$	—	$	—	—	2	$	22,364
	Former Employee Claims	19		12,695		340		162	—	—
	Macquarie Capital (USA) Inc.	1		8,672		2,500		—	—	—
	Swann and Buzzard Creek Royalty Trust	1		3,200		2,000		—	—	—
	Other Various Claims (1)	37		2,339		543		47	26	17,860
	Total	59		$	26,906	$	5,383	209	28	$	40,224
	_____________________________
	(1)	Includes reserve for contingent/unliquidated claims in the amount of $10 million.
	Capital Leases
	Within our refining, distribution and marketing segment, we have capital lease obligations related primarily to the leases of five retail stations with initial terms of 17 years and generally five years remaining on the current term, with four 5-year renewal options. Minimum annual lease payments including interest, for capital leases are as follows (in thousands):
	2015	$	382
	2016	382
	2017	382
	2018	420
	2019	420
	Thereafter	—
	Total minimum lease payments	1,986
	Less amount representing interest	460
	Total minimum rental payments	$	1,526
	Operating Leases
	Within our refining, distribution and marketing segment, we have various cancellable and noncancellable operating leases related to land, vehicles, office and retail facilities, 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 primary terms of up to 50 years with an average of 12 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 2027.
	In addition, with our commodity marketing and logistics segment, we have various agreements to lease storage facilities, primarily along the Mississippi River, railcars, inland river tank barges and towboats, and other equipment. These leasing agreements have been classified as operating leases for financial reporting purposes and the related rental fees are charged to expense over the lease term as they become payable. The leases generally range in duration of five years or less and contain lease renewal options at fair value. Our railcar leases contain an empty mileage indemnification provision whereby if the empty mileage exceeds the loaded mileage, we are charged for the empty mileage at the rate established by the tariff of the railroad on which the empty miles accrued.
	Minimum annual lease payments extending to 2044 for operating leases to which we are legally obligated and having initial or remaining non-cancellable lease terms in excess of one year are as follows (in thousands):
	2015	$	28,944
	2016	13,263
	2017	11,224
	2018	9,902
2019	7,954
Thereafter	18,194
Total minimum rental payments	$	89,481
Rent expense for the year ended December 31, 2014 and 2013 was approximately $30.2 million and $6.2 million, respectively.
Major Customers
For the year ended December 31, 2014 and 2013, no individual customer accounted for more than 10% of our consolidated revenue.
Other
On April 22, 2013, Texadian entered into a terminaling and storage agreement whereby the operator would provide Texadian with storage facilities, access to a marine terminal and pipelines and railcar offloading services. The initial term of the agreement was for a period of four years and Texadian's minimum commitment during the initial term was approximately $28 million. Effective February 1, 2015, Texadian and the counterparty (i) terminated this terminaling and storage agreement and (ii) entered into a new agreement with an initial term of one year.

Stockholders_Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Stockholders' Equity	Note 13—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.
	We amended our certificate of incorporation to implement a one-for-ten (1:10) reverse stock split of our issued and outstanding common stock, par value $0.01 per share, effective on January 29, 2014 for trading purposes. All references in the financial statements to the number of shares of common stock or warrants, price per share and weighted average number of common stock shares outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted.
	In July 2014, we issued, at no charge, one transferable subscription right with respect to each share of our common stock then outstanding. Holders of subscription rights were entitled to purchase 0.21 shares of our common stock for each subscription right held at an exercise price of $16.00 per whole share. The rights offering was fully subscribed and we issued approximately 6.4 million shares of our common stock resulting in net proceeds of approximately $101.5 million in August 2014. We incurred approximately $237 thousand of offering costs which are included as a reduction of Additional paid-in capital on our consolidated balance sheet.
	On September 25, 2013, we completed a private placement transaction and issued approximately 14.4 million shares of common stock resulting in net proceeds of approximately $199.2 million. We incurred approximately $830 thousand of offering costs which are included as a reduction of Additional paid-in capital on our consolidated balance sheet.
	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 (i) is not filed with the SEC on or prior to the applicable deadline (ii) is not declared effective by the SEC prior to the applicable deadline, or (iii) does not remain effective for the applicable effectiveness period described above then from the 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.
	Incentive Plan
	On December 20, 2012, our Board of Directors (“Board”) approved the Par Petroleum Corporation 2012 Long Term Incentive Plan (“Incentive Plan”). Under the Incentive Plan, the Board, or a committee of the Board, may issue up to 1.6 million shares of our common stock, or incentive stock options, nonstatutory stock options or restricted stock to our employee or directors, or other individuals providing services to us. In general, the terms of any award issue will be determined by the committee upon grant.
	These awards primarily vest ratably over five years. For the year ended December 31, 2014, the following activity occurred under our Incentive Plan (in thousands, except per share amounts), which includes the restricted common stock issued under the Stock Purchase Plan discussed below:
		Shares		Weighted-
				Average
				Grant Date Fair
				Value
	Non vested balance, beginning of period	524		$	16.29
	Granted	239		18.49
	Vested	(196	)	15.04
	Forfeited	—
	Non vested balance, end of period	567		$	17.65
	Available for grant	852
	For the years ended December 31, 2014 and 2013, we recognized compensation costs of approximately $4.8 million and $1.2 million, respectively, related to restricted stock awards in general and administrative expenses within our consolidated statements of operations related to restricted stock awards under our Incentive Plan. As of December 31, 2014 and 2013, there was approximately $7.5 million and $8.1 million, of total unrecognized compensation costs related to restricted stock awards, which are expected to be recognized on a straight-line basis over a weighted average period of 3.75 years and 4.37 years, respectively.
	On September 8, 2014, we entered into a separation agreement with our former chief operating officer and he retired. Pursuant to the separation agreement, we agreed to vest approximately 110 thousand shares of unvested restricted common stock issued under the Incentive Plan as follows (i) approximately 27 thousand shares vested on December 31, 2014 and (ii) approximately 83 thousand shares will vest upon the earlier of the closing or termination of the Mid Pac acquisition. Please read Note 4—Acquisitions for more information. Such shares would have been forfeited under the original terms of the restricted stock grant. As a result of this modification, we recorded $1.7 million of compensation costs during the year ended December 31, 2014, which is included in annual activity disclosed above.
	Stock Purchase Plan
	On June 12, 2014, the Board adopted a Stock Purchase Plan (“SPP”) plan. The SPP is limited to the Company’s qualifying executive officers and directors. The SPP provides that each participant may during the twelve month period beginning with the date of adoption of the SPP, purchase, in a single transaction, up to $1 million of shares of our common stock 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 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 the Company or its 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 shares purchased with 50% of the restricted common stock vesting on each of the two annual anniversaries of the date of grant, pursuant to the terms and conditions of the award of restricted stock. Each purchasing participant will also be granted a nonstatutory stock option 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 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 fair value of each option is estimated on the grant date using the Black-Scholes option-pricing model. The estimated weighted-average grant-date fair value per share of options granted during 2014 was $5.91. Unrecognized compensation cost related to non-vested stock options as of December 31, 2014 totaled $2.2 million and is expected to be recognized over a weighted-average period of 2.0 years.
	For the year ended December 31, 2014, the following stock option activity occurred (options in thousands):
		Number of Options		Weighted-Average		Weighted-Average	Aggregate
				Exercise		Remaining	Intrinsic
				Price		Contractual	Value
						Term in Years
	Outstanding, beginning of year	—		$	—	—	$	—
	Issued	401		16.18
	Exercised	—		—
	Forfeited / canceled	—		—
	Outstanding, end of year	401		$	16.18	5.5	$	—
	Vested, end of year	—					$	—
	Exercisable, end of year	—					$	—
	The expected life of options granted is based on the term of the option. Expected volatilities are based on the historical volatility of our stock. Expected dividend yield is based on annualized dividends at the grant date. The risk-free rate for periods within the contractual life of the option is based on the U.S. Treasury yield curve in effect at the time of grant. Our weighted-average assumptions used to measure stock options granted during 2014 are presented below:
		2014
	Expected life from date of grant (years)	5
	Expected volatility	35	%
	Expected dividend yield	—	%
	Risk-free interest rate	1.76	%

Benefit_Plans_Notes

Benefit Plans (Notes)	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Benefit Plans	Note 14—Benefit Plans
	Defined Contribution Plan
	We maintain several defined contribution plans for our employees. Eligible employees can enter the plans either immediately or after one year of service, depending on the plan. The plans permit employee contributions up to the IRS limits per year. For some plans, we contribute 3% of the employee’s eligible compensation to the plan regardless of the employee’s contribution. On all plans, we match a portion of all the employee’s contributions up to 6% depending on the plan. In addition, we have a money purchase pension plan for certain eligible employees. Under this plan, we make contributions to employee directed investment accounts ranging from 5.5% to 8.5% of eligible compensation depending on the employee’s age. For the years ended December 31, 2014 and 2013, we made contributions to the plans totaling approximately $1.2 million and $502 thousand, respectively.
	Other Post-retirement Benefits - Medical
	Our refining, marketing and distribution segment sponsors 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 are generally eligible to participate in the plan after five years of service and reaching the age of 55 and will pay 20% of the monthly insurance premium. Employees hired after 2006 are generally eligible to participate in the plan after five years of service and reaching the age of 55 and are required to pay 100% of the monthly insurance premium; however, after 10 years of service, they are only required to pay 50% of the monthly insurance premium.
	The post-retirement medical plan resulted from the HIE acquisition and qualifying employees were credited with their prior service under Tesoro which resulted in the recognition of a liability for the projected benefit obligation. However, employees who were vested under the Tesoro post-retirement medical plan on the date of acquisition remain a liability under the Tesoro plan. As such, we did not assume any of these employees’ liability under the plan.
	The changes in the benefit obligation of our post-retirement medical plan as of and for the years ended December 31, 2014, and 2013 were as follows (in thousands):
		2014		2013
	Benefit obligation at the beginning of year	$	4,505	$	—
	Acquisition of HIE	—		4,385
	Service cost	260		69
	Interest cost	194		52
	Plan amendments	48		—
	Actuarial loss (gain)	407		(1		)
	Projected benefit obligation at end of year	$	5,414	$	4,505
	The post-retirement medical plan is an unfunded plan and therefor had no plan assets as of and for the years ended December 31, 2014, and 2013.
	Estimated future benefit payments, which reflect expected future services, that we expect to pay for our post-retirement medical plan are as follows (in thousands):
	2015	$	14
	2016	37
	2017	74
	2018	123
	2019	195
	2020–2024	2,359
	The components of the net periodic benefit cost for the years ended December 31, 2014, and 2013 were as follows (in thousands):
		2014		2013
	Service cost	$	260	$	69
	Interest cost	194		52
	Amortization of prior service cost	9		—
	Net periodic benefit cost	$	463	$	121
	The pre-tax amounts in accumulated other comprehensive loss as of December 31, 2014 and 2013 that have not yet been recognized as components of net periodic costs were as follows (in thousands):
		2014		2013
	Prior service cost (credit)	$	39	$	—
	Net actuarial loss (gain)	407		(1		)
	Total	$	446	$	(1	)
	The weighted-average discount rates used to determine the benefit obligations as of December 31, 2014 and 2013 were 3.50% and 4.50% respectively. The discount rates were selected by comparing the expected plan cash flows to the December 31, 2014 and 2013 Citigroup Pension Discount Curve. The weighted average discount rate used to determine net periodic benefit costs for the years ended December 31, 2014 and 2013 was 4.5%.

