Par Pacific (PARR) 10-K 31 Mar 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Mar. 26, 2014	Jun. 28, 2013
Document Information [Line Items]	'	'	'
Entity Registrant Name	'PAR PETROLEUM CORP/CO	'	'
Entity Central Index Key	'0000821483	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Smaller Reporting Company	'	'
Trading Symbol	'PARR	'	'
Entity Common Stock, Shares Outstanding	'	30,159,039	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$55,000,000

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$38,061	$6,185
Restricted cash	802	23,970
Trade accounts receivable	122,913	17,730
Inventories	389,075	10,466
Prepaid and other current assets	7,522	1,575
Total current assets	558,373	59,926
Property and equipment	'	'
Property, plant and equipment	107,623	1,415
Proved oil and gas properties, at cost, successful efforts method of accounting	4,949	4,804
Total property and equipment	112,572	6,219
Less accumulated depreciation, depletion and amortization	-3,968	-373
Property and equipment, net	108,604	5,846
Long-term assets	'	'
Investments in unconsolidated affiliate	101,796	104,434
Intangible assets, net	11,170	8,809
Goodwill	20,603	7,756
Assets held for sale	0	2,800
Other long-term assets	26,539	11
Total assets	827,085	189,582
Current liabilities	'	'
Current maturities of long-term debt	3,250	35,000
Obligations under supply and exchange agreements	390,839	0
Accounts payable	28,870	25,329
Other accrued liabilities	31,956	981
Accrued settlement claims	3,793	8,667
Total current liabilities	458,708	69,977
Long-term liabilities	'	'
Long-term debt	94,030	7,391
Derivative liabilities	17,336	10,945
Long-term capital lease obligations	1,526	0
Deferred tax liability	216	0
Contingent consideration liability	11,980	0
Other liabilities	6,473	512
Total liabilities	590,269	88,825
Commitments and contingencies (Note 13)	'	'
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, 2013 and 2012, respectively, 30,151,000 shares and 15,008,092 shares issued at December 31, 2013 and 2012, respectively	301	150
Additional paid-in capital	315,975	109,446
Accumulated deficit	-79,460	-8,839
Total stockholders' equity	236,816	100,757
Total liabilities and stockholders' equity	$827,085	$189,582

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS [Parenthetical] (USD $)	Dec. 31, 2013	Dec. 31, 2012
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	30,151,000	15,008,092

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	4 Months Ended		12 Months Ended		8 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012
					Predecessor [Member]
Revenues	'		'		'
Refining, distribution and marketing revenues	$0		$778,126		$0
Commodity marketing and logistics revenues	0		100,149		0
Oil and gas sales	2,144		7,739		23,079
Total operating revenues	2,144		886,014		23,079
Operating expenses	'		'		'
Cost of revenues	0		848,924		0
Operating expense, excluding depreciation, depletion and amortization expense shown separately below	0		27,251		0
Lease operating expense	1,684		5,627		9,038
Transportation expense	0		0		6,963
Production taxes	4		49		979
Exploration expense	0		0		2
Dry hole costs and impairments	0		0		151,347
Depreciation, depletion and amortization	401		5,982		16,041
Trust litigation and settlements	0		6,206		0
General and administrative expense	4,520		21,494		9,386
Acquisition and integration costs	556		9,794		0
Total operating expenses	7,165		925,327		193,756
Operating loss	-5,021		-39,313		-170,677
Other income and (expense):	'		'		'
Interest expense and financing costs, net	-1,056		-19,471		-6,852
Other income	86		808		516
Change in value of common stock warrants	-4,280		-10,114		0
Gain on derivative instruments, net	0		410		0
Loss from unconsolidated affiliates	-1,325		-2,941		-20
Total other expense	-6,575		-31,308		-6,356
Loss before income taxes and reorganization items	-11,596		-70,621		-177,033
Income tax benefit	-2,757		0		0
Loss before reorganization items	-8,839		-70,621		-177,033
Reorganization items	'		'		'
Professional fees and administrative costs	0		0		22,354
Changes in asset fair values due to fresh start accounting adjustments	0		0		14,765
Gain on settlement of senior debt	0		0		-166,144
Gain on settlement of liabilities	0		0		-2,571
Net loss	($8,839)		($70,621)		($45,437)
Basic loss per common share (in dollars per share)	($0.56)	[1]	($3.57)	[1]	($1.57)	[1]
Diluted loss per common share (in dollars per share)	($0.56)	[1]	($3.57)	[1]	($1.57)	[1]
Weighted average number of shares outstanding:	'		'		'
Basic (in shares)	15,734		19,740		28,841
Diluted (in shares)	15,734		19,740		28,841
[1]	Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (USD $)	Total	Common Stock [Member]	Additional Paid In Capital [Member]	Retained Earnings [Member]	Predecessor [Member]	Predecessor [Member]	Predecessor [Member]	Predecessor [Member]
In Thousands						Common Stock [Member]	Additional Paid In Capital [Member]	Retained Earnings [Member]
Balance at Dec. 31, 2011	'	'	'	'	$50,225	$288	$1,641,390	($1,591,453)
Balance (in shares) at Dec. 31, 2011	'	'	'	'	'	28,841	'	'
Forfeitures	'	'	'	'	0	0	0	0
Forfeitures (in shares)	'	'	'	'	'	-58	'	'
Cancellation of predecessor common stock	0	-288	288	0	'	'	'	'
Cancellation of predecessor common stock (in shares)	'	-28,783	'	'	'	'	'	'
Elimination of predecessor accumulated deficit	0	0	-1,636,890	1,636,890	'	'	'	'
Issuance of common stock and fresh start accounting upon emergence from Chapter 11	102,879	148	102,731	0	'	'	'	'
Issuance of common stock and fresh start accounting upon emergence from Chapter 11 (in shares)	'	14,766	'	'	'	'	'	'
Stock issued to settle bankruptcy claims	'	'	'	'	0	'	'	'
Stock-based compensation	'	'	'	'	1,895	0	1,895	0
Net loss	'	'	'	'	-45,437	0	0	-45,437
Balance at Aug. 31, 2012	109,562	148	109,414	0	6,683	288	1,643,285	-1,636,890
Balance (in shares) at Aug. 31, 2012	'	14,766	'	'	'	28,783	'	'
Stock issued to settle bankruptcy claims	0	0	0	0	'	'	'	'
Stock issued to settle bankruptcy claims (in shares)	'	20	'	'	'	'	'	'
Stock-based compensation	34	2	32	0	'	'	'	'
Stock-based compensation (in shares)	'	222	'	'	'	'	'	'
Net loss	-8,839	0	0	-8,839	'	'	'	'
Balance at Dec. 31, 2012	100,757	150	109,446	-8,839	'	'	'	'
Balance (in shares) at Dec. 31, 2012	'	15,008	'	'	'	'	'	'
Stock issued to settle bankruptcy claims	2,605	2	2,603	0	'	'	'	'
Stock issued to settle bankruptcy claims (in shares)	'	209	'	'	'	'	'	'
Stock issued in a private transaction, net of offering cost of $830	199,170	144	199,026	0	'	'	'	'
Stock issued in a private transaction, net of offering cost of $830 (in shares)	'	14,388	'	'	'	'	'	'
Stock-based compensation	1,164	3	1,161	0	'	'	'	'
Stock-based compensation (in shares)	'	362	'	'	'	'	'	'
Stock issued through exercise of warrants	3,741	2	3,739	0	'	'	'	'
Stock issued through exercise of warrants (in shares)	'	184	'	'	'	'	'	'
Net loss	-70,621	0	0	-70,621	'	'	'	'
Balance at Dec. 31, 2013	$236,816	$301	$315,975	($79,460)	'	'	'	'
Balance (in shares) at Dec. 31, 2013	'	30,151	'	'	'	'	'	'

CONSOLIDATED_STATEMENTS_OF_CHA1

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

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	4 Months Ended	12 Months Ended	8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012
			Predecessor [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'
Net loss	($8,839)	($70,621)	($45,437)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:	'	'	'
Depreciation, depletion, amortization and accretion	401	5,982	16,041
Non cash interest expense	1,056	16,742	2,989
Change in asset values due to fresh - start accounting adjustments	0	0	14,765
Gain on extinguishment of senior debt	0	0	-166,144
Gain on settlement of liabilities	0	0	-2,188
(Gain) loss on property sales	-82	-50	126
Dry hole costs and impairments	0	0	151,347
Stock-based compensation	34	1,161	1,895
Change in value of common stock warrants	4,280	10,114	0
Loss from unconsolidated affiliates	1,325	2,941	20
Deferred income tax expense (benefit)	-2,757	179	0
Other	0	0	-699
Net changes in operating assets and liabilities:	'	'	'
Trade accounts receivable	-2,234	-45,698	3,472
Prepaids and other current assets	-538	-2,569	-1,378
Inventories	0	40,141	0
Accounts payable	2,718	15,829	-4,187
Supply and exchange agreements	0	-13,061	0
Settlement liability	0	1,898	0
Accrued reorganization costs	0	0	9,116
Other accrued liabilities	0	1,335	0
Net cash used in operating activities	-4,636	-35,677	-20,262
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'
Capital expenditures	0	-7,768	-1,613
Acquisitions, net of cash acquired	-17,439	-559,279	0
Proceeds from asset sales	0	2,850	74,209
Proceeds from sale of other fixed assets	39	0	26
Capitalized drilling costs paid to operator	-415	-303	0
Proceeds from sale of unconsolidated affiliates	125	0	0
Net cash (used in) provided by investing activities	-17,690	-564,500	72,622
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'
Funding of purchase of HIE from supply and exchange agreements	0	378,238	0
Proceeds from sale of common stock, net of offering costs	0	199,170	0
Proceeds from exercise of common stock warrants	0	18	0
Proceeds from borrowings	35,000	159,800	23,000
Repayments of borrowings	0	-121,909	-59,535
Payment of deferred loan costs	0	-2,264	0
Fund distribution agent account	0	0	-21,805
Proceeds from (funding of) Wapiti and General Recovery Trusts	2,446	0	-2,000
Recoveries from bankruptcy settlements	5,183	0	0
Restricted cash released from (held to) secure letter of credits	-19,000	19,000	0
Net cash provided by (used in) financing activities	23,629	632,053	-60,340
Net increase (decrease) in cash and cash equivalents	1,303	31,876	-7,980
Cash at beginning of period	4,882	6,185	12,862
Cash at end of period	6,185	38,061	4,882
SUPPLEMENTAL CASH FLOW INFORMATION	'	'	'
Cash paid for interest and financing costs	0	2,186	3,745
NON-CASH INVESTING AND FINANCING ACTIVITIES	'	'	'
Stock issued used to settle bankruptcy claims	0	2,605	0
Interest payable capitalized to principal balance	0	6,096	0
Non-cash additions to property, plant and equipment	$209	$0	$0

Overview

Overview	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	Note 1 - Overview
	We are a diversified energy holding company based in Houston, Texas (OTCQB:PARR). We were created through the successful reorganization of Delta Petroleum in August 2012. The reorganization converted approximately $265 million of unsecured debt to equity and allowed us to preserve significant tax attributes. Currently, we operate in three segments: (i) refining, distribution and marketing, (ii) natural gas and oil operations and (iii) commodity marketing and logistics operations.
	Our refining, distribution and marketing segment consists of a refinery in Kapolei, Hawaii. The refinery produces ultra-low sulfur diesel, gasoline, jet fuel, marine fuel and other associated refined products primarily for consumption in Hawaii. Our refinery logistics assets include refined products terminals, pipelines, a single point mooring and other associated logistics assets. In addition, we distribute products though 31 branded retail outlets located across the islands of Oahu, Maui and Hawaii. The refining, distribution and marketing segment was established through the acquisition of Hawaii Independent Energy, LLC (“HIE”) (formerly known as Tesoro Hawaii, LLC (“Tesoro Hawaii”)) in September 2013 for approximately $75 million in cash, plus net working capital and inventories and certain contingent earn out payments of up to approximately $40 million (the “HIE Acquisition”).  As part of the purchase price, we also funded  $24.3  million of start-up expenses and for a major overhaul of a co-generation turbine used at the refinery prior to closing.
	Our natural gas and oil operations consist primarily of a 33.34% interest in Piceance Energy, LLC (“Piceance Energy”) (Note 3 - Investment in Piceance Energy). Piceance Energy is a joint venture with Laramie Energy II, LLC (“Laramie”), who owns the remaining interest and manages the day to day operations of the joint venture. Laramie is a Denver-based company primarily focused on finding and developing natural gas reserves from unconventional gas reservoirs within the Rocky Mountain region. Piceance Energy was formed and capitalized in August 2012 when we and Laramie Energy contributed oil and natural gas assets, surface real estate, and other related assets located in the Piceance Basin geological province of Colorado to the joint venture entity.
	Our commodity marketing and logistics segment focuses on sourcing, marketing, transportation and distribution of crude oil and refined products. Our logistics capability consists of historical pipeline shipping status, a rail car fleet, and expertise in contracted chartering of tows and barges, with the capability of moving crude oil from land-locked locations in the Western U.S. and Canada to the refining hubs in the Midwest, the Gulf Coast, and the East Coast regions of the U.S. The commodity marketing and logistics operations segment was established through the acquisition of Texadian Energy, Inc. (“Texadian”) (formerly known as SEACOR Energy, Inc.) in December 2012 for approximately $14 million in cash, plus approximately $3 million in working capital.
	As a result of these transactions, our results of operations for any period after December 31, 2013 will not be comparable to any prior period.
	On January 23, 2014, we amended and restated 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. 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 outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor (see Note 20 - Subsequent Events).
	To generate earnings and cash flows from operations, the Company’s refining, distribution and marketing segment is primarily dependent upon processing crude oil and selling refined petroleum products at margins sufficient to cover fixed and variable costs and other expenses. Crude oil and refined petroleum products are commodities and factors largely out of the Company’s control can cause prices to vary over time.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	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 consolidated subsidiaries. All inter-company balances and transactions have been eliminated in consolidation. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.
	Our wholly-owned subsidiaries include Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”)  which acquired all of the outstanding membership interests of HIE on September 25, 2013 (see Note 4– Acquisitions and Dispositions), Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3 – Investment in Piceance Energy) and Texadian, which we acquired on December 31, 2012 (see Note 4 – Acquisitions and Dispositions). Certain amounts from prior periods have been reclassified to conform to the current presentation.
	Use of Estimates
	The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include fair value of assets and liabilities recorded in connection with the application of fresh-start reporting or acquisitions, natural gas and oil reserves, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, bad debts,  derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.
	Fresh-Start Reporting and the Effects of the Plan
	Certain companies qualify for fresh-start reporting in connection with their emergence from bankruptcy. Fresh-start reporting is appropriate on the emergence from bankruptcy if the reorganization value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims, and if the holders of existing voting shares immediately before confirmation receive less than 50 percent of the voting shares of the emerging entity. We met these requirements on August 31, 2012 and adopted fresh-start reporting resulting in the creation of a new reporting entity.
	The bankruptcy court issued a confirmation order approving our plan of reorganization (the “Plan”) on August 15, 2012 and we met the requirements of the Plan on August 31, 2012. Under the requirements of fresh-start reporting, we have adjusted our assets and liabilities to their estimated fair values as of August 31, 2012 in conformity with the guidance for the acquisition method of accounting for business combinations. The net effect of all fresh-start adjustments, including the effects of implementing the plan, resulted in a gain of approximately $154 million, which is reflected in the 2012 Predecessor Period. The application of the fresh-start reporting provisions created a new reporting entity having no retained earnings nor accumulated deficit.
	Our fresh-start adjustments consisted primarily of (i) estimates of the fair value of our minority interest in Piceance Energy and (ii) of the fair value of our remaining existing fixed assets and liabilities. A description of the adjustments and amounts is provided in Note 19 – Reorganization under Chapter 11, Fresh-Start Reporting and the Effects of the Plan.
	Cash and Cash Equivalents
	Cash and cash equivalents consist of demand deposits and funds invested in highly liquid short-term investments with original maturities of three months or less.
	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 collectability and establish or adjust our allowance as necessary using the specific identification method.  As of December 31, 2013 and 2012, we had no significant allowance for doubtful accounts.
	Refined Product Exchanges
	We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.
	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.
	HIE 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 HIE’s storage tanks governed by a storage agreement. Legal title to the crude oil passes to HIE at the tank outlet. After processing, Barclays takes title to the refined products when the refined products enter the tanks which are then stored in HIE’s storage tanks until sold to HIE’s 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 Unconsolidated Affiliate
	We account for our investment in unconsolidated affiliate using the equity method as we have the ability to exert significant influence, but do not control the operating and financial policies. Our proportionate share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations. Investment in unconsolidated affiliate is reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.
	At December 31, 2013 and 2012, our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3 - Investment in Piceance Energy.)
	Property, Plant and Equipment (Other than Natural Gas and Oil Properties)
	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
	Logistic	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 with significant acquisition costs 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 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.
	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. 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 or when circumstances indicate that impairment may exist. 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.
	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 depreciation, depletion and amortization expense 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 statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, 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.
	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 it will not net settle.  Should we not designate a contract as a normal purchase or normal sale then 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, 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. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.
	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.
	As a part of the Plan of Reorganization, we issued warrants (see Note 10 - Debt) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in change in value of common stock warrants and loss on derivative instruments, net respectively, on our consolidated statement of operations.
	Accrued Settlement Claims
	We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy (See Note 13 - Commitments and Contingencies). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.
	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 2010, 2011, and 2012. 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. These transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.
	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, 2013 and 2012, 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 rail cars. 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.
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 statements of consolidated operations, while the related transportation costs are included in cost of sales. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.
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 (see Note 16 - Loss Per Share). 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 our functional currency (“U.S. $”). 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) in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.

Investment_in_Piceance_Energy

Investment in Piceance Energy	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments Disclosure [Text Block]	'
	Note 3 - Investment in Piceance Energy
	We account for our 33.34% ownership interest in Piceance Energy using the equity method of accounting because we are able to exert significant influence but do not control the operating and financial policies. The Piceance Energy  LLC Agreement provides that its sole manager may make a written capital call such that each member shall make additional capital contributions up to an aggregate combined total capital contribution of $60 million ($20 million to our interest), if approved by a majority of its board. If any member does not fund its share of the capital call, its interest may be reduced or diluted by the amount of the shortfall. In addition, Piceance Energy has a $400 million secured revolving credit facility secured by a lien on its natural gas and oil properties and related assets with a borrowing base currently set at $120 million.  As of December 31, 2013, the balance outstanding on the revolving credit facility was approximately $90.2 million. We are guarantors of Piceance Energy’s credit facility, with recourse limited to the pledge of our equity interests of Par Piceance Energy. 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):
				September 1
		Year Ended		through
		December 31, 2013		December 31, 2012
	Beginning balance	$	104,434	$	105,344
	Loss from unconsolidated affiliates		-3,516		-1,325
	Accretion of basis difference		575		—
	Capitalized drilling costs obligation paid		303		415
	Ending balance	$	101,796	$	104,434
	Summarized financial information for Piceance Energy is as follows (in thousands):
		December 31, 2013		December 31, 2012
	Assets
	Current assets	$	5,901	$	6,275
	Non-current assets		454,402		460,991
	Current liabilities		-13,040		-11,826
	Non-current liabilities		-96,738		-94,369
		Year Ended		September 1 through
		December 31, 2013		December 31, 2012
		100%		100%
	Oil, natural gas and natural gas liquids	$	61,091	$	19,391
	revenues
	Loss from operations		-6,765		-2,095
	Net loss		-10,546		-3,975
	The net loss for the year ended December 31, 2013 includes $26.6 million and $770 thousand in DD&A expense and losses on derivative instruments, respectively. The net loss for the period from September 1 through December 31, 2012 include $8.5 million and $917 thousand of DD&A expense and losses on derivative instruments, respectively.
	At December 31, 2013 and 2012, our equity in the underlying net assets of Piceance Energy exceeded the carrying value of our investment by approximately $15.1  million and $15.9 million, respectively. This difference arose due to lack of control and marketability discounts and we attributed it to natural gas and oil properties and will amortize the difference over 15 years based on the estimate of proved reserves at the date Piceance Energy was formed.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business Combination Disclosure [Text Block]	'
	Note 4 – Acquisitions and Dispositions
	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.
	Texadian Energy, Inc.
	On December 31, 2012, we acquired Texadian, an indirect wholly-owned subsidiary of SEACOR Holdings Inc., for $14 million plus estimated net working capital of approximately $3 million at closing resulting in approximately $17 million of cash paid at closing. Texadian operates an oil transportation, distribution and marketing business with significant logistics capabilities. The purchase price for the acquisition was funded with a combination of cash and additional borrowings under the Tranche B Loan (see Note 10 - Debt). During 2013, the purchase price was reduced by $1.3 million due to funds received from SEACOR Holdings, Inc. for certain employee-related benefits.
	The purchase was accounted for as a business combination whereby the purchase price is allocated to the assets acquired and liabilities assumed based on their estimated fair values on the date of acquisition. Goodwill recognized in the transaction was attributable to opportunities expected to arise from combining our operations with Texadian’s, and specifically 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. These include relationships with suppliers and shippers and favorable railcar leases. These intangible assets will be amortized over their estimated useful lives on a straight line basis, which approximates their consumptive life.
	A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Intangible assets	$	8,809
	Goodwill		6,990
	Net non cash-working capital		3,097
	Deferred tax liabilities		-2,757
	Total, net of cash acquired	$	16,139
	None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes.    Acquisition costs of approximately $556 thousand are included in our consolidated statements of operations for the period ended December 31, 2012.
	HawaiiIndependent Energy, LLC
	On June 17, 2013 (the “Execution Date”), our wholly-owned subsidiary, Hawaii Pacific Energy, entered into a membership interest purchase agreement (the “HIE Purchase Agreement”) with Tesoro Corporation, (the “Seller”) and solely for the purpose set forth in the HIE Purchase Agreement, Tesoro Hawaii. Pursuant to the HIE Purchase Agreement, on September 25, 2013 (the “Effective Date”), Hawaii Pacific Energy purchased from the Seller all of the issued and outstanding units representing the membership interests in Tesoro Hawaii (the “Purchased Units”), and indirectly thereby also acquired Tesoro Hawaii’s wholly-owned subsidiary, Smiley’s Super Service, Inc. Tesoro Hawaii owns and operates (i) a petroleum refinery located at the Campbell Industrial Park in Kapolei, Hawaii (the “Refinery”), (ii) certain pipeline assets, floating pipeline mooring equipment, and refined products terminals, and (iii) 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”).
	Hawaii Pacific Energy acquired the Purchased Units for $75 million, paid in cash at the closing of the HIE Purchase Agreement, plus net working capital and inventories at closing and 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 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 in the event Hawaii Pacific Energy disposes of any facility used in the acquired business, Hawaii Pacific Energy's obligation to make earnout payments could be modified and/or accelerated as provided in the HIE Purchase Agreement. The purchase price was paid with a portion of the net proceeds from the sale of the shares of our common stock in a private transaction (see Note 14 - Stockholders’ Equity), amounts received pursuant to the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements) and the ABL Facility (see Note 10 - Debt).
	We accounted for the acquisition of HIE as a business combination whereby the purchase price has been preliminary 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. These include 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.
	A summary of the preliminary estimated fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Inventory	$	418,750
	Trade accounts receivable		59,485
	Prepaids and other current assets		1,978
	Property, plant and equipment		58,782
	Land		39,800
	Goodwill		13,613
	Intangible assets		4,689
	Accounts payable and other current liabilities		-18,154
	Contingent consideration liability		-11,980
	Other noncurrent liabilities		-6,384
	Total	$	560,579
	We are continuing to evaluate certain liabilities assumed in the acquisition, including those related to employee benefits. We have recorded a preliminary estimate of the liability and expect to finalize the purchase price allocation during 2014.
	The acquisition was partially funded from proceeds totaling approximately $378.2 million from the Supply and Exchange Agreements (see Note 9 - Supply and Exchange Agreements). None of the goodwill or intangible assets are expected to be deductible for income tax reporting purposes. Acquisition costs totaled approximately $7 million are included in acquisition and integration costs our consolidated statement of operations for the year ended December 31, 2013.
	Pro Forma Effects of the Acquisitions
	The unaudited pro forma financial information presented below assumes that the Texadian and HIE acquisitions occurred as of January 1, 2012 and combines the Predecessor and Successor periods to include a full year of results for the year ended December 31, 2012.  We did not include any adjustments related to the application of fresh-start reporting for the year ended December 31, 2012.
		2013		2012
	(in millions)
	Revenues	$	2,986.80	$	3,811.10
	Net loss	$	-113.6	$	-12
	Revenue and earnings for HIE subsequent to the acquisition are included in Note 17 - Segment Information.
	Assets Contributed to Piceance Energy
	At December 31, 2011, Delta’s oil and gas assets were classified as held for use and no impairment charges resulted from the analysis performed at December 31, 2011 as the estimated undiscounted net cash flows exceeded carrying amounts for all properties. In August 2012, the Bankruptcy Court approved a plan of sale of substantially all of the Predecessor’s assets and accordingly these assets were classified as held for sale and an impairment of approximately $151.3 million was recognized for the period from January 1, 2012 through August 31, 2012 to write-down these assets to fair value due to the application of fresh-start reporting.   The  assets were then contributed to Piceance Energy in accordance with our Plan of Reorganization.
	Assets Held for Sale
	As of December 31, 2012, we classified certain compressors as held for sale, which were recorded at the lower of cost or estimated net realizable value. On February 20, 2013, these compressors were sold for approximately $2.9 million resulting in a gain of $50  thousand.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment Disclosure [Text Block]	'
	Note 5 – Property, Plant and Equipment
	Major classes of property, plant and equipment consist of the following (in thousands):
		December 31,
		2013		2012
	Land	$	39,800	$	—
	Buildings and equipment		65,878		—
	Other		1,945		1,415
	Property, plant and equipment		107,623		1,415
	Proved oil and gas properties		4,949		4,804
	Less: accumulated depreciation, depletion		-3,968		-373
	and amortization
		$	108,604	$	5,846