Loss_Per_Share

Loss Per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Loss Per Share	Note 15—Loss Per Share
	Basic loss per share is computed by dividing net loss 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 749,148 shares and 790,683 shares as of December 31, 2014 and 2013, respectively. The common stock warrants are included in the calculation of basic loss per share because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the basic weighted-average common stock outstanding computation as these shares are not considered earned until vested. The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share amounts):
		Year Ended December 31,
		2014			2013
	Net loss attributable to common stockholders	$	(47,041	)	$	(79,173	)
	Basic weighted-average common stock outstanding	32,739			19,740
	Add dilutive effects of common stock equivalents (1)	—			—
	Diluted weighted-average common stock outstanding	32,739			19,740
	Basic loss per common share (1)	$	(1.44	)	$	(4.01	)
	Diluted loss per common share (1)	$	(1.44	)	$	(4.01	)
	________________________________________________________
	(1)	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.
	As of December 31, 2014 and 2013, our weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding consisted of 567 thousand and 524 thousand shares of non-vested restricted stock and 401 thousand and no shares of stock options, respectively.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	Note 16—Income Taxes
	We have approximately $1.4 billion in net operating loss carryforwards ("NOL carryforwards"); however, we currently have a full valuation allowance against this tax asset. 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 current and 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 of ASC 740 in order to recognize deferred tax assets and a valuation allowance has been recorded for the full amount of our net deferred tax assets at December 31, 2014 and 2013.
	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 will qualify 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 are eliminated should another ownership change occur within three years. Our amended and restated certificate of incorporation places restrictions upon the ability of the certain equity interest holders to transfer their ownership interest 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, 2014 and 2013, 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 carry forwards will not always be available to offset taxable income apportioned to the various states. The states from which Texadian’s revenues and HIE’s revenues are derived are not the same states in which our NOLs were incurred; therefore we expect to incur state tax liabilities on the net income of Texadian’s and HIE’s operations.
	During 2015 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 tax expense (benefit) consisted of the following:
		Year Ended December 31,
		2014				2013
	Current:
	U.S.—Federal	$	—			$	—
	U.S.—State	(264		)		(179		)
	Foreign	(80		)		—
	Deferred:
	U.S.—Federal	(14		)		(14		)
	U.S.—State	(177		)		193
	Foreign	80				—
	Total	$	(455	)		$	—
	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,
		2014			2013
	Federal statutory rate	35	%		35	%
	State income taxes, net of federal benefit	1.3	%		(0.1	)%
	Change in valuation allowance	(38.8	)%		(23.1	)%
	Permanent Items	3.6	%		(3.7	)%
	Provision to return adjustments	(0.1	)%		(8.1	)%
	Actual income tax rate	1	%		—	%
	Deferred tax assets (liabilities) are comprised of the following (in thousands):
		December 31,
		2014				2013
	Deferred tax assets:
	Net operating loss	$	528,782			$	535,959
	State deferred tax assets	7,885				8,418
	Capital loss carry forwards	26,141				26,141
	Property and equipment	34,312				34,683
	Investment in Piceance Energy	31,334				32,138
	Other	6,112				2,510
	Total deferred tax assets	634,566				639,849
	Valuation allowance	(631,599		)		(637,464		)
	Net deferred tax assets	$	2,967			$	2,385
	Deferred tax liabilities:
	Property and equipment	$	—			$	5
	Texadian Energy intangibles	1,677				2,380
	Other	1,272				—
	State liabilities	57				216
	Total deferred tax liabilities	$	3,006			$	2,601
	Total deferred tax liability, net	$	(39	)		$	(216	)
	We have net operating loss carryovers as of December 31, 2014 of $1.4 billion for federal income tax purposes. If not utilized, the tax net operating loss carryforwards will expire during 2027 through 2033. Our capital loss carryovers as of December 31, 2014 are $74.7 million. If not utilized, these carryovers will expire during 2015 and 2016. We also have Alternative Minimum Tax Credit Carryovers of $800 thousand. These credits do not expire; however, we must first generate regular taxable income before they can be used.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Information	Note 17—Segment Information
	We operate three business segments: (i) Refining, Distribution and Marketing, (ii) Natural Gas and Oil Operations, and (iii) Commodity Marketing and Logistics. Corporate and Other includes trust litigation and settlements and other administrative costs. Summarized financial information concerning reportable segments consists of the following (in thousands):
	For the year ended December 31, 2014	Refining, Distribution and Marketing			Natural Gas and Oil Operations			Commodity Marketing and Logistics			Corporate and Other			Total
	Revenues	$	2,912,881		$	5,984		$	189,160		$	—		$	3,108,025
	Costs of revenue	2,753,961			—			183,511			—			2,937,472
	Operating expense, excluding DD&A	140,900			—			—			—			140,900
	Lease operating expenses	—			5,673			—			—			5,673
	Depreciation, depletion, and amortization	10,242			2,376			2,018			261			14,897
	Loss on sale of assets, net	—			624			—			—			624
	General and administrative expense	15,604			37			4,310			14,353			34,304
	Acquisition and integration costs	4,576			—			—			7,111			11,687
	Operating loss	(12,402		)	(2,726		)	(679		)	(21,725		)	(37,532		)
	Interest expense and financing costs, net													(19,783		)
	Other income (expense), net													(312		)
	Change in value of common stock warrants													4,433
	Change in value of contingent consideration													2,849
	Equity earnings from Piceance Energy, LLC													2,849
	Loss before income taxes													(47,496		)
	Income tax expense													455
	Net loss													$	(47,041	)
	Total assets	$	460,600		$	105,615		$	87,695		$	87,097		$	741,007
	Goodwill	$	13,796		$	—		$	6,990		$	—		$	20,786
	Capital expenditures	$	14,793		$	12		$	300		$	1,523		$	16,628
	For the year ended December 31, 2013	Refining, Distribution and Marketing			Natural Gas and Oil Operations			Commodity Marketing and Logistics			Corporate and Other			Total
	Revenues	$	778,126		$	7,739		$	100,149		$	—		$	886,014
	Costs of revenue	773,583			—			83,483			—			857,066
	Operating expense, excluding DD&A	27,251			—			—			—			27,251
	Lease operating expense	—			5,676			—			—			5,676
	Depreciation, depletion, and amortization	2,267			1,706			2,009			—			5,982
	Loss on sale of assets, net	—			(50		)	—			—			(50		)
	Trust litigation and settlements	—			—			—			6,206			6,206
	General and administrative expense	2,896			130			5,206			13,262			21,494
	Acquisition and integration costs	—			—			—			9,794			9,794
	Operating (loss) income	(27,871		)	277			9,451			(29,262		)	(47,405		)
	Interest expense and financing costs, net													(19,426		)
	Other income (expense), net													758
	Change in value of common stock warrants													(10,159		)
	Equity loss from Piceance Energy, LLC													(2,941		)
	Loss before income taxes													(79,173		)
	Income tax expense													—
	Net loss													$	(79,173	)
	Total assets	$	641,840		$	109,316		$	52,048		$	10,009		$	813,213
	Goodwill	$	13,613		$	—		$	6,990		$	—		$	20,603
	Capital expenditures	$	6,753		$	471		$	—		$	544		$	7,768

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	Note 18—Related Party Transactions
	Term Loan
	Certain of our stockholders, or affiliates of our stockholders, are 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. Please read Note 10—Debt for further information.
	Equity Group Investments ("EGI") and Whitebox - Service Agreements
	On September 17, 2013, we entered into letter agreements (“Services Agreements”) with Equity Group Investments (“EGI”), an affiliate of Zell Credit Opportunities Fund, LP ("ZCOF"), and Whitebox Advisors, LLC, ("Whitebox") each of which own 10% or more of our common stock directly or through affiliates. Pursuant to the Services Agreements, EGI and Whitebox 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 and Whitebox will not receive a fee for the provision of the strategic, advisory or consulting services set forth in the Services Agreements, 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 or Whitebox, as applicable, 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 or Whitebox’s, as applicable, services under the Services Agreements. In consideration of the services provided by EGI and Whitebox under the Services Agreements, we agreed to indemnify each of them for certain losses incurred by them relating to or arising out of the Services Agreements or the services provided thereunder.
	The Services Agreements have 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 these agreements during the year ended December 31, 2014 or 2013.

Disclosures_About_Capitalized_

Disclosures About Capitalized Costs, Costs Incurred (Unaudited)	12 Months Ended
	Dec. 31, 2014
Extractive Industries [Abstract]
Disclosures About Capitalized Costs, Costs Incurred (Unaudited)	Note 19—Disclosures About Capitalized Costs, Costs Incurred (Unaudited)
	Capitalized costs related to oil and gas activities are as follows (in thousands):
		December 31,
		2014			2013
	Company:
	Unproved properties	$	—		$	—
	Proved properties	1,122			4,949
		1,122			4,949
	Accumulated depreciation and depletion	(824		)	(1,868		)
		$	298		$	3,081
	Company’s Share of Piceance Energy:
	Unproved properties	$	15,872		$	15,763
	Proved properties	183,937			168,378
		199,809			184,141
	Accumulated depreciation and depletion	(49,666		)	(38,452		)
		$	150,143		$	145,689
	Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):
		Year Ended December 31,
		2014			2013
	Company:
	Development costs incurred on proved undeveloped reserves	$	—		$	—
	Development costs—other	102			142
	Total	$	102		$	142
	Company’s Share of Piceance Energy:
	Unproved properties acquisition costs	$	—		$	—
	Development costs—other	15,599			6,380
	Total	$	15,599		$	6,380
	For the years ended December 31, 2014 and 2013, neither we or Piceance incurred exploratory well costs so no amounts were capitalized or expensed during these respective periods. Accordingly, there were no suspended exploratory well costs at 2014 and 2013 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:
		Year Ended December 31,
		2014			2013
	Company:
	Revenue:
	Oil and gas revenues	$	5,984		$	7,739
	Expenses:
	Production costs	5,673			5,696
	Depletion and amortization	2,376			1,593
	Exploration	—			—
	Abandoned and impaired properties	—			—
	Results of operations of oil and gas producing activities	$	(2,065	)	$	450
	Company’s share of Piceance Energy:
	Revenue:
	Oil and gas revenues	$	26,829		$	20,364
	Expenses:
	Production costs	11,140			9,885
	Depletion and amortization	10,921			8,855
	Results of operations of oil and gas producing activities	$	4,768		$	1,624
	Total Company and Piceance Energy income from operations of oil and gas producing activities	$	2,703		$	2,074

Information_Regarding_Proved_O

Information Regarding Proved Oil and Gas Reserves (Unaudited)	12 Months Ended
	Dec. 31, 2014
Extractive Industries [Abstract]
Information Regarding Proved Oil and Gas Reserves (Unaudited)	Note 20—Information Regarding Proved Oil and Gas Reserves (Unaudited)
	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 oil and natural gas reserves and present values as of December 31, 2014 and 2013, 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, 2014 and 2013 is as follows:
		Gas			Oil			NGLS			Total
		(MMcf)			(MBbl)			(MBbl)			(MMcfe) (1)
	Company:
	Estimated Proved Reserves: Balance at January 1, 2013	446			286			—			2,163
	Revisions of quantity estimate	460			16			—			557
	Extensions and discoveries	9			3			—			25
	Production	(253	)		(69	)		—			(667	)
	Estimated Proved Reserves: Balance at December 31, 2013(2)	662			236			—			2,078
	Revisions of quantity estimate	65			(67	)		21			(211	)
	Extensions and discoveries	8			1			—			14
	Production	(134	)		(93	)		(4	)		(716	)
	Estimated Proved Reserves: Balance at December 31, 2014(3)	601			77			17			1,165
	Company’s Share of Piceance Energy:
	Estimated Proved Reserves: Balance at January 1, 2013	122,650			831			6,345			165,700
	Revisions of quantity estimate	72,436			174			2,818			90,387
	Extensions and discoveries	3,599			(374	)		(1,334	)		(6,643	)
	Production	(12,088	)		(47	)		(428	)		(14,935	)
	Estimated Proved Reserves: Balance at December 31, 2013(2)	186,597			584			7,401			234,509
	Revisions of quantity estimate	8,876			34			(1,689	)		(1,054	)
	Extensions and discoveries	21,108			128			489			24,808
	Production	(4,831	)		(18	)		(125	)		(5,689	)
	Estimated Proved Reserves: Balance at December 31, 2014(3)	211,750			728			6,076			252,574
	Total Estimated Proved Reserves: Balance at December 31, 2014	212,351			805			6,093			253,739
	__________________________________________________
	(1)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
	(2)	During 2013, the Company's estimated proved reserves, inclusive of the Company's share of Piceance Energy's estimated proved reserves, increased by 68,724 MMcfe or approximately 41%. Revisions of quantity estimates related to our share of Piceance Energy's estimated proved reserves resulted in an increase of 90,387 MMcfe from the beginning of year reserves. These revisions are primarily associated with wells that became economic during 2013.
	(3)	During 2014, the Company's estimated proved reserves, inclusive of the Company's share of Piceance Energy's estimated proved reserves, increased by 17,152 MMcfe or approximately 7%. Extensions and discoveries related to our share of Piceance Energy's estimated proved reserves resulted in an increase of 24,808 MMcfe from the beginning of year reserves. These extensions and discoveries are primarily associated with successful completions by Piceance Energy.
		Gas			Oil			NGLS			Total
		(MMcf)			(MBbl)			(MBbl)			(MMcfe) (1)
	Proved developed reserves
	December 31, 2013	662			236			—			2,078
	December 31, 2013-Company Share of Piceance Energy	45,072			165			1,627			55,829
	Total December 31, 2013	45,734			401			1,627			57,907
	Proved undeveloped reserves
	December 31, 2013	—			—			—			—
	December 31, 2013-Company Share of Piceance Energy	141,525			419			5,774			178,680
	Total December 31, 2013	141,525			419			5,774			178,680
	Proved developed reserves
	December 31, 2014	601			77			17			1,165
	December 31, 2014-Company Share of Piceance Energy	48,855			195			1,226			57,381
	Total December 31, 2014	49,456			272			1,243			58,546
	Proved undeveloped reserves
	December 31, 2014	—			—			—			—
	December 31, 2014-Company Share of Piceance Energy	162,895			533			4,850			195,193
	Total December 31, 2014	162,895			533			4,850			195,193
	__________________________________________________
	(1)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
		CIG				WTI
		per MMbtu				per Bbl
	Base pricing, before adjustments for contractual
	differentials (Company and Piceance): (1)
	December 31, 2013	$	3.53			$	96.91
	December 31, 2014	$	4.36			$	94.99
	__________________________________________________
	(1)	Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.
	Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests.
		December 31,
		2014				2013
		(in thousands)
	Company:
Future net cash flows	$	10,452			$	26,861
Future costs:
Production	7,760				21,999
Development and abandonment	37				319
Income taxes (1)	—				—
Future net cash flows	2,655				4,543
10% discount factor	(889		)		(1,006		)
Standardized measure of discounted future net cash	$	1,766			$	3,537
flows
Company’s Share of Piceance Energy:
Future net cash flows	$	1,268,704			$	984,205
Future costs:
Production	539,796				430,506
Development and abandonment	236,027				234,905
Income taxes (1)	—				—
Future net cash flows	492,881				318,794
10% discount factor	(322,282		)		(229,469		)
Standardized measure of discounted future net	$	170,599			$	89,325
cash flows
Total Company and Company share of equity	$	172,365			$	92,862
investee in the standardized measure of
discounted future net revenues
________________________________________________
(1) No income tax provision is included in the standardized measure calculation shown above as we do not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.
The principal sources of changes in the standardized measure of discounted net cash flows for the years ended December 31, 2014 and 2013 are as follows (in thousands):
	Year Ended December 31, 2014
	Company				Company Share				Total
					of Piceance
					Energy
Beginning of the year
Beginning of the period	$	3,537			$	89,325			$	92,862
Sales of oil and gas production during the period, net of	(1,288		)		(3,763		)		(5,051		)
production costs
Net change in prices and production costs	(31		)		35,837				35,806
Changes in estimated future development costs	118				(6,292		)		(6,174		)
Extensions, discoveries and improved recovery	85				4,914				4,999
Revisions of previous quantity estimates, estimated timing of	(1,111		)		27,632				26,521
development and other
Previously estimated development and abandonment costs	102				14,013				14,115
incurred during the period
Other	—				—				—
Accretion of discount	354				8,933				9,287
End of period	$	1,766			$	170,599			$	172,365
	Year Ended December 31, 2013
	Company				Company Share				Total
					of Piceance
					Energy
Beginning of the year
Beginning of the period	$	8,010			$	71,959			$	79,969
Sales of oil and gas production during the period, net of	(2,044		)		(10,478		)		(12,522		)
production costs
Net change in prices and production costs	(3,833		)		(2,588		)		(6,421		)
Changes in estimated future development costs	—				8,831				8,831
Extensions, discoveries and improved recovery	147				15,471				15,618
Revisions of previous quantity estimates, estimated timing of	395				(4,948		)		(4,553		)
development and other
Previously estimated development and abandonment costs	—				3,142				3,142
incurred during the period
Other	61				740				801
Accretion of discount	801				7,196				7,997
End of period	$	3,537			$	89,325			$	92,862

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
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 Petroleum Corporation and its subsidiaries. All inter-company 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 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. Significant estimates include the fair value of assets and liabilities, natural gas and oil reserves, income taxes and the valuation allowances related to deferred tax assets, derivatives, asset retirement obligations, and contingencies and litigation accruals.
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 and cash held at commercial banks to support letter of credit facilities.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts
	We establish provisions for losses on trade receivables if it becomes probable 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 market value using the first-in, first-out accounting method. We value merchandise along with spare parts, materials and supplies at average cost.
	Our refining, distribution, and marketing segment acquires substantially all of its crude oil from Barclays Bank PLC (“Barclays”) under supply and exchange agreements as described in Note 9—Supply and Exchange Agreements. The crude oil remains in the legal title of Barclays 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, Barclays takes title to the refined products stored in our storage tanks until sold to our retail locations or to third parties. We record the inventory owned by Barclays on our behalf as inventory with a corresponding accrued liability on our balance sheet because we maintain the risk of loss until the refined products are sold to third parties.
Investment in Piceance Energy, LLC	Investment in Piceance Energy, LLC
	We account for our Investment in Piceance 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 Piceance 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 improve 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	Natural Gas and Oil Properties
	We account for our natural gas and oil exploration and development activities using the successful efforts method of accounting. Under such method, costs of productive exploratory wells, development dry holes, and productive wells and undeveloped leases are capitalized. Natural gas and oil lease acquisition costs are also capitalized. Exploration costs, including personnel costs, certain geological or geophysical expenses, and delay rentals for natural gas and oil leases, are charged to expense as incurred. Exploratory drilling costs are initially capitalized, then evaluated quarterly and charged to expense if and when the well is determined not to have found reserves in commercial quantities. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of producing properties.
	Unproved properties are assessed quarterly on a property-by-property basis and any impairment in value is charged to expense. If the unproved properties are determined to be productive, the related costs are transferred to proved oil and natural gas properties and are depleted. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain or loss until all costs have been recovered.
	Depreciation, depletion, and amortization ("DD&A") of capitalized acquisition, exploration, and development costs is computed using the units-of-production method by individual fields (common reservoirs) using proved producing natural gas and oil reserves as the related reserves are produced. Associated leasehold costs are depleted using the unit-of-production method based on total proved natural gas and oil reserves as the related reserves are produced.
	Our natural gas and oil assets are reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.
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, distribution, and marketing business’ refinery and retail operations, as well as plugging and abandonment of wells within our natural gas and 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 DD&A on our consolidated statement of operations and the related capitalized cost is depreciated over the asset’s useful life. We recognize a gain or loss at settlement for any difference between the settlement amount and the recorded liability, which is recorded as a loss on asset disposals and impairments 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.
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 two-step quantitative test is required. If required, we will review 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 indicator exists and an estimate of the impairment loss is calculated.
	Our intangible assets include relationships with suppliers and shippers, favorable railcar leases, trade names, and trademarks. These intangible assets will be 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 environmental expenses are recorded in operating expenses in our consolidated statements of operations.
Derivatives and Other Financial Instruments	Derivatives and Other Financial instruments
	We periodically enter into commodity price risk transactions to manage our exposure to natural gas and oil price volatility. These transactions may take the form of non-exchange traded fixed price forward contracts and exchange-traded futures contracts, collar agreements, swaps, or options. The purpose of the transactions is to provide a measure of stability to our cash flows in an environment of volatile commodity prices.
	Our commodity marketing and logistics segment enters into fixed-price forward purchase and sale contracts for crude oil. The contracts typically contain settlement provisions in the event of a failure of either party to fulfill its commitments under the contract. Our policy is to fulfill or accept the physical delivery of the product, even if shipment is delayed, and will not net settle. Should we not designate a contract as a normal purchase or normal sale, the contract would be accounted for at fair value on our consolidated balance sheets and marked to market each reporting period with changes in fair value being charged to earnings. As of December 31, 2014 and 2013, we have elected the normal purchase normal sale exemption for all outstanding contracts. As a result, we did not recognize the unrealized gains or losses related to these contracts in our consolidated financial statements.
	In addition, from time to time 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. Such instruments are initially recorded at fair value and subsequently adjusted to fair value at the end of each reporting period through earnings.
	Please read Note 10—Debt and Note 11—Fair Value Measurements for information regarding our common stock warrants which are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were accounted for as embedded derivatives.
Accrued Settlement Claims	Accrued Settlement Claims
	We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy. Please read Note 12—Commitments and Contingencies for further information.
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 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 2011, 2012, and 2013. 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 over the period the employee provides service, generally the vesting period, and include such costs in General and administrative expense in the consolidated statements of operations. The fair value of equity instruments issued to employees is measured on the grant date and recognized over the service period on a straight-line basis.
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 collectability is reasonably assured. Revenue that does not meet these criteria is deferred until the criteria are met.
	Certain transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another and are recorded on a net basis and included in Cost of revenues on our consolidated statements of operations.
	Refining, Distribution and Marketing. 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.
	Federal excise and state motor fuel taxes, which are collected from customers and remitted to governmental agencies within our refining, marketing, and distribution segment are excluded from both Revenues and Cost of revenues in our consolidated statements of operations.
	Natural Gas and Oil. Revenues are recognized when title to the products transfers to the purchaser. We follow the “sales method” of accounting for our natural gas and oil revenue and recognize sales revenue on all natural gas or oil sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves. As of December 31, 2014 and 2013, our aggregate natural gas and oil imbalances were not material to our consolidated financial statements.
	Commodity Marketing and Logistics. We earn revenues from the sale and transportation of oil and the rental of railcars. Accordingly, revenues and related costs from sales of oil are recorded when title transfers to the buyer. Transportation revenues are recognized when title passes to the customer, which is when risk of ownership transfers to the purchaser, and physical delivery occurs. Revenues from the rental of railcars are recognized ratably over the lease periods.
Other Post-retirement Benefits - Medical	Other Post-retirement Benefits - Medical
	We recognize an asset for the overfunded status or a liability for the underfunded status of its post-retirement benefit plan. The funded status is recorded within Other long-term liabilities. Changes in the plan's funded status are recognized in Other comprehensive 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 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. We use data from peers as well as external sources in the determination of the volatility and risk free rates used in our fair value calculations. A sensitivity analysis is performed as well to determine the impact of inputs on the ending fair value estimate.
Loss Per Share	Loss Per Share
	Basic loss per share (“EPS”) is computed by dividing net loss by the sum of the weighted average number of common shares outstanding and the weighted average number of shares issuable under the warrants. Please read Note 15—Loss Per Share for further information. The warrants are included in the calculation of basic EPS because they are issuable for minimal consideration. Non-vested restricted stock is excluded from the computation of basic EPS as these shares are not considered earned until vesting occurs.
Foreign Currency Transactions	Foreign Currency Transactions
	We may, on occasion, enter into transactions denominated in currencies other than the U. S. dollar, 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 Note 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 No. 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. ASU No. 2014-09 is effective for interim and annual periods beginning after December 15, 2016 and early adoption is not permitted. We are in the process of determining the impact this guidance will have on our financial condition, results of operations and cash flows.
	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 is intended to define management’s responsibility to evaluate whether there is substantial doubt about an organization’s ability to continue as a going concern and to provide related footnote disclosures. The amendments in this ASU are effective for interim and annual periods beginning after December 15, 2016 and early adoption is permitted. We do not expect the adoption of ASU 2014-15 to have a material impact on our financial condition, results of operations and cash flows.
	In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis ("ASU 2015-02"). ASU 2015-02 changes the consolidation analysis required under U.S.generally accepted accounting principles. ASU 2015-02 eliminates the presumption that a general partner should consolidate a limited partnership and modifies the evaluation of whether limited partnerships are Variable Interest Entities ("VIEs") or voting interest entities. Under the amended guidance, limited partners would be required to consolidate a partnership if the limited partner retains certain powers and obligations. The amendments in this ASU are effective for annual periods beginning after December 15, 2016, and interim periods beginning after December 15, 2017. Early adoption is permitted, but the guidance must be applied as of the beginning of the annual period containing the adoption date. We are in the process of determining the impact this guidance will have on our financial condition, results of operations and cash flows.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
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

Equity_Method_Investments_Disc1

Equity Method Investments Disclosure (Tables)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	The change in our equity investment in Piceance Energy is as follows (in thousands):
		Year Ended December 31,
		2014		2013
	Beginning balance	$	101,796	$	104,434
	Equity earnings (loss) from Piceance Energy	2,278		(3,516		)
	Accretion of basis difference	571		575
	Investments	12		303
	Ending balance	$	104,657	$	101,796
Equity Method Investees Financial Information	Summarized financial information for Piceance Energy is as follows (in thousands):
		December 31,
		2014		2013
	Current assets	$	13,168	$	5,901
	Non-current assets	468,379		454,402
	Current liabilities	17,103		13,040
	Non-current liabilities	107,087		96,738
		Year Ended December 31,
		2014		2013
		100%		100%
	Natural gas and oil revenues	$	80,471	$	61,091
	Income (loss) from operations	3,768		(6,765		)
	Net income (loss)	6,831		(10,546		)

Business_Combination_Disclosur1

Business Combination Disclosure (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Schedule Of Purchase Price Allocation Preliminary Estimated Fair Value Of The Assets Acquired And Liabilities Assumed	A summary of the final estimated fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Inventory	$	418,750
	Trade accounts receivable	59,553
	Prepaid and other current assets	2,497
	Property, plant and equipment	59,670
	Land	39,800
	Goodwill	13,796
	Intangible assets	4,596
	Accounts payable and other current liabilities	(18,542		)
	Contingent consideration liability	(11,980		)
	Other non-current liabilities	(7,561		)
	Total	$	560,579
Business Acquisition, Pro Forma Information	The unaudited pro forma financial information for the year ended December 31, 2013 presented below assumes that the HIE acquisitions occurred as of January 1, 2013 (in thousands):
	Revenues	$	2,987
	Net income	$	(122	)

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	Inventories at December 31, 2014 and 2013 consist of the following (in thousands):
		December 31, 2014
		Titled Inventory		Supply and Exchange Agreements		Total
	Crude oil and feedstocks	$	—	$	62,594	$	62,594
	Refined products and blend stock	47,922		118,375		166,297
	Warehouse stock and other	14,962		—		14,962
	Total	$	62,884	$	180,969	$	243,853
		December 31, 2013
		Titled Inventory		Supply and Exchange Agreements		Total
	Crude oil and feedstocks	$	—	$	137,706	$	137,706
	Refined products and blend stock	67,532		161,554		229,086
	Warehouse stock and other	13,831		—		13,831
	Total	$	81,363	$	299,260	$	380,623

Property_Plant_and_Equipment_D1

Property, Plant and Equipment Disclosure (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Major classes of property, plant and equipment consist of the following (in thousands):
		December 31,
		2014			2013
	Land	$	39,800		$	39,800
	Buildings and equipment	81,488			65,878
	Other	2,035			1,945
	Total property, plant and equipment	123,323			107,623
	Proved oil and gas properties	1,122			4,949
	Less accumulated depreciation, depletion and amortization	(11,510		)	(3,968		)
	Property, plant and equipment, net	$	112,935		$	108,604

Asset_Retirement_Obligation_Di

Asset Retirement Obligation Disclosure (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The table below summarizes the changes in our asset retirement obligations (in thousands):
		Year Ended December 31,
		2014			2013
	Asset retirement obligation – beginning of period	$	3,172		$	512
	Obligation acquired	—			2,601
	Accretion expense	239			59
	Change in estimate	(831		)	—
	Asset retirement obligation – end of period	$	2,580		$	3,172

Intangible_assets_Tables

Intangible assets (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	Intangible assets consist of the following (in thousands):
		December 31,
		2014			2013
	Intangible assets:
	Supplier relationships	$	3,360		$	3,360
	Railcar leases	3,249			3,249
	Historical shipper status	2,200			2,200
	Trade names and trademarks	4,689			4,689
	Total intangible assets	$	13,498		$	13,498
	Accumulated amortization:
	Supplier relationships	$	(516	)	$	(258	)
	Railcar leases	(1,301		)	(650		)
	Historical shipper status	(2,200		)	(1,100		)
	Trade name and trademarks	(1,975		)	(320		)
	Total accumulated amortization	$	(5,992	)	$	(2,328	)
	Net:
	Supplier relationships	$	2,844		$	3,102
	Railcar leases	1,948			2,599
	Historical shipper status	—			1,100
	Trade name and trademarks	2,714			4,369
	Total intangible assets, net	$	7,506		$	11,170
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
	2015		$	2,518
	2016		2,012
	2017		908
	2018		258
	2019		258
	Thereafter		1,552
			$	7,506
Schedule of Goodwill	During the year ended December 31, 2014, the changes in the carrying amount of goodwill were as follows (in thousands):
	Balance at beginning of period	$	20,603
	HIE acquisition purchase price allocation adjustments (1)	183
	Balance at end of period	$	20,786
	________________________________________________________
	(1) Please read Note 4—Acquisitions for further discussion of these adjustments.

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Debt	Our debt is as follows (in thousands):
		December 31,
		2014				2013
	Term Loan	$	87,360			$	19,480
	ABL Facility	—				51,800
	Retail Credit Agreement	22,750				26,000
	Texadian Uncommitted Credit Agreement	26,500				—
	Total debt, net of unamortized debt discount	136,610				97,280
	Less current maturities	(29,100		)		(3,250		)
	Long-term debt, net of current maturities and unamortized discount	$	107,510			$	94,030
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		Amount Due
	2015		$	29,100
	2016		39,371
	2017		2,600
	2018		53,189
	2019		2,600
	Thereafter		9,750
			$	136,610
Schedule Of Applicable Margin For Debt Instrument	The Applicable Margin for each fiscal quarter is the applicable rate per annum set forth below, such amount to be determined as of the last day of the immediately preceding fiscal quarter.
	Level		Leverage Ratio		Applicable Margin for			Applicable Margin for Base
					LIBOR Loans			Rate Loans
	1		<4.00x		2	%		—	%
	2		4.00x-5.00x		2.25	%		0.25	%
	3		>5.00x		2.5	%		0.5	%
Schedule Of Revolver Applicable Margin for Debt Instrument	The Retail Revolver Applicable Margin and the Unused Fee, for each quarter is determined, on the last date of the immediately preceding fiscal quarter:
								Revolver		Revolver
								Applicable Margin for		Applicable Margin for
	Level		Leverage Ratio		Unused Fee			LIBOR Loans		Base Rate Loans
	1		<4.00x		0.25	%		1.75	%	-0.25	%
	2		4.00x-5.00x		0.375	%		2	%	—	%
	3		>5.00x		0.5	%		2.25	%	0.25	%