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligation Disclosure [Text Block]	'
	Note 6 – Asset Retirement Obligations
	The following is a reconciliation of our AROs (in thousands):
		Successor				Predecessor
				September 1		January 1
		Year Ended		through		through
		December 31, 2013		December 31, 2012		August 31, 2012
	Asset retirement obligation –	$	512	$	476	$	3,799
	beginning of period
	Obligation acquired		2,601		—		—
	Accretion expense		59		36		178
	Change in estimate		—		—		437
	Settlement upon transfer to		—		—		-3,938
	Piceance Energy
	Asset retirement obligation –	$	3,172	$	512	$	476
	end of period
	As the result of the contribution of assets to Piceance Energy during the reorganization, approximately $3.9 million of our AROs was deemed settled as of the Emergence Date.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventory Disclosure [Text Block]	'
	Note 7 - Inventories
	The following is a summary of our inventory (in thousands):
									December 31,
		December 31, 2013							2012
					Supply and
			Titled		Exchange
			Inventory		Agreements		Total		Titled Inventory
	Crude oil and feedstocks	$	—	$	146,158	$	146,158	$	10,466
	Refined products and blend stock		67,532		161,554		229,086		—
	Spare parts, materials and supplies, and merchandise		13,831		—		13,831		—
		$	81,363	$	307,712	$	389,075	$	10,466

Intangible_assets

Intangible assets	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Intangible Assets Disclosure [Text Block]	'
	Note 8 – Intangible assets
	Our intangible assets consist of the following (in thousands):
		December 31,
		2013		2012
	Amortized intangible assets:
	Gross carrying amount:
	Supplier relationships	$	3,360	$	3,360
	Rail car leases		3,249		3,249
	Historical shipper status		2,200		2,200
	Trade names and trademarks		4,689		—
	Subtotal		13,498		8,809
	Accumulated amortization
	Supplier relationships		-258		—
	Rail car leases		-650		—
	Historical shipper status		-1,100		—
	Trade name and trademarks		-320		—
	Subtotal		-2,328		—
	Net:
	Supplier relationships		3,102		3,360
	Rail car leases		2,599		3,249
	Historical shipper status		1,100		2,200
	Trade name and trademarks		4,369		—
	Total amortized intangible assets, net	$	11,170	$	8,809
	Amortization expense was approximately $2.3 million for the year ended December 31, 2013. There was no amortization expense during 2012. Expected future amortization expense for each of the next five years and thereafter is as follows (in thousands):
	Year Ended	Amount
	2014	$	3,571
	2015		2,471
	2016		2,151
	2017		908
	2018		258
	Thereafter		1,811
		$	11,170
	During the year ended December 31, 2013 the changes in the carrying amount of goodwill for the year ended December 31, 2013 were as follows (in thousands):
	Balance at beginning of period	$	7,756
	Additions		13,613
	Texadian purchase price adjustments		-766
	Balance at end of period	$	20,603

Supply_and_Exchange_Agreements

Supply and Exchange Agreements	12 Months Ended
	Dec. 31, 2013
Supply And Exchange Agreements [Abstract]	'
Supply And Exchange Agreements [Text Block]	'
	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. We entered into the Supply and Exchange Agreements for the purpose of managing our working capital and the crude oil and refined product inventory at the refinery.
	Pursuant to the Supply and Exchange Agreements, Barclays holds title to all of the crude oil in the tanks at the refinery.  Additionally, Barclays 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 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.
	As described in Note 2—Summary of Significant Accounting Policies, 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 products inventory volumes at period-end in excess of the Block Volume, we record a liability for the Block Volume valued at the per barrel carrying value of the refined product inventory owned by Barclays.  From time to time, we may sell refined product inventory that causes our refined product inventory to be less than the Block Volume.  To the extent of this shortfall, we record a liability for the volumes that we would need to purchase at current market prices in order to meet the Block Volume requirement. The liability related to the Supply and Exchange Agreements is included in obligations under supply and exchange agreements on our consolidated balance sheet.
	For the year ended December 31, 2013, we incurred approximately $3.7 million in handling fees related to the Supply and Exchange Agreements, which is included in cost of revenues on our consolidated statement of operations. F or the year ended December 31, 2013, interest expense and financing costs, net includes $1.4 million of expense related to the Supply and Exchange Agreements.

Debt

Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	Note 10 - Debt
	Our debt is as follows (in thousands):
		December 31,
		2013			2012
	Tranche B Loan	$	19,480		$	35,000
	Delayed Draw Term Loan Agreement		—			13,465
	ABL Facility		51,800			—
	Retail Credit Agreement		26,000			—
	Less: unamortized debt discount – warrants		—			-6,014
	Less: unamortized debt discount – embedded derivative		—			-60
	Total debt, net of unamortized debt discount		97,280			42,391
	Less: current maturities		-3,250			-35,000
	Long-term debt, net of current maturities and unamortized discount	$	94,030		$	7,391
	Annual maturities of our long-term debt are due during the following years (in thousands):
	Year		Amount Due
	2014	$	3,250
	2015		2,600
	2016		22,080
	2017		54,400
	2018		2,600
	Thereafter		12,350
		$	97,280
	Delayed Draw Term Loan Credit Agreement
	Pursuant to the Plan, on the Emergence Date, we and certain of our subsidiaries (the “Guarantors” and, together with the company, the “Loan Parties”) entered into a Delayed Draw Term Loan Credit Agreement (the “Loan Agreement”) with Jefferies Finance LLC, as administrative agent (the “Agent”) for the lenders party thereto from time to time, including WB Delta, Ltd., Waterstone Offshore ER Fund, Ltd., Prime Capital Master SPC, GOT WAT MAC Segregated Portfolio, Waterstone Market Neutral MAC51, Ltd., Waterstone Market Neutral Master Fund, Ltd., Waterstone MF Fund, Ltd., Nomura Waterstone Market Neutral Fund, ZCOF Par Petroleum Holdings, L.L.C. and Highbridge International, LLC (collectively, the “Lenders”), pursuant to which the Lenders agreed to extend credit to us in the form of term loans (each, a “Loan” and collectively, the “Loans”) of up to $30 million. We borrowed $13 million on the Emergence Date in order to, along with the proceeds from the Contribution Agreement: (i) repay the loans and obligations due under the Predecessor’s secured debtor-in-possession credit facility, and (ii) pay allowed but unpaid administrative expenses to the Debtors related to the Plan. During 2013, we borrowed an additional $17 million for general corporate use.  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. Included in interest expense and financing cost, net on the consolidated statements of operations is $6.1 million recorded as loss on extinguishment of debt related to the November 2013 repayment.
	Amendment to the Loan Agreement
	On December 28, 2012, in order to fund a portion of the purchase price for our acquisition of Texadian Energy, the Loan Parties entered into an amendment to the Loan Agreement with the Agent and the Lenders, pursuant to which certain lenders (the “Tranche B Lenders”) agreed to extend additional borrowings to us (the “Tranche B Loan”). The total commitment of the Tranche B Loan of $35 million was drawn at closing. In addition to funding a portion of the purchase price of the acquisition of Texadian, the Tranche B Loan provided cash collateral for our former cash collateralized  letter of credit facility. Pursuant to the Eighth Amendment to the Loan Agreement entered into on June 24, 2013, the Lenders refinanced and replaced the Tranche B Loan with new Tranche B Loans in the aggregate principal amount of $65 million (the “New Tranche B Loans”). The proceeds from the New Tranche B Loans were applied to prepay in full the Tranche B Loan, to make payments due under the membership interests purchase agreement in connection with the acquisition of HIE (the “HIE Purchase Agreement”), and for working capital and general corporate purposes.
	On September 25, 2013 and in connection with the acquisition of HIE, we entered into a Tenth Amendment to the Loan Agreement pursuant to which the Lenders (i) consented to the consummation of the transactions contemplated by the HIE Purchase Agreement and the use of a portion of the proceeds from the Private Placement to fund a portion of the consideration for the acquisition of HIE and for certain other purposes, (ii) provided certain other consents in connection with the transactions contemplated by the HIE Purchase Agreement, (iii) increased the interest rate applicable to certain of the loans, and (iv) amended certain provisions of the Loan Agreement and the other loan documents in connection with the consummation of the transactions contemplated by the HIE Purchase Agreement and the Private Placement (see Note 14 – Stockholder’s Equity).
	The consent provided by the Lenders was conditioned on, among other things, (i) the repayment in full of the New Tranche B Loans owing to all Lenders except for ZCOF Par Petroleum Holdings, L.L.C., and a partial repayment of the New Tranche B Loans owing to ZCOF Par Petroleum Holdings, L.L.C. from a portion of the proceeds from the Private Placement and (ii) a portion of the proceeds from the Private Placement being used to consummate the transactions contemplated by the HIE Purchase Agreement.
	The New Tranche B Loans bear interest (a) from June 24, 2013 through October 31, 2013 at a rate equal  to 9.75% per annum payable, at the election of the company, either (i) in cash or (ii) in kind, and (b) from and after November 1, 2013, at a rate equal to 14.75% per annum payable either (i) in cash or (ii) in kind. Additionally, we agreed to pay the New Tranche B Lenders a nonrefundable exit fee equal to 2.5% of the aggregate amount of the New Tranche B Loans. The exit fee is earned in full and payable on the maturity date of the Tranche B Loans or, if earlier, the date on which the New Tranche B Loans are paid in full.
	The New Tranche B Loans mature and are payable in full on August 31, 2016.  We may prepay the New Tranche B Loans at any time, provided that any prepayment is in an integral multiple of $100,000 and not less than $100,000 or, if less, the outstanding principal amount of the New Tranche B Loans. Amounts to be applied to prepayment of New Tranche B Loans shall be applied (i) first, towards payment of interest then outstanding and fees then due, and (ii) second, towards payment of principal then outstanding.
	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.
	ABL Facility
	On September 25, 2013 and in connection with the with the acquisition of HIE, HIE and its subsidiary (the “ABL Borrowers”) and Hawaii Pacific Energy entered into an asset-based revolving credit facility (the “ABL Facility”) to provide the ABL Borrowers with a senior secured revolving credit facility of up to $125.0 million under which the ABL Borrowers may borrow amounts from time to time based on the available borrowing base as determined in accordance with the ABL Facility. The ABL Facility also allows the ABL Borrowers to use up to $50 million of availability under the ABL Facility for the issuances of letters of credit. The ABL Borrowers borrowed $15 million on September 25, 2013 under the ABL Facility in order to, in part, (i) fund the purchase price under the Purchase Agreement, and (ii) provide working capital to the ABL Borrowers. The proceeds from any future amounts borrowed pursuant to the ABL Facility will be used for general corporate purposes and to fund the working capital of the ABL Borrowers. As of December 31, 2013, the total capacity of the ABL Facility was $83.3 million.
	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%. The effective weighted-average interest rate for 2013 was 3.13%.
	The amounts borrowed pursuant the ABL Facility and all obligations arising under the ABL Facility are secured by a lien in favor of the ABL Agent on substantially all of HIE’s assets.
	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.
	All loans and other obligations outstanding under the ABL Facility are payable in full on September 25, 2017.
	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.
	HIE Retail Credit Agreement
	On  November 14, 2013 , HIE Retail, LLC (“HIE Retail”), our subsidiary, entered into a Credit Agreement (the “Retail Credit Agreement”) in the form of a senior secured term loan of up to $30 million  the (“Term Loan”) and a senior secured revolving line of credit of up to $5 million (the “Revolver”). HIE Retail initially borrowed $26 million of the Term Loan at the closing and an additional $4 million of the Term Loan upon HIE Retail’s compliance with certain liquor licensing requirements, if such requirements are satisfied prior to December 31, 2014, will be available. The proceeds of the Term Loan are available for general corporate purposes.
	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) as follows:
	Period (during and as of the last day of)	Maximum Leverage Ratio
	2013 Fiscal Year	5.75 to 1.00
	2014 Fiscal Year	5.50 to 1.00
	2015 Fiscal Year	5.25 to 1.00
	2016 Fiscal Year	5.00 to 1.00
	2017 Fiscal Year, and at all times thereafter	4.75 to 1.00
	HIE Retail is also required to maintain a Fixed Charge Coverage Ratio of 1.15:1.00.
	Term Loan
	Principal on the Term Loan will be repaid in 28 quarterly principal payments over the term through November 14, 2020.
	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. The effective interest rate for 2013 on the outstanding loan was 2.5%.
	Interest is payable at the end of the selected interest period, but no less frequently than quarterly.  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	%		0	%
	2	4.00x-5.00x		2.25	%		0.25	%
	3	>5.00x		2.5	%		0.5	%
	Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.
	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.
	Revolver
	T he Revolver matures on November 14, 2016. Letters of credit issued under the Revolver are not to expire beyond the maturity date of the Revolver.
	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.
HIE Retail agreed to pay a fee (the “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 commencing on the November 14, 2013.
The 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	%	0	%
3	>5.00x		0.5	%	2.25	%	0.25	%
Initial pricing from the Effective Date until March 31, 2014 was set at Level 2.
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. Fees for the issuance and negotiation of Commercial Letters of Credit will be based on the Agent’s standard fee schedule then in effect.
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, 2013, we had $41.6 million of letters of credit outstanding related to this agreement.
Letter of Credit Facility
On December 27, 2012, we entered into a letter of credit facility agreement (the “Letter of Credit Facility”). The Letter of Credit Facility provided for a letter of credit facility in an aggregate principal amount of $30 million that was available for the issuance of cash-collateralized standby letters of credit for us or any of our subsidiaries.
In connection with the acquisition of Texadian, we issued an Irrevocable Standby Letter of Credit in favor of SEACOR Holdings, Inc. in the amount of $11.7 million (the “Irrevocable Standby Letter of Credit”). The Irrevocable Standby Letter of Credit secured SEACOR Holdings, Inc. in the event that certain letters of credit were drawn. Those letters of credit have been terminated and released. The Letter of Credit Facility was terminated on June 17, 2013.
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, 2013, we are in compliance with all of our credit agreements.
Warrant Issuance Agreement
Pursuant to the Plan of Reorganization, on the Emergence Date, we issued to the Lenders warrants (the “Warrants”) to purchase up to an aggregate of 959,213 shares of our common stock (the “Warrant Shares”). In connection with the issuance of the Warrants, we also entered into a Warrant Issuance Agreement, dated as of the Emergence Date (the “Warrant Issuance Agreement”). Subject to the terms of the Warrant Issuance Agreement, the holders are entitled to purchase shares of common stock upon exercise of the Warrants at an exercise price of $0.10 per share of common stock (the “Exercise Price”), subject to certain adjustments from time to time as provided in the Warrant Issuance Agreement. The Warrants expire on the earlier of (i) August 31, 2022 or (ii) the occurrence of certain merger or consolidation transactions specified in the Warrant Issuance Agreement. A holder may exercise the Warrants by paying the applicable exercise price in cash or on a cashless basis.
The number of shares of our common stock issuable upon exercise of the Warrants and the exercise prices of the Warrants will be adjusted in connection with certain issuances or sales of shares of the company’s common stock and convertible securities, or any subdivision, reclassification or combinations of common stock. Additionally, in the case of any reclassification or capital reorganization of the capital stock of the company, the holder of each Warrant outstanding immediately prior to the occurrence of such reclassification or reorganization shall have the right to receive upon exercise of the applicable Warrant, the kind and amount of stock, other securities, cash or other property that such holder would have received if such Warrant had been exercised.
From the Emergence Date through December 31, 2013, we issued an additional 228,735 shares of our common stock to settle bankruptcy matters. This entitled the Lenders to receive an additional 14,859 Warrant Shares through December 31, 2013. On December 12, 2013, Warrants to purchase 183,389 Warrant Shares were exercised.    At December 31, 2013, Warrants to purchase an aggregate of  790,683 Warrant Shares were outstanding.
Based on certain anti-dilution provisions in the Warrant Issuance Agreement, we have concluded that the Warrants are not indexed to our equity. Accordingly, on the Emergence Date we estimated the fair value of the Warrants on the date of grant to be approximately $6.6 million and recorded the estimated fair value of the Warrants as a derivative liability with the offset to debt discount. The debt discount was being amortized over the life of the Loan Agreement, using the effective interest method until repayment of the delayed draw term loan in November 2013. Subsequent changes in the fair value of the Warrants are reflected in earnings (see Note 11 – Fair Value Measurements ).

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures [Text Block]	'
	Note 11 - 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 the valuation techniques discussed below 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.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Fresh-Start Reporting –  The fair value of the Successor was based on its estimated enterprise value post-bankruptcy using valuation techniques described in notes (a) through (e) below. The individual components consist of the estimated enterprise value of Piceance Energy and the sum of the estimated fair value of the assets we retained. The estimates of fair value of the net assets were reflected in the Successor’s consolidated balance sheet as of August 31, 2012.
			Fair Value at			Fair Value
			August 31, 2012			Technique
			(in thousands)
	Oil and gas properties
	Proved		$	4,587		(a)(b)
	Other assets
	Frac tanks			1,400		(c)
	Compressors			2,800		(c)
	Miscellaneous			39		(d)
	Investment in Piceance Energy			105,344		(e)
	(a)	Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.
	(b)	The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.
	(c)	The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.
	(d)	Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.
	(e)	The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves’ future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.
	Purchase Price Allocation of Texadian – The fair values of the assets acquired and liabilities assumed as a result of the Texadian acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (f) described below.
			Fair Value at			Fair Value
			December 31, 2012			Technique
			(in thousands)
	Net non-cash working capital		$	3,631		(a)
	Supplier relationship			3,360		(b)
	Historical shipper status			2,200		(c)
	Railcar leases			3,249		(d)
	Goodwill			7,756		(e)
	Deferred tax liabilities			-2,757		(f)
			$	17,439
	(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
	(b)	The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.
	(c)	The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.
	(d)	The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.
	(e)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
	(f)	A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.
	Purchase Price Allocation of HIE – The preliminary 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 using valuation techniques described in notes (a) through (g) described below.
			Fair Value at			Fair Value
			September 25, 2013			Technique
			(in thousands)
	Net working capital		$	462,059		(a)
	Property, plant and equipment			58,782		(b)
	Land			39,800		(c)
	Trade names and trade marks			4,689		(d)
	Goodwill			13,613		(e)
	Contingent consideration liability			-11,980		(f)
	Other noncurrent liabilities			-6,384		(g)
			$	560,579
		(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
		(b)	The estimated 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 estimated 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 estimated 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.
		(e)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
		(f)	The estimated 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 noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.
	Assets and Liabilities Measure at Fair Value on a Recurring Basis
	Common stock warrants – We estimate the fair value of our outstanding Warrants using a Monte Carlo Simulation analysis, which is considered to be Level 3 fair value measurement. Significant inputs used in the Monte Carlo Simulation Analysis include:
			December 31,
			2013			2012
Stock price		$	22.3		$	12
Initial exercise price		$	0.1		$	0.1
Term (years)			8.67			9.67
Risk-free rate			2.78	%		1.68	%
Expected volatility			52.9	%		75	%
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 Warrants was $21.64 and $11.30 per share, or approximately $17.3 million and $10.9 million, as of December 31, 2013 and 2012, respectively. Since the 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 Warrants other than changes in the value of our common stock. Increases in the value of our common stock will directly be correlated to increases in the value of the Warrants. Likewise, a decrease in the value of our common stock will result in a decrease in the value of the Warrants.
Debt Prepayment Derivative - Our Loan Agreement contained mandatory repayments subject to premiums as set forth in the agreement. Factors such as the sale of assets, distributions from our investment in Piceance Energy, issuance of additional debt or issuance of additional equity may result in a mandatory prepayment. We considered the contingent prepayment feature to be an embedded derivative which was bifurcated from the loan and accounted for as a derivative. The fair value of the embedded derivative was estimated using an income valuation technique and a Crystal Ball forecast. The fair value measurement is considered to be a Level 3 fair value measurement. We do not believe that changes to the inputs in the model would have a significant impact on the valuation of the embedded derivative, other than a change to the estimate of the probability that a triggering event would occur. An increase in the probability of a triggering event occurring would cause an increase in the fair value of the embedded derivative. Likewise, a decrease in the probability of a triggering event occurring would cause a decrease in the value of the embedded derivative. At December 31, 2012, we estimated the fair value of the embedded derivative to be $145 thousand based on the probability of us repaying the loan prior to maturity. In November 2013, we repaid in full and terminated all of our obligations, including any repayment premiums, under this Loan Agreement (other than the new Tranche B loans described above) extinguishing the liability (see Note 10 - Debt).
Derivative instruments – With the acquisition of Texadian, we assumed certain open positions consisting of non-exchange traded fixed price physical contracts. These contracts were not treated as normal purchase or normal sales contracts and changes in fair value were recorded in earnings. In addition, we had certain exchange traded oil contracts that settled during the period and had no open positions as of December 31, 2013.  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. As of December 31, 2013, we had no open positions relating to these non-exchange traded fixed price physical contracts for which we have not elected the  normal purchase or normal sale exception.
Contingent consideration liability – As described in Note 4, the purchase price for our acquisition of HIE may be increased pursuant to an earn out provision. The initial value of the contingent consideration was estimated to be approximately $12.0  million. The liability is re-measured at the end of each reporting period using the valuation technique as described above. We do not believe that there has been a material change in the liability from September 25, 2013 through December 31, 2013.
Financial Statement Impact
Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their placement with our consolidated balance sheet consist of the following (in thousands):
		Location on
		Consolidated			Fair Value at		Fair Value at
		Balance Sheet		December 31, 2013			December 31, 2012
Commodities – physical forward		Prepaid and other current assets		$	—		$	-307
contracts
Commodities – exchange traded		Prepaid and other current assets			—			542
futures
Warrant derivatives		Derivative liabilities			-17,336			-10,900
Contingent consideration liability		Contingent consideration liability			-11,980			—
Debt repayment derivative		Derivative liabilities			—			-45
The following table summarizes the pre-tax effect resulting from changes in fair value of derivative instruments charged directly to earnings (in thousands):
							September 1
							through
				December 31, 2013			December 31, 2012
				Gain (loss)			Gain (loss)
		Income Statement		recognized in			recognized in
		Classification		income			income
Derivatives not designated as
hedges:
Warrants		Change in value		$	-10,114		$	-4,280
		of warrants
Debt repayment derivative		Interest expense and			45			—
		financing costs, net
Commodities - exchange traded		Gain on derivative			104			—
futures		instruments, net
Commodities - physical forward		Gain on derivative			306			—
contracts		instruments, net
Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their level within the fair value hierarchy is as follows (in thousands):
		December 31, 2013
		Fair Value			Level 1			Level 2		Level 3
Liabilities
Warrants derivative		$	-17,336		$	—		$	—	$	-17,336
Contingent consideration liability			-11,980			—			—		-11,980
		$	-29,316		$	—		$	—	$	-29,316
		December 31, 2012
		Fair Value			Level 1			Level 2		Level 3
Assets
Commodities – exchange traded futures		$	542		$	542		$	—	$	—
Liabilities
Warrants derivative		$	-10,900		$	—		$	—	$	-10,900
Debt prepayment derivative			-45			—			—		-45
Commodities – physical forward contracts			-307			—			-307		—
		$	-11,252		$	—		$	-307	$	-10,945
A rollforward of Level 3 derivative instruments measured at fair value on a recurring basis is as follows (in thousands):
Description		2013			2012
Balance, at beginning of period		$	-10,945		$	-6,665
Settlements			3,723			—
Acquired			-11,980			—
Total unrealized losses included in earnings			-10,114			-4,280
Transfers			—			—
Balance, at end of period		$	-29,316		$	-10,945
The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2013 and 2012 is as follows (in thousands):
		December 31, 2013
		Carrying Value			Fair Value(1)
Tranche B		$	19,480		$	18,800
ABL Facility			51,800			51,800
HIE Retail Credit Agreement			26,000			26,000
Warrants			17,336			17,336
Contingent consideration liability			11,980			11,980
		December 31, 2012
		Carrying Value			Fair Value(1)
Long-term debt		$	7,391		$	10,900
Warrants			10,900			10,900
Debt repayment derivative			45			45
_________________________________________________________
(1)                   The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.
The fair value of all non-derivative financial instruments included in current assets, including cash and cash equivalents, restricted cash and trade accounts receivable, current liabilities and accounts payable approximate their carrying value due to their short term nature.
We estimate our long term debt’s fair value using a discounted cash flow analysis and an estimate of the current yield of  5.72%  and  5.72%  as of December 31, 2013 and 2012, respectively, by reference to market interest rates for term debt of comparable companies.