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements, Nonrecurring	The final fair values of the assets acquired and liabilities assumed as a result of the HIE acquisition were estimated as of the date of the acquisition and finalized during the quarter ended September 30, 2014 using valuation techniques described in notes (a) through (g) described below.
						Valuation
		Fair Value				Technique
		(in thousands)
	Net working capital	$	462,258			(a)
	Property, plant and equipment	59,670				(b)
	Land	39,800				(c)
	Goodwill	13,796				(d)
	Intangible assets	4,596				(e)
	Contingent consideration liability	(11,980		)		(f)
	Other non-current liabilities	(7,561		)		(g)
	Total	$	560,579
	(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
	(b)	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 external obsolescence. We consider this to be a Level 3 fair value measurement.
	(c)	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.
	(d)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
	(e)	The fair value of the trade names and trademarks was estimated using a form of the income approach, 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. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.
	(f)	The fair value of the liability for contingent consideration was estimated using Monte Carlo simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.
	(g)	Other non-current assets and liabilities are recorded at their estimated net present value.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	Significant inputs used in the Monte Carlo simulation analysis include:
		December 31,
		2014		2013
	Stock price	$16.25		$22.30
	Weighted average exercise price	$0.10		$0.10
	Term (years)	7.67		8.67
	Risk-free rate	2.01%		2.78%
	Expected volatility	50.20%		52.90%
Fair Value, Assets Measured on Recurring Basis	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 and 2013 and their level within the fair value hierarchy is as follows (in thousands):
		December 31, 2014
		Fair Value				Level 1				Level 2		Level 3
	Common stock warrants	$	(12,123	)		$	—			$	—	$	(12,123	)
	Contingent consideration liability	(9,131		)		—				—		(9,131		)
	Derivatives - exchange traded futures	1,015				1,015				—		—
		December 31, 2013
		Fair Value				Level 1				Level 2		Level 3
	Common stock warrants	$	(17,336	)		$	—			$	—	$	(17,336	)
	Contingent consideration liability	(11,980		)		—				—		(11,980		)
	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2014 and 2013 and their placement within our consolidated balance sheet consist of the following (in thousands):
				December 31,
		Balance Sheet Location		2014				2013
				Asset (Liability)
	Common stock warrants	Common stock warrants		$	(12,123	)		$	(17,336	)
	Contingent consideration liability	Contingent consideration liability		(9,131		)		(11,980		)
	Exchange-traded futures	Prepaid and other current assets		1,015				—
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The following table summarizes the pre-tax gain (loss) recognized in our consolidated statement 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		2014				2013
	Common stock warrants	Change in value of common stock warrants		$	4,433			$	(10,159	)
	Contingent consideration liability	Change in value of contingent consideration		2,849				—
	Debt repayment derivative	Interest expense and financing costs, net		—				45
	Derivatives - exchange traded futures	Cost of revenues		8,228				104
	Commodities - physical forward contracts	Cost of revenues		—				306
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	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,
			2014				2013
	Balance, at beginning of period		$	(29,316	)		$	(10,945	)
	Settlements		780				3,723
	Acquired		—				(11,980		)
	Total unrealized income (loss) included in earnings		7,282				(10,114		)
	Balance, at end of period		$	(21,254	)		$	(29,316	)
Fair Value and Carrying Value Liabilities Measured On Recurring Basis	The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2014 and 2013 is as follows (in thousands):
		31-Dec-14
		Carrying Value				Fair Value (1)
	Term Loan	$	87,360			$	87,068
	ABL Facility (2)	—				—
	HIE Retail Credit Agreement (2)	22,750				22,750
	Texadian Uncommitted Credit Agreement	26,500				26,500
	Common stock warrants	12,123				12,123
	Contingent consideration liability	9,131				9,131
		31-Dec-13
		Carrying Value				Fair Value (1)
	Term Loan	$	19,480			18,800
	ABL Facility (2)	51,800				51,800
	HIE Retail Credit Agreement (2)	26,000				26,000
	Common stock warrants	17,336				17,336
	Contingent consideration liability	11,980				11,980

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule Of Reorganization Distributions To Satisfy Allowed Claims	A summary of claims is as follows (in thousands, except number of filed claims):
		For The Year Ended December 31, 2014
									Remaining Filed
		Settled Claims							Claims
						Consideration
		Count		Amount		Cash		Stock	Count	Amount
	U.S. Government Claims	—		$	—	$	—	—	2	$	22,364
	Other Various Claims	1		3,702		—		146	25	4,158
	Total	1		$	3,702	$	—	146	27	$	26,522
		For The Year Ended December 31, 2013
									Remaining Filed
		Settled Claims							Claims
						Consideration
		Count		Amount		Cash		Stock	Count	Amount
	U.S. Government Claims	1		$	—	$	—	—	2	$	22,364
	Former Employee Claims	19		12,695		340		162	—	—
	Macquarie Capital (USA) Inc.	1		8,672		2,500		—	—	—
	Swann and Buzzard Creek Royalty Trust	1		3,200		2,000		—	—	—
	Other Various Claims (1)	37		2,339		543		47	26	17,860
	Total	59		$	26,906	$	5,383	209	28	$	40,224
	_____________________________
	(1)	Includes reserve for contingent/unliquidated claims in the amount of $10 million.
Schedule of Future Minimum Lease Payments for Capital Leases	Minimum annual lease payments including interest, for capital leases are as follows (in thousands):
	2015	$	382
	2016	382
	2017	382
	2018	420
	2019	420
	Thereafter	—
	Total minimum lease payments	1,986
	Less amount representing interest	460
	Total minimum rental payments	$	1,526
Schedule of Future Minimum Rental Payments for Operating Leases	Minimum annual lease payments extending to 2044 for operating leases to which we are legally obligated and having initial or remaining non-cancellable lease terms in excess of one year are as follows (in thousands):
	2015	$	28,944
	2016	13,263
	2017	11,224
	2018	9,902
	2019	7,954
	Thereafter	18,194
	Total minimum rental payments	$	89,481

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Schedule Of Equity Incentive Plan Disclosures	These awards primarily vest ratably over five years. For the year ended December 31, 2014, the following activity occurred under our Incentive Plan (in thousands, except per share amounts), which includes the restricted common stock issued under the Stock Purchase Plan discussed below:
		Shares		Weighted-
				Average
				Grant Date Fair
				Value
	Non vested balance, beginning of period	524		$	16.29
	Granted	239		18.49
	Vested	(196	)	15.04
	Forfeited	—
	Non vested balance, end of period	567		$	17.65
	Available for grant	852
Schedule of Share-based Compensation, Stock Options, Activity	For the year ended December 31, 2014, the following stock option activity occurred (options in thousands):
		Number of Options		Weighted-Average		Weighted-Average	Aggregate
				Exercise		Remaining	Intrinsic
				Price		Contractual	Value
						Term in Years
	Outstanding, beginning of year	—		$	—	—	$	—
	Issued	401		16.18
	Exercised	—		—
	Forfeited / canceled	—		—
	Outstanding, end of year	401		$	16.18	5.5	$	—
	Vested, end of year	—					$	—
	Exercisable, end of year	—					$	—
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	Our weighted-average assumptions used to measure stock options granted during 2014 are presented below:
		2014
	Expected life from date of grant (years)	5
	Expected volatility	35	%
	Expected dividend yield	—	%
	Risk-free interest rate	1.76	%

Benefit_Plans_Tables

Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
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 years ended December 31, 2014, and 2013 were as follows (in thousands):
		2014		2013
	Benefit obligation at the beginning of year	$	4,505	$	—
	Acquisition of HIE	—		4,385
	Service cost	260		69
	Interest cost	194		52
	Plan amendments	48		—
	Actuarial loss (gain)	407		(1		)
	Projected benefit obligation at end of year	$	5,414	$	4,505
Schedule of Expected Benefit Payments	Estimated future benefit payments, which reflect expected future services, that we expect to pay for our post-retirement medical plan are as follows (in thousands):
	2015	$	14
	2016	37
	2017	74
	2018	123
	2019	195
	2020–2024	2,359
Schedule of Net Periodic Benefit Cost Not yet Recognized	The components of the net periodic benefit cost for the years ended December 31, 2014, and 2013 were as follows (in thousands):
		2014		2013
	Service cost	$	260	$	69
	Interest cost	194		52
	Amortization of prior service cost	9		—
	Net periodic benefit cost	$	463	$	121
Schedule of Amounts Recognized in Other Comprehensive Income (Loss)	The pre-tax amounts in accumulated other comprehensive loss as of December 31, 2014 and 2013 that have not yet been recognized as components of net periodic costs were as follows (in thousands):
		2014		2013
	Prior service cost (credit)	$	39	$	—
	Net actuarial loss (gain)	407		(1		)
	Total	$	446	$	(1	)

Loss_Per_Share_Tables

Loss Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
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 earnings per share (in thousands, except per share amounts):
		Year Ended December 31,
		2014			2013
	Net loss attributable to common stockholders	$	(47,041	)	$	(79,173	)
	Basic weighted-average common stock outstanding	32,739			19,740
	Add dilutive effects of common stock equivalents (1)	—			—
	Diluted weighted-average common stock outstanding	32,739			19,740
	Basic loss per common share (1)	$	(1.44	)	$	(4.01	)
	Diluted loss per common share (1)	$	(1.44	)	$	(4.01	)
	________________________________________________________
	(1)	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.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Income tax expense (benefit) consisted of the following:
		Year Ended December 31,
		2014				2013
	Current:
	U.S.—Federal	$	—			$	—
	U.S.—State	(264		)		(179		)
	Foreign	(80		)		—
	Deferred:
	U.S.—Federal	(14		)		(14		)
	U.S.—State	(177		)		193
	Foreign	80				—
	Total	$	(455	)		$	—
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,
		2014			2013
	Federal statutory rate	35	%		35	%
	State income taxes, net of federal benefit	1.3	%		(0.1	)%
	Change in valuation allowance	(38.8	)%		(23.1	)%
	Permanent Items	3.6	%		(3.7	)%
	Provision to return adjustments	(0.1	)%		(8.1	)%
	Actual income tax rate	1	%		—	%
Schedule of Deferred Tax Assets and Liabilities	Deferred tax assets (liabilities) are comprised of the following (in thousands):
		December 31,
		2014				2013
	Deferred tax assets:
	Net operating loss	$	528,782			$	535,959
	State deferred tax assets	7,885				8,418
	Capital loss carry forwards	26,141				26,141
	Property and equipment	34,312				34,683
	Investment in Piceance Energy	31,334				32,138
	Other	6,112				2,510
	Total deferred tax assets	634,566				639,849
	Valuation allowance	(631,599		)		(637,464		)
	Net deferred tax assets	$	2,967			$	2,385
	Deferred tax liabilities:
	Property and equipment	$	—			$	5
	Texadian Energy intangibles	1,677				2,380
	Other	1,272				—
	State liabilities	57				216
	Total deferred tax liabilities	$	3,006			$	2,601
	Total deferred tax liability, net	$	(39	)		$	(216	)

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014	Refining, Distribution and Marketing			Natural Gas and Oil Operations			Commodity Marketing and Logistics			Corporate and Other			Total
	Revenues	$	2,912,881		$	5,984		$	189,160		$	—		$	3,108,025
	Costs of revenue	2,753,961			—			183,511			—			2,937,472
	Operating expense, excluding DD&A	140,900			—			—			—			140,900
	Lease operating expenses	—			5,673			—			—			5,673
	Depreciation, depletion, and amortization	10,242			2,376			2,018			261			14,897
	Loss on sale of assets, net	—			624			—			—			624
	General and administrative expense	15,604			37			4,310			14,353			34,304
	Acquisition and integration costs	4,576			—			—			7,111			11,687
	Operating loss	(12,402		)	(2,726		)	(679		)	(21,725		)	(37,532		)
	Interest expense and financing costs, net													(19,783		)
	Other income (expense), net													(312		)
	Change in value of common stock warrants													4,433
	Change in value of contingent consideration													2,849
	Equity earnings from Piceance Energy, LLC													2,849
	Loss before income taxes													(47,496		)
	Income tax expense													455
	Net loss													$	(47,041	)
	Total assets	$	460,600		$	105,615		$	87,695		$	87,097		$	741,007
	Goodwill	$	13,796		$	—		$	6,990		$	—		$	20,786
	Capital expenditures	$	14,793		$	12		$	300		$	1,523		$	16,628
	For the year ended December 31, 2013	Refining, Distribution and Marketing			Natural Gas and Oil Operations			Commodity Marketing and Logistics			Corporate and Other			Total
	Revenues	$	778,126		$	7,739		$	100,149		$	—		$	886,014
	Costs of revenue	773,583			—			83,483			—			857,066
	Operating expense, excluding DD&A	27,251			—			—			—			27,251
	Lease operating expense	—			5,676			—			—			5,676
	Depreciation, depletion, and amortization	2,267			1,706			2,009			—			5,982
	Loss on sale of assets, net	—			(50		)	—			—			(50		)
	Trust litigation and settlements	—			—			—			6,206			6,206
	General and administrative expense	2,896			130			5,206			13,262			21,494
	Acquisition and integration costs	—			—			—			9,794			9,794
	Operating (loss) income	(27,871		)	277			9,451			(29,262		)	(47,405		)
	Interest expense and financing costs, net													(19,426		)
	Other income (expense), net													758
	Change in value of common stock warrants													(10,159		)
	Equity loss from Piceance Energy, LLC													(2,941		)
	Loss before income taxes													(79,173		)
	Income tax expense													—
	Net loss													$	(79,173	)
	Total assets	$	641,840		$	109,316		$	52,048		$	10,009		$	813,213
	Goodwill	$	13,613		$	—		$	6,990		$	—		$	20,603
	Capital expenditures	$	6,753		$	471		$	—		$	544		$	7,768

Disclosures_About_Capitalized_1

Disclosures About Capitalized Costs, Costs Incurred (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
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,
		2014			2013
	Company:
	Unproved properties	$	—		$	—
	Proved properties	1,122			4,949
		1,122			4,949
	Accumulated depreciation and depletion	(824		)	(1,868		)
		$	298		$	3,081
	Company’s Share of Piceance Energy:
	Unproved properties	$	15,872		$	15,763
	Proved properties	183,937			168,378
		199,809			184,141
	Accumulated depreciation and depletion	(49,666		)	(38,452		)
		$	150,143		$	145,689
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,
		2014			2013
	Company:
	Development costs incurred on proved undeveloped reserves	$	—		$	—
	Development costs—other	102			142
	Total	$	102		$	142
	Company’s Share of Piceance Energy:
	Unproved properties acquisition costs	$	—		$	—
	Development costs—other	15,599			6,380
	Total	$	15,599		$	6,380
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:
		Year Ended December 31,
		2014			2013
	Company:
	Revenue:
	Oil and gas revenues	$	5,984		$	7,739
	Expenses:
	Production costs	5,673			5,696
	Depletion and amortization	2,376			1,593
	Exploration	—			—
	Abandoned and impaired properties	—			—
	Results of operations of oil and gas producing activities	$	(2,065	)	$	450
	Company’s share of Piceance Energy:
	Revenue:
	Oil and gas revenues	$	26,829		$	20,364
	Expenses:
	Production costs	11,140			9,885
	Depletion and amortization	10,921			8,855
	Results of operations of oil and gas producing activities	$	4,768		$	1,624
	Total Company and Piceance Energy income from operations of oil and gas producing activities	$	2,703		$	2,074

Information_Regarding_Proved_O1

Information Regarding Proved Oil and Gas Reserves (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013 is as follows:
		Gas			Oil			NGLS			Total
		(MMcf)			(MBbl)			(MBbl)			(MMcfe) (1)
	Company:
	Estimated Proved Reserves: Balance at January 1, 2013	446			286			—			2,163
	Revisions of quantity estimate	460			16			—			557
	Extensions and discoveries	9			3			—			25
	Production	(253	)		(69	)		—			(667	)
	Estimated Proved Reserves: Balance at December 31, 2013(2)	662			236			—			2,078
	Revisions of quantity estimate	65			(67	)		21			(211	)
	Extensions and discoveries	8			1			—			14
	Production	(134	)		(93	)		(4	)		(716	)
	Estimated Proved Reserves: Balance at December 31, 2014(3)	601			77			17			1,165
	Company’s Share of Piceance Energy:
	Estimated Proved Reserves: Balance at January 1, 2013	122,650			831			6,345			165,700
	Revisions of quantity estimate	72,436			174			2,818			90,387
	Extensions and discoveries	3,599			(374	)		(1,334	)		(6,643	)
	Production	(12,088	)		(47	)		(428	)		(14,935	)
	Estimated Proved Reserves: Balance at December 31, 2013(2)	186,597			584			7,401			234,509
	Revisions of quantity estimate	8,876			34			(1,689	)		(1,054	)
	Extensions and discoveries	21,108			128			489			24,808
	Production	(4,831	)		(18	)		(125	)		(5,689	)
	Estimated Proved Reserves: Balance at December 31, 2014(3)	211,750			728			6,076			252,574
	Total Estimated Proved Reserves: Balance at December 31, 2014	212,351			805			6,093			253,739
	__________________________________________________
	(1)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
	(2)	During 2013, the Company's estimated proved reserves, inclusive of the Company's share of Piceance Energy's estimated proved reserves, increased by 68,724 MMcfe or approximately 41%. Revisions of quantity estimates related to our share of Piceance Energy's estimated proved reserves resulted in an increase of 90,387 MMcfe from the beginning of year reserves. These revisions are primarily associated with wells that became economic during 2013.
	(3)	During 2014, the Company's estimated proved reserves, inclusive of the Company's share of Piceance Energy's estimated proved reserves, increased by 17,152 MMcfe or approximately 7%. Extensions and discoveries related to our share of Piceance Energy's estimated proved reserves resulted in an increase of 24,808 MMcfe from the beginning of year reserves. These extensions and discoveries are primarily associated with successful completions by Piceance Energy.
		Gas			Oil			NGLS			Total
		(MMcf)			(MBbl)			(MBbl)			(MMcfe) (1)
	Proved developed reserves
	December 31, 2013	662			236			—			2,078
	December 31, 2013-Company Share of Piceance Energy	45,072			165			1,627			55,829
	Total December 31, 2013	45,734			401			1,627			57,907
	Proved undeveloped reserves
	December 31, 2013	—			—			—			—
	December 31, 2013-Company Share of Piceance Energy	141,525			419			5,774			178,680
	Total December 31, 2013	141,525			419			5,774			178,680
	Proved developed reserves
	December 31, 2014	601			77			17			1,165
	December 31, 2014-Company Share of Piceance Energy	48,855			195			1,226			57,381
	Total December 31, 2014	49,456			272			1,243			58,546
	Proved undeveloped reserves
	December 31, 2014	—			—			—			—
	December 31, 2014-Company Share of Piceance Energy	162,895			533			4,850			195,193
	Total December 31, 2014	162,895			533			4,850			195,193
	__________________________________________________
	(1)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
		CIG				WTI
		per MMbtu				per Bbl
	Base pricing, before adjustments for contractual
	differentials (Company and Piceance): (1)
	December 31, 2013	$	3.53			$	96.91
	December 31, 2014	$	4.36			$	94.99
	__________________________________________________
	(1)	Proved reserves are required to be calculated based on the 12-month, first day of the month historical average price in accordance with SEC rules. The prices shown above are base index prices to which adjustments are made for contractual deducts and other factors.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	Future net cash flows presented below are computed using applicable prices (as summarized above) and costs and are net of all overriding royalty revenue interests.
		December 31,
		2014				2013
		(in thousands)
	Company:
	Future net cash flows	$	10,452			$	26,861
	Future costs:
	Production	7,760				21,999
	Development and abandonment	37				319
	Income taxes (1)	—				—
	Future net cash flows	2,655				4,543
	10% discount factor	(889		)		(1,006		)
	Standardized measure of discounted future net cash	$	1,766			$	3,537
	flows
	Company’s Share of Piceance Energy:
	Future net cash flows	$	1,268,704			$	984,205
	Future costs:
	Production	539,796				430,506
	Development and abandonment	236,027				234,905
	Income taxes (1)	—				—
	Future net cash flows	492,881				318,794
	10% discount factor	(322,282		)		(229,469		)
	Standardized measure of discounted future net	$	170,599			$	89,325
	cash flows
	Total Company and Company share of equity	$	172,365			$	92,862
	investee in the standardized measure of
	discounted future net revenues
	________________________________________________
	(1) No income tax provision is included in the standardized measure calculation shown above as we do not project to be taxable or pay cash income taxes based on its available tax assets and additional tax assets generated in the development of its reserves because the tax basis of its oil and gas properties and NOL carryforwards exceeds the amount of discounted future net earnings.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The principal sources of changes in the standardized measure of discounted net cash flows for the years ended December 31, 2014 and 2013 are as follows (in thousands):
		Year Ended December 31, 2014
		Company				Company Share				Total
						of Piceance
						Energy
	Beginning of the year
	Beginning of the period	$	3,537			$	89,325			$	92,862
	Sales of oil and gas production during the period, net of	(1,288		)		(3,763		)		(5,051		)
	production costs
	Net change in prices and production costs	(31		)		35,837				35,806
	Changes in estimated future development costs	118				(6,292		)		(6,174		)
	Extensions, discoveries and improved recovery	85				4,914				4,999
	Revisions of previous quantity estimates, estimated timing of	(1,111		)		27,632				26,521
	development and other
	Previously estimated development and abandonment costs	102				14,013				14,115
	incurred during the period
	Other	—				—				—
	Accretion of discount	354				8,933				9,287
	End of period	$	1,766			$	170,599			$	172,365
		Year Ended December 31, 2013
		Company				Company Share				Total
						of Piceance
						Energy
	Beginning of the year
	Beginning of the period	$	8,010			$	71,959			$	79,969
	Sales of oil and gas production during the period, net of	(2,044		)		(10,478		)		(12,522		)
	production costs
	Net change in prices and production costs	(3,833		)		(2,588		)		(6,421		)
	Changes in estimated future development costs	—				8,831				8,831
	Extensions, discoveries and improved recovery	147				15,471				15,618
	Revisions of previous quantity estimates, estimated timing of	395				(4,948		)		(4,553		)
	development and other
	Previously estimated development and abandonment costs	—				3,142				3,142
	incurred during the period
	Other	61				740				801
	Accretion of discount	801				7,196				7,997
	End of period	$	3,537			$	89,325			$	92,862

Summary_of_Effects_of_Error_on

Summary of Effects of Error on Consolidated Financial Statements (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Trade accounts receivable	$112,968		$117,493
Inventories	243,853		380,623
Total current assets	460,789		544,501
Total assets	741,007		813,213
Obligations under supply and exchange agreements	197,394		385,519
Total current liabilities	310,806		453,388
Total liabilities	448,848		584,949
Accumulated deficit	-135,053		-88,012
Total stockholders' equity	292,159		228,264
Total liabilities and stockholders' equity	741,007		813,213
Cost of revenues	2,937,472		857,066
Total operating expenses	3,145,557		933,419
Operating loss	-37,532		-47,405
Loss before income taxes and reorganization items	-47,496		-79,173
Net loss	-47,041		-79,173
Basic loss per common share	($1.44)	[1]	($4.01)	[1]
Diluted loss per common share	($1.44)	[1]	($4.01)	[1]
Trade accounts receivable	5,608		-40,278
Inventories	$59,085		$69,211
[1]	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.

Overview_Additional_Informatio

Overview Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014
	segment
Operating segments	3
Piceance Energy [Member]
Ownership of Piceance Energy, LLC	33.34%

Summary_of_Significant_Account3

Summary of Significant Accounting Policies Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
Significant allowance for doubtful accounts		$0
Refining Equipment [Member] | Minimum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	8 years
Refining Equipment [Member] | Maximum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	47 years
Transportation Equipment [Member] | Minimum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Transportation Equipment [Member] | Maximum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	30 years
Retail Site [Member] | Minimum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	14 years
Retail Site [Member] | Maximum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	18 years
Office Equipment [Member] | Minimum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years
Office Equipment [Member] | Maximum [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	7 years
Software and Software Development Costs [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]
PP&E useful life	3 years

Investment_in_Piceance_Energy_

Investment in Piceance Energy Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Depreciation, depletion, amortization and accretion	$14,897,000	$5,982,000
Unrealized gains on derivative instruments	1,015,000	0
Amortization of natural gas and oil properties	15 years
Piceance Energy [Member]
Schedule of Equity Method Investments [Line Items]
Ownership of Piceance Energy, LLC	33.34%
Line credit maximum borrowing amount	400,000,000
Asset borrowing base currently at	125,000,000
Balance outstanding on the revolving credit facility	98,000,000	90,200,000
Depreciation, depletion, amortization and accretion	32,800,000	26,600,000
Unrealized gains on derivative instruments	9,800,000
Unrealized losses on derivative instruments	1,100,000
Amount of equity in underlying assets exceeding carrying value	$14,700,000	$15,300,000

Investment_in_Piceance_Energy_1

Investment in Piceance Energy Change in Equity Investment (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance	$101,796
Equity earnings (loss) from Piceance Energy	2,849	-2,941
Ending balance	104,657	101,796
Piceance Energy [Member]
Investments in and Advances to Affiliates, at Fair Value [Roll Forward]
Beginning balance	101,796	104,434
Equity earnings (loss) from Piceance Energy	2,278	-3,516
Accretion of basis difference	571	575
Investments	12	303
Ending balance	$104,657	$101,796

Investment_in_Piceance_Energy_2

Investment in Piceance Energy Summarized Financial Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
ASSETS
Current assets	$460,789	$544,501
Current liabilities	310,806	453,388
Natural gas and oil revenues	5,984	7,739
Income (loss) from operations	-37,532	-47,405
Net income (loss)	-47,041	-79,173
Piceance Energy [Member]
ASSETS
Current assets	13,168	5,901
Non-current assets	468,379	454,402
Current liabilities	17,103	13,040
Non-current liabilities	107,087	96,738
Natural gas and oil revenues	80,471	61,091
Income (loss) from operations	3,768	-6,765
Net income (loss)	$6,831	($10,546)

Acquisitions_and_Dispositions_

Acquisitions and Dispositions Additional Information (Detail) (USD $)	12 Months Ended		0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Jun. 02, 2014	Sep. 25, 2013
Business Acquisition [Line Items]
Payment of deposit for Koko'oha acquisition	$10,000,000	$0
Earnout payment maximum	9,131,000	11,980,000
Koko' oha Investments, Inc. [Member]
Business Acquisition [Line Items]
Percentage expected to acquire			100.00%
Acquisition amount			107,000,000
Deposit against purchase price			10,000,000
Additional deposit obligation			5,000,000
Mid Pac Petroleum, LLC [Member]
Business Acquisition [Line Items]
Acquisition related costs	6,400,000
Hawaii Independent Energy LLC [Member]
Business Acquisition [Line Items]
Acquisition related costs	7,000,000
Payment of deposit for Koko'oha acquisition				75,000,000
Start-up expenses				24,300,000
Earnout payment percentage of gross margin	20.00%
Earnout payment gross margin minimum	165,000,000
Earnout payment annual cap	20,000,000
Significant acquisitions and disposals, terms	The earnout payments, if any, are to be paid annually following each of the three calendar years beginning January 1, 2014 through the year ending December 31, 2016, in an amount equal to 20% of the consolidated annual gross margin of HIE in excess of $165 million during such calendar years, with an annual cap of $20 million
Funding of acquisition from supply and exchange agreements	378,200,000
Minimum [Member] | Koko' oha Investments, Inc. [Member]
Business Acquisition [Line Items]
Early termination fee			5,000,000
Maximum [Member] | Koko' oha Investments, Inc. [Member]
Business Acquisition [Line Items]
Early termination fee			7,500,000
Maximum [Member] | Hawaii Independent Energy LLC [Member]
Business Acquisition [Line Items]
Earnout payment maximum				$40,000,000
Koko' oha Investments, Inc. [Member] | Mid Pac Petroleum, LLC [Member]
Business Acquisition [Line Items]
Outstanding membership interests of Mid Pac Petroleum, LLC			100.00%

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions Summary of Assets Acquired and Liabilities Assumed (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Goodwill	$20,786	$20,603	$20,603
Hawaii Independent Energy LLC [Member]
Inventory	418,750
Trade accounts receivable	59,553
Prepaid and other current assets	2,497
Property, plant and equipment	59,670
Land	39,800
Goodwill	13,796
Intangible assets	4,596
Accounts payable and other current liabilities	-18,542
Contingent consideration liability	-11,980
Other non-current liabilities	-7,561
Total	$560,579

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions Unaudited Pro Forma Financial Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Business Combinations [Abstract]
Revenues	$2,987
Net income	($122)

Inventories_Detail

Inventories (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Crude oil and feedstocks	$62,594,000	$137,706,000
Refined products and blend stock	166,297,000	229,086,000
Warehouse stock and other	14,962,000	13,831,000
Total	243,853,000	380,623,000
Reserves for the lower of cost or market value of inventory	2,400,000	0
Titled Inventory [Member]
Crude oil and feedstocks	0	0
Refined products and blend stock	47,922,000	67,532,000
Warehouse stock and other	14,962,000	13,831,000
Total	62,884,000	81,363,000
Supply and Exchange Agreements [Member]
Crude oil and feedstocks	62,594,000	137,706,000
Refined products and blend stock	118,375,000	161,554,000
Warehouse stock and other	0	0
Total	$180,969,000	$299,260,000

Property_Plant_and_Equipment_D2

Property, Plant and Equipment (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Land	$39,800	$39,800
Buildings and equipment	81,488	65,878
Other	2,035	1,945
Total property, plant and equipment	123,323	107,623
Proved oil and gas properties	1,122	4,949
Less accumulated depreciation, depletion and amortization	-11,510	-3,968
Property and equipment, net	$112,935	$108,604

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation - beginning of period	$3,172	$512
Obligation acquired	0	2,601
Accretion expense	239	59
Change in estimate	-831	0
Asset retirement obligation - end of period	$2,580	$3,172

Schedule_of_FiniteLived_Intang

Schedule of Finite-Lived Intangible Assets (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	$13,498,000		$13,498,000
Amortization of Intangible Assets	-5,992,000		-2,328,000
Amortized intangible assets, Net	7,506,000		11,170,000
Amortization expense	-3,700,000	-2,300,000
Supplier relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	3,360,000		3,360,000
Amortization of Intangible Assets	-516,000		-258,000
Amortized intangible assets, Net	2,844,000		3,102,000
Rail car leases [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	3,249,000		3,249,000
Amortization of Intangible Assets	-1,301,000		-650,000
Amortized intangible assets, Net	1,948,000		2,599,000
Historical Shipper Status [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	2,200,000		2,200,000
Amortization of Intangible Assets	-2,200,000		-1,100,000
Amortized intangible assets, Net	0		1,100,000
Trade names and trademarks [Member]
Finite-Lived Intangible Assets [Line Items]
Amortized intangible assets, Gross carrying amount	4,689,000		4,689,000
Amortization of Intangible Assets	-1,975,000		-320,000
Amortized intangible assets, Net	$2,714,000		$4,369,000

Finitelived_Intangible_Assets_

Finite-lived Intangible Assets Amortization Expense (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Goodwill and Intangible Assets Disclosure [Abstract]
2015	$2,518
2016	2,012
2017	908
2018	258
2019	258
Thereafter	1,552
Amortized intangible assets, Net	$7,506	$11,170

Schedule_of_Goodwill_Detail

Schedule of Goodwill (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2012
Goodwill [Roll Forward]
Balance at beginning of period	$20,603		$20,603
HIE acquisition purchase price allocation adjustments (1)	183	[1]
Balance at end of period	$20,786		$20,603
[1]	Please read Note 4—Acquisitions for further discussion of these adjustments.