Defined_Contribution_Plans

Defined Contribution Plans	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
Pension and Other Postretirement Benefits Disclosure [Text Block]	'
	Note 12 – Defined Contribution Plans
	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 year ended December 31, 2013, we made contributions to the plans totaling approximately $502 thousand.   There were no such plans in place for the period from September 1, 2012 through December 31, 2012.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments And Contingencies Disclosure [Text Block]	'
	Note 13 - Commitments and Contingencies
	Environmental Matters
	Like other petroleum refiners and oil and gas 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 (“US EPA”) has begun regulating greenhouse gases under the Clean Air Act Amendments of 1990 (the “Clean Air Act”).  New construction or material expansions that meet certain greenhouse gas emissions thresholds will likely require that, among other things, a greenhouse gas 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 greenhouse gas emissions.
	Furthermore, the US EPA is currently developing refinery-specific greenhouse gas regulations and performance standards that are expected to impose, on new and modified operations, greenhouse gas 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 greenhouse gas emissions be rolled back on a state wide 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 greenhouse gas emissions were reported to the US 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 greenhouse gas 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 greenhouse gas inventory and future year projection. 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 US 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 36.0 billion gallons by 2022. In the near term, the RSF2 will be satisfied primarily with fuel ethanol blended into gasoline. The RSF2 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 US  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 US EPA issued a second waiver for the use of E15 in vehicles model year 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 US 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 nation-wide little time to engineer, permit and implement substantial modifications. Along with credit and trading options, potential capital upgrades for the refinery are being evaluated. The American Petroleum Institute and American Fuel and Petrochemical Association may challenge the final regulation.
	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 (the “Closing Date”), Hawaii Pacific Energy (a wholly-owned subsidiary of Par created for purposes of the Tesoro Acquisition), Tesoro and HIE entered into an Environmental Agreement (the “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 US 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 (the “Consent Decree”), including the Hawaii refinery.  It is anticipated that the Consent Decree will be finalized sometime during 2014 and will require certain capital improvements to our refinery to reduce emissions of air pollutants.
	It is not possible at this time to estimate the cost of compliance with the ultimate decree. 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 has agreed, at its expense, to replace the existing underground storage tanks at certain retail assets.
	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 Environment 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 assets, fines or penalties imposed on HIE by the Consent Decree related to acts or omissions of Tesoro prior to the Closing Date and 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 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.
	Helicopter Litigation.
	HIE is the defendant in a lawsuit styled State of Hawaii Department of Transportation Airports Division et al. v. Tesoro Hawaii, Civil No. 09-2253-09 JHC. In this matter, the insurance company for the State of Hawaii is seeking reimbursement of the attorney’s fees and costs incurred by outside council to defend against Tesoro Hawaii’s third-party complaints for contribution in three previously-settled underlying litigation matters. The underlying litigation was filed by three helicopter tour operators flying on the Island of Kauau. The helicopter tour operators allege bad jet fuel caused the formation of coking deposits in their engines which resulted in millions of dollars of repair costs and lost income. There were no in-flight issues.
	Tesoro Hawaii filed third-party complaints against the State of Hawaii in each of the three underlying lawsuits alleging that any fuel issues arose from improper design and maintenance of the underground pipeline and dispensers owned and maintained by the State of Hawaii. The helicopter operators settled with the State of Hawaii, and Tesoro Hawaii and its aviation liability insurers subsequently settled with the helicopter operators.
	The lawsuit alleges that the State of Hawaii was entitled to a defense and indemnity under the terms of its lease for the Tesoro Hawaii facility at the Lihue airport. The suit alleges defense costs of approximately $2 million in the underlying lawsuits. The State of Hawaii and its insurance company have since demanded $3.25 million. The issue at trial is ultimately whether Tesoro Hawaii owed a contractual duty to pay for the State of Hawaii’s defense against Tesoro Hawaii’s third-party complaints against the State of Hawaii for the State’s own negligence. The case is set for a bench trial in September 2014.
	There is a companion lawsuit by the State of Hawaii and its insurance company against Tesoro Hawaii’s former liability insurer on the same issues. The Court previously held by way of a Motion for Summary Judgment that Tesoro Hawaii’s insurer had a duty to defend the State of Hawaii against Tesoro Hawaii’s third-party complaints. That matter is going to trial in July 2014 on the issue of damages only (e.g. the reasonable amount of attorney’s fees and costs the State of Hawaii is entitled to for the defense of the third-Party Complaints in the underlying lawsuits).
	We do not believe that any loss relating to this litigation is probable. However, should any loss become probable before the end of the measurement period, such loss would be reflected as a purchase price adjustment relating to the HIE Acquisition.
	Recovery Trusts
	On the date we emerged from bankruptcy, or the Emergence Date, two trusts were formed; the Wapiti Recovery Trust (the “Wapiti Trust”) and the Delta Petroleum General Recovery Trust (the “General Trust,” and together with the Wapiti Trust, the “Recovery Trusts”). The Recovery Trusts were formed to pursue certain litigation against third-parties or causes of action under the U.S. Bankruptcy Code, and other claims and potential claims that the Debtors hold against third parties. The Recovery Trusts were funded with $1.0 million each pursuant to the Plan.
	In September 2012, the Wapiti Trust settled all causes of action against Wapiti Oil & Gas, LLC (“Wapiti Oil & Gas”). Wapiti Oil & Gas made a one-time cash payment in the amount of $1.5 million to the Wapiti Trust, as consideration for the release of claims against it. These proceeds were then distributed to us, along with funds remaining from the initial funding of the Wapiti Trust of approximately $1.0 million. The Wapiti Trust was liquidated during 2013.
	The General Trust is pursuing all bankruptcy causes of action not otherwise vested in the Wapiti Trust, claim objections and resolutions, and all other responsibilities for winding-up the bankruptcy. The General Trust is overseen by a three person General Trust Oversight Board and our Chief Legal Officer is currently the trustee  (the “Recovery Trustee”). Costs, expenses and obligations incurred by the General Trust are charged against assets in the General Trust. To conduct its operations and fulfill its responsibilities under the Plan and the trust agreements, the Recovery Trustee may request additional funding from us. Any litigation pending at the time we emerged from Chapter 11 was transferred to the General Trust for resolution and settlement in accordance with the Plan and the order confirming the Plan. We are the beneficiary of the General Trust, subject to the terms of the 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.
	From the Emergence Date through December 31, 2013, the Recovery Trusts have released approximately $5.2 million to us, which is available for our general use, due to a negotiated reduction in certain fees and claims associated with the bankruptcy, as well as a favorable variance in actual expenses versus budgeted expenses. The entire $5.2 million was released prior to December 31, 2012.
	Shares Reserved for Unsecured Claims
	The Plan provides that certain allowed general unsecured claims be paid with shares of our common stock. On the Emergence Date, 112 claims totaling approximately $73.7 million had been filed in the bankruptcy. Pursuant to the Plan, between the Emergence Date and December 31, 2012, the Recovery Trustee settled 25 claims with an aggregate face amount of $6.6 million for approximately $259 thousand in cash and 20,275 shares of common stock.  Pursuant to the Plan, during the year ended December 31, 2013, the Recovery Trustee settled an additional 59 claims with an aggregate face amount of $26.9 million for approximately $5.4 million in cash and 208,460 shares of common stock.
	As of December 31, 2013, it is estimated that a total of 28 claims totaling approximately $40.2 million remain to be resolved by the Recovery Trustee. The largest remaining proof of claim was filed by the US Government for approximately $22.4 million relating to ongoing litigation concerning a plugging and abandonment obligation in Pacific Outer Continental Shelf Lease OCS-P 0320, comprising part of the Sword Unit in the Santa Barbara Channel, California. We believe the probability of issuing stock to satisfy the full claim amount is remote, as the obligations upon which such proof of claim is asserted are joint and several among all working interest owners, and the Predecessor company owned a 2.41934% working interest in the unit.
	The settlement of claims is subject to ongoing litigation and we are unable to predict with certainty how many shares will be required to satisfy all claims. Pursuant to the Plan, allowed claims are settled at a ratio of 54.4 shares per $1,000 of claim. At December 31, 2013 and 2012, we have reserved approximately $3.8 million and $8.7 million, respectively, representing the estimated value of claims remaining to be settled which are deemed probable and estimable at period end. A summary of claims is as follows (in thousands, except number of filed claims):
		Emergence-Date					From Emergence-Date through December 31, 2012
		August 31, 2012
																Remaining Filed
		Filed Claims					Settled Claims									Claims
												Consideration
		Count			Amount		Count		Amount			Cash		Stock		Count	Amount
	U.S. Government Claims		3		$	22,364	—		$	—		$	—	—		3	$	22,364
	Former Employee Claims		32			16,380	13			3,685			230	20		19		12,695
	Macquarie Capital (USA) Inc.		1			8,672	—			—			—	—		1		8,672
	Swann and BuzzardCreek		1			3,200	—			—			—	—		1		3,200
	RoyaltyTrust
	Other Various Claims*		75			23,114	12			2,915			29	—		63		20,199
	Total		112		$	73,730	25		$	6,600		$	259	20		87	$	67,130
			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, with four 5-year renewal options. Minimum annual lease payments including interest, for capital leases are as follows (in thousands):
	2014		$	382
	2015			382
2016			382
2017			382
2018			420
Thereafter			420
Total minimum lease payments			2,368
Less amount representing interest			634
Total minimum rental payments		$	1,734
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 32 years, 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 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):
2014		$	22,724
2015			13,277
2016			12,362
2017			10,375
2018			9,244
Thereafter			25,614
Total minimum rental payments		$	93,596
Rent expense for the year ended December 31, 2013 and for the period from September 1, 2012 through December 31, 2012 was approximately $6.2 million  and $61 thousand, respectively.
Major Customers
For the year ended December 31, 2013, no individual customer accounted for more than 10% of our consolidated revenue. For the period September 1, 2012 to December 31, 2012, we had one customer that accounted for 96% of our total oil and natural gas sales. During the period from January 1, 2012 to August 31, 2012, our Predecessor had two customers that accounted individually for 59% and 24%, respectively, of its total oil and natural gas sales.
Other
On April 22, 2013, Texadian entered into a terminaling and storage agreement whereby the operator will provide Texadian with storage facilities, access to a marine terminal and pipelines, and railcar offloading services. The initial term of the agreement is for a period of four years and Texadian’s minimum commitment during the initial term is approximately $28 million.

Stockholders_Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Stockholders Equity Note Disclosure [Text Block]	'
	Note 14 - Stockholders’ Equity
	Pursuant to the Plan, on the Emergence Date, (i) all shares of our common stock outstanding prior to the Effective Date were cancelled, (ii) each holder of our 7% senior unsecured notes due 2015 and our 3 3/4% senior convertible notes due 2037 received, in exchange for its total claim (including principal and interest), its pro rata portion of 14,573,608 shares of our common stock, (iii) each holder of an allowed general unsecured claim received, in exchange for its total claim, its pro rata portion of 191,973 shares of our common stock, and (iii) the Lenders under the Loan Agreement received warrants to purchase up to an aggregate of 959,213 shares of our common stock (which number of shares may be increased to an aggregate of 1,220,000 shares of our common stock pursuant to the terms of the Warrant Issuance Agreement).
	Amendments to the Certificate of Incorporation and Bylaws
	Pursuant to the Plan, on the Emergence Date, our certificate of incorporation and bylaws were amended and restated in their entirety.
	Under the restated certificate of incorporation, the total number of all shares of capital stock that we are authorized to issue is 303 million shares, consisting of 300 million shares of common stock and 3 million shares of preferred stock, par value $0.01 per share. The restated 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 Code, of us or any direct or indirect subsidiary thereof.
	On November 25, 2013, our amended and restated certificate of incorporation was further amended to (i) increase the authorized shares of Common Stock from 300,000,000 to 500,000,000 and (ii) revise certain provisions regarding approval by the company’s Board of Directors of transfers of Common Stock by holders of five percent or more of the outstanding Common Stock.
	Preferred Stock
	As of December 31, 2013 and 2012, no shares of preferred stock were outstanding.
	Common Stock
	On December 31, 2012, a total of 3,052 shares of our common stock were issued to members of our Board of Directors in lieu of a cash fee for their service on the Board. We recognized compensation costs of approximately $33 thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $10.00 to $12.00 per share of common stock. Due to our limited daily trading activity, we believe that this represents a more accurate reflection of the fair value of our common stock.
	On September 13, 2013, we entered into a Common Stock Purchase Agreement pursuant to which we agreed to sell shares of our common stock at a price of $13.90  per share, as adjusted to reflect the one for ten reverse stock split effective for trading purposes on January 29, 2014 (the “Reverse Stock Split”),  in a private placement transaction (the “Private Placement”) in reliance upon an exemption from registration pursuant to Regulation D under the Securities Act of 1933. Certain purchasers, namely, ZCOF Par Petroleum Holdings, L.L.C., an affiliate of Zell Credit Opportunities Master Fund, L.P. (“ZCOF”), and affiliates of Whitebox Advisors, LLC (“Whitebox”), each owned 10% or more of the our common stock directly or through affiliates prior to the execution of the Common Stock Purchase Agreement and are deemed to be our affiliates as a result of such ownership. ZCOF and Whitebox have representatives on our board of directors.
	On September 25, 2013, we completed the Private Placement and issued approximately 14.4 million shares of common stock resulting in aggregate gross proceeds to us of approximately $200 million. We did not engage any investment advisors with respect to the Private Placement, and no finders’ fees or commissions were paid to any party in connection therewith. The proceeds from the Private Placement were used to fund a portion of the purchase price of the HIE acquisition.
	During the year ended December 31, 2013, we issued approximately 208,512 shares of our common stock for settlement of bankruptcy claims, approximately 183,390 shares due to the exercise of Warrants and approximately  5,585  shares of unrestricted common stock to certain key employees and directors. We recognized compensation costs of approximately $90  thousand relating to these shares, which represent their estimated fair value on the date of grant based on the previous 20 days average trading price of our common stock which ranged from $12.22 to $19.87  per share of common stock.
	Registration Rights Agreements
	Pursuant to the Plan, on the Effective Date, we entered into a registration rights agreement (the “Registration Rights Agreement”) providing the stockholders party thereto (the “Stockholders”) with certain registration rights.
	The Registration Rights Agreement states that, among other things, at any time after the earlier of the consummation of a qualified public offering or 60 days after the Effective Date, 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 on Form S-1 or S-3, or any other appropriate form under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, 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, on any form for which we then qualify and which is available for the sale of the Registrable Shares in accordance with the intended methods of distribution thereof, with respect to the Demand Registration. We are required to use commercially reasonable efforts to cause the registration statement to be declared effective as soon as practicable after such filing. We will not be obligated (i) to effect a Demand Registration within 90 days after the effective date of a previous Demand Registration, other than for a shelf registration, or (ii) to effect a Demand Registration unless the Demand Request is for a number of Registrable Shares with an expected market value that is equal to at least (x) $15 million as of the date of such Demand Request or is for one hundred percent of the demanding Stockholder’s Registrable Shares with respect to any Demand Registration made on Form S-1 or (y) $5 million as of the date of such Demand Request with respect to any Demand Registration made on Form S-3.
	Upon receipt of any Demand Request, we are required to give written notice, within ten (10) days of such Demand Registration, to all other holders of Registrable Shares, who will have the right to elect to include in such Demand Registration such portion of their Registrable Shares as they may request, subject to certain exceptions.
	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.
	The rights of a holder of Registrable Shares may be transferred, assigned or otherwise conveyed on to any transferee or assignee of such Registrable Shares, subject to applicable state and federal securities laws and regulations, our Certificate of Incorporation and the Stockholders Agreement. We will be responsible for expenses relating to the registrations contemplated by the Registration Rights Agreement.
	The registration rights granted in the Registration Rights Agreement are subject to customary indemnification and contribution provisions, as well as customary restrictions such as suspension periods and, if a registration is for an underwritten offering, limitations on the number of shares to be included in the underwritten offering imposed by the managing underwriter.
	In connection with the closing of the sale of the 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 U.S. Securities and Exchange Commission 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. We will accrue an obligation for this registration rights agreement when it is probable that an obligation has been incurred and the amount can be reasonably determined.
	Incentive Plan
	On December 20, 2012, our Board of Directors (the “Board”) approved the Par Petroleum Corporation 2012 Long Term Incentive Plan (the “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. In addition, in December 2012, we approved a new compensation plan for our directors. Our directors receive an annual retainer of $50 thousand, paid quarterly in cash or shares of our common stock at the election of the director. In addition, the Chairman of the Audit Committee receives an additional annual retainer of $15 thousand and the members of the Audit Committee (other than the Chairman) receive an annual retainer of $5 thousand, such retainers paid quarterly in cash or shares of our common stock at the election of the director. There are no fees for the members of any other committee or for attendance at meetings. Our directors are also entitled to receive an annual grant of restricted stock on the last day of each calendar year with a target value of $75 thousand, with the number of shares determined by the 60-day volume weighted average share price as of the day prior to the grant date.
	On December 31, 2012, a total of 219,183 shares of restricted common stock were granted to members of the Board of Directors and certain employees. During the year ended December 31, 2013, an additional 355,481 shares of restricted stock were granted to certain employees. Restricted stock granted to members of the Board vests in full after one year from the date of grant, while most restricted stock granted to employees vests on a pro-rata basis over five years. For the year ended December 31, 2013, the following activity occurred under our Incentive Plan (in thousands, except per share amounts):
		Shares	Weighted-
			Average
			Grant Date Fair
			Value
	Non vested balance, beginning of period	219	$	12
	Granted	356		18.32
	Vested	-51		12
	Forfeited	—		—
	Non vested balance, end of period	524	$	16.29
	Available for grant	1,025
	For the year ended December 31, 2013, we recognized compensation costs of approximately  $1.2 million related to restricted stock awards. As of December 31, 2013, there is approximately $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 4.37 years. The grant date fair value was estimated using the previous 20 days average trading price of our common stock.
	Predecessor Stock Compensation Plans
	On December 22, 2009, the Predecessor’s stockholders approved its 2009 Performance and Equity Plan (the “2009 Plan”). On June 21, 2011, the Predecessor granted 489,227 shares of non-vested common stock to certain employees. The shares vested in full on the earlier of a change in control or July 1, 2012. In conjunction with this grant, the Predecessor agreed to establish a “floor” price for the value of the shares on the date of vesting equal to the value of the shares on the grant date ($5.50 per share). In the event that the market price of the shares on the date of vesting was lower than the floor price on the date of vesting, the difference would be paid to the employees in cash. The compensation expense for the shares consists of a fixed equity component ($5.50 per share) and a variable liability component (based on the difference between the market price of the shares, if lower, and the floor price of the shares), both of which are included as a component of general and administrative expense in the accompanying Predecessor consolidated statement of operations. The Predecessor recognized stock compensation expense of approximately $1.9 million for the period from January 1, 2012 through August 31, 2012, which is included in general and administrative expenses. Under the terms of the Plan, the Predecessor’s stock compensation plans, and all awards issued under such plans, were canceled.
	A summary of the stock option activity under the Predecessor’s various plans and related information for the period from January 1 through August 31, 2012 follows:
		Period from January 1
		through August 31, 2012
		Options	Weighted-Average		Weighted-Average	Aggregate
			Exercise		Remaining  Contractual	Intrinsic
			Price		Term	Value
	Outstanding-beginning of year	150,300	$	75
	Granted	—		—
	Exercised	—		—
	Expired / canceled	-150,300		-75
	Outstanding-end of year	—	$	—	—	$	—
	Exercisable-end of year	—	$	—	—	$	—
	A summary of the restricted stock (nonvested stock) activity under the Predecessor’s plan and related information for the period from January 1 through August 31, 2012 follows (in thousands, except share and per share amounts):
		Period from January 1
		through August 31, 2012
		Nonvested	Weighted-Average		Weighted-Average	Aggregate
		Stock	Grant-Date Fair		Remaining Contractual	Intrinsic
			Value		Term	Value
	Nonvested-beginning of year	558,301	$	7.45
	Granted	—		—
	Vested	—		—
	Expired / canceled	-558,301		-7.45
	Nonvested-end of year	—	$	—	—	$	—

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Tax Disclosure [Text Block]	'
	Note 15 - Income Taxes
	Under the Plan of Reorganization, our prepetition debt securities, primarily prepetition notes, were extinguished. Absent an exception, a debtor recognizes cancellation of debt income (“CODI”) upon discharge of its outstanding indebtedness for an amount of consideration that is less than its adjusted issue price. Tax regulations provide that a debtor in a bankruptcy case may exclude CODI from income but must reduce certain of its tax attributes by the amount of any CODI realized as a result of the consummation of a plan of reorganization. The amount of CODI realized by a taxpayer is the adjusted issue price of any indebtedness discharged less the sum of (i) the amount of cash paid, (ii) the issue price of any new indebtedness issued and (iii) the fair market value of any other consideration, including equity, issued. As a result of the market value of our equity upon emergence from Chapter 11 bankruptcy proceedings, we were able to retain a significant portion of our NOLs and other “Tax Attributes” after reduction of the Tax Attributes for CODI realized on emergence from Chapter 11 and certain prior interest payments on debt converted to equity. Our NOLs have been reduced by approximately $225 million of CODI as a result of emergence from Chapter 11.
	Pursuant to the Plan, on the Emergence Date, the existing equity interests of the Predecessor were extinguished. New equity interests were issued to creditors in connection with the terms of the Plan, resulting in an ownership change as defined under Section 382 of the Code. Section 382 generally places a limit on the amount of net operating losses and other tax attributes arising before the change that may be used to offset taxable income after the ownership change. We believe, however, 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 net operating losses; however the net operating losses are eliminated should another ownership change occur within two years. Our amended and restated certificate of incorporation places restrictions upon the ability of the equity interest holders to transfer their ownership in us. These restrictions are designed to provide us with the maximum assurance that another ownership change does not occur that could adversely impact our net operating loss carry forwards.
	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, 2013 and 2012.
	During the years ended December 31, 2013 and 2012, 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 2014 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:
		Successor						Predecessor
					Period from			Period from
					September 1			January 1
		Year Ended			through			through
		December 31,			December 31,			August 31,
		2013				2012			2012
	Current:
	U.S.—Federal	$	—		$	—		$	—
	U.S.—State		-179			—			—
	Deferred:
	U.S.—Federal		-14			-2,757			—
	U.S.—State		193			—			—
	Total	$	—		$	-2,757		$	—
	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:
		Successor						Predecessor
					Period from			Period from
					September 1			January 1
		Year Ended			through			through
		December 31,			December 31,			August 31,
		2013			2012			2012
	Federal statutory rate		-35	%		-35	%		-35	%
	State income taxes, net of federal benefit		0.1	%		—			—
	Change in valuation allowance		21.7	%		-2	%		-33
	Professional fees related to bankruptcy reorganization		—			8	%		17	%
	Revenue from Wapiti Trust settlement		—			5	%		—
	Cancellation of debt tax attribute reduction		—			—			51	%
	Permanent Items		4.1	%
	Provision to return adjustments		9.1	%		—			—
	Actual income tax rate		—	%		-24	%		—	%
	Deferred tax assets (liabilities) are comprised of the following at December 31, 2013 and 2012 (in thousands):
		2013				2012
	Deferred tax assets:
	Net operating loss	$	540,867		$	450,195
	Capital loss carry forwards		26,141			26,141
	Property and equipment		34,683			23,045
	Investment in Piceance Energy		32,138			45,172
	Derivative instruments		—			1,498
	Accrued bonuses		—			—
	Trust liabilitiy		1,327			—
	Other		1,183			1,506
	Total deferred tax assets		636,339			547,557
	Valuation allowance		-633,954			-544,442
	Net deferred tax assets	$	2,385		$	3,115
	Deferred tax liabilities:
	Property and equipment	$	5		$	—
	Texadian Energy intangibles		2,380			3,083
	Prepaid insurance, marketable securities and other		—			32
	State liabilities		216			—
	Total deferred tax liabilities	$	2,601		$	3,115
	Total deferred tax liability, net	$	-216		$	—
	We have net operating loss carryovers as of December 31, 2013 of $1.3 billion for federal income tax purposes. If not utilized, the tax net operating loss carryforwards will expire during 2027 through 2032. Our capital loss carryovers as of December 31, 2013 are $74.7 million. If not utilized, these carryovers will expire during 2015 and 2016. We also have Alternative Minimum Tax Credit Carryovers of $0.8 million. These credits do not expire; however, we must first generate regular taxable income before they can be used. We will not likely generate regular taxable income utilized our net operating loss carry over.