Supply_and_Exchange_Agreements1

Supply and Exchange Agreements (Textual) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Handling fees	$16,500,000	$3,700,000
Supply and exchange agreement expenses	19,783,000	19,426,000
Supply and Exchange Agreements [Member]
Supply and exchange agreement expenses	$4,200,000	$1,100,000

Debt_Schedule_of_Debt_Detail

Debt Schedule of Debt (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Total debt, net of unamortized debt discount	$136,610	$97,280
Less current maturities	-29,100	-3,250
Long-term debt, net of current maturities and unamortized discount	107,510	94,030
Tranche b [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	87,360	19,480
ABL Facility [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	0	51,800	[1]
HIE Retail Credit Agreement [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	22,750	26,000	[1]
Retail Credit Agreement [Member]
Debt Instrument [Line Items]
Long-term Line of Credit		26,000
Texadian Uncommitted Credit Agreement [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	26,500	0
Tranche B Loan [Member]
Debt Instrument [Line Items]
Long-term Line of Credit		$19,480
[1]	Fair value approximates carrying value due to the floating rate interest.

Debt_LongTerm_Debt_Maturities_

Debt Long-Term Debt Maturities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Disclosure [Abstract]
2015	$29,100
2016	39,371
2017	2,600
2018	53,189
2019	2,600
Thereafter	9,750
Total debt, net of unamortized debt discount	$136,610	$97,280

Debt_Additional_Information_De

Debt Additional Information (Detail) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

Jul. 28, 2014

Dec. 28, 2012

Dec. 31, 2014

Dec. 31, 2013

Jul. 11, 2014

Nov. 30, 2013

Dec. 31, 2012

Jun. 24, 2013

Sep. 01, 2014

30-May-14

Sep. 01, 2014

Sep. 03, 2014

Oct. 10, 2014

Nov. 14, 2013

Jul. 31, 2014

Sep. 25, 2013

Jun. 12, 2013

Mar. 30, 2014

Feb. 20, 2015

Outlet

Debt Disclosure [Line Items]

Proceeds from borrowings

$35,000,000

$363,620,000

$159,800,000

Additional amount borrowed (Advance)

35,000,000

Net proceeds

32,000,000

Distribution outlets

31

Percent of annual excess cash flow

0.5

Uncommitted Credit Agreement temporary increase

85,000,000

Debt Instrument, Covenant, Fixed Charge Coverage Ratio Required

1.5

Secured Debt [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

50,000,000

Original issue discount

5.00%

Balance outstanding on the revolving credit facility

15,500,000

ABL Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

125,000,000

Balance outstanding on the revolving credit facility

15,000,000

Senior secured revolving credit facility used for letters of credit issuance

50,000,000

Total capacity at period end

79,500,000

Letters of credit outstanding

2,400,000

Debt Instrument, Interest Rate Terms

Outstanding balances on the ABL Facility bear interest at the base rate specified below (“Base Rate”) plus a margin (based on a sliding scale of 1.00% to 1.50% depending on the borrowing base usage) or the adjusted LIBO rate specified below (“LIBO Rate”) plus a margin (based on a sliding scale of 2.00% to 2.50% depending on the borrowing base usage). The margin was 1.25% for Base Rate loans and 2.25% for LIBO Rate loans during 2013. The Base Rate is equal to the highest of (i) the prime lending rate of the ABL Agent, (ii) the Federal Funds Rate plus 0.5% per annum, and (iii) the LIBO Rate for a LIBO Rate loan denominated in dollars with a one-month interest period commencing on such day plus 1.00%.

Debt Instrument, Fee

The ABL Borrowers agreed to pay commitment fees for the ABL Facility equal to 0.375% if the borrowing base usage is greater than 50% and 0.500% if the borrowing base usage is less than or equal to 50%. Outstanding letters of credit will be charged a participation fee at a per annum rate equal to the margin applicable to LIBO Rate loans, a facing fee and customary administrative fees.

Debt Instrument, Covenant Description

The ABL Facility requires HIE and its subsidiaries and Hawaii Pacific Energy to comply with various affirmative and negative covenants affecting its business and operations, including compliance by HIE in certain circumstances with a minimum ratio of consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”), as adjusted, to total fixed charges of 1.0 to 1.0.

Texadian Uncommitted Credit Agreement [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

50,000,000

Consolidated leverage ratio minimum

5

Letters of credit outstanding

27,600,000

Line of Credit Facility, Collateral

Loans and letters of credit issued under the Uncommitted Credit Agreement are secured by a security interest in and lien on substantially all of Texadian’s assets, including, but not limited to, cash, accounts receivable, and inventory, a pledge by Texadian of 65% of its ownership interest in Texadian Canada, and a pledge by us of 100% of our ownership interest in Texadian.

Delayed Draw Term Loan Agreement [Member]

Debt Disclosure [Line Items]

Proceeds from borrowings

13,000,000

Additional amount borrowed

17,000,000

Financing costs expensed

6,100,000

Delayed Draw Term Loan Agreement [Member] | Tranche B Term Loan [Member]

Debt Disclosure [Line Items]

Proceeds from borrowings

65,000,000

HIE Retail [Member] | Term Loan [Member] | Retail Credit Agreement [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

30,000,000

Maximum leverage ratio

5.5

Maximum leverage ratio future adjustment

4.75

Fixed charge coverage ratio

1.15:1.00

Effective interest rate

2.60%

Consolidated leverage ratio minimum

4.5

Line of Credit Facility, Interest Rate Description

The Term Loan will bear interest, at HIE Retail’s election, at a rate equal to (i) 30, 90 and 180 day LIBOR plus the Applicable Margin (as specified below) for LIBOR Loans (as defined in the Retail Credit Agreement), or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Applicable Margin

Excess Cash Flow Recapture Description

Fifty percent of annual Excess Cash Flow (as defined in the Retail Credit Agreement) will be applied to the outstanding principal balance of the Term Loan beginning with Excess Cash Flow for fiscal year 2014 to the extent the leverage ratio is equal to or greater than 4.50:1.00.

HIE Retail [Member] | Revolving Credit Facility [Member] | Retail Credit Agreement [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

5,000,000

Commitment fee percentage

2.00%

Line of Credit Facility, Interest Rate Description

Advances under the Revolver will bear interest, at HIE Retail’s election, at a rate equal to (a) 30, 90 and 180 day LIBOR plus the Revolver Applicable Margin (as defined below) for LIBOR Loans, or (ii) the primary interest rate established from time to time by the Agent in the ordinary course of its business plus the Revolver Applicable Margin

Texadian Canada [Member] | Texadian Uncommitted Credit Agreement [Member]

Debt Disclosure [Line Items]

Ownership interested pledged as collaterall

0.65

Texadian [Member] | Texadian Uncommitted Credit Agreement [Member]

Debt Disclosure [Line Items]

Ownership interested pledged as collaterall

1

Minimum [Member] | Secured Debt [Member]

Debt Disclosure [Line Items]

Interest rate under credit facility

10.00%

Maximum [Member] | Secured Debt [Member]

Debt Disclosure [Line Items]

Interest rate under credit facility

12.00%

Tranche B Term Loan [Member]

Debt Disclosure [Line Items]

Line of Credit Facility, Increase (Decrease), Net

13,200,000

Interest rate under credit facility

14.75%

12.00%

Nonrefundable amendment fee

506,000

Original issue discount

630,000

Accrued exit fee

97,000

ABL Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

Borrowing base usage less than or equal

50.00%

ABL Revolving Credit Facility [Member] | Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

Effective weighted-average interest rate

2.95%

ABL Revolving Credit Facility [Member] | Minimum [Member]

Debt Disclosure [Line Items]

Commitment fee percentage

0.38%

ABL Revolving Credit Facility [Member] | Maximum [Member]

Debt Disclosure [Line Items]

Commitment fee percentage

0.50%

London Interbank Offered Rate (LIBOR) [Member] | ABL Revolving Credit Facility [Member] | Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

1.00%

2.25%

London Interbank Offered Rate (LIBOR) [Member] | ABL Revolving Credit Facility [Member] | Minimum [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

2.00%

London Interbank Offered Rate (LIBOR) [Member] | ABL Revolving Credit Facility [Member] | Maximum [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

2.50%

London Interbank Offered Rate (LIBOR) [Member] | Federal Funds Rate [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

0.50%

Base Rate [Member] | ABL Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

1.25%

Base Rate [Member] | ABL Revolving Credit Facility [Member] | Minimum [Member] | Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

1.00%

Base Rate [Member] | ABL Revolving Credit Facility [Member] | Maximum [Member] | Revolving Credit Facility [Member]

Debt Disclosure [Line Items]

ABL Facility interest rate

1.50%

Subsequent Event [Member] | Letter of Credit [Member] | Texadian Uncommitted Credit Agreement [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

200,000,000

Bridge Loan [Member] | Secured Debt [Member]

Debt Disclosure [Line Items]

Line credit maximum borrowing amount

75,000,000

Financing costs expensed

$1,800,000

Debt_Margin_Detail

Debt Margin (Detail)	12 Months Ended
	Dec. 31, 2014
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Margin rate	2.00%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Margin rate	0.00%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Margin rate	2.25%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Margin rate	0.25%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Margin rate	2.50%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Margin rate	0.50%

Debt_Retail_Revolver_Applicabl

Debt Retail Revolver Applicable Margin and Unused Fee (Detail)	12 Months Ended
	Dec. 31, 2014
Leverage Ratio Less Than 4.00 [Member]
Debt Instrument [Line Items]
Unused Fee	0.25%
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	1.75%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	-0.25%
Leverage Ratio 4.00-5.00 [Member]
Debt Instrument [Line Items]
Unused Fee	0.38%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	2.00%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	0.00%
Leverage Ratio Grater Than 5.00 [Member]
Debt Instrument [Line Items]
Unused Fee	0.50%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	2.25%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]
Debt Instrument [Line Items]
Revolver Applicable Margin	0.25%

Fair_Value_Measurements_Fair_V

Fair Value Measurements Fair Values of Assets Acquired and Liabilities Assumed (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Goodwill	$20,786		$20,603	$20,603
Long-term capital lease obligations	-1,295		-1,526
Purchase Price Allocation of HIE
Net working capital	462,258	[1]
Goodwill	13,796	[2]
Intangible assets	4,596	[3]
Long-term capital lease obligations	-11,980	[4]
Other non-current liabilities	-7,561	[5]
Total	560,579
Purchase Price Allocation of HIE | Property, Plant and Equipment, Other Types [Member]
Property, plant and equipment	59,670	[6]
Purchase Price Allocation of HIE | Land [Member]
Property, plant and equipment	$39,800	[7]
[1]	Current assets acquired and liabilities assumed were recorded at their net realizable value.
[2]	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
[3]	The fair value of the trade names and trademarks was estimated using a form of the income approach, 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. An increase in the estimated revenue or royalty rate would result in an increase in the value attributable to the trade names and trademarks. We consider this to be a Level 3 fair value measurement.
[4]	The fair value of the liability for contingent consideration was estimated using Monte Carlo simulation. Significant inputs used in the model include estimated future gross margin, annual gross margin volatility and a present value factor. An increase in estimated future gross margin, volatility or the present value factor would result in an increase in the liability. We consider this to be a Level 3 fair value measurement.
[5]	Other non-current assets and liabilities are recorded at their estimated net present value.
[6]	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 external obsolescence. We consider this to be a Level 3 fair value measurement.
[7]	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.