Loss_Per_Share

Loss Per Share	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share [Text Block]	'
	Note 16 - Loss Per Share
	The following table sets forth the computation of basic and diluted loss per share (in thousands, except per share amounts):
			Successor						Predecessor
						September 1			January 1
			Year Ended			through			through
			December 31,			December 31,			August 31,
			2013			2012			2012
	Net loss attributable to common stockholders		$	-70,621		$	-8,839		$	-45,437
	Basic weighted-average common shares			19,740			15,734			28,841
	outstanding
	Add: dilutive effects of stock options and			—			—			—
	unvested stock grants (1)
	Diluted weighted-average common stock outstanding			19,740			15,734			28,841
	Basic loss per common share attributable to
	common stockholders:
	Net loss (1)		$	-3.57		$	-0.56		$	-1.57
	Diluted loss per common share attributable to
	common stockholders:
	Net loss (1)		$	-3.57		$	-0.56		$	-1.57
	________________________________________________________
		-1	Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.
	Weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding include the following (in thousands):
			Successor					Predecessor
					Period from			Period from
					September 1			January 1
			Year Ended		through			through
			December 31,		December 31,			August 31,
			2013		2012			2012
	Stock issuable upon conversion of convertible notes		—		—			379
	Stock options		—		—			150
	Non-vested restricted stock		523		—			558
	Total potentially dilutive securities		523		—			1,087

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Reporting Disclosure [Text Block]	'
	Note 17 - Segment Information
	Following our acquisitions of HIE and Texadian, we have 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, 2013	Refining,		Natural Gas		Commodity		Corporate and		Total
		Distribution		and Oil		Marketing and		Other
		and Marketing		Operations		Logistics
	Sales and operating revenues	$	778,126	$	7,739	$	100,149	$	—	$	886,014
	Depreciation, depletion, amortization		2,267		1,686		2,009		20		5,982
	and accretion
	Operating income (loss)		-19,318		246		9,126		-29,367		-39,313
	Loss from unconsolidated affiliate										-2,941
	Interest expense and financing costs, net										-19,471
	Other income (expense)										808
	Change in value of common stock warrants										-10,114
	Gain on derivative instruments										410
	Loss before income taxes										-70,621
	Income tax benefit										—
	Net loss									$	-70,621
	Capital expenditures, including acquisitions	$	567,332	$	471	$	-1,300	$	544	$	567,047
	Following our acquisition of Texadian, at December 31, 2012, we had two business segments: (i) Natural Gas and Oil Operations and (ii) Commodity Marketing and Logistics. For the period from September 1 through December 31, 2012, all of the operations as reported on our consolidated statement of operations related to Natural Gas and Oil Operations. For the period from September 1 through December 31, 2012, expenditures for long term assets, including goodwill and other intangible assets by segment were as follows (in thousands):
		Natural Gas		Commodity		Corporate and		Total
		and Oil		Marketing and		Other
		Operations		Logistics
	Capital expenditures, including acquisitions	$	415	$	17,439	$	—	$	17,854
	Total assets by segment were as follows (in thousands):
		Refining,		Natural Gas		Commodity		Corporate and		Total
		Distribution		and Oil		Marketing and		Other
		and Marketing		Operations		Logistics
	At December 31, 2013	$	655,712	$	109,316	$	52,048	$	10,009	$	827,085
	At December 31, 2012	$	—	$	116,034	$	62,754	$	10,794	$	189,582

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions Disclosure [Text Block]	'
	Note 18 - Related Party Transactions
	Certain of our stockholders who are lenders under the Loan Agreement received Warrants exercisable for shares of common stock in connection with such loan (see Note 10 - Debt).
	Certain of our stockholders and their affiliates who are owners of 10% or more of our common shares participated in the Stock Sale (see Note 14 - Stockholders’ Equity).
	On September 17, 2013, we entered into letter agreements (the “Services Agreements”) with Equity Group Investments, an affiliate of ZCOF (“EGI”), and Whitebox.  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 indemnity 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 this agreement during 2013.

Reorganization_Under_Chapter_1

Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan	12 Months Ended
	Dec. 31, 2013
Reorganizations [Abstract]	'
Reorganization Under Chapter 11 Of U S Bankruptcy Code Disclosure [Text Block]	'
	Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan
	In December 2011 and January 2012, Delta and its subsidiaries filed voluntary petitions under Chapter 11 of the U.S. Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”). Delta and its subsidiaries included in the bankruptcy petitions are collectively referred to as the “Debtors.”
	In March 2012, the Bankruptcy Court approved the procedures relating to plans of reorganization as well as asset sales. Following completion of the asset sales, the Debtors obtained approval from the Bankruptcy Court to proceed with Laramie Energy II, LLC (“Laramie”) as the sponsor of a plan of reorganization (the “Plan”). In June 2012, Delta entered into a Contribution Agreement (the “Contribution Agreement”) with a new joint venture formed by Delta and Laramie, Piceance Energy LLC (“Piceance Energy”), and Laramie to effect the transactions contemplated by Plan.
	The Plan was declared effective on August 31, 2012 (the “Emergence Date”). On the Emergence Date, Delta consummated the transaction contemplated by the Contribution Agreement and each of Delta and Laramie contributed to Piceance Energy their respective assets in the Piceance Basin. Piceance Energy is owned 66.66% by Laramie and 33.34% by Delta. At the closing, Piceance Energy entered into a new credit agreement, borrowed $100 million under that agreement, and distributed approximately $72.6 million net of settlements to the company and approximately $24.9 million to Laramie. The company used its distribution to pay bankruptcy expenses and to repay its secured debt. The company also entered into a new credit facility and borrowed $13 million under that facility at closing, and used those funds primarily to pay bankruptcy claims and expenses.
	Following the reorganization, Par retained its interest in the Point Arguello Unit offshore California and other miscellaneous assets and certain tax attributes, including significant net operating loss carryforwards. Based upon the Plan as confirmed by the Bankruptcy Court, Delta’s creditors were issued approximately 14.8 million shares of common stock, and Delta’s former stockholders received no consideration under the Plan.
	Contemporaneously with the consummation of the Contribution Agreement, the company, through a wholly-owned subsidiary, entered into a Limited Liability company Agreement with Laramie that will govern the operations of Piceance Energy.
	On the Emergence Date, Par adopted fresh-start reporting resulting in us becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to August 31, 2012 reflect the operations of Delta prior to reorganization (hereinafter also referred to as the “Predecessor”) and are not comparable to the consolidated financial statements presented on or after August 31, 2012. Fresh-start reporting was required upon emergence from Chapter 11 because (i) holders of voting shares immediately before confirmation of the Plan received less than 50% of the emerging entity and (ii) the reorganization value of our assets immediately before confirmation of the Plan was less than our post-petition liabilities and allowed claims. Fresh-start reporting results in a new basis of accounting and reflects the allocation of our estimated fair value to underlying assets and liabilities. The effects of the implementation of the Plan and fresh-start adjustments are reflected in the results of operations of the Predecessor in the eight month period ended August 31, 2012. Our estimates of fair value are inherently subject to significant uncertainties and contingencies beyond our reasonable control. Accordingly, there can be no assurance that the estimates, assumptions, valuations, appraisals and financial projections will be realized, and actual results could vary materially. Moreover, the market value of our common stock may differ materially from the equity valuation for accounting purposes.
	In the application of fresh-start reporting, a successor entity must determine a value to be assigned to the equity of the emerging company as of the date of adoption of fresh-start reporting, which for us is August 31, 2012, the date the Debtors emerged from Chapter 11. To facilitate this calculation, we first determined the enterprise value of the Successor and the individual components of the opening balance sheet. The most significant item is our  33.34% interest in Piceance Energy, the value of which was estimated to be approximately $105.3 million as of the Emergence Date. We also considered the fair value of the other remaining assets. See Note 11 - Fair Value Measurements  for a detailed discussion of fair value and the valuation techniques.
	The estimated enterprise value and the equity value are highly dependent on the achievement of the future financial results contemplated in the projections that were set forth in the Plan. The estimates and assumptions made in the valuation are inherently subject to significant uncertainties. The primary assumptions for which there is a reasonable possibility of the occurrence of a variation that would have significantly affected the reorganization value include the assumptions regarding our direct ownership of estimated proved reserves, our indirect ownership of estimated proved reserves through our equity ownership in Piceance Energy, operating expenses, the amount and timing of capital expenditures and the discount rate utilized.
	Fresh-start reporting reflects the value of the Successor as determined in the confirmed Plan. Under fresh-start reporting, our asset values are remeasured and allocated based on their respective fair values in conformity with the acquisition method of accounting for business combinations. The reorganization values approximated the fair values of the identifiable net assets. Liabilities existing as of the Effective Date, other than deferred taxes and derivatives, were recorded at the present value of amounts expected to be paid using appropriate risk adjusted interest rates. Deferred taxes and derivatives were determined in conformity with applicable accounting standards. Predecessor accumulated depreciation, accumulated amortization and retained deficit were eliminated. Under the Plan, our priority non-tax claims and secured claims are unimpaired in accordance with the Bankruptcy Code. Each general unsecured claim and noteholder claims received its pro rata share of new common stock of Par in full satisfaction of its claims.
	The following condensed consolidated balance sheet presents the implementation of the Plan and the adoption of fresh-start reporting as of the Effective Date. Reorganization adjustments have been recorded within the condensed consolidated balance sheet to reflect the effects of the Plan, including discharge of liabilities subject to compromise and the adoption of fresh-start reporting.
				August 31, 2012
						Plan of			Fresh Start
						Reorganization			Reporting
				Predecessor		Adjustments			Adjustments			Successor
			(in thousands)
	ASSETS
	Current assets
	Cash and cash equivalents		$	1,954	$	74,167	(a)	$			$	4,882
						-45,035	(c)
						-24,204	(d)
						-2,000	(e)
	Trust assets			—		3,446	(e)					3,446
	Restricted cash			—		20,359	(d)					20,359
	Trade accounts receivable, net			3,708		-1,727	(a)		-1,981	(g)		—
	Prepaid assets			4,777					-4,777	(g)		—
	Prepaid reorganization costs			1,326					-1,326	(g)		—
	Total current assets			11,765								28,687
	Property and equipment
	Oil and gas properties
	Unproved			84					-84	(g)		—
	Proved			759,755		-740,392	(a)		-14,776	(g)		4,587
	Land			4,000		-4,000	(a)					—
	Other			73,021		-47,493	(a)		-21,289	(g)		4,239
	Total property and equipment			836,860								8,826
	Less accumulated depreciation and depletion			-642,172		607,603	(a)		34,569	(g)		—
	Property and equipment, net			194,688								8,826
	Long-term assets:
	Investments in unconsolidated affiliates			3,629		105,344	(a)		-3,629	(g)		105,344
	Other long-term assets			307					-253	(g)		54
	Total long-term assets			3,936								105,398
	Total assets		$	210,389							$	142,911
	LIABILITIES AND EQUITY
	Current liabilities
	Liabilities not subject to compromise
	Debtor in possession financing		$	56,535		-56,535	(c)				$	—
	Accounts payable and other accrued liabilities			4,897								4,897
	Other accrued liabilities			9,224		-2,685	(b)					2,640
						-1,500	(c)
						-3,845	(d)
						1,446	(e)
	Accrued reorganization and trustee expense			70,656								7,537
	Liabilities subject to compromise
	3 3/4% Senior notes			115,000		-115,000	(b)					—
	7% Senior convertible notes			150,000		-150,000	(b)					—
	Accounts payable and other accrued liabilities			17,203		-2,560	(a)		-1,981	(g)		12,336
						-3,526	(d)		3,200	(g)
	Total current liabilities			352,859								19,873
	Long-term liabilities
	Liabilities not subject to compromise
	Long – term debt			—		6,335	(c)					6,335
	Derivative liabilities			—		6,665	(c)					6,665
	Asset retirement obligations			4,414		-3,938	(a)					476
Total liabilities			357,273								33,349
Stockholders’ equity
Common stock			288		1,457	(b)		-288	(f)		1,477
					20	(d)
Additional paid-in capital			1,643,285		100,084	(b)		288	(f)		108,085
					1,318	(d)		-1,636,890	(h)
Retained earnings (accumulated deficit)			-1,790,457		166,144	(b)		-14,765	(g)		—
					2,188	(d)		1,636,890	(h)
Total stockholders’ equity (deficit)			-146,884								109,562
Total liabilities and equity (deficit)		$	210,389							$	142,911
Notes to Plan of Reorganization and Fresh Start Accounting Adjustments
	(a)	Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.
	(b)	Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(c)	Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.
	(d)	Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(e)	Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).
	(f)	Reflects the cancellation of Predecessor common stock.
	(g)	Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(h)	Reflects the elimination of Predecessor’s accumulated deficit.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	Note 20 - Subsequent Events
	On the January 23, 2014 and in connection with the consummation of the Reverse Stock Split as described in Note 1-Overview, we and certain of our subsidiaries entered into an Eleventh Amendment to our Loan Agreement pursuant to which the Lender consented to Fractional Share Cash Payments.
	As a result of the Reverse Stock Split, every ten pre-split shares of Common Stock issued prior to January 29, 2014, the effective date of the reverse stock split for trading purposes, were exchanged for one post-split share of Common Stock, with fractional shares paid in cash at an amount equal to the product obtained by multiplying (a) the closing price of the Common Stock as reported on the OTCQB Marketplace on January 23, 2014, by (b) the fraction of one share owned by the stockholder. Further, the number of shares of Common Stock issued and outstanding was reduced from approximately 301,141,520 on January 23, 2014 to approximately 30,114,352. The number of authorized shares of Common Stock will remain at 500,000,000 and the par value of the Common Stock will remain at $0.01 per share. 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 outstanding prior to the 1:10 reverse stock split have been adjusted to reflect this stock split on a retroactive basis, unless otherwise noted. No adjustments have been made to the share or per share amounts of our Predecessor.

Disclosures_About_Capitalized_

Disclosures About Capitalized Costs, Costs Incurred	12 Months Ended
	Dec. 31, 2013
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Capitalized Costs Relating To Oil And Gas Producing Activities Disclosure [Text Block]	'
	Note 21- Disclosures About Capitalized Costs, Costs Incurred (Unaudited)
	Capitalized costs related to oil and gas activities are as follows (in thousands):
			Successor				Predecessor
			December 31,		December 31,		August 31,
			2013		2012		2012
	Company:
	Unproved properties		$	—	$	—	$	84
	Proved properties			4,949		4,804		759,755
				4,949		4,804		759,839
	Accumulated depreciation and depletion			-1,868		-337		-642,172
			$	3,081	$	4,467	$	117,667
	Company’s Share of Piceance Energy:
	Unproved properties		$	15,763	$	16,180
	Proved properties			168,378		134,638
				184,141		150,818
	Accumulated depreciation and depletion			-38,452		-2,808
			$	145,689	$	148,010
	-1	The capitalized cost amounts presented are as of August 31, 2012 for the Predecessor and exclude adjustments resulting from the plan or reorganization and fresh-start reporting (see Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan).
	Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):
			Successor				Predecessor
			Year Ended		Period from		Period from
			December 31,		September 1		January 1
			2013		through		through
					December 31,		August 31,
					2012		2012
	Company:
	Development costs incurred on proved undeveloped		$	—	$	—	$	1,613
	reserves
	Development costs—other			142		—		—
	Total		$	142	$	—	$	1,613
	Company’s Share of Piceance Energy:
	Unproved properties acquisition costs		$	—	$	206
	Proved properties acquisition costs (1)			—		32,519
	Development costs—other			6,380		291
	Total		$	6,380	$	33,016
	_______________________________________________________
	-1	Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.
	At December 31, 2011, the company had $8,770 of suspended exploratory well cost subject to evaluation. Upon the emergency from Bankruptcy on August 31, 2012 all capitalized oil and natural gas property costs, including suspended exploratory well cost, were transferred to Piceance in exchange for cash and a 33.34% equity interest in Piceance. For the period from September 1, 2012 through December 31, 2012 and for the year ended December 31, 2013 neither the company 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 December 31, 2012 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:
			Successor				Predecessor
			Year Ended		September 1		January 1
			December 31,		through		through
			2013		December 31,		August 31,
					2012		2012
	Company:
	Revenue:
	Oil and gas revenues		$	7,739	$	2,144	$	23,079
	Expenses:
	Production costs			5,696		1,688		16,980
	Depletion and amortization			1,593		370		16,041
	Exploration			—		—		2
	Abandoned and impaired properties			—		—		151,347
	Results of operations of oil and gas producing activities		$	450	$	86	$	-161,291
	Company’s share of Piceance Energy:
	Revenue:
	Oil and gas revenues		$	20,364	$	6,464
	Expenses:
	Production costs			9,885		3,033
	Depletion and amortization			8,855		2,808
	Results of operations of oil and gas producing activities		$	1,624	$	623
	Total Company and Piceance Energy income from		$	2,074	$	709
	operations of oil and gas producing activities

Information_Regarding_Proved_O

Information Regarding Proved Oil and Gas Reserves	12 Months Ended
	Dec. 31, 2013
Oil and Gas Property [Abstract]	'
Oil And Gas Properties [Text Block]	'
	Note 22 - 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 the company’s oil and natural gas reserves and present values as of December 31, 2013 and 2012,  and August 31, 2012 were prepared by Netherland, Sewell & Associates, Inc., independent reserve engineers.
	A summary of changes in estimated quantities of proved reserves for the year ended December 31, 2013 and for respective periods in 2012 is as follows:
			Gas		Oil		NGLS	Total
			(MMcf)		(MBbl)		(MBb1)	(MMcfe) (5)
	Company:
	Estimated Proved Reserves: Balance at January 1, 2012		87,209		494		—	90,173
	(Predecessor) (1)
	Revisions of quantity estimate		—		85		—	512
	Sale/disposition of properties (2)		-82,357		-235		—	-83,770
	Production		-4,852		-67		—	-5,256
	Estimated Proved Reserves: Balance at August 31, 2012		—		277		—	1,659
	(Successor)
	Revisions of quantity estimate		456		31		—	643
	Production		-10		-22		—	-139
	Estimated Proved Reserves: Balance at December 31, 2012		446		286		—	2,163
	(Successor)
	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		662		236		—	2,078
	(Successor)
	Company’s Share of Piceance Energy:
	Estimated Proved Reserves: Balance at September 1, 2012		—		—		—	—
	Transfer from investees (3)		83,915		560		4,228	112,639
	Revisions of quantity estimate		8,053		41		387	10,621
	Extensions and discoveries		32,073		236		1,778	44,151
	Production		-1,391		-6		-48	-1,711
	Estimated Proved Reserves: Balance at December 31, 2012		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		186,597		584		7,401	234,509
	Total Estimated Proved Reserves: Balance at December 31, 2013		187,259		820		7,401	236,587
	Proved developed reserves
	31-Dec-12		158		286		—	1,875
	December 31, 2012—Company Share of Piceance Energy		48,680		237		2,253	63,617
	Total December 31, 2012		48,838		523		2,253	65,492
	Proved undeveloped reserves
	31-Dec-12		288		—		—	288
	December 31, 2012—Company Share of Piceance Energy		73,970		594		4,092	102,083
	Total December 31, 2012		74,258		594		4,092	102,371
	Proved developed reserves
	31-Dec-13		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
	31-Dec-13		—		—		—	—
	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
			CIG per Mbtu			WTI per Bbl
	Base pricing, before adjustments for contractual
	differentials: (4)
	31-Aug-12		$	2.75		$	90.85
	31-Dec-12		$	2.56		$	91.21
	December 31, 2012 – Piceance		$	2.56		$	91.21
	31-Dec-13		$	3.53		$	96.91
	December 31, 2013 – Piceance		$	3.53		$	96.91
	_________________________________________________________
	-1	At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.
	-2	On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).
	-3	On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).
(4)	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.
(5)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
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.
		Successor						Predecessor
		December 31,						August 31,
		2013			2012			2012
		(in thousands)						(in thousands)
Company:
Future net cash flows		$	26,861		$	30,444		$	28,691
Future costs:
Production			21,999			20,596			19,973
Development and abandonment			319			319			319
Income taxes1			—			—			—
Future net cash flows			4,543			9,529			8,399
10% discount factor			-1,006			-1,519			-1,176
Standardized measure of discounted future net cash		$	3,537		$	8,010		$	7,223
flows
Company’s Share of Piceance Energy:
Future net cash flows		$	984,205		$	568,706
Future costs:
Production			430,506			199,277
Development and abandonment			234,905			154,054
Income taxes1			—			—
Future net cash flows			318,794			215,375
10% discount factor			-229,469			-143,416
Standardized measure of discounted future net		$	89,325		$	71,959
cash flows
Total Company and Company share of equity		$	92,862		$	79,969
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 the company does 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 year ended December 31, 2013 and for the respective periods during 2012 are as follows (in thousands):
		Successor
		December 31,			Company Share		Total
					of Piceance
					Energy
					December 31,
		2013			2013		2013
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
		Successor								Predecessor
		Period from			Company Share		Total			January 1,
		September 1,			of Piceance					through
		through			Energy					August 31,
		December 31,			September 1,
					through
					December 31,
		2012			2012		2012			2012
Beginning of the year										$	129,695
Beginning of the period		$	7,223		$	—	$	7,223			—
Transfer from investees			—			55,253		55,253			—
Sales of oil and gas production during the period,			-456			-3,639		-4,095			-5,954
net of production costs
Net change in prices and production costs			-667			-139		-806			378
Changes in estimated future development costs			—			5		5			—
Extensions, discoveries and improved recovery			763			569		1,332			—
Revisions of previous quantity estimates, estimated			648			13,708		14,356			-7,439
timing of development and other
Sales/disposition of reserves in place			—			—		—			-118,104
Other			258			4,360		4,618			—
Accretion of discount			241			1,842		2,083			8,647
End of period		$	8,010		$	71,959	$	79,969		$	7,223

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Organization Consolidation And Presentation Of Financial Statements Disclosure, Policy [Policy Text Block]	'
	Principles of Consolidation and Basis of Presentation
	The consolidated financial statements include the accounts of Par Petroleum Corporation and its consolidated subsidiaries. All inter-company balances and transactions have been eliminated in consolidation. We do not have any off-balance sheet financing arrangements (other than operating leases) or any unconsolidated special purpose entities.
	Our wholly-owned subsidiaries include Hawaii Pacific Energy, LLC (“Hawaii Pacific Energy”)  which acquired all of the outstanding membership interests of HIE on September 25, 2013 (see Note 4– Acquisitions and Dispositions), Par Piceance Energy, LLC, which owns our investment in Piceance Energy (see Note 3 – Investment in Piceance Energy) and Texadian, which we acquired on December 31, 2012 (see Note 4 – Acquisitions and Dispositions). Certain amounts from prior periods have been reclassified to conform to the current presentation.
Use Of Estimates, Policy [Policy Text Block]	'
	Use of Estimates
	The preparation of financial statements in conformity with U.S. GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include fair value of assets and liabilities recorded in connection with the application of fresh-start reporting or acquisitions, natural gas and oil reserves, depletion and impairment of natural gas and oil properties, income taxes and the valuation allowances related to deferred tax assets, bad debts,  derivatives, asset retirement obligations, contingencies and litigation accruals. Actual results could differ from these estimates.
Reorganization, Policy [Policy Text Block]	'
	Fresh-Start Reporting and the Effects of the Plan
	Certain companies qualify for fresh-start reporting in connection with their emergence from bankruptcy. Fresh-start reporting is appropriate on the emergence from bankruptcy if the reorganization value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims, and if the holders of existing voting shares immediately before confirmation receive less than 50 percent of the voting shares of the emerging entity. We met these requirements on August 31, 2012 and adopted fresh-start reporting resulting in the creation of a new reporting entity.
	The bankruptcy court issued a confirmation order approving our plan of reorganization (the “Plan”) on August 15, 2012 and we met the requirements of the Plan on August 31, 2012. Under the requirements of fresh-start reporting, we have adjusted our assets and liabilities to their estimated fair values as of August 31, 2012 in conformity with the guidance for the acquisition method of accounting for business combinations. The net effect of all fresh-start adjustments, including the effects of implementing the plan, resulted in a gain of approximately $154 million, which is reflected in the 2012 Predecessor Period. The application of the fresh-start reporting provisions created a new reporting entity having no retained earnings nor accumulated deficit.
	Our fresh-start adjustments consisted primarily of (i) estimates of the fair value of our minority interest in Piceance Energy and (ii) of the fair value of our remaining existing fixed assets and liabilities. A description of the adjustments and amounts is provided in Note 19 – Reorganization under Chapter 11, Fresh-Start Reporting and the Effects of the Plan.
Cash And Cash Equivalents, Policy [Policy Text Block]	'
	Cash and Cash Equivalents
	Cash and cash equivalents consist of demand deposits and funds invested in highly liquid short-term investments with original maturities of three months or less.
Cash And Cash Equivalents Restricted Cash And Cash Equivalents, Policy [Policy Text Block]	'
	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.
Receivables Trade And Other Accounts Receivable Allowance For Doubtful Accounts, Policy [Policy Text Block]	'
	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 collectability and establish or adjust our allowance as necessary using the specific identification method.  As of December 31, 2013 and 2012, we had no significant allowance for doubtful accounts.
Refined Product Exchanges Policy [Policy Text Block]	'
	Refined Product Exchanges
	We enter into exchange and supply contracts whereby we agree to deliver a particular quantity and quality of refined products at a specified location and date to a particular counterparty and to receive from the same counterparty a particular quantity and quality of refined products at a specified location on the same or another specified date. The exchange receipts and deliveries are nonmonetary transactions with the exception of associated grade or location differentials that are settled in cash each month. These transactions are not recorded as revenue because they involve the exchange of refined product inventories held for sale in the ordinary course of business to facilitate sales to customers. The exchange transactions are recognized at the carrying amount of the inventory transferred plus or minus any cash settlement due to grade or location differentials.
Inventory, Policy [Policy Text Block]	'
	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.
	HIE 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 HIE’s storage tanks governed by a storage agreement. Legal title to the crude oil passes to HIE at the tank outlet. After processing, Barclays takes title to the refined products when the refined products enter the tanks which are then stored in HIE’s storage tanks until sold to HIE’s 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.
Investments In Unconsolidated Entities, Policy [Policy Text Block]	'
	Investment in Unconsolidated Affiliate
	We account for our investment in unconsolidated affiliate using the equity method as we have the ability to exert significant influence, but do not control the operating and financial policies. Our proportionate share of net income (loss) of these entities is recorded as income (loss) from unconsolidated affiliates in the consolidated statements of operations. Investment in unconsolidated affiliate is reviewed for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable.
	At December 31, 2013 and 2012, our investment in unconsolidated affiliates consisted of our ownership interest in Piceance Energy (see Note 3 - Investment in Piceance Energy.)
Property Plant And Equipment, Policy [Policy Text Block]	'
	Property, Plant and Equipment (Other than Natural Gas and Oil Properties)
	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
	Logistic	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.
Oil and Gas Properties Policy [Policy Text Block]	'
	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 with significant acquisition costs 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 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.
Goodwill And Intangible Assets, Policy [Policy Text Block]	'
	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. 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 or when circumstances indicate that impairment may exist. 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.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	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 depreciation, depletion and amortization expense 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 statements of consolidated operations. We estimate settlement dates by considering our past practice, industry practice, 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.
Environmental Costs, Policy [Policy Text Block]	'
	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, Policy [Policy Text Block]	'
	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 it will not net settle.  Should we not designate a contract as a normal purchase or normal sale then 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, 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. As of December 31, 2012, we did not elect this exemption for our open contracts which were settled in the first quarter of 2013.
	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.
	As a part of the Plan of Reorganization, we issued warrants (see Note 10 - Debt) that are not considered to be indexed to our equity. Accordingly, these warrants are accounted for as liabilities. In addition, our former delayed draw term loan facility contained certain puts that were required to be accounted for as embedded derivatives. The warrant liabilities and embedded derivatives are accounted for at fair value with changes in fair value reported in change in value of common stock warrants and loss on derivative instruments, net respectively, on our consolidated statement of operations.
Settlements, Policy [Policy Text Block]	'
	Accrued Settlement Claims
	We accrued an estimate of the settlement liability relating to claims resulting from our bankruptcy (See Note 13 - Commitments and Contingencies). Professional fees relating to the settlement of bankruptcy claims are charged to earnings in the period incurred.
Income Tax, Policy [Policy Text Block]	'
	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 2010, 2011, and 2012. 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.
Share Based Compensation Option And Incentive Plans, Policy [Policy Text Block]	'
	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, Policy [Policy Text Block]	'
	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. These transactions include sale and purchase transactions entered into with the same counterparty that are deemed to be in contemplation with one another.
	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, 2013 and 2012, 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 rail cars. 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.
	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 statements of consolidated operations, while the related transportation costs are included in cost of sales. Federal excise and state motor fuel taxes, which are remitted to governmental agencies through our refining segment and collected from customers in our retail segment, are included in both revenues and cost of sales in our statements of consolidated operations.
Earnings Per Share, Policy [Policy Text Block]	'
	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 (see Note 16 - Loss Per Share). 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 And Translations, Policy [Policy Text Block]	'
	Foreign Currency Transactions
	We may, on occasion, enter into transactions denominated in currencies other than our functional currency (“U.S. $”). 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) in the accompanying consolidated statement of operations in the period in which the currency exchange rates change.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Property Plant And Equipment Estimated Useful Life [Table Text Block]	'
	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
	Logistic	3 to 30
	Retail	14 to 18
	Corporate	3 to 7
	Software	3

Investment_in_Piceance_Energy_

Investment in Piceance Energy (Tables)	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments [Table Text Block]	'
	The change in our equity investment in Piceance Energy is as follows (in thousands):
				September 1
		Year Ended		through
		December 31, 2013		December 31, 2012
	Beginning balance	$	104,434	$	105,344
	Loss from unconsolidated affiliates		-3,516		-1,325
	Accretion of basis difference		575		—
	Capitalized drilling costs obligation paid		303		415
	Ending balance	$	101,796	$	104,434
Equity Method Investees Financial Information [Table Text Block]	'
	Summarized financial information for Piceance Energy is as follows (in thousands):
		December 31, 2013		December 31, 2012
	Assets
	Current assets	$	5,901	$	6,275
	Non-current assets		454,402		460,991
	Current liabilities		-13,040		-11,826
	Non-current liabilities		-96,738		-94,369
		Year Ended		September 1 through
		December 31, 2013		December 31, 2012
		100%		100%
	Oil, natural gas and natural gas liquids	$	61,091	$	19,391
	revenues
	Loss from operations		-6,765		-2,095
	Net loss		-10,546		-3,975

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business Acquisition, Pro Forma Information [Table Text Block]	'
	The unaudited pro forma financial information presented below assumes that the Texadian and HIE acquisitions occurred as of January 1, 2012 and combines the Predecessor and Successor periods to include a full year of results for the year ended December 31, 2012.  We did not include any adjustments related to the application of fresh-start reporting for the year ended December 31, 2012.
		2013		2012
	(in millions)
	Revenues	$	2,986.80	$	3,811.10
	Net loss	$	-113.6	$	-12
Texadian Energy Inc [Member]	'
Business Combinations [Abstract]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	A summary of the fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Intangible assets	$	8,809
	Goodwill		6,990
	Net non cash-working capital		3,097
	Deferred tax liabilities		-2,757
	Total, net of cash acquired	$	16,139
Hawaii Independent Energy LLC [Member]	'
Business Combinations [Abstract]	'
Schedule Of Purchase Price Allocation Preliminary Estimated Fair Value Of The Assets Acquired And Liabilities Assumed [Table Text Block]	'
	A summary of the preliminary estimated fair value of the assets acquired and liabilities assumed is as follows (in thousands):
	Inventory	$	418,750
	Trade accounts receivable		59,485
	Prepaids and other current assets		1,978
	Property, plant and equipment		58,782
	Land		39,800
	Goodwill		13,613
	Intangible assets		4,689
	Accounts payable and other current liabilities		-18,154
	Contingent consideration liability		-11,980
	Other noncurrent liabilities		-6,384
	Total	$	560,579

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	Major classes of property, plant and equipment consist of the following (in thousands):
		December 31,
		2013		2012
	Land	$	39,800	$	—
	Buildings and equipment		65,878		—
	Other		1,945		1,415
	Property, plant and equipment		107,623		1,415
	Proved oil and gas properties		4,949		4,804
	Less: accumulated depreciation, depletion		-3,968		-373
	and amortization
		$	108,604	$	5,846

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation [Table Text Block]	'
	The following is a reconciliation of our AROs (in thousands):
		Successor				Predecessor
				September 1		January 1
		Year Ended		through		through
		December 31, 2013		December 31, 2012		August 31, 2012
	Asset retirement obligation –	$	512	$	476	$	3,799
	beginning of period
	Obligation acquired		2,601		—		—
	Accretion expense		59		36		178
	Change in estimate		—		—		437
	Settlement upon transfer to		—		—		-3,938
	Piceance Energy
	Asset retirement obligation –	$	3,172	$	512	$	476
	end of period

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Schedule of Inventory, Current [Table Text Block]	'
	The following is a summary of our inventory (in thousands):
									December 31,
		December 31, 2013							2012
					Supply and
			Titled		Exchange
			Inventory		Agreements		Total		Titled Inventory
	Crude oil and feedstocks	$	—	$	146,158	$	146,158	$	10,466
	Refined products and blend stock		67,532		161,554		229,086		—
	Spare parts, materials and supplies, and merchandise		13,831		—		13,831		—
		$	81,363	$	307,712	$	389,075	$	10,466

Intangible_assets_Tables

Intangible assets (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Our intangible assets consist of the following (in thousands):
		December 31,
		2013		2012
	Amortized intangible assets:
	Gross carrying amount:
	Supplier relationships	$	3,360	$	3,360
	Rail car leases		3,249		3,249
	Historical shipper status		2,200		2,200
	Trade names and trademarks		4,689		—
	Subtotal		13,498		8,809
	Accumulated amortization
	Supplier relationships		-258		—
	Rail car leases		-650		—
	Historical shipper status		-1,100		—
	Trade name and trademarks		-320		—
	Subtotal		-2,328		—
	Net:
	Supplier relationships		3,102		3,360
	Rail car leases		2,599		3,249
	Historical shipper status		1,100		2,200
	Trade name and trademarks		4,369		—
	Total amortized intangible assets, net	$	11,170	$	8,809
Finite-lived Intangible Assets Amortization Expense [Table Text Block]	'
	Expected future amortization expense for each of the next five years and thereafter is as follows (in thousands):
	Year Ended	Amount
	2014	$	3,571
	2015		2,471
	2016		2,151
	2017		908
	2018		258
	Thereafter		1,811
		$	11,170
Schedule of Goodwill [Table Text Block]	'
	During the year ended December 31, 2013 the changes in the carrying amount of goodwill for the year ended December 31, 2013 were as follows (in thousands):
	Balance at beginning of period	$	7,756
	Additions		13,613
	Texadian purchase price adjustments		-766
	Balance at end of period	$	20,603

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Debt [Table Text Block]	'
	Our debt is as follows (in thousands):
		December 31,
		2013			2012
	Tranche B Loan	$	19,480		$	35,000
	Delayed Draw Term Loan Agreement		—			13,465
	ABL Facility		51,800			—
	Retail Credit Agreement		26,000			—
	Less: unamortized debt discount – warrants		—			-6,014
	Less: unamortized debt discount – embedded derivative		—			-60
	Total debt, net of unamortized debt discount		97,280			42,391
	Less: current maturities		-3,250			-35,000
	Long-term debt, net of current maturities and unamortized discount	$	94,030		$	7,391
Contractual Obligation, Fiscal Year Maturity Schedule [Table Text Block]	'
	Annual maturities of our long-term debt are due during the following years (in thousands):
	Year		Amount Due
	2014	$	3,250
	2015		2,600
	2016		22,080
	2017		54,400
	2018		2,600
	Thereafter		12,350
		$	97,280
Schedule of Maximum Leverage Ratio [Table Text Block]	'
	Such covenants require HIE Retail to maintain a maximum Leverage Ratio (as defined in the Retail Credit Agreement) as follows:
	Period (during and as of the last day of)	Maximum Leverage Ratio
	2013 Fiscal Year	5.75 to 1.00
	2014 Fiscal Year	5.50 to 1.00
	2015 Fiscal Year	5.25 to 1.00
	2016 Fiscal Year	5.00 to 1.00
	2017 Fiscal Year, and at all times thereafter	4.75 to 1.00
Schedule Of Applicable Margin For Debt Instrument [Table Text Block]	'
	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	%		0	%
	2	4.00x-5.00x		2.25	%		0.25	%
	3	>5.00x		2.5	%		0.5	%
Schedule Of Revolver Applicable Margin for Debt Instrument [Table Text Block]	'
	The 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	%	0	%
	3	>5.00x		0.5	%	2.25	%	0.25	%

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Nonrecurring [Table Text Block]	'
	The estimates of fair value of the net assets were reflected in the Successor’s consolidated balance sheet as of August 31, 2012.
			Fair Value at			Fair Value
			August 31, 2012			Technique
			(in thousands)
	Oil and gas properties
	Proved		$	4,587		(a)(b)
	Other assets
	Frac tanks			1,400		(c)
	Compressors			2,800		(c)
	Miscellaneous			39		(d)
	Investment in Piceance Energy			105,344		(e)
	(a)	Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a Level 3 fair value measurement.
	(b)	The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a Level 2 fair value measurement.
	(c)	The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be Level 2 fair value measurements.
	(d)	Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a Level 3 fair value measurement.
	(e)	The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reserves’ future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	'
	Significant inputs used in the Monte Carlo Simulation Analysis include:
			December 31,
			2013			2012
	Stock price		$	22.3		$	12
	Initial exercise price		$	0.1		$	0.1
	Term (years)			8.67			9.67
	Risk-free rate			2.78	%		1.68	%
	Expected volatility			52.9	%		75	%
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	'
	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their placement with our consolidated balance sheet consist of the following (in thousands):
			Location on
			Consolidated			Fair Value at		Fair Value at
			Balance Sheet		December 31, 2013			December 31, 2012
	Commodities – physical forward		Prepaid and other current assets		$	—		$	-307
	contracts
	Commodities – exchange traded		Prepaid and other current assets			—			542
	futures
	Warrant derivatives		Derivative liabilities			-17,336			-10,900
	Contingent consideration liability		Contingent consideration liability			-11,980			—
	Debt repayment derivative		Derivative liabilities			—			-45
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]	'
	The following table summarizes the pre-tax effect resulting from changes in fair value of derivative instruments charged directly to earnings (in thousands):
								September 1
								through
					December 31, 2013			December 31, 2012
					Gain (loss)			Gain (loss)
			Income Statement		recognized in			recognized in
			Classification		income			income
	Derivatives not designated as
	hedges:
	Warrants		Change in value		$	-10,114		$	-4,280
			of warrants
	Debt repayment derivative		Interest expense and			45			—
			financing costs, net
	Commodities - exchange traded		Gain on derivative			104			—
	futures		instruments, net
	Commodities - physical forward		Gain on derivative			306			—
	contracts		instruments, net
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	'
	Our assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012 and their level within the fair value hierarchy is as follows (in thousands):
			December 31, 2013
			Fair Value			Level 1			Level 2		Level 3
	Liabilities
	Warrants derivative		$	-17,336		$	—		$	—	$	-17,336
	Contingent consideration liability			-11,980			—			—		-11,980
			$	-29,316		$	—		$	—	$	-29,316
			December 31, 2012
			Fair Value			Level 1			Level 2		Level 3
	Assets
	Commodities – exchange traded futures		$	542		$	542		$	—	$	—
	Liabilities
	Warrants derivative		$	-10,900		$	—		$	—	$	-10,900
	Debt prepayment derivative			-45			—			—		-45
	Commodities – physical forward contracts			-307			—			-307		—
			$	-11,252		$	—		$	-307	$	-10,945
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	'
	A rollforward of Level 3 derivative instruments measured at fair value on a recurring basis is as follows (in thousands):
	Description		2013			2012
	Balance, at beginning of period		$	-10,945		$	-6,665
	Settlements			3,723			—
	Acquired			-11,980			—
	Total unrealized losses included in earnings			-10,114			-4,280
	Transfers			—			—
	Balance, at end of period		$	-29,316		$	-10,945
Fair Value and Carrying Value Liabilities Measured On Recurring Basis [Table Text Block]	'
	The carrying value and fair value of long-term debt and other financial instruments as of December 31, 2013 and 2012 is as follows (in thousands):
			December 31, 2013
			Carrying Value			Fair Value(1)
	Tranche B		$	19,480		$	18,800
	ABL Facility			51,800			51,800
	HIE Retail Credit Agreement			26,000			26,000
	Warrants			17,336			17,336
	Contingent consideration liability			11,980			11,980
			December 31, 2012
			Carrying Value			Fair Value(1)
	Long-term debt		$	7,391		$	10,900
	Warrants			10,900			10,900
	Debt repayment derivative			45			45
	_________________________________________________________
	(1)                   The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.
HIE Retail, LLC [Member]	'
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Table Text Block]	'
	Purchase Price Allocation of HIE – The preliminary 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 using valuation techniques described in notes (a) through (g) described below.
			Fair Value at			Fair Value
			September 25, 2013			Technique
			(in thousands)
	Net working capital		$	462,059		(a)
	Property, plant and equipment			58,782		(b)
	Land			39,800		(c)
	Trade names and trade marks			4,689		(d)
	Goodwill			13,613		(e)
	Contingent consideration liability			-11,980		(f)
	Other noncurrent liabilities			-6,384		(g)
			$	560,579
		(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
		(b)	The estimated 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 estimated 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 estimated 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.
		(e)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
		(f)	The estimated 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 noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.
Texadian Energy Inc [Member]	'
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Table Text Block]	'
	Purchase Price Allocation of Texadian – The fair values of the assets acquired and liabilities assumed as a result of the Texadian acquisition were estimated as of the date of the acquisition using valuation techniques described in notes (a) through (f) described below.
			Fair Value at			Fair Value
			December 31, 2012			Technique
			(in thousands)
	Net non-cash working capital		$	3,631		(a)
	Supplier relationship			3,360		(b)
	Historical shipper status			2,200		(c)
	Railcar leases			3,249		(d)
	Goodwill			7,756		(e)
	Deferred tax liabilities			-2,757		(f)
			$	17,439
	(a)	Current assets acquired and liabilities assumed were recorded at their net realizable value.
	(b)	The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.
	(c)	The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a Level 3 fair value measurement.
	(d)	The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a Level 3 fair value measurement.
	(e)	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
	(f)	A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule Of Reorganization Distributions To Satisfy Allowed Claims [Table Text Block]	'
	A summary of claims is as follows (in thousands, except number of filed claims):
		Emergence-Date					From Emergence-Date through December 31, 2012
		August 31, 2012
																Remaining Filed
		Filed Claims					Settled Claims									Claims
												Consideration
		Count			Amount		Count		Amount			Cash		Stock		Count	Amount
	U.S. Government Claims		3		$	22,364	—		$	—		$	—	—		3	$	22,364
	Former Employee Claims		32			16,380	13			3,685			230	20		19		12,695
	Macquarie Capital (USA) Inc.		1			8,672	—			—			—	—		1		8,672
	Swann and BuzzardCreek		1			3,200	—			—			—	—		1		3,200
	RoyaltyTrust
	Other Various Claims*		75			23,114	12			2,915			29	—		63		20,199
	Total		112		$	73,730	25		$	6,600		$	259	20		87	$	67,130
			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 Rental Payments for Operating Leases [Table Text Block]	'
	Minimum annual lease payments including interest, for capital leases are as follows (in thousands):
	2014		$	382
	2015			382
	2016			382
	2017			382
	2018			420
	Thereafter			420
	Total minimum lease payments			2,368
	Less amount representing interest			634
	Total minimum rental payments		$	1,734
Schedule of Future Minimum Lease Payments for Capital Leases [Table Text Block]	'
	Minimum annual lease payments extending to 2027, for operating leases to which we are legally obligated and having initial or remaining noncancellable lease terms in excess of one year are as follows (in thousands):
	2014		$	22,724
	2015			13,277
	2016			12,362
	2017			10,375
	2018			9,244
	Thereafter			25,614
	Total minimum rental payments		$	93,596

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Schedule Of Equity Incentive Plan Disclosures [Table Text Block]	'
	For the year ended December 31, 2013, the following activity occurred under our Incentive Plan (in thousands, except per share amounts):
		Shares	Weighted-
			Average
			Grant Date Fair
			Value
	Non vested balance, beginning of period	219	$	12
	Granted	356		18.32
	Vested	-51		12
	Forfeited	—		—
	Non vested balance, end of period	524	$	16.29
	Available for grant	1,025
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	'
	A summary of the stock option activity under the Predecessor’s various plans and related information for the period from January 1 through August 31, 2012 follows:
		Period from January 1
		through August 31, 2012
		Options	Weighted-Average		Weighted-Average	Aggregate
			Exercise		Remaining  Contractual	Intrinsic
			Price		Term	Value
	Outstanding-beginning of year	150,300	$	75
	Granted	—		—
	Exercised	—		—
	Expired / canceled	-150,300		-75
	Outstanding-end of year	—	$	—	—	$	—
	Exercisable-end of year	—	$	—	—	$	—
Schedule of Nonvested Share Activity [Table Text Block]	'
	A summary of the restricted stock (nonvested stock) activity under the Predecessor’s plan and related information for the period from January 1 through August 31, 2012 follows (in thousands, except share and per share amounts):
		Period from January 1
		through August 31, 2012
		Nonvested	Weighted-Average		Weighted-Average	Aggregate
		Stock	Grant-Date Fair		Remaining Contractual	Intrinsic
			Value		Term	Value
	Nonvested-beginning of year	558,301	$	7.45
	Granted	—		—
	Vested	—		—
	Expired / canceled	-558,301		-7.45
	Nonvested-end of year	—	$	—	—	$	—

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	Income tax expense (benefit) consisted of the following:
		Successor						Predecessor
					Period from			Period from
					September 1			January 1
		Year Ended			through			through
		December 31,			December 31,			August 31,
		2013				2012			2012
	Current:
	U.S.—Federal	$	—		$	—		$	—
	U.S.—State		-179			—			—
	Deferred:
	U.S.—Federal		-14			-2,757			—
	U.S.—State		193			—			—
	Total	$	—		$	-2,757		$	—
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	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:
		Successor						Predecessor
					Period from			Period from
					September 1			January 1
		Year Ended			through			through
		December 31,			December 31,			August 31,
		2013			2012			2012
	Federal statutory rate		-35	%		-35	%		-35	%
	State income taxes, net of federal benefit		0.1	%		—			—
	Change in valuation allowance		21.7	%		-2	%		-33
	Professional fees related to bankruptcy reorganization		—			8	%		17	%
	Revenue from Wapiti Trust settlement		—			5	%		—
	Cancellation of debt tax attribute reduction		—			—			51	%
	Permanent Items		4.1	%
	Provision to return adjustments		9.1	%		—			—
	Actual income tax rate		—	%		-24	%		—	%
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	Deferred tax assets (liabilities) are comprised of the following at December 31, 2013 and 2012 (in thousands):
		2013				2012
	Deferred tax assets:
	Net operating loss	$	540,867		$	450,195
	Capital loss carry forwards		26,141			26,141
	Property and equipment		34,683			23,045
	Investment in Piceance Energy		32,138			45,172
	Derivative instruments		—			1,498
	Accrued bonuses		—			—
	Trust liabilitiy		1,327			—
	Other		1,183			1,506
	Total deferred tax assets		636,339			547,557
	Valuation allowance		-633,954			-544,442
	Net deferred tax assets	$	2,385		$	3,115
	Deferred tax liabilities:
	Property and equipment	$	5		$	—
	Texadian Energy intangibles		2,380			3,083
	Prepaid insurance, marketable securities and other		—			32
	State liabilities		216			—
	Total deferred tax liabilities	$	2,601		$	3,115
	Total deferred tax liability, net	$	-216		$	—

Loss_Per_Share_Tables

Loss Per Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Schedule Of Computation Of Basic And Diluted Earnings Per Share [Table Text Block]	'
	The following table sets forth the computation of basic and diluted loss per share (in thousands, except per share amounts):
			Successor						Predecessor
						September 1			January 1
			Year Ended			through			through
			December 31,			December 31,			August 31,
			2013			2012			2012
	Net loss attributable to common stockholders		$	-70,621		$	-8,839		$	-45,437
	Basic weighted-average common shares			19,740			15,734			28,841
	outstanding
	Add: dilutive effects of stock options and			—			—			—
	unvested stock grants (1)
	Diluted weighted-average common stock outstanding			19,740			15,734			28,841
	Basic loss per common share attributable to
	common stockholders:
	Net loss (1)		$	-3.57		$	-0.56		$	-1.57
	Diluted loss per common share attributable to
	common stockholders:
	Net loss (1)		$	-3.57		$	-0.56		$	-1.57
	________________________________________________________
		-1	Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	'
	Weighted average potentially dilutive securities excluded from the calculation of diluted shares outstanding include the following (in thousands):
			Successor					Predecessor
					Period from			Period from
					September 1			January 1
			Year Ended		through			through
			December 31,		December 31,			August 31,
			2013		2012			2012
	Stock issuable upon conversion of convertible notes		—		—			379
	Stock options		—		—			150
	Non-vested restricted stock		523		—			558
	Total potentially dilutive securities		523		—			1,087

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	Summarized financial information concerning reportable segments consists of the following (in thousands):
	For the year ended December 31, 2013	Refining,		Natural Gas		Commodity		Corporate and		Total
		Distribution		and Oil		Marketing and		Other
		and Marketing		Operations		Logistics
	Sales and operating revenues	$	778,126	$	7,739	$	100,149	$	—	$	886,014
	Depreciation, depletion, amortization		2,267		1,686		2,009		20		5,982
	and accretion
	Operating income (loss)		-19,318		246		9,126		-29,367		-39,313
	Loss from unconsolidated affiliate										-2,941
	Interest expense and financing costs, net										-19,471
	Other income (expense)										808
	Change in value of common stock warrants										-10,114
	Gain on derivative instruments										410
	Loss before income taxes										-70,621
	Income tax benefit										—
	Net loss									$	-70,621
	Capital expenditures, including acquisitions	$	567,332	$	471	$	-1,300	$	544	$	567,047
	For the period from September 1 through December 31, 2012, expenditures for long term assets, including goodwill and other intangible assets by segment were as follows (in thousands):
		Natural Gas		Commodity		Corporate and		Total
		and Oil		Marketing and		Other
		Operations		Logistics
	Capital expenditures, including acquisitions	$	415	$	17,439	$	—	$	17,854
Schedule of Segment Reporting Information, by Segment, Financial Position [Table Text Block]	'
	Total assets by segment were as follows (in thousands):
		Refining,		Natural Gas		Commodity		Corporate and		Total
		Distribution		and Oil		Marketing and		Other
		and Marketing		Operations		Logistics
	At December 31, 2013	$	655,712	$	109,316	$	52,048	$	10,009	$	827,085
	At December 31, 2012	$	—	$	116,034	$	62,754	$	10,794	$	189,582