Fair_Value_Measurements_Fair_F

Fair Value Measurements Fair Falue of Outstanding Common Stock Warrants (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Fair Value Disclosures [Abstract]
Stock price	$16.25	$22.30
Weighted average exercise price	$0.10	$0.10
Term (years)	7 years 8 months 0 days	8 years 8 months 1 day
Risk-free rate	2.01%	2.78%
Expected volatility	50.20%	52.90%
Historical volatilities period	10 years
Fair value of common stock warrants	$16.17	$21.64

Fair_Value_Measurements_Assets

Fair Value Measurements Assets and Liabilities Measured at Fair Value on a Recurring Basis (Detail) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Warrant [Member] | Derivative Financial Instruments, Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset (Liability)	($12,123)	($17,336)
Contingent Consideration Liability [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset (Liability)	-9,131	-11,980
Embedded Derivative [Member] | Derivative Financial Instruments, Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset (Liability)	($1,015)	$0

Fair_Value_Measurements_PreTax

Fair Value Measurements Pre-Tax Gain (Loss) Recognized From Derivative Instruments (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Change in Value of Contingent Consideration [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	$2,849	$0
Warrant [Member] | Change In Value Of Warrants [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	4,433	-10,159
Debt Repayment Derivative [Member] | Interest Expense and Financing Costs, Net [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	0	45
Future [Member] | Loss On Derivative Instruments, Net [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	8,228	104
Forward Contracts [Member] | Loss On Derivative Instruments, Net [Member]
Derivatives not designated as hedges, Gain (loss) recognized in income	$0	$306

Fair_Value_Measurements_Deriva

Fair Value Measurements Derivative Assets and Liabilities Measured at Fair Value on a Recurring Basis (Detail) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Warrant [Member]
Liabilities
Fair value of derivative liability	($12,123)	($17,336)
Debt Prepayment Derivative [Member]
Liabilities
Fair value of derivative liability		-11,980
Fair Value, Inputs, Level 1 [Member] | Warrant [Member]
Liabilities
Fair value of derivative liability	0	0
Fair Value, Inputs, Level 1 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Fair value of derivative liability		0
Fair Value, Inputs, Level 2 [Member] | Warrant [Member]
Liabilities
Fair value of derivative liability	0	0
Fair Value, Inputs, Level 2 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Fair value of derivative liability		0
Fair Value, Inputs, Level 3 [Member] | Warrant [Member]
Liabilities
Fair value of derivative liability	-12,123	-17,336
Fair Value, Inputs, Level 3 [Member] | Debt Prepayment Derivative [Member]
Liabilities
Fair value of derivative liability		-11,980
Contingent Consideration Liability [Member]
Liabilities
Fair value of derivative liability	-9,131
Contingent Consideration Liability [Member] | Fair Value, Inputs, Level 1 [Member]
Liabilities
Fair value of derivative liability	0
Contingent Consideration Liability [Member] | Fair Value, Inputs, Level 2 [Member]
Liabilities
Fair value of derivative liability	0
Contingent Consideration Liability [Member] | Fair Value, Inputs, Level 3 [Member]
Liabilities
Fair value of derivative liability	-9,131
Embedded Derivative [Member]
Assets
Fair value of derivative asset	1,015
Embedded Derivative [Member] | Fair Value, Inputs, Level 1 [Member]
Assets
Fair value of derivative asset	1,015
Embedded Derivative [Member] | Fair Value, Inputs, Level 2 [Member]
Assets
Fair value of derivative asset	0
Embedded Derivative [Member] | Fair Value, Inputs, Level 3 [Member]
Assets
Fair value of derivative asset	$0

Fair_Value_Measurements_Deriva1

Fair Value Measurements Derivative Instruments Measured at Fair Value (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, at beginning of period	($29,316)	($10,945)
Settlements	780	3,723
Acquired	0	-11,980
Total unrealized income (loss) included in earnings	7,282	-10,114
Balance, at end of period	($21,254)	($29,316)

Fair_Value_Measurements_Carryi

Fair Value Measurements Carrying Value and Fair Value of Long-Term Debt and Other Financial Instruments (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Common stock warrants, Carrying Value	$12,123,000		$17,336,000
Contingent consideration liability, Carrying Value	9,131,000		11,980,000
Common stock warrants, Fair Value	12,123,000	[1]	17,336,000	[1]
Contingent consideration liability, Fair Value	9,131,000	[1]	11,980,000	[1]
Long term debt fair value	14.11%		15.28%
Tranche b [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Line of credit, Carrying Value	87,360,000		19,480,000
Lines of credit, Fair Value	87,068,000	[1]	18,800,000	[1]
ABL Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Line of credit, Carrying Value	0		51,800,000	[2]
Lines of credit, Fair Value	0	[1],[2]	51,800,000	[1],[2]
HIE Retail Credit Agreement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Line of credit, Carrying Value	22,750,000		26,000,000	[2]
Lines of credit, Fair Value	22,750,000	[1],[2]	26,000,000	[1],[2]
Texadian Uncommitted Credit Agreement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Line of credit, Carrying Value	26,500,000		0
Lines of credit, Fair Value	$26,500,000	[1]
[1]	The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.
[2]	Fair value approximates carrying value due to the floating rate interest.

Commitments_and_Contingencies_1

Commitments and Contingencies Additional Information (Detail) (USD $)	12 Months Ended		0 Months Ended
Share data in Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Apr. 22, 2013
	Option	Count
	claim	claim
	Count
Commitments and Contingencies [Line Items]
Settlement ratio for allowed claims	0.0544
Number of capital lease renewals	4
Capital lease period	5 years
Number of remaining claim to be resolved	27	28
Remaining Filed Claims	$26,522,000	$40,224,000
Estimated value of claims remaining to be settled	1,096,000	3,793,000
Number of claims settled		59
Amount of claims settled	3,702,000	26,906,000
Amount of claim settled in cash	0	5,383,000
Amount of claim settled in stock	146	209
Reserve for unliquidated claims	10,000,000
Capital lease obligation term	17 years
Capital lease renewal term	with four 5-year renewal options
Operating lease term	50 years
Remaining term on operating lease	12 years
Rent expense	30,200,000	6,200,000
Customer Revenue Description	no individual customer accounted for more than 10% of our consolidated revenue
Tesoros [Member]
Commitments and Contingencies [Line Items]
Deductible for indemnification obligation	1,000,000
Indemnification obligation cap	15,000,000
Tesoros [Member] | Hawaii Independent Energy LLC [Member]
Commitments and Contingencies [Line Items]
Indemnification Obligation Limitation, Description	Tesoro’s indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a cap of $15 million for certain of Tesoro’s indemnification obligations related to certain pre-existing conditions as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions.
Texadian Energy Inc [Member]
Commitments and Contingencies [Line Items]
Service agreement term			4 years
Agreement commitment amount			28,000,000
U.S. Bank [Member]
Commitments and Contingencies [Line Items]
Number of claims settled	1
Common Stock [Member]
Commitments and Contingencies [Line Items]
Bankruptcy claim settlements (in shares)	146	209
Clear Air Act Violation [Member]
Commitments and Contingencies [Line Items]
Final decree low estimate	20,000,000
Final decree high estimate	$25,000,000

Commitments_and_Contingencies_2

Commitments and Contingencies Summary of Claims (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
	claim		Count
	Count		claim
Commitment And Contingencies [Line Items]
Number of claims settled			59
Amount of claims settled	$3,702		$26,906
Amount of claim settled in cash	0		5,383
Amount of claim settled in stock	146		209
Number of remaining claim to be resolved	27		28
Remaining Filed Claims	26,522		40,224
U S Government [Member]
Commitment And Contingencies [Line Items]
Number of claims settled	0		1
Amount of claims settled	0		0
Amount of claim settled in cash	0		0
Amount of claim settled in stock	0		0
Number of remaining claim to be resolved	2		2
Remaining Filed Claims	22,364		22,364
Former Employee Claims [Member]
Commitment And Contingencies [Line Items]
Number of claims settled			19
Amount of claims settled			12,695
Amount of claim settled in cash			340
Amount of claim settled in stock			162
Number of remaining claim to be resolved			0
Remaining Filed Claims			0
Macquarie Capital Incorporated [Member]
Commitment And Contingencies [Line Items]
Number of claims settled			1
Amount of claims settled			8,672
Amount of claim settled in cash			2,500
Amount of claim settled in stock			0
Number of remaining claim to be resolved			0
Remaining Filed Claims			0
Swann And BuzzardCreek RoyaltyTrust [Member]
Commitment And Contingencies [Line Items]
Number of claims settled			1
Amount of claims settled			3,200
Amount of claim settled in cash			2,000
Amount of claim settled in stock			0
Number of remaining claim to be resolved			0
Remaining Filed Claims			0
Other Various Claims [Member]
Commitment And Contingencies [Line Items]
Number of claims settled	1	[1]	37	[1]
Amount of claims settled	3,702	[1]	2,339	[1]
Amount of claim settled in cash	0	[1]	543	[1]
Amount of claim settled in stock	146	[1]	47	[1]
Number of remaining claim to be resolved	25	[1]	26	[1]
Remaining Filed Claims	$4,158	[1]	$17,860	[1]
[1]	Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Commitments_and_Contingencies_3

Commitments and Contingencies Capital Lease Payment Schedule (Detail) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]
2015	$382
2016	382
2017	382
2018	420
2019	420
Thereafter	0
Total minimum lease payments	1,986
Less amount representing interest	460
Total minimum rental payments	$1,526

Commitments_and_Contingencies_4

Commitments and Contingencies Operating Lease Payment Schedule (Detail) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]
2015	$28,944
2016	13,263
2017	11,224
2018	9,902
2019	7,954
Thereafter	18,194
Total minimum rental payments	$89,481

Stockholders_Equity_Details_Te

Stockholders' Equity (Details Textual) (Detail) (USD $)	0 Months Ended			1 Months Ended		12 Months Ended		0 Months Ended
	Jan. 29, 2014	Sep. 25, 2013	Dec. 20, 2012	Aug. 31, 2014	Jul. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Jun. 12, 2014	Sep. 08, 2014
Class of Stock [Line Items]
Reverse stock split	0.1
Common stock, par value (in dollars per share)	$0.01					$0.01	$0.01
Transferable subscription right with respect to each share of common stock					1
Common stock per subscription right					0.21
Subscription right exercise price					16
Common stock, shares issued		14,400,000		6,400,000		37,068,886	30,151,000
Proceeds from sale of common stock		$199,200,000		$101,500,000		$103,949,000	$199,170,000
Offering costs		830,000				237,000
Maximum amount of repurchase rights agreement						50,000,000
Shares of compensation authorized to be issued under the Incentive Plan (in shares)			1,600,000
Total shares of restricted stock vested in separation agreement									110,000
Compensation cost from separation agreement						1,700,000
Weighted-average grant-date fair value per share of options granted (in usd per share)						$5.91
Period of stock option compensation cost recognition						2 years
Diluted weighted-average common stock outstanding (in shares)						32,739,000	19,740,000
Restricted Stock [Member]
Class of Stock [Line Items]
Restricted stock vesting period			5 years
Compensation cost						4,800,000	1,200,000
Unrecognized compensation costs related to restricted stock awards						7,500,000	8,100,000
Period of restricted stock compensation cost recognition						3 years 9 months	4 years 4 months 13 days
Employee Stock Option [Member]
Class of Stock [Line Items]
Unrecognized compensation costs related to restricted stock awards						2,200,000
Diluted weighted-average common stock outstanding (in shares)						401,000	0
Share-based Compensation Award, Tranche One [Member]
Class of Stock [Line Items]
Separation agreement with former chief operating officer, first tranche						27,000
Koko' oha Investments, Inc. [Member] | Share-based Compensation Award, Tranche Two [Member]
Class of Stock [Line Items]
Separation agreement with former chief operating officer, second tranche						83,000
Stock Purchase Plan [Member] | Employee Stock [Member]
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
Stock Purchase Plan [Member] | Non-Employee Chairman [Member] | Employee Stock [Member]
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan								50.00%
Stock Purchase Plan [Member] | Non-Employee Board Member [Member] | Employee Stock [Member]
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan								35.00%
Stock Purchase Plan [Member] | Executive Officer [Member] | Minimum [Member] | Employee Stock [Member]
Class of Stock [Line Items]
Vesting percentage of purchase of stock options in relation to shares purchased under the Stock Purchase Plan								50.00%
Stock Purchase Plan [Member] | Executive Officer [Member] | Maximum [Member] | Employee Stock [Member]
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_Details_De

Stockholders' Equity (Details) (Detail) (Long Term Incentive Plan [Member], USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Long Term Incentive Plan [Member]
Stock Awards, Shares
Non vested balance, beginning of period	567	524
Granted	239
Vested	-196
Forfeited	0
Non vested balance, end of period	567	524
Available for grant	852
Stock Awards, Weighted-Average Grant Date Fair Value
Non vested balance, beginning of period (in usd per share)	$16.29
Granted (in usd per share)	$18.49
Vested (in usd per share)	$15.04
Non vested balance, end of period (in usd per share)	$17.65

Stockholders_Equity_Details_1_

Stockholders' Equity (Details 1) (Detail) (USD $)	12 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Number of Options
Outstanding, beginning of year (in shares)	32,739	19,740
Issued (in shares)	401
Forfeited / canceled (in shares)	0
Outstanding, end of year (in shares)	32,739	19,740
Weighted-Average Exercise Price
Issued (in usd per share)	$16.18
Forfeited / canceled (in usd per share)	$0
Aggregate Intrinsic Value
Vested, end of year	$0
Predecessor [Member]
Number of Options
Exercised (in shares)	0
Vested, end of year (in shares)	0
Exercisable, end of year (in shares)	0
Weighted-Average Exercise Price
Outstanding, beginning of year (in usd per share)	$0
Exercised (in usd per share)	$0
Outstanding, end of year (in usd per share)	$16.18
Weighted-Average Remaining Contractual Term in Years
Outstanding, end of year	5 years 6 months
Aggregate Intrinsic Value
Outstanding, beginning of year	0
Outstanding, end of year	0
Exercisable, end of year	$0

Stockholders_Equity_Details_2_

Stockholders' Equity (Details 2) (Detail)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life from date of grant (years)	5 years
Expected volatility	35.00%
Expected dividend yield	0.00%
Risk-free interest rate	1.76%

Benefit_Plans_Benefit_Plans_Po

Benefit Plans Benefit Plans Post Retirement Medical Plan Benefit Obligation and Plan Assets (Details) (Postretirement Medical Plan [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Postretirement Medical Plan [Member]
Change in benefit obligation:
Benefit obligation at the beginning of year	$5,414	$4,505	$0
Acquisition of HIE	0	4,385
Service cost	260	69
Interest cost	194	52
Plan amendments	48	0
Actuarial loss (gain)	407	-1
Projected benefit obligation at end of year	$5,414	$4,505	$0

Benefit_Plans_Benefit_Plans_Po1

Benefit Plans Benefit Plans Post Retirement Medical Plan Payments (Details) (Postretirement Medical Plan [Member], USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Postretirement Medical Plan [Member]
Estimated Future Benefit Payments
2015	$14
2016	37
2017	74
2018	123
2019	195
2020-2024	$2,359

Benefit_Plans_Benefit_Plans_Po2

Benefit Plans Benefit Plans Post Retirement Medical Plan Net Periodic Benefit Cost (Details) (Postretirement Medical Plan [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Postretirement Medical Plan [Member]
Components of net periodic benefit cost:
Service cost	$260	$69
Interest cost	194	52
Amortization of prior service cost	9	0
Net periodic benefit cost	$463	$121

Benefit_Plans_Benefit_Plans_Po3

Benefit Plans Benefit Plans Post Retirement Medical Plan Accumulated Other Comprehensive Income (Details) (Postretirement Medical Plan [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Postretirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit)	$39	$0
Net actuarial loss (gain)	407	-1
Total	$446	($1)

Benefit_Plans_Benefit_Plans_Po4

Benefit Plans Benefit Plans Post Retirement Medical Plan Additional Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Schedule of Defined Benefit Plans and Defined Contribution Plans Disclosures [Line Items]
Company contribution percentage	3.00%
Company maximum match percentage	6.00%
Total plan contributions	$1,200	$502
Post-retirement medical, maximum age of coverage	65
Post-retirement medical, minimum service requirement	5 years
Post-retirement medical, minimum age of coverage	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	3.50%	4.50%
Weighted average discount rate use to determine net periodic benefit costs	4.50%	4.50%
Minimum [Member]
Schedule of Defined Benefit Plans and Defined Contribution Plans Disclosures [Line Items]
Range of contribution percentage to employee directed investment accounts	5.50%
Maximum [Member]
Schedule of Defined Benefit Plans and Defined Contribution Plans Disclosures [Line Items]
Range of contribution percentage to employee directed investment accounts	8.50%

Basic_and_Diluted_Loss_Per_Sha

Basic and Diluted Loss Per Share (Detail) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Net loss	($47,041)		($79,173)
Basic weighted-average common stock outstanding	32,739,000		19,740,000
Add dilutive effects of common stock equivalents	$0	[1]	$0	[1]
Diluted weighted-average common stock outstanding	32,739,000		19,740,000
Basic loss per common share attributable to common stockholders:
Net loss (in usd per share)	($1.44)	[1]	($4.01)	[1]
Diluted loss per common share attributable to common stockholders:
Net loss (in usd per share)	($1.44)	[1]	($4.01)	[1]
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average number of shares issuable under the common stock warrants	749,148		790,683
Diluted weighted-average common stock outstanding	401,000		0
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non vested balance, beginning of period	567,000		524,000
[1]	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.