Reorganization_Under_Chapter_11

Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Tables)	12 Months Ended
	Dec. 31, 2013
Reorganizations [Abstract]	'
Schedule Of Reorganization Items And Fresh Start Accounting [Table Text Block]	'
	The following condensed consolidated balance sheet presents the implementation of the Plan and the adoption of fresh-start reporting as of the Effective Date. Reorganization adjustments have been recorded within the condensed consolidated balance sheet to reflect the effects of the Plan, including discharge of liabilities subject to compromise and the adoption of fresh-start reporting.
				August 31, 2012
						Plan of			Fresh Start
						Reorganization			Reporting
				Predecessor		Adjustments			Adjustments			Successor
			(in thousands)
	ASSETS
	Current assets
	Cash and cash equivalents		$	1,954	$	74,167	(a)	$			$	4,882
						-45,035	(c)
						-24,204	(d)
						-2,000	(e)
	Trust assets			—		3,446	(e)					3,446
	Restricted cash			—		20,359	(d)					20,359
	Trade accounts receivable, net			3,708		-1,727	(a)		-1,981	(g)		—
	Prepaid assets			4,777					-4,777	(g)		—
	Prepaid reorganization costs			1,326					-1,326	(g)		—
	Total current assets			11,765								28,687
	Property and equipment
	Oil and gas properties
	Unproved			84					-84	(g)		—
	Proved			759,755		-740,392	(a)		-14,776	(g)		4,587
	Land			4,000		-4,000	(a)					—
	Other			73,021		-47,493	(a)		-21,289	(g)		4,239
	Total property and equipment			836,860								8,826
	Less accumulated depreciation and depletion			-642,172		607,603	(a)		34,569	(g)		—
	Property and equipment, net			194,688								8,826
	Long-term assets:
	Investments in unconsolidated affiliates			3,629		105,344	(a)		-3,629	(g)		105,344
	Other long-term assets			307					-253	(g)		54
	Total long-term assets			3,936								105,398
	Total assets		$	210,389							$	142,911
	LIABILITIES AND EQUITY
	Current liabilities
	Liabilities not subject to compromise
	Debtor in possession financing		$	56,535		-56,535	(c)				$	—
	Accounts payable and other accrued liabilities			4,897								4,897
	Other accrued liabilities			9,224		-2,685	(b)					2,640
						-1,500	(c)
						-3,845	(d)
						1,446	(e)
	Accrued reorganization and trustee expense			70,656								7,537
	Liabilities subject to compromise
	3 3/4% Senior notes			115,000		-115,000	(b)					—
	7% Senior convertible notes			150,000		-150,000	(b)					—
	Accounts payable and other accrued liabilities			17,203		-2,560	(a)		-1,981	(g)		12,336
						-3,526	(d)		3,200	(g)
	Total current liabilities			352,859								19,873
	Long-term liabilities
	Liabilities not subject to compromise
	Long – term debt			—		6,335	(c)					6,335
	Derivative liabilities			—		6,665	(c)					6,665
	Asset retirement obligations			4,414		-3,938	(a)					476
	Total liabilities			357,273								33,349
	Stockholders’ equity
	Common stock			288		1,457	(b)		-288	(f)		1,477
						20	(d)
	Additional paid-in capital			1,643,285		100,084	(b)		288	(f)		108,085
						1,318	(d)		-1,636,890	(h)
	Retained earnings (accumulated deficit)			-1,790,457		166,144	(b)		-14,765	(g)		—
						2,188	(d)		1,636,890	(h)
	Total stockholders’ equity (deficit)			-146,884								109,562
	Total liabilities and equity (deficit)		$	210,389							$	142,911
Notes to Plan of Reorganization and Fresh Start Accounting Adjustments
	(a)	Reflects the contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.
	(b)	Reflects the extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(c)	Reflects the Successor drawing $13 million under the Loan Agreement (see Note 10 - Debt) to repay amounts outstanding under the DIP Credit Facility with those proceeds and cash from contribution of assets to Piceance Energy.
	(d)	Reflects the settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.00 per share on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(e)	Reflects the funding of the Recovery Trusts (see Note 13 - Commitments and Contingencies).
	(f)	Reflects the cancellation of Predecessor common stock.
	(g)	Reflects adjustments to remaining assets due to fresh-start reporting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh-start reporting adjustments within Reorganization items of approximately $14.8 million on the Predecessor’s consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
	(h)	Reflects the elimination of Predecessor’s accumulated deficit.

Disclosures_About_Capitalized_1

Disclosures About Capitalized Costs, Costs Incurred (Tables)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Oil And Gas Property Successful Effort Method [Table Text Block]	'
	Capitalized costs related to oil and gas activities are as follows (in thousands):
			Successor				Predecessor
			December 31,		December 31,		August 31,
			2013		2012		2012
	Company:
	Unproved properties		$	—	$	—	$	84
	Proved properties			4,949		4,804		759,755
				4,949		4,804		759,839
	Accumulated depreciation and depletion			-1,868		-337		-642,172
			$	3,081	$	4,467	$	117,667
	Company’s Share of Piceance Energy:
	Unproved properties		$	15,763	$	16,180
	Proved properties			168,378		134,638
				184,141		150,818
	Accumulated depreciation and depletion			-38,452		-2,808
			$	145,689	$	148,010
	-1	The capitalized cost amounts presented are as of August 31, 2012 for the Predecessor and exclude adjustments resulting from the plan or reorganization and fresh-start reporting (see Note 19 - Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan).
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	'
	Costs incurred in oil and gas activities including costs associated with assets retirement obligations, are as follows (in thousands):
			Successor				Predecessor
			Year Ended		Period from		Period from
			December 31,		September 1		January 1
			2013		through		through
					December 31,		August 31,
					2012		2012
	Company:
	Development costs incurred on proved undeveloped		$	—	$	—	$	1,613
	reserves
	Development costs—other			142		—		—
	Total		$	142	$	—	$	1,613
	Company’s Share of Piceance Energy:
	Unproved properties acquisition costs		$	—	$	206
	Proved properties acquisition costs (1)			—		32,519
	Development costs—other			6,380		291
	Total		$	6,380	$	33,016
	_______________________________________________________
	-1	Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy, of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]	'
	A summary of the results of operations for oil and gas producing activities, excluding general and administrative costs, is as follows:
			Successor				Predecessor
			Year Ended		September 1		January 1
			December 31,		through		through
			2013		December 31,		August 31,
					2012		2012
	Company:
	Revenue:
	Oil and gas revenues		$	7,739	$	2,144	$	23,079
	Expenses:
	Production costs			5,696		1,688		16,980
	Depletion and amortization			1,593		370		16,041
	Exploration			—		—		2
	Abandoned and impaired properties			—		—		151,347
	Results of operations of oil and gas producing activities		$	450	$	86	$	-161,291
	Company’s share of Piceance Energy:
	Revenue:
	Oil and gas revenues		$	20,364	$	6,464
	Expenses:
	Production costs			9,885		3,033
	Depletion and amortization			8,855		2,808
	Results of operations of oil and gas producing activities		$	1,624	$	623
	Total Company and Piceance Energy income from		$	2,074	$	709
	operations of oil and gas producing activities

Information_Regarding_Proved_O1

Information Regarding Proved Oil and Gas Reserves (Tables)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Property [Abstract]	'
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	'
	A summary of changes in estimated quantities of proved reserves for the year ended December 31, 2013 and for respective periods in 2012 is as follows:
			Gas		Oil		NGLS	Total
			(MMcf)		(MBbl)		(MBb1)	(MMcfe) (5)
	Company:
	Estimated Proved Reserves: Balance at January 1, 2012		87,209		494		—	90,173
	(Predecessor) (1)
	Revisions of quantity estimate		—		85		—	512
	Sale/disposition of properties (2)		-82,357		-235		—	-83,770
	Production		-4,852		-67		—	-5,256
	Estimated Proved Reserves: Balance at August 31, 2012		—		277		—	1,659
	(Successor)
	Revisions of quantity estimate		456		31		—	643
	Production		-10		-22		—	-139
	Estimated Proved Reserves: Balance at December 31, 2012		446		286		—	2,163
	(Successor)
	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		662		236		—	2,078
	(Successor)
	Company’s Share of Piceance Energy:
	Estimated Proved Reserves: Balance at September 1, 2012		—		—		—	—
	Transfer from investees (3)		83,915		560		4,228	112,639
	Revisions of quantity estimate		8,053		41		387	10,621
	Extensions and discoveries		32,073		236		1,778	44,151
	Production		-1,391		-6		-48	-1,711
	Estimated Proved Reserves: Balance at December 31, 2012		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		186,597		584		7,401	234,509
	Total Estimated Proved Reserves: Balance at December 31, 2013		187,259		820		7,401	236,587
	Proved developed reserves
	31-Dec-12		158		286		—	1,875
	December 31, 2012—Company Share of Piceance Energy		48,680		237		2,253	63,617
	Total December 31, 2012		48,838		523		2,253	65,492
	Proved undeveloped reserves
	31-Dec-12		288		—		—	288
	December 31, 2012—Company Share of Piceance Energy		73,970		594		4,092	102,083
	Total December 31, 2012		74,258		594		4,092	102,371
	Proved developed reserves
	31-Dec-13		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
	31-Dec-13		—		—		—	—
	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
			CIG per Mbtu			WTI per Bbl
	Base pricing, before adjustments for contractual
	differentials: (4)
	31-Aug-12		$	2.75		$	90.85
	31-Dec-12		$	2.56		$	91.21
	December 31, 2012 – Piceance		$	2.56		$	91.21
	31-Dec-13		$	3.53		$	96.91
	December 31, 2013 – Piceance		$	3.53		$	96.91
	_________________________________________________________
	-1	At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.
	-2	On August 31, 2012, substantially all of the reserves of the company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 3 - Investment in Piceance Energy).
	-3	On August 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy).
	(4)	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.
	(5)	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	'
	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.
			Successor						Predecessor
			December 31,						August 31,
			2013			2012			2012
			(in thousands)						(in thousands)
	Company:
	Future net cash flows		$	26,861		$	30,444		$	28,691
	Future costs:
	Production			21,999			20,596			19,973
	Development and abandonment			319			319			319
	Income taxes1			—			—			—
	Future net cash flows			4,543			9,529			8,399
	10% discount factor			-1,006			-1,519			-1,176
	Standardized measure of discounted future net cash		$	3,537		$	8,010		$	7,223
	flows
	Company’s Share of Piceance Energy:
	Future net cash flows		$	984,205		$	568,706
	Future costs:
	Production			430,506			199,277
	Development and abandonment			234,905			154,054
	Income taxes1			—			—
	Future net cash flows			318,794			215,375
	10% discount factor			-229,469			-143,416
	Standardized measure of discounted future net		$	89,325		$	71,959
	cash flows
	Total Company and Company share of equity		$	92,862		$	79,969
	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 the company does 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 [Table Text Block]	'
	The principal sources of changes in the standardized measure of discounted net cash flows for the year ended December 31, 2013 and for the respective periods during 2012 are as follows (in thousands):
			Successor
			December 31,			Company Share		Total
						of Piceance
						Energy
						December 31,
			2013			2013		2013
	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
			Successor								Predecessor
			Period from			Company Share		Total			January 1,
			September 1,			of Piceance					through
			through			Energy					August 31,
			December 31,			September 1,
						through
						December 31,
			2012			2012		2012			2012
	Beginning of the year										$	129,695
	Beginning of the period		$	7,223		$	—	$	7,223			—
	Transfer from investees			—			55,253		55,253			—
	Sales of oil and gas production during the period,			-456			-3,639		-4,095			-5,954
	net of production costs
	Net change in prices and production costs			-667			-139		-806			378
	Changes in estimated future development costs			—			5		5			—
	Extensions, discoveries and improved recovery			763			569		1,332			—
	Revisions of previous quantity estimates, estimated			648			13,708		14,356			-7,439
	timing of development and other
	Sales/disposition of reserves in place			—			—		—			-118,104
	Other			258			4,360		4,618			—
	Accretion of discount			241			1,842		2,083			8,647
	End of period		$	8,010		$	71,959	$	79,969		$	7,223

Overview_Details_Textual

Overview (Details Textual) (USD $)	Dec. 31, 2013	Jan. 23, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2013
		Subsequent Event [Member]	Hawaii Independent Energy LLC [Member]	Texadian Energy Inc [Member]	Delta Petroleum [Member]	Piceance Energy [Member]	Tesoro Acquisition [Member]
							Hawaii Independent Energy LLC [Member]
Unsecured Debt	'	'	'	'	$265,000,000	'	'
Payments to Acquire Businesses, Gross	'	'	75,000,000	14,000,000	'	'	'
Business Combination, Contingent Consideration, Liability	11,980,000	'	11,980,000	'	'	'	40,000,000
Noncontrolling Interest, Ownership Percentage by Parent	'	'	'	'	'	33.34%	'
Business Combination, Consideration Transferred, Liabilities Incurred	'	'	'	3,000,000	'	'	'
Business Combination, start-up expenses	'	'	$24,300,000	'	'	'	'
Stockholders Equity Reverse Stock Split	'	'1:10 reverse stock split	'	'	'	'	'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details)	12 Months Ended
	Dec. 31, 2013
Refining [Member] | Minimum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'8 years
Refining [Member] | Maximum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'47 years
Logistic [Member] | Minimum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'3 years
Logistic [Member] | Maximum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'30 years
Retail [Member] | Minimum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'14 years
Retail [Member] | Maximum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'18 years
Corporate [Member] | Minimum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'3 years
Corporate [Member] | Maximum [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'7 years
Software [Member]	'
Property, Plant and Equipment [Line Items]	'
Property, Plant and Equipment, Useful Life	'3 years

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details Textual) (USD $)	4 Months Ended	12 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012	Dec. 31, 2012
			Predecessor [Member]	Predecessor [Member]
Basis Of Presentation And Summary Of Significant Accounting Policies [Line Items]	'	'	'	'
Allowance for Doubtful Accounts Receivable	$0	$0	'	'
Income Tax Expense Benefit	($2,757,000)	$0	$0	$154,000,000

Investment_in_Piceance_Energy_1

Investment in Piceance Energy (Details) (USD $)	4 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]	'	'
Beginning balance	'	$104,434
Loss from unconsolidated affiliates	'	-2,941
Ending balance	'	101,796
Piceance Energy [Member]	'	'
Schedule of Equity Method Investments [Line Items]	'	'
Beginning balance	105,344	104,434
Loss from unconsolidated affiliates	-1,325	-3,516
Accretion of basis difference	0	575
Capitalized drilling costs obligation paid	415	303
Ending balance	$104,434	$101,796

Investment_in_Piceance_Energy_2

Investment in Piceance Energy (Details 1) (USD $)	4 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013
Assets	'	'
Current assets	$59,926	$558,373
Current liabilities	-69,977	-458,708
Oil, natural gas and natural gas liquids revenues	2,144	7,739
Loss from operations	-5,021	-39,313
Net loss	-8,839	-70,621
Piceance Energy [Member]	'	'
Assets	'	'
Current assets	6,275	5,901
Non-current assets	460,991	454,402
Current liabilities	-11,826	-13,040
Non-current liabilities	-94,369	-96,738
Oil, natural gas and natural gas liquids revenues	19,391	61,091
Loss from operations	-2,095	-6,765
Net loss	($3,975)	($10,546)

Investment_in_Piceance_Energy_3

Investment in Piceance Energy (Details Textual) (USD $)	4 Months Ended	12 Months Ended				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012	Dec. 31, 2013
			Piceance Energy [Member]	Piceance Energy [Member]	Piceance Energy [Member]	Parent Company [Member]
						Piceance Energy [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'
Equity Method Investment Ownership Percentage	'	'	33.34%	'	33.34%	'
Equity Method Investments, Additional Capital Contribution	'	'	$60,000,000	'	'	$20,000,000
Line Of Credit Facility Maximum Borrowing Capacity	'	'	400,000,000	'	'	'
Line Of Credit Facility Current Borrowing Capacity	'	'	120,000,000	'	'	'
Line Of Credit Facility Amount Outstanding	'	'	90,200,000	'	100,000,000	'
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	'	'	15,100,000	15,900,000	'	'
Lack Of Control And Marketability Discounts Amortization Term	'	'15 years	'	'	'	'
Depreciation, Depletion, Amortization and Accretion Expense	401,000	5,982,000	26,600,000	8,500,000	'	'
Losses on derivative instruments	'	'	$770,000	$917,000	'	'

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Goodwill	$20,603	$7,756
Contingent consideration liability	-11,980	'
Texadian Energy Inc [Member]	'	'
Intangible assets	8,809	'
Goodwill	6,990	'
Net non cash-working capital	3,097	'
Deferred tax liabilities	-2,757	'
Total	16,139	'
Hawaii Independent Energy LLC [Member]	'	'
Inventory	418,750	'
Trade accounts receivable	59,485	'
Prepaids and other current assets	1,978	'
Property, plant and equipment	58,782	'
Land	39,800	'
Intangible assets	4,689	'
Goodwill	13,613	'
Accounts payable and other current liabilities	-18,154	'
Contingent consideration liability	-11,980	'
Other noncurrent liabilities	-6,384	'
Total	$560,579	'

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions (Details 1) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Business Acquisition [Line Items]	'	'
Revenues	$2,986.80	$3,811.10
Net loss	($113.60)	($12)

Acquisitions_and_Dispositions_3

Acquisitions and Dispositions (Details Textual) (USD $)	4 Months Ended	12 Months Ended		8 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Aug. 31, 2012	Dec. 31, 2012	Dec. 31, 2013
			Assets Held-for-sale [Member]	Piceance Energy [Member]	Texadian Energy, Inc.	Hawaii Independent Energy LLC [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'
Payments to Acquire Businesses, Gross	'	'	'	'	$14,000,000	$75,000,000
Business acquisition purchase price allocation working capital	'	'	'	'	3,000,000	'
Business Combination, Separately Recognized Transactions, Additional Disclosures, Acquisition Costs	'	'	'	'	17,000,000	'
Payments To Acquire Businesses Net Of Cash Acquired	17,439,000	559,279,000	'	'	'	40,000,000
Funding Of Acquisition From Supply And Exchange Agreements	'	'	'	'	'	378,200,000
Significant Acquisitions and Disposals, Terms	'	'	'	'	'	'The earnout payments, if any, are to be paid annually following each of the three calendar years beginning January1, 2014 through the year ending December31, 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.
Debtor Reorganization Items, Impairment Loss	'	'	'	151,300,000	'	'
Proceeds from Sale of Productive Assets, Total	'	'	2,900,000	'	'	'
Gain (Loss) on Disposition of Property Plant Equipment, Total	'	'	50,000	'	'	'
Business Combination, Consideration Transferred, funds received from subsidiary	'	1,300,000	'	'	'	'
Business Combination, Acquisition Related Costs	'	'	'	'	556,000	7,000,000
Business Combination, funded for overhaul of co-generation turbine	'	'	'	'	'	$24,300,000

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Land	$39,800	$0
Buildings and equipment	65,878	0
Other	1,945	1,415
Property, plant and equipment	107,623	1,415
Proved oil and gas properties	4,949	4,804
Less: accumulated depreciation, depletion and amortization	-3,968	-373
Property Plant And Equipment Net	$108,604	$5,846

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	4 Months Ended	12 Months Ended	8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012
			Predecessor [Member]
Asset Retirement Obligations [Line Items]	'	'	'
Asset retirement obligation - beginning of period	$476	$512	$3,799
Obligation acquired	0	2,601	0
Accretion expense	36	59	178
Change in estimate	0	0	437
Settlement upon transfer to Piceance Energy	0	0	-3,938
Asset retirement obligation - end of period	$512	$3,172	$476

Asset_Retirement_Obligations_D1

Asset Retirement Obligations (Details Textual) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012
In Thousands, unless otherwise specified
Asset Retirement Obligations [Line Items]	'	'	'
Asset Retirement Obligation	$3,172	$512	$476
Piceance Energy [Member]	'	'	'
Asset Retirement Obligations [Line Items]	'	'	'
Asset Retirement Obligation	$3,900	'	'

Inventories_Details

Inventories (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Crude oil and feedstocks	$146,158	'
Refined products and blend stock	229,086	'
Spare parts, materials and supplies, and merchandise	13,831	'
Inventory, Net, Total	389,075	10,466
Titled Inventory [Member]	'	'
Crude oil and feedstocks	0	10,466
Refined products and blend stock	67,532	0
Spare parts, materials and supplies, and merchandise	13,831	0
Inventory, Net, Total	81,363	10,466
Supply and Exchange Agreements [Member]	'	'
Crude oil and feedstocks	146,158	'
Refined products and blend stock	161,554	'
Spare parts, materials and supplies, and merchandise	0	'
Inventory, Net, Total	$307,712	'

Intangible_assets_Details

Intangible assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
Amortized intangible assets, Gross carrying amount	$13,498	$8,809
Amortized intangible assets, Accumulated Amortization	-2,328	0
Amortized intangible assets, Net	11,170	8,809
Supplier Relation Ships [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Amortized intangible assets, Gross carrying amount	3,360	3,360
Amortized intangible assets, Accumulated Amortization	-258	0
Amortized intangible assets, Net	3,102	3,360
Rail car leases [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Amortized intangible assets, Gross carrying amount	3,249	3,249
Amortized intangible assets, Accumulated Amortization	-650	0
Amortized intangible assets, Net	2,599	3,249
Historical Shipper Status [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Amortized intangible assets, Gross carrying amount	2,200	2,200
Amortized intangible assets, Accumulated Amortization	-1,100	0
Amortized intangible assets, Net	1,100	2,200
Trade names and trademarks [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Amortized intangible assets, Gross carrying amount	4,689	0
Amortized intangible assets, Accumulated Amortization	-320	0
Amortized intangible assets, Net	$4,369	$0

Intangible_assets_Details_1

Intangible assets (Details 1) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
2014	$3,571	'
2015	2,471	'
2016	2,151	'
2017	908	'
2018	258	'
Thereafter	1,811	'
Total	$11,170	$8,809

Intangible_assets_Details_2

Intangible assets (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Goodwill [Line Items]	'
Balance at beginning of period	$7,756
Additions	13,613
Texadian purchase price adjustments	-766
Balance at end of period	$20,603

Intangible_assets_Details_Text

Intangible assets (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]	'	'
Amortization of Intangible Assets	$2,300,000	$0

Supply_and_Exchange_Agreements1

Supply and Exchange Agreements (Details Textual) (USD $)	4 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Shipping, Handling and Transportation Costs, Total	'	$3,700,000
Interest Expense, Total	1,056,000	19,471,000
Supply and Exchange Agreements [Member]	'	'
Interest Expense, Total	'	$1,400,000

Debt_Details

Debt (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Total debt, net of unamortized debt discount	$97,280	$42,391
Less: current maturities	-3,250	-35,000
Long term debt, net of current maturities and unamortized discount	94,030	7,391
Delayed Draw Term Loan Agreement [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Line of Credit	0	13,465
Unamortized Debt Discount - Warrants [Member]	'	'
Debt Instrument [Line Items]	'	'
Unamortized Debt Discount	0	-6,014
Unamortized Debt Discount - Embedded Derivative [Member]	'	'
Debt Instrument [Line Items]	'	'
Unamortized Debt Discount	0	-60
ABL Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Line of Credit	51,800	0
Retail Credit Agreement [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Line of Credit	26,000	0
Tranche B Loan [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Line of Credit	$19,480	$35,000

Debt_Details_1

Debt (Details 1) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
2014	$3,250	'
2015	2,600	'
2016	22,080	'
2017	54,400	'
2018	2,600	'
Thereafter	11,700	'
Total	$97,280	$42,391

Debt_Details_2

Debt (Details 2)	12 Months Ended
	Dec. 31, 2013
2013 Fiscal Year [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Maximum Leverage Ratio	5.75
2014 Fiscal Year [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Maximum Leverage Ratio	5.5
2015 Fiscal Year [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Maximum Leverage Ratio	5.25
2016 Fiscal Year [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Maximum Leverage Ratio	5
2017 Fiscal Year, and at all times thereafter [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Maximum Leverage Ratio	4.75

Debt_Details_3

Debt (Details 3)	12 Months Ended
	Dec. 31, 2013
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	2.00%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	0.00%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	2.25%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	0.25%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	2.50%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Margin Rate	0.50%

Debt_Details_4

Debt (Details 4)	12 Months Ended
	Dec. 31, 2013
Leverage Ratio Less Than 4.00 [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Unused Fee Percentage	0.25%
Leverage Ratio Less Than 4.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	1.75%
Leverage Ratio Less Than 4.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	-0.25%
Leverage Ratio 4.00-5.00 [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Unused Fee Percentage	0.38%
Leverage Ratio 4.00-5.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	2.00%
Leverage Ratio 4.00-5.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	0.00%
Leverage Ratio Grater Than 5.00 [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Unused Fee Percentage	0.50%
Leverage Ratio Grater Than 5.00 [Member] | LIBOR loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	2.25%
Leverage Ratio Grater Than 5.00 [Member] | Base Rate Loans [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument Revolver Applicable Margin	0.25%

Debt_Details_Textual

Debt (Details Textual) (USD $)

4 Months Ended

12 Months Ended

8 Months Ended

12 Months Ended

12 Months Ended

4 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Aug. 31, 2012

Dec. 27, 2012

Dec. 31, 2013

Sep. 25, 2013

Dec. 31, 2013

Dec. 27, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

ABL Facility [Member]

Predecessor [Member]

Financial Standby Letter Of Credit [Member]

ABL Revolving Credit Facility [Member]

ABL Revolving Credit Facility [Member]

Texadian Uncommitted Credit Agreement [Member]

Letter of Credit Facility [Member]

Warrant Issuance Agreement [Member]

Warrant Issuance Agreement [Member]

Senior Secured Delayed Draw Term Loan [Member]

Senior Secured Delayed Draw Term Loan [Member]

Senior Secured Delayed Draw Term Loan [Member]

HIE Retail [Member]

HIE Retail [Member]

Tranche B Term Loan [Member]

Tranche B Term Loan [Member]

Term Loan [Member]

Revolving Credit Facility [Member]

Retail Credit Agreement [Member]

Retail Credit Agreement [Member]

Debt Disclosure [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds From Lines Of Credit

$35,000,000

$159,800,000

'

$23,000,000

'

'

'

'

'

'

'

$30,000,000

'

$65,000,000

$26,000,000

'

Interest rate under credit facility

'

'

'

'

'

'

'

'

'

'

'

'

9.75%

14.75%

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

'

'

'

Interest rate after an event of default

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

'

'

Debt instrument principal prepayment amount

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

'

'

Line credit maximum borrowing amount

'

'

'

'

'

125,000,000

'

50,000,000

30,000,000

'

'

'

'

'

30

5

Letters Of Credit Outstanding Amount

'

'

'

'

11,700,000

'

'

41,600,000

'

'

'

'

'

'

'

'

Common stock warrant exercise price

'

'

'

'

'

'

'

'

'

0.1

0.1

'

'

'

'

'

Common stock warrant expiration period

'

'

'

'

'

'

'

'

'

31-Aug-22

31-Aug-22

'

'

'

'

'

Fair value of warrant on grant date

'

'

'

'

'

'

'

'

'

'

6,600,000

'

'

'

'

'

Line of Credit Facility, Capacity Available for Specific Purpose Other than for Trade Purchases

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

Line Of Credit Facility Amount Outstanding

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

'

'

'

'

'

'

'

'

'

14,859

959,213

'

'

'

'

'

Stock Issued To Settle Bankruptcy Claims

'

'

'

'

'

'

'

'

'

'

228,735

'

'

'

'

'

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.

'

'

'

'

'

'

'

'

'

'

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 Texadians 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.

'

'

'

'

'

'

'

'

Advances To Be Received Upon Compliance Of Requirements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

Fixed Charge Coverage Ratio To Be Maintained

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1.15:1.00

'

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

'

Line of Credit Facility, Interest Rate Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'The Term Loan will bear interest, at HIE Retails 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 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

'Advances under the Revolver will bear interest, at HIE Retails 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

Line of Credit Facility, Commitment Fee Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Exercised

'

'

'

'

'

'

'

'

'

'

183,389

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Beginning Balance

'

'

'

'

'

'

'

'

'

790,683

790,683

'

'

'

'

'

Extinguishment of Debt, Amount

'

'

'

'

'

'

'

'

'

'

'

$6,100,000

'

'

'

'

Debt, Weighted Average Interest Rate

'

'

3.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Aug. 31, 2012
In Thousands, unless otherwise specified
Piceance Energy [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Investment in Piceance Energy	$105,300
Fair Value, Measurements, Nonrecurring [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Proved	4,587	[1],[2]
Fair Value, Measurements, Nonrecurring [Member] | Frac tanks [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Other assets	1,400	[3]
Fair Value, Measurements, Nonrecurring [Member] | Compressors [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Other assets	2,800	[3]
Fair Value, Measurements, Nonrecurring [Member] | Miscellaneous [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Other assets	39	[4]
Fair Value, Measurements, Nonrecurring [Member] | Piceance Energy [Member]	'
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'
Investment in Piceance Energy	$105,344	[5]
[1]	Certain proved property was valued using the cost valuation technique. A significant input in this measurement was the estimated cost of the properties. A change in that estimated cost would be directly correlated to change in the estimated fair value of the property. We consider this to be a level 3 fair value measurement.
[2]	The estimated fair value of our Point Arguello Unit offshore California was valued using a market valuation technique based on standalone bids received by third-parties during the sale process. We consider this to be a level 2 fair value measurement.
[3]	The estimated fair value of our frac tanks and compressor units was valued using a market valuation technique which was based on published listings of similar equipment or standalone bids received by third-parties. We consider these to be level 2 fair value measurements.
[4]	Miscellaneous assets (assets that we were unable to value using the income or market valuation techniques) were valued using the cost valuation technique. We consider this to be a level 3 fair value measurement.
[5]	The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reservesb future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 1) (USD $)	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net, Total	$17,439
Net non-cash working capital [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,631	[1]
Supplier relationships [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,360	[2]
Historical shipper status [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	2,200	[3]
Railcar leases [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	3,249	[4]
Goodwill [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Total	7,756	[5]
Deferred tax liability [Member]	'
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities, Total	($2,757)	[6]
[1]	Current assets acquired and liabilities assumed were recorded at their net realizable value.
[2]	The estimated fair value of the supplier relationship was estimated using a form of the income approach, the Multiple-Period Excess Earnings Method. Significant inputs used in this model include estimated cash flows from the suppliers, customer growth and rates and a discount rate. An increase in the cash flows attributable to the supplier relationships would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a level 3 fair value measurement.
[3]	The estimated fair value of the historical shipper status was estimated using a form of the income approach, the Greenfield Method. Significant inputs used in this model include estimated cash flows with and without the historical shipper status, and a discount rate. An increase in the cash flows attributable to the shipper would result in an increase in the value of such relationship, while an increase in the discount rate would result in a decrease in the value. We consider this to be a level 3 fair value measurement.
[4]	The estimated fair value of the railcar leases was estimated using a form of the income approach, the Lost Income Method. Significant inputs used in this model include the cost of providing services with and without the favorable railcar leases and a discount rate. An increase in market rates of railcar leases would result in an increase in the value attributable to the acquired leases. We consider this to be a level 3 fair value measurement.
[5]	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
[6]	A deferred tax liability has been recorded since the acquired intangible assets will not be deductible for tax purposes until the eventual sale of the company.

Fair_Value_Measurements_Detail2

Fair Value Measurements (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Sep. 25, 2013		Sep. 25, 2013		Sep. 25, 2013
In Thousands, unless otherwise specified			Purchase Price Allocation of HIE [Member]		Purchase Price Allocation of HIE [Member]		Purchase Price Allocation of HIE [Member]
					Property, Plant and Equipment, Other Types [Member]		Land [Member]
Net working capital	'	'	$462,059	[1]	'		'
Property, Plant, and Equipment, Fair Value Disclosure	'	'	'		58,782	[2]	39,800	[3]
Trade names and trade marks	'	'	4,689	[4]	'		'
Goodwill	'	'	13,613	[5]	'		'
Other noncurrent liabilities	'	'	-6,384	[6]	'		'
Contingent consideration liability	11,980	0	-11,980	[7]	'		'
Fair Value, Net Asset (Liability), Total	'	'	$560,579		'		'
[1]	Current assets acquired and liabilities assumed were recorded at their net realizable value.
[2]	The estimated 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.
[3]	The estimated fair value of the land was estimated using the sales comparison approach. Under this approach, the sales prices of similar properties are adjusted to account for differences in land characteristics. We consider this to be a Level 3 fair value measurement.
[4]	The estimated 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.
[5]	The excess of the purchase price paid over the fair value of the identifiable assets acquired and liabilities assumed is allocated to goodwill.
[6]	Other noncurrent assets and liabilities are recorded at their estimated net present value as estimated by management.
[7]	The estimated 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.

Fair_Value_Measurements_Detail3

Fair Value Measurements (Details 3) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Fair Value Measurements [Line Items]	'	'
Stock price	$22.30	$12
Initial exercise price	$0.10	$0.10
Term (years)	'8 years 8 months 1 day	'9 years 8 months 1 day
Risk-free rate	2.78%	1.68%
Expected volatility	52.90%	75.00%

Fair_Value_Measurements_Detail4

Fair Value Measurements (Details 4) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Contingent consideration liability [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities Fair Value Disclosure	($11,980)	$0
Prepaid and Other Current Assets [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Asset fair value disclosure	0	-307
Prepaid and Other Current Assets [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Asset fair value disclosure	0	542
Derivative liabilities [Member] | Warrant [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities Fair Value Disclosure	-17,336	-10,900
Derivative liabilities [Member] | Embedded Derivative [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities Fair Value Disclosure	$0	($45)

Fair_Value_Measurements_Detail5

Fair Value Measurements (Details 5) (USD $)	4 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013
Gain on derivative instruments, net [Member] | Exchange Traded Futures [Member]	'	'
Derivatives not designated as hedges, Gain (loss) recognized in income	$0	$104
Gain on derivative instruments, net [Member] | Physical Forward Contacts [Member]	'	'
Derivatives not designated as hedges, Gain (loss) recognized in income	0	306
Change In Value Of Warrants [Member] | Warrant [Member]	'	'
Derivatives not designated as hedges, Gain (loss) recognized in income	-4,280	-10,114
Interest expense and financing costs, net [Member] | Debt repayment derivative [Member]	'	'
Derivatives not designated as hedges, Gain (loss) recognized in income	$0	$45

Fair_Value_Measurements_Detail6

Fair Value Measurements (Details 6) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	($29,316)	($11,252)
Contingent consideration liability [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	-11,980	'
Commodity Contract [Member] | Exchange Traded Futures [Member]	'	'
Assets	'	'
Commodities - exchange traded futures	'	542
Commodity Contract [Member] | Physical Forward Contracts [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	-307
Warrants derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	-17,336	-10,900
Debt Prepayment Derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	-45
Fair Value Inputs Level 1 [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 1 [Member] | Contingent consideration liability [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	'
Fair Value Inputs Level 1 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]	'	'
Assets	'	'
Commodities - exchange traded futures	'	542
Fair Value Inputs Level 1 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	0
Fair Value Inputs Level 1 [Member] | Warrants derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 1 [Member] | Debt Prepayment Derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	0
Fair Value Inputs Level 2 [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	-307
Fair Value Inputs Level 2 [Member] | Contingent consideration liability [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	'
Fair Value Inputs Level 2 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]	'	'
Assets	'	'
Commodities - exchange traded futures	'	0
Fair Value Inputs Level 2 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	-307
Fair Value Inputs Level 2 [Member] | Warrants derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	0	0
Fair Value Inputs Level 2 [Member] | Debt Prepayment Derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	0
Fair Value Inputs Level 3 [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	-29,316	-10,945
Fair Value Inputs Level 3 [Member] | Contingent consideration liability [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	-11,980	'
Fair Value Inputs Level 3 [Member] | Commodity Contract [Member] | Exchange Traded Futures [Member]	'	'
Assets	'	'
Commodities - exchange traded futures	'	0
Fair Value Inputs Level 3 [Member] | Commodity Contract [Member] | Physical Forward Contracts [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	0
Fair Value Inputs Level 3 [Member] | Warrants derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	-17,336	-10,900
Fair Value Inputs Level 3 [Member] | Debt Prepayment Derivative [Member]	'	'
Liabilities	'	'
Derivative Fair Value Of Derivative Liability	'	($45)

Fair_Value_Measurements_Detail7

Fair Value Measurements (Details 7) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'
Balance, at beginning of period	($10,945)	($6,665)
Settlements	3,723	0
Acquired	-11,980	0
Total unrealized losses included in earnings	-10,114	-4,280
Transfers	0	0
Balance, at end of period	($29,316)	($10,945)

Fair_Value_Measurements_Detail8

Fair Value Measurements (Details 8) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, Carrying Value	$94,030		$7,391
Warrants, Carrying Value	17,336		10,945
Contingent consideration liability, Carrying Value	11,980		'
Debt repayment derivative, Carrying Value	'		45
Long-term Debt, Fair Value	'		10,900
Warrants, Fair Value	17,336	[1]	10,900
Contingent consideration liability, Fair Value	11,980	[1]	'
Debt repayment derivative, Fair Value	'		45
Tranche B [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term Line of Credit, Noncurrent	19,480		'
Lines of Credit, Fair Value Disclosure	18,800		'
ABL Facility [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term Line of Credit, Noncurrent	51,800		0
Lines of Credit, Fair Value Disclosure	51,800	[1]	'
HIE Retail Credit Agreement [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term Line of Credit, Noncurrent	26,000		'
Lines of Credit, Fair Value Disclosure	$26,000	[1]	'
[1]	The fair values of these instruments are considered Level 3 measurements in the fair value hierarchy.

Fair_Value_Measurements_Detail9

Fair Value Measurements (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Aug. 31, 2012	Aug. 31, 2012		Aug. 31, 2012	Aug. 31, 2012	Aug. 31, 2012
			Hawaii Independent Energy LLC [Member]	Piceance Energy [Member]	Piceance Energy [Member]	Fair Value, Measurements, Nonrecurring [Member]		Fair Value, Measurements, Nonrecurring [Member]	Fair Value, Measurements, Nonrecurring [Member]	Fair Value, Measurements, Nonrecurring [Member]
						Piceance Energy [Member]		Proved Developed and Producing Reserves	Proved Developed Non Producing Reserves	Proved Undeveloped Reserves
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Line Items]	'	'	'	'	'	'		'	'	'
Cash flow model discount rate	'	'	'	'	'	'		10.00%	15.00%	20.00%
Equity method investment ownership percentage	'	'	'	33.34%	33.34%	33.34%		'	'	'
Investment in Piceance Energy	'	'	'	'	$105,300,000	$105,344,000	[1]	'	'	'
Warrants Not Settleable In Cash Fair Value Disclosure, Per Share	$21.64	$11.30	'	'	'	'		'	'	'
Warrants Not Settleable in Cash, Fair Value Disclosure	17,300,000	10,900,000	'	'	'	'		'	'	'
Fair Value Assumptions Historical Volatilities Period1	'10 years	'	'	'	'	'		'	'	'
Embedded Derivative, Fair Value of Embedded Derivative Liability	'	145,000	'	'	'	'		'	'	'
Business Combination, Contingent Consideration, Liability	$11,980,000	'	$11,980,000	'	'	'		'	'	'
Fair Value Assumptions, Expected Current Yield	5.72%	5.72%	'	'	'	'		'	'	'
[1]	The estimated fair value of our investment in Piceance Energy was based on its enterprise value and uses various valuation techniques including (i) an income approach based on proved developed reservesb future net income discounted back to net present value based on the weighted average cost of capital for comparable independent oil and natural gas producers, and (ii) a market multiple approach. Proved property was valued using the income approach. A discounted cash flow model was prepared based off of an independent reserve report with a discount rate of 10% applied to proved developed producing reserves, 15% to proved developed non-producing reserves and 20% to proved undeveloped reserves. The prices for oil and natural gas were forecasted based on NYMEX strip pricing adjusted for basis differentials. For the market multiple approach, we reviewed the transaction values of recent similar asset transactions and compared the purchase price per Mcfe of proved developed reserves and purchase price per Mcfe per day of net equivalent production of those transactions to the independent reserve report. Unproved acreage was valued using a cost approach based on recent sales of acreage in the area. Based on these valuations, the equity value of our 33.34% interest in Piceance Energy was estimated to be approximately $105.3 million on the Emergence date. We consider this to be a Level 3 fair value measurement.

Defined_Contribution_Plans_Det

Defined Contribution Plans (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]	'
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	3.00%
Defined Contribution Plan, Employers Matching Contribution, Annual Vesting Percentage	6.00%
Defined Contribution Plan, Cost Recognized	$0
Defined Benefit Plan, Benefit Obligation, Period Increase (Decrease)	$502,000
Minimum [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	5.50%
Maximum [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	8.50%

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	0 Months Ended		4 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Aug. 31, 2012		Dec. 31, 2012		Dec. 31, 2013
	Count		Count		Count
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	112		'		'
Amount of claims filed	$73,730		'		'
Number of claim settled	'		25		59
Amount of claim settled	'		6,600		26,906
Amount of claim settled in cash	'		259		5,383
Amount of claim settled stock	'		20		209
Number of remaining claim to be resolved	'		87		28
Amount of remaining claim to be resolved	'		67,130		40,224
U S Government [Member]	'		'		'
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	3		'		'
Amount of claims filed	22,364		'		'
Number of claim settled	'		0		1
Amount of claim settled	'		0		0
Amount of claim settled in cash	'		0		0
Amount of claim settled stock	'		0		0
Number of remaining claim to be resolved	'		3		2
Amount of remaining claim to be resolved	'		22,364		22,364
Former Employee Claims [Member]	'		'		'
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	32		'		'
Amount of claims filed	16,380		'		'
Number of claim settled	'		13		19
Amount of claim settled	'		3,685		12,695
Amount of claim settled in cash	'		230		340
Amount of claim settled stock	'		20		162
Number of remaining claim to be resolved	'		19		0
Amount of remaining claim to be resolved	'		12,695		0
Macquarie Capital Incorporated [Member]	'		'		'
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	1		'		'
Amount of claims filed	8,672		'		'
Number of claim settled	'		0		1
Amount of claim settled	'		0		8,672
Amount of claim settled in cash	'		0		2,500
Amount of claim settled stock	'		0		0
Number of remaining claim to be resolved	'		1		0
Amount of remaining claim to be resolved	'		8,672		0
Swann And BuzzardCreek RoyaltyTrust [Member]	'		'		'
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	1		'		'
Amount of claims filed	3,200		'		'
Number of claim settled	'		0		1
Amount of claim settled	'		0		3,200
Amount of claim settled in cash	'		0		2,000
Amount of claim settled stock	'		0		0
Number of remaining claim to be resolved	'		1		0
Amount of remaining claim to be resolved	'		3,200		0
Other Various Claims [Member]	'		'		'
Commitment And Contingencies [Line Items]	'		'		'
Number of claims filed	75	[1]	'		'
Amount of claims filed	23,114	[1]	'		'
Number of claim settled	'		12	[1]	37	[1]
Amount of claim settled	'		2,915	[1]	2,339	[1]
Amount of claim settled in cash	'		29	[1]	543	[1]
Amount of claim settled stock	'		0	[1]	47	[1]
Number of remaining claim to be resolved	'		63	[1]	26	[1]
Amount of remaining claim to be resolved	'		$20,199	[1]	$17,860	[1]
[1]	Includes reserve for contingent/unliquidated claims in the amount of $10 million.

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 1) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Commitment And Contingencies [Line Items]	'
2014	$382
2015	382
2016	382
2017	382
2018	420
Thereafter	420
Total minimum lease payments	2,368
Less amount representing interest	634
Total minimum rental payments	$1,734

Commitments_and_Contingencies_3

Commitments and Contingencies (Details 2) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Commitment And Contingencies [Line Items]	'
2014	$22,724
2015	13,277
2016	12,362
2017	10,375
2018	9,244
Thereafter	25,614
Operating Leases, Future Minimum Payments Due, Total	$93,596

Commitments_and_Contingencies_4

Commitments and Contingencies (Details Textual) (USD $)

12 Months Ended

16 Months Ended

12 Months Ended

12 Months Ended

4 Months Ended

12 Months Ended

8 Months Ended

4 Months Ended

1 Months Ended

4 Months Ended

16 Months Ended

Share data in Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2012

Aug. 31, 2012

Dec. 31, 2012

Sep. 30, 2012

Dec. 31, 2012

Dec. 31, 2013

Texadian [Member]

Tesoros [Member]

Tesoro Acquisition [Member]

Customer One [Member]

Predecessor [Member]

Predecessor [Member]

Predecessor [Member]

Wapiti Oil And Gas [Member]

Wapiti Trust [Member]

Wapiti Trust [Member]

Wapiti Trust [Member]

Hawaii Independent Energy LLC [Member]

Customer One [Member]

Customer Two [Member]

Commitments And Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Recovery Trust Funded Amount

$1,000,000

$1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

One Time Cash Payment As Consideration For Release Of Claims

'

'

'

'

'

'

'

'

'

'

1,500,000

'

'

'

Distribution From Trust

'

'

'

'

'

'

'

'

'

'

'

'

5,200,000

5,200,000

Shares Of Beneficial Interest Owned Per 1000 Of Claim

'

'

'

'

'

'

'

54.4

'

'

'

1

'

'

Loss Contingency, Estimate of Possible Loss

3,800,000

3,800,000

8,700,000

'

'

'

'

'

'

'

'

'

'

'

Long-term Purchase Commitment, Amount

'

'

'

28,000,000

'

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Operating Leases, Term of Contract

'32 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Capital Leases, Term of Contract

'17 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Capital Leases, Renewal Term Description

'with four 5-year renewal options

'

'

'

'

'

'

'

'

'

'

'

'

'

Concentration Risk, Percentage

'

'

'

'

'

'

96.00%

'

59.00%

24.00%

'

'

'

'

Percentage Of Beneficial Interest Owned

2.42%

'

'

'

'

'

'

'

'

'

'

'

'

'

Contingency Reserve For Litigation

10,000,000

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Claims Settled, Number

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewable Fuel Usage Description

'The RFS2 requires an increasing amount of renewable fuel usage, up to 36.0 billion gallons by 2022

'

'

'

'

'

'

'

'

'

'

'

'

'

Customer Revenue Description

'no individual customer accounted for more than 10% of our consolidated revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases, Rent Expense, Net, Total

6,200,000

61,000

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Assets (Liabilities), at Fair Value, Net, Total

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

Legal Fees

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Damages Sought, Value

$3,250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Indemnification Obligation Limitation, Description

'

'

'

'

'

'Tesoros indemnification obligations are subject to certain limitations as set forth in the Environmental Agreement. These limitations include a cap of $15 million forcertain of Tesoros indemnification obligationsrelated to certainpre-existing conditions as well as certain restrictions regarding the time limits for submitting notice and supporting documentation for remediation actions.