Income_Taxes_Textual_Detail

Income Taxes (Textual) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014
Income Taxes [Line Items]
Net operating loss carryovers	1,400,000,000
Capital Loss carryovers	74,700,000
Alternative minimum tax credit carryovers	800,000
Minimum [Member]
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2027
Capital Loss carryovers, expiry year	2015
Maximum [Member]
Income Taxes [Line Items]
Net operating loss carryforwards expiration year	2033
Capital Loss carryovers, expiry year	2016

Income_Taxes_Expense_Benefit_D

Income Taxes Expense (Benefit) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Current:
U.S.—Federal	$0	$0
U.S.—State	-264	-179
Foreign	-80	0
Deferred:
U.S.—Federal	-14	-14
U.S.—State	-177	193
Foreign	80	0
Total	($455)	$0

Income_Tax_Rate_Reconciliation

Income Tax Rate Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Federal statutory rate	35.00%	35.00%
State income taxes, net of federal benefit	1.30%
Change in valuation allowance	-38.80%	-23.10%
Permanent Items	3.60%	-3.70%
Provision to return adjustments	-0.10%	-8.10%
Actual income tax rate	1.00%	0.00%

Deferred_Tax_Asset_Liabilities

Deferred Tax Asset (Liabilities) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Deferred tax assets:
Net operating loss	$528,782	$535,959
State deferred tax assets	7,885	8,418
Capital loss carry forwards	26,141	26,141
Property and equipment	34,312	34,683
Investment in Piceance Energy	31,334	32,138
Other	6,112	2,510
Total deferred tax assets	634,566	639,849
Valuation allowance	-631,599	-637,464
Net deferred tax assets	2,967	2,385
Deferred tax liabilities:
Property and equipment	0	5
Texadian Energy intangibles	1,677	2,380
Other	1,272	0
State liabilities	57	216
Total deferred tax liabilities	3,006	2,601
Total deferred tax liability, net	($39)	($216)

Segment_Information_Detail

Segment Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Segment
Revenues	$3,108,025	$886,014
Cost of revenues	2,937,472	857,066
Operating expense, excluding depreciation, depletion and amortization expense	140,900	27,251
Lease operating expense	5,673	5,676
Depreciation, depletion and amortization	14,897	5,982
Loss on sale of assets, net	624	-50
Trust litigation and settlements		6,206
General and administrative expense	34,304	21,494
Acquisition and integration expense	11,687	9,794
Operating loss	-37,532	-47,405
Interest expense and financing costs, net	-19,783	-19,426
Other income (expense), net	-312	758
Change in value of common stock warrants	4,433	-10,159
Change in value of contingent consideration	2,849	0
Equity earnings (losses) from Piceance Energy, LLC	2,849	-2,941
Loss before income taxes	-47,496	-79,173
Income tax benefit (expense)	455	0
Net loss	-47,041	-79,173
Total assets	741,007	813,213
Goodwill	20,786	20,603	20,603
Capital expenditures	16,628	7,768
Number of businsess segment	3
Refining Distribution and Marketing [Member]
Revenues	2,912,881	778,126
Cost of revenues	2,753,961	773,583
Operating expense, excluding depreciation, depletion and amortization expense	140,900	27,251
Lease operating expense	0	0
Depreciation, depletion and amortization	10,242	2,267
Loss on sale of assets, net	0	0
Trust litigation and settlements		0
General and administrative expense	15,604	2,896
Acquisition and integration expense	4,576	0
Operating loss	-12,402	-27,871
Total assets	460,600	641,840
Goodwill		13,613
Capital expenditures	14,793	6,753
Natural Gas and Oil Operations [Member]
Revenues	5,984	7,739
Cost of revenues	0	0
Operating expense, excluding depreciation, depletion and amortization expense	0	0
Lease operating expense	5,673	5,676
Depreciation, depletion and amortization	2,376	1,706
Loss on sale of assets, net	624	-50
Trust litigation and settlements		0
General and administrative expense	37	130
Acquisition and integration expense	0	0
Operating loss	-2,726	277
Total assets	105,615	109,316
Goodwill	0	0
Capital expenditures	12	471
Commodity Marketing And Logistics [Member]
Revenues	189,160	100,149
Cost of revenues	183,511	83,483
Operating expense, excluding depreciation, depletion and amortization expense	0	0
Lease operating expense	0	0
Depreciation, depletion and amortization	2,018	2,009
Loss on sale of assets, net	0	0
Trust litigation and settlements		0
General and administrative expense	4,310	5,206
Acquisition and integration expense	0	0
Operating loss	-679	9,451
Total assets	87,695	52,048
Goodwill	6,990	6,990
Capital expenditures	300	0
Corporate and Other [Member]
Revenues	0	0
Cost of revenues	0	0
Operating expense, excluding depreciation, depletion and amortization expense	0	0
Lease operating expense	0	0
Depreciation, depletion and amortization	261	0
Loss on sale of assets, net	0	0
Trust litigation and settlements		6,206
General and administrative expense	14,353	13,262
Acquisition and integration expense	7,111	9,794
Operating loss	-21,725	-29,262
Total assets	87,097	10,009
Goodwill	0	0
Capital expenditures	$1,523	$544

Related_Party_Transaction_Deta

Related Party Transaction (Details Textual) (Detail) (USD $)	12 Months Ended		3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2014	Sep. 17, 2013
Percentage ownership of Par common stock				10.00%
Service agreement costs	$0	$0
Investor [Member]
Travel and out of pocket expenses			$50,000
Initial term of service agreements	1 year
Services Agreements, Renewal Term	1 year
Termination period between extension date	60 days

Disclosures_About_Capitalized_2

Disclosures About Capitalized Costs, Costs Incurred (Details) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Company:
Proved properties	$1,122	$4,949
Company [Member]
Company:
Unproved properties	0	0
Proved properties	1,122	4,949
Oil and Gas Property, Successful Effort Method, Gross, Total	1,122	4,949
Accumulated depreciation and depletion	-824	-1,868
Oil and gas property, successful efforts method	298	3,081
Company's Share of Piceance Energy [Member]
Company:
Unproved properties	15,872	15,763
Proved properties	183,937	168,378
Oil and Gas Property, Successful Effort Method, Gross, Total	199,809	184,141
Accumulated depreciation and depletion	-49,666	-38,452
Oil and gas property, successful efforts method	$150,143	$145,689

Disclosures_About_Capitalized_3

Disclosures About Capitalized Costs, Costs Incurred (Details 1) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Company [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Development costs incurred on proved undeveloped reserves	$0	$0
Development costs—other	102	142
Total	102	142
Company's Share of Piceance Energy [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Development costs—other	15,599	6,380
Unproved properties acquisition costs	0	0
Total	$15,599	$6,380

Disclosures_About_Capitalized_4

Disclosures About Capitalized Costs, Costs Incurred (Details 2) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Revenue:
Oil and gas revenues	$5,984	$7,739
Company [Member]
Revenue:
Oil and gas revenues	5,984	7,739
Expenses:
Production costs	5,673	5,696
Depletion and amortization	2,376	1,593
Exploration	0	0
Abandoned and impaired properties	0	0
Results of operations of oil and gas producing activities	-2,065	450
Company's Share of Piceance Energy [Member]
Revenue:
Oil and gas revenues	26,829	20,364
Expenses:
Production costs	11,140	9,885
Depletion and amortization	10,921	8,855
Results of operations of oil and gas producing activities	4,768	1,624
Total Company and Piceance Energy income from operations of oil and gas producing activities	$2,703	$2,074

Information_Regarding_Proved_O2

Information Regarding Proved Oil and Gas Reserves (Details) (Detail)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013
	MMcf		MMcf
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	253,739	[1]
Proved developed reserve	58,546	[1]	57,907	[1]
Proved undeveloped reserve	195,193	[1]	178,680	[1]
Company [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	2,078	[1]	2,163	[1]
Revisions of quantity estimate	-211	[1]	557	[1]
Extensions and discoveries	14	[1]	25	[1]
Production	-716	[1]	-667	[1]
Ending Balance	1,165	[1]	2,078	[1]
Proved developed reserve	1,165	[1]	2,078	[1]
Proved undeveloped reserve	0	[1]	0	[1]
Company's Share of Piceance Energy [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	234,509	[1]	165,700	[1]
Revisions of quantity estimate	-1,054	[1]	90,387	[1]
Extensions and discoveries	24,808	[1]	-6,643	[1]
Production	-5,689	[1]	-14,935	[1]
Ending Balance	252,574	[1]	234,509	[1]
Proved developed reserve	57,381	[1]	55,829	[1]
Proved undeveloped reserve	195,193	[1]	178,680	[1]
Natural Gas [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	212,351
Proved developed reserve	49,456		45,734
Proved undeveloped reserve	162,895		141,525
Natural Gas [Member] | Company [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	662		446
Revisions of quantity estimate	65		460
Extensions and discoveries	8		9
Production	-134		-253
Ending Balance	601		662
Proved developed reserve	601		662
Proved undeveloped reserve	0		0
Base Pricing, before adjustments for contractual differentials	4.36	[2]	3.53	[2]
Natural Gas [Member] | Company's Share of Piceance Energy [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	186,597		122,650
Revisions of quantity estimate	8,876		72,436
Extensions and discoveries	21,108		3,599
Production	-4,831		-12,088
Ending Balance	211,750		186,597
Proved developed reserve	48,855		45,072
Proved undeveloped reserve	162,895		141,525
Oil [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	805
Proved developed reserve	272		401
Proved undeveloped reserve	533		419
Oil [Member] | Company [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	236		286
Revisions of quantity estimate	-67		16
Extensions and discoveries	1		3
Production	-93		-69
Ending Balance	77		236
Proved developed reserve	77		236
Proved undeveloped reserve	0		0
Base Pricing, before adjustments for contractual differentials	94.99	[2]	96.91	[2]
Oil [Member] | Company's Share of Piceance Energy [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	584		831
Revisions of quantity estimate	34		174
Extensions and discoveries	128		-374
Production	-18		-47
Ending Balance	728		584
Proved developed reserve	195		165
Proved undeveloped reserve	533		419
Natural Gas Liquids [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Ending Balance	6,093
Proved developed reserve	1,243		1,627
Proved undeveloped reserve	4,850		5,774
Natural Gas Liquids [Member] | Company [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	0		0
Revisions of quantity estimate	21		0
Extensions and discoveries	0		0
Production	-4		0
Ending Balance	17		0
Proved developed reserve	17		0
Proved undeveloped reserve	0		0
Natural Gas Liquids [Member] | Company's Share of Piceance Energy [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning Balance	7,401		6,345
Revisions of quantity estimate	-1,689		2,818
Extensions and discoveries	489		-1,334
Production	-125		-428
Ending Balance	6,076		7,401
Proved developed reserve	1,226		1,627
Proved undeveloped reserve	4,850		5,774
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmYxNWExMGZiN2RmMTRlNzY5MGFhN2I5ZjdkYTM1NmEyfFRleHRTZWxlY3Rpb246Mjk1N0U4QTU3OEYzOEI4NDNDRTg1NjJDRTNGRDJDQTIM}
[2]	No income tax provision is included in the standardized measure 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.

Information_Regarding_Proved_O3

Information Regarding Proved Oil and Gas Reserves (Details 1) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Company [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Discount Rate Used To Present Value Future Net Revenues From Proved Reserves			10.00%
Future net cash flows	$10,452		$26,861
Production	7,760		21,999
Development and abandonment	37		319
Income taxes	0	[1]	0	[1]
Future net cash flows	2,655		4,543
10% discount factor	-889		-1,006
Standardized measure of discounted future net cash flows	1,766		3,537
Company's Share of Piceance Energy [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future net cash flows	1,268,704		984,205
Production	539,796		430,506
Development and abandonment	236,027		234,905
Income taxes	0	[1]	0	[1]
Future net cash flows	492,881		318,794
10% discount factor	-322,282		-229,469
Standardized measure of discounted future net cash flows	170,599		89,325
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues	$172,365		$92,862
[1]	No income tax provision is included in the standardized measure 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.

Information_Regarding_Proved_O4

Information Regarding Proved Oil and Gas Reserves (Details 2) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	$92,862	$79,969
Sales of oil and gas production during the period, net of production costs	-5,051	12,522
Net change in prices and production costs	35,806	-6,421
Changes in estimated future development costs	-6,174	8,831
Extensions, discoveries and improved recovery	4,999	15,618
Revisions of previous quantity estimates, estimated timing of development and other	26,521	-4,553
Previously estimated development and abandonment costs incurred during the period	14,115	3,142
Other	0	801
Accretion of discount	9,287	7,997
End of period	172,365	92,862
Company [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	3,537	8,010
Sales of oil and gas production during the period, net of production costs	-1,288	2,044
Net change in prices and production costs	-31	-3,833
Changes in estimated future development costs	118	0
Extensions, discoveries and improved recovery	85	147
Revisions of previous quantity estimates, estimated timing of development and other	-1,111	395
Previously estimated development and abandonment costs incurred during the period	102	0
Other	0	61
Accretion of discount	354	801
End of period	1,766	3,537
Company's Share of Piceance Energy [Member]
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	89,325	71,959
Sales of oil and gas production during the period, net of production costs	-3,763	10,478
Net change in prices and production costs	35,837	-2,588
Changes in estimated future development costs	-6,292	8,831
Extensions, discoveries and improved recovery	4,914	15,471
Revisions of previous quantity estimates, estimated timing of development and other	27,632	-4,948
Previously estimated development and abandonment costs incurred during the period	14,013	3,142
Other	0	740
Accretion of discount	8,933	7,196
End of period	$170,599	$89,325