'

'

'

'

'

'

'

'

Stockholders_Equity_Details

Stockholders' Equity (Details) (Long Term Incentive Plan, USD $)	12 Months Ended
	Dec. 31, 2013
Long Term Incentive Plan	'
Stock Awards, Shares	'
Non vested balance, beginning of period	219,000
Granted	356,000
Vested	-51,000
Forfeited	0
Non vested balance, end of period	524,000
Available for grant	1,025,000
Stock Awards, Weighted-Average Grant Date Fair Value	'
Non vested balance, beginning of period	$12
Granted	$18.32
Vested	$12
Forfeited	$0
Non vested balance, end of period	$16.29

Stockholders_Equity_Details_1

Stockholders' Equity (Details 1) (Predecessor [Member], USD $)	8 Months Ended
	Aug. 31, 2012
Predecessor [Member]	'
Options	'
Outstanding-beginning of year	150,300
Granted	0
Exercised	0
Expired / canceled	-150,300
Outstanding-end of year	0
Exercisable-end of year	0
Weighted-Average Exercise Price	'
Outstanding-beginning of year	$0
Granted	$0
Exercised	$0
Expired / canceled	$0
Outstanding-end of year	$0
Exercisable-end of year	$0
Weighted-Average Remaining Contractual Term	'
Outstanding-end of year	'0 years
Exercisable-end of year	'0 years
Aggregate Intrinsic Value	'
Outstanding-end of year	$0
Exercisable-end of year	$0

Stockholders_Equity_Details_2

Stockholders' Equity (Details 2) (Predecessor [Member], USD $)	8 Months Ended
	Aug. 31, 2012
Predecessor [Member]	'
Nonvested Stock	'
Non vested balance, beginning of period	558,301
Granted	0
Vested	0
Expired / canceled	-558,301
Non vested balance, end of period	0
Weighted-Average Grant-Date Fair Value	'
Non vested balance, beginning of period	$7.45
Granted	$0
Vested	$0
Expired / canceled	($7.45)
Non vested balance, end of period	$0
Weighted-Average Remaining Contractual Term	'
Nonvested-end of year	'0 years
Aggregate Intrinsic Value	'
Nonvested-end of year	$0

Stockholders_Equity_Details_Te

Stockholders' Equity (Details Textual) (USD $)

4 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

8 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Dec. 20, 2012

Jan. 23, 2014

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Aug. 31, 2012

Jun. 21, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Subsequent Event

Board Of Directors [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Incentive Plans [Member]

Incentive Plans [Member]

Incentive Plans [Member]

Incentive Plans [Member]

Restatement [Member]

Form S-1 [Member]

Form S-3 [Member]

Predecessor [Member]

Predecessor [Member]

7% Senior Unsecured Notes, due 2015 [Member]

3 3/4% Senior Convertible Notes, due 2037 [Member]

Senior Unsecured Note [Member]

Unsecured Debt [Member]

Board Of Directors [Member]

Settlement of Bankruptcy Claims [Member]

Exercise of Warrants [Member]

Employees and Directors [Member]

Employees and Directors [Member]

Board Of Directors [Member]

Employees and Directors [Member]

Board Of Directors [Member]

Chairperson Of Audit Committee [Member]

Non Chairman Audit Committee [Member]

Common Stock [Member]

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest percentage of senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.00%

3.75%

'

'

Maturity period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2015

'2037

'

'

Shares allotted to note holders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14,573,608

191,973

Number of shares issuable under warrants

'

959,213

'

'

'

'

'

'

'

'

'

'

1,220,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares authorized

'

'

1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

303,000,000

'

'

'

'

'

'

'

'

Common Stock Shares Authorized

300,000,000

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

Preferred stock, shares authorized

3,000,000

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

Preferred stock, par value

$0.01

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

Expected Market Value Of Registrable Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$15,000,000

$5,000,000

'

'

'

'

'

'

Stockholders Equity Reverse Stock Split

'

'

'

'1:10 reverse stock split

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common shares Issued

'

'

'

'

3,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common shares Issued amount

34,000

1,164,000

'

'

33,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share price

$12

$22.30

'

'

'

'

'

'

'

'

'

'

'

'

$12

'

$10

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested shares Granted

'

'

'

'

'

355,481

219,183

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

489,227

'

'

'

'

Vesting period

'

'

'

'

'

'5 years

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

'

8,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average period

'

'

'

'

'

'4 years 4 months 13 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Annual retainer to amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000

15,000

5,000

'

'

'

'

'

'

'

'

'

Annual grant of restricted stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75,000

75,000

'

'

'

'

'

'

'

'

'

'

'

Period of volume weighted average share price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

'

'

Value of shares on the grant date, floor

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$5.50

'

'

'

'

Stock compensation expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,900,000

'

'

'

'

'

Stock Issued During Period, Shares, New Issues

'

'

'

'

'

'

'

'

14,400,000

208,000

183,000

6,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Common Stock

0

199,170,000

'

'

'

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

Share Based Compensation

34,000

1,161,000

'

'

'

1,200,000

'

'

'

'

'

90,000

'

'

'

'

'

'

'

'

'

'

'

'

1,895,000

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value

'

'

'

'

'

'

'

'

'

'

'

'

'

$19.87

'

$12.22

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Repurchase Program, Price of Common Stock

'

$13.90

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum Amount of Repurchase Rights Agreement

'

$50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income_Taxes_Details

Income Taxes (Details) (USD $)	4 Months Ended	12 Months Ended	8 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012	Dec. 31, 2012
			Predecessor [Member]	Predecessor [Member]
Current:	'	'	'	'
U.S.BFederal	$0	$0	$0	'
U.S.BState	0	-179	0	'
Deferred:	'	'	'	'
U.S.BFederal	-2,757	-14	0	'
U.S.BState	0	193	0	'
Total	($2,757)	$0	$0	$154,000

Income_Taxes_Details_1

Income Taxes (Details 1)	4 Months Ended	12 Months Ended	8 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012
			Predecessor [Member]
Income Tax Rate Reconciliation [Line Items]	'	'	'
Federal statutory rate	-35.00%	-35.00%	-35.00%
State income taxes, net of federal benefit	0.00%	0.10%	0.00%
Change in valuation allowance	-2.00%	21.70%	-33.00%
Professional fees related to bankruptcy reorganization	8.00%	0.00%	17.00%
Revenue from Wapiti Trust settlement	5.00%	0.00%	0.00%
Cancellation of debt tax attribute reduction	0.00%	0.00%	51.00%
Permanent Items	0.00%	4.10%	0.00%
Provision to return adjustments	0.00%	9.10%	0.00%
Actual income tax rate	-24.00%	0.00%	0.00%

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Deferred tax assets:	'	'
Net operating loss	$540,867	$450,195
Capital loss carry forwards	26,141	26,141
Property and equipment	34,683	23,045
Investment in Piceance Energy	32,138	45,172
Derivative instruments	0	1,498
Accrued bonuses	0	0
Trust liabilitiy	1,327	0
Other	1,183	1,506
Total deferred tax assets	636,339	547,557
Valuation allowance	-633,954	-544,442
Net deferred tax assets	2,385	3,115
Deferred tax liabilities:	'	'
Property and equipment	5	0
Texadian Energy intangibles	2,380	3,083
Prepaid insurance, marketable securities and other	0	32
State liabilities	216	0
Total deferred tax liabilities	2,601	3,115
Total deferred tax liability, net	($216)	$0

Income_Taxes_Details_Textual

Income Taxes (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013
Income Taxes [Line Items]	'
Reduction in operating loss	$225,000,000
Net operating loss carryovers	1,300,000,000
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	'2032
Capital Loss carryovers, expiry year	'2016

Loss_Per_Share_Details

Loss Per Share (Details) (USD $)	4 Months Ended		12 Months Ended		8 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012
					Predecessor [Member]
Schedule Of Computation Of Basic And Diluted Earnings Per Common Share [Line Items]	'		'		'
Net loss attributable to common stockholders	($8,839)		($70,621)		($45,437)
Basic weighted-average common shares outstanding	15,734		19,740		28,841
Add: dilutive effects of stock options and unvested stock grants	0	[1]	0	[1]	0	[1]
Diluted weighted-average common stock outstanding	15,734		19,740		28,841
Basic loss per common share attributable to common stockholders:	'		'		'
Net loss	($0.56)	[1]	($3.57)	[1]	($1.57)	[1]
Diluted loss per common share attributable to common stockholders:	'		'		'
Net loss	($0.56)	[1]	($3.57)	[1]	($1.57)	[1]
[1]	Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Therefore, we have utilized the basic weighted-average common shares outstanding to calculate both basic and diluted loss per share for all parties presented.

Loss_Per_Share_Details_1

Loss Per Share (Details 1)

4 Months Ended

12 Months Ended

4 Months Ended

12 Months Ended

4 Months Ended

12 Months Ended

4 Months Ended

12 Months Ended

8 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2012

Aug. 31, 2012

Aug. 31, 2012

Aug. 31, 2012

Stock Issuable upon Conversion of Convertible Notes [Member]

Stock Issuable upon Conversion of Convertible Notes [Member]

Stock Options and Warrants

Stock Options and Warrants

Non Vested Restricted Stock [Member]

Non Vested Restricted Stock [Member]

Predecessor [Member]

Predecessor [Member]

Predecessor [Member]

Predecessor [Member]

Stock Issuable upon Conversion of Convertible Notes [Member]

Stock Options and Warrants

Non Vested Restricted Stock [Member]

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total potentially dilutive securities

0

523

0

0

0

0

0

523

1,087

379

150

558

Segment_Information_Details

Segment Information (Details) (USD $)	4 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013
Sales and operating revenues	$2,144	$886,014
Depreciation, depletion, amortization and accretion	401	5,982
Operating income (loss)	-5,021	-39,313
Loss from unconsolidated affiliate	'	-2,941
Interest expense and financing costs, net	1,056	19,471
Other income (expense)	86	808
Change in value of common stock warrants	-4,280	-10,114
Gain on derivative instruments	0	410
Loss before income taxes	-11,596	-70,621
Income tax benefit	-2,757	0
Net loss	-8,839	-70,621
Capital expenditures, including acquisitions	17,854	567,047
Refining Distribution and Marketing [Member]	'	'
Sales and operating revenues	'	778,126
Depreciation, depletion, amortization and accretion	'	2,267
Operating income (loss)	'	-19,318
Capital expenditures, including acquisitions	'	567,332
Natural Gas and Oil Operations [Member]	'	'
Sales and operating revenues	'	7,739
Depreciation, depletion, amortization and accretion	'	1,686
Operating income (loss)	'	246
Capital expenditures, including acquisitions	415	471
Commodity Marketing And Logistics [Member]	'	'
Sales and operating revenues	'	100,149
Depreciation, depletion, amortization and accretion	'	2,009
Operating income (loss)	'	9,126
Capital expenditures, including acquisitions	17,439	-1,300
Corporate and Other [Member]	'	'
Sales and operating revenues	'	0
Depreciation, depletion, amortization and accretion	'	20
Operating income (loss)	'	-29,367
Capital expenditures, including acquisitions	$0	$544

Segment_Information_Details_1

Segment Information (Details 1) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets	$827,085	$189,582
Refining Distribution and Marketing [Member]	'	'
Assets	655,712	0
Natural Gas and Oil Operations [Member]	'	'
Assets	109,316	116,034
Commodity Marketing And Logistics [Member]	'	'
Assets	52,048	62,754
Corporate and Other [Member]	'	'
Assets	$10,009	$10,794

Segment_Information_Details_Te

Segment Information (Details Textual)	4 Months Ended
	Dec. 31, 2012
Number of businsess segment	2

Related_Party_Transaction_Deta

Related Party Transaction (Details Textual)	12 Months Ended
	Dec. 31, 2013
Travel And Out Of Pocket Expense Description	'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

Reorganization_Under_Chapter_12

Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012
In Thousands, unless otherwise specified
Preconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	$1,954
Trust assets	'	'	0
Restricted cash	'	'	0
Trade accounts receivable, net	'	'	3,708
Prepaid assets	'	'	4,777
Prepaid reorganization costs	'	'	1,326
Total current assets	'	'	11,765
Preconfirmation, Oil and gas properties	'	'	'
Unproved	'	'	84
Proved	'	'	759,755
Land	'	'	4,000
Other	'	'	73,021
Total property and equipment	'	'	836,860
Less accumulated depreciation and depletion	'	'	-642,172
Property and equipment, net	'	'	194,688
Preconfirmation, Long-term assets:	'	'	'
Investments in unconsolidated affiliates	'	'	3,629
Other long-term assets	'	'	307
Total long-term assets	'	'	3,936
Total assets	'	'	210,389
Preconfirmation, Liabilities not subject to compromise	'	'	'
Debtor in possession financing	'	'	56,535
Accounts payable and other accrued liabilities	'	'	4,897
Other accrued liabilities	'	'	9,224
Accrued reorganization and trustee expense	'	'	70,656
Preconfirmation, Liabilities subject to compromise	'	'	'
3 3/4% Senior notes	'	'	115,000
7% Senior convertible notes	'	'	150,000
Accounts payable and other accrued liabilities	'	'	17,203
Total current liabilities	'	'	352,859
Preconfirmation, Liabilities not subject to compromise	'	'	'
Long - term debt	'	'	0
Derivative liabilities	'	'	0
Asset retirement obligations	3,172	512	476
Total liabilities	'	'	357,273
Preconfirmation, Stockholdersb equity	'	'	'
Common stock	'	'	288
Additional paid-in capital	'	'	1,643,285
Retained earnings (accumulated deficit)	'	'	-1,790,457
Total stockholders' equity (deficit)	'	'	-146,884
Total liabilities and equity (deficit)	'	'	210,389
Fresh Start Reporting Adjustments, Current assets	'	'	'
Trade accounts receivable, net	'	'	-1,981	[1]
Prepaid assets	'	'	-4,777	[1]
Prepaid reorganization costs	'	'	-1,326	[1]
Fresh Start Reporting Adjustments, Oil and gas properties	'	'	'
Unproved	'	'	-84	[1]
Proved	'	'	-14,776	[1]
Other	'	'	-21,289	[1]
Less accumulated depreciation and depletion	'	'	34,569	[1]
Fresh Start Reporting Adjustments, Long-term assets:	'	'	'
Investments in unconsolidated affiliates	'	'	-3,629	[1]
Other long-term assets	'	'	-253	[1]
Fresh Start Reporting Adjustments, Liabilities subject to compromise	'	'	'
Accounts payable and other accrued liabilities	'	'	-1,981	[1]
Fresh Start Reporting Adjustments, Stockholders' equity	'	'	'
Common stock	'	'	-288	[2]
Additional paid-in capital	'	'	288	[2]
Retained earnings (accumulated deficit)	'	'	-14,765	[1]
Postconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	4,882
Trust assets	'	'	3,446
Restricted cash	'	'	20,359
Trade accounts receivable, net	'	'	0
Prepaid assets	'	'	0
Prepaid reorganization costs	'	'	0
Total current assets	'	'	28,687
Postconfirmation, Oil and gas properties	'	'	'
Unproved	'	'	0
Proved	'	'	4,587
Land	'	'	0
Other	'	'	4,239
Total property and equipment	'	'	8,826
Less accumulated depreciation and depletion	'	'	0
Property and equipment, net	'	'	8,826
Postconfirmation, Long-term assets:	'	'	'
Investments in unconsolidated affiliates	'	'	105,344
Other long-term assets	'	'	54
Total long-term assets	'	'	105,398
Total assets	'	'	142,911
Postconfirmation, Liabilities not subject to compromise	'	'	'
Debtor in possession financing	'	'	0
Accounts payable and other accrued liabilities	'	'	4,897
Other accrued liabilities	'	'	2,640
Accrued reorganization and trustee expense	'	'	7,537
Postconfirmation, Liabilities subject to compromise	'	'	'
3 3/4% Senior notes	'	'	0
7% Senior convertible notes	'	'	0
Accounts payable and other accrued liabilities	'	'	12,336
Total current liabilities	'	'	19,873
Postconfirmation, Liabilities not subject to compromise	'	'	'
Long - term debt	'	'	6,335
Derivative liabilities	'	'	6,665
Asset retirement obligations	'	'	476
Total liabilities	'	'	33,349
Postconfirmation, Stockholders' equity	'	'	'
Common stock	'	'	1,477
Additional paid-in capital	'	'	108,085
Retained earnings (accumulated deficit)	'	'	0
Total stockholders' equity (deficit)	'	'	109,562
Total liabilities and equity (deficit)	'	'	142,911
Reflects Adjustments To Remaining Assets [Member]	'	'	'
Fresh Start Reporting Adjustments, Liabilities subject to compromise	'	'	'
Accounts payable and other accrued liabilities	'	'	3,200	[1]
Reflects Elimination of Predecessor Accumulated Deficit [Member]	'	'	'
Fresh Start Reporting Adjustments, Stockholders' equity	'	'	'
Additional paid-in capital	'	'	-1,636,890	[3]
Retained earnings (accumulated deficit)	'	'	1,636,890	[3]
Plan of Reorganization Adjustments [Member]	'	'	'
Preconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	74,167	[4]
Trust assets	'	'	3,446	[5]
Restricted cash	'	'	20,359	[6]
Trade accounts receivable, net	'	'	-1,727	[4]
Preconfirmation, Oil and gas properties	'	'	'
Proved	'	'	-740,392	[4]
Land	'	'	-4,000	[4]
Other	'	'	-47,493	[4]
Less accumulated depreciation and depletion	'	'	607,603	[4]
Preconfirmation, Long-term assets:	'	'	'
Investments in unconsolidated affiliates	'	'	105,344	[4]
Preconfirmation, Liabilities not subject to compromise	'	'	'
Debtor in possession financing	'	'	-56,535	[7]
Other accrued liabilities	'	'	-2,685	[8]
Preconfirmation, Liabilities subject to compromise	'	'	'
3 3/4% Senior notes	'	'	-115,000	[8]
7% Senior convertible notes	'	'	-150,000	[8]
Accounts payable and other accrued liabilities	'	'	-2,560	[4]
Preconfirmation, Liabilities not subject to compromise	'	'	'
Long - term debt	'	'	6,335	[7]
Derivative liabilities	'	'	6,665	[7]
Asset retirement obligations	'	'	-3,938	[4]
Preconfirmation, Stockholdersb equity	'	'	'
Common stock	'	'	1,457	[8]
Additional paid-in capital	'	'	100,084	[8]
Retained earnings (accumulated deficit)	'	'	166,144	[8]
Plan of Reorganization Adjustments [Member] | Reflects The Successor Drawing [Member]	'	'	'
Preconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	-45,035	[7]
Preconfirmation, Liabilities not subject to compromise	'	'	'
Other accrued liabilities	'	'	-1,500	[7]
Plan of Reorganization Adjustments [Member] | Reflects Settlement of Other Claims [Member]	'	'	'
Preconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	-24,204	[6]
Preconfirmation, Liabilities not subject to compromise	'	'	'
Other accrued liabilities	'	'	-3,845	[6]
Preconfirmation, Liabilities subject to compromise	'	'	'
Accounts payable and other accrued liabilities	'	'	-3,526	[6]
Preconfirmation, Stockholdersb equity	'	'	'
Common stock	'	'	20	[6]
Additional paid-in capital	'	'	1,318	[6]
Retained earnings (accumulated deficit)	'	'	2,188	[6]
Plan of Reorganization Adjustments [Member] | Reflects Funding of The Recovery Trusts [Member]	'	'	'
Preconfirmation, Current assets	'	'	'
Cash and cash equivalents	'	'	-2,000	[5]
Preconfirmation, Liabilities not subject to compromise	'	'	'
Other accrued liabilities	'	'	$1,446	[5]
[1]	Reflects adjustments to remaining assets due to fresh start accounting. On the Emergence Date, we adjusted the carrying value of our remaining assets to their estimated fair values. As a result of these adjustments, we recorded a loss for changes in asset fair values due to fresh start accounting adjustments within Reorganization items of approximately $14.8 million on the Predecessorbs consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
[2]	Reflects cancellation of Predecessor common stock.
[3]	Reflects elimination of Predecessor accumulated deficit.
[4]	Reflects contribution of certain of our oil and gas assets and related prepaid expenses and asset retirement obligations to Piceance Energy in exchange for cash and a 33.34% interest in Piceance Energy.
[5]	Reflects funding of the Recovery Trusts (see Note 9).
[6]	Reflects settlement of other claims with common stock of Successor and cash. On the Emergence Date, we issued 191,973 shares of our common stock to various creditors. We estimated the fair value of our common stock to be $7.0 on the Emergence Date. Accordingly, we recorded a gain on settlement of liabilities within Reorganization items of approximately $2.2 million on the Predecessorbs consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.
[7]	Reflects the Successor drawing $13 million under the Loan Agreement (see Note 6) to repay amounts outstanding under the DIP Credit Facility (see Note 6) with those proceeds and cash from contribution of assets to Piceance Energy.
[8]	Reflects extinguishment of secured debt in exchange for common stock of the Successor. On the Emergence Date, we issued 14,573,608 shares of our common stock and warrants to acquire 959,213 shares of our common stock to the holders of our secured debt or their affiliates. We estimated the fair value of our common stock to be $7.0 on the Emergence Date. Accordingly, we recorded a gain on the settlement of secured debt within Reorganization items of approximately $166.1 million on the Predecessorbs consolidated statement of operations in the period from January 1, 2012 through August 31, 2012.

Reorganization_Under_Chapter_13

Reorganization Under Chapter 11, Fresh-Start Reporting and the Effects of the Plan (Details Textual) (USD $)	4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2012	Aug. 31, 2012	Dec. 31, 2013
Reorganization [Line Items]	'	'	'
Common Stock Shares Issued	15,008,092	'	30,151,000
Class Of Warrant Or Right Number Of Securities Called By Warrants Or Rights	'	'	959,213
Share Price	$12	'	$22.30
Gains Losses On Extinguishment Of Debt	$0	'	$0
Fresh Start Adjustments Pretax Loss	'	14,800,000	'
Settlement Of Other Claims [Member]	'	'	'
Reorganization [Line Items]	'	'	'
Common Stock Shares Issued	'	191,973	'
Share Price	'	$7	'
Gains Losses On Extinguishment Of Debt	'	2,200,000	'
Secured Debt [Member]	'	'	'
Reorganization [Line Items]	'	'	'
Common Stock Shares Issued	'	14,573,608	'
Class Of Warrant Or Right Number Of Securities Called By Warrants Or Rights	'	959,213	'
Share Price	'	$7	'
Gains Losses On Extinguishment Of Debt	'	166,100,000	'
Reorganized Delta Petroleum [Member]	'	'	'
Reorganization [Line Items]	'	'	'
Line Of Credit Facility Amount Outstanding	'	13,000,000	'
Piceance Energy [Member]	'	'	'
Reorganization [Line Items]	'	'	'
Equity Method Investment Ownership Percentage	'	33.34%	33.34%
Line Of Credit Facility Amount Outstanding	'	100,000,000	90,200,000
Equity Method Investments Fair Value Disclosure	'	105,300,000	'
Piceance Energy [Member] | Laramie	'	'	'
Reorganization [Line Items]	'	'	'
Equity Method Investment Ownership Percentage	'	66.66%	'
Debtor In Possession Financing Amount Arranged	'	24,900,000	'
Piceance Energy [Member] | Reorganized Delta Petroleum [Member]	'	'	'
Reorganization [Line Items]	'	'	'
Equity Method Investment Ownership Percentage	'	33.34%	'
Debtor In Possession Financing Amount Arranged	'	$72,600,000	'

Subsequent_Events_Details_Text

Subsequent Events (Details Textual) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Jan. 23, 2014
			Subsequent Event [Member]
Subsequent Event [Line Items]	'	'	'
Common Stock Shares Authorized	500,000,000	300,000,000	'
Common stock, shares issued	30,151,000	15,008,092	301,141,520
Common Stock Par Or Stated Value Per Share	$0.01	$0.01	'
Stockholders Equity, Reverse Stock Split	'	'	'1:10 reverse stock split

Disclosures_About_Capitalized_2

Disclosures About Capitalized Costs, Costs Incurred (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2012
In Thousands, unless otherwise specified			Company [Member]	Company [Member]	Company's Share of Piceance Energy [Member]	Company's Share of Piceance Energy [Member]	Predecessor [Member]
							Company [Member]
Oil and Gas In Process Activities [Line Items]	'	'	'	'	'	'	'
Unproved properties	'	'	$0	$0	$15,763	$16,180	$84
Proved properties	4,949	4,804	4,949	4,804	168,378	134,638	759,755
Oil and Gas Property, Successful Effort Method, Gross, Total	'	'	4,949	4,804	184,141	150,818	759,839
Accumulated depreciation and depletion	'	'	-1,868	-337	-38,452	-2,808	-642,172
Oil and gas property, successful efforts method	'	'	$3,081	$4,467	$145,689	$148,010	$117,667

Disclosures_About_Capitalized_3

Disclosures About Capitalized Costs, Costs Incurred (Details 1) (USD $)	4 Months Ended	12 Months Ended	4 Months Ended		12 Months Ended		8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012
	Company [Member]	Company [Member]	Company's Share of Piceance Energy [Member]		Company's Share of Piceance Energy [Member]		Predecessor [Member]
							Company [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'		'		'
Unproved properties acquisition costs	'	'	$206		$0		'
Proved properties acquisition costs	'	'	32,519	[1]	0	[1]	'
Development costs incurred on proved undeveloped reserves	0	0	'		'		1,613
Development costs-other	0	142	291		6,380		0
Total	$0	$142	$33,016		$6,380		$1,613
[1]	Amount represents our share of proved oil and natural gas property acquired at inception of the formation of Piceance Energy of which $24.2 million relates to oil and natural gas properties purchased from Delta contemplated as part the emergence from bankruptcy and $8.3 million relates oil and natural gas properties purchased from Laramie.

Disclosures_About_Capitalized_4

Disclosures About Capitalized Costs, Costs Incurred (Details 2) (USD $)	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012	Aug. 31, 2012
			Company [Member]	Company [Member]	Company's Share of Piceance Energy [Member]	Company's Share of Piceance Energy [Member]	Predecessor [Member]	Predecessor [Member]
								Company [Member]
Revenue:	'	'	'	'	'	'	'	'
Oil and gas revenues	$2,144	$7,739	$2,144	$7,739	$6,464	$20,364	$23,079	$23,079
Expenses:	'	'	'	'	'	'	'	'
Production costs	'	'	1,688	5,696	3,033	9,885	'	16,980
Depletion and amortization	'	'	370	1,593	2,808	8,855	'	16,041
Exploration	'	'	0	0	'	'	'	2
Abandoned and impaired properties	'	'	0	0	'	'	'	151,347
Results of operations of oil and gas producing activities	'	'	86	450	623	1,624	'	-161,291
Total Company and Piceance Energy income from operations of oil and gas producing activities	'	'	'	'	$709	$2,074	'	'

Disclosures_About_Capitalized_5

Disclosures About Capitalized Costs, Costs Incurred (Details Textual) (USD $)	4 Months Ended	8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Aug. 31, 2012
Piceance Energy [Member]	'	'
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'
Proved properties acquisition costs	$24,200	'
Capitalized Exploratory Well Costs, Suspended, Percentage of Equity Interest	'	33.34%
Laramie [Member]	'	'
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'
Proved properties acquisition costs	$8,300	'

Information_Regarding_Proved_O2

Information Regarding Proved Oil and Gas Reserves (Details)	4 Months Ended		8 Months Ended		12 Months Ended
	Dec. 31, 2012		Aug. 31, 2012		Dec. 31, 2013
	MMcf		MMcf		MMcf
Reserve Quantities [Line Items]	'		'		'
Ending Balance	'		'		236,587	[1]
Proved developed reserve	65,492	[1]	'		57,907	[1]
Proved undeveloped reserve	102,371	[1]	'		178,680	[1]
Natural Gas [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Ending Balance	'		'		187,259
Proved developed reserve	48,838		'		45,734
Proved undeveloped reserve	74,258		'		141,525
Oil [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Ending Balance	'		'		820
Proved developed reserve	523		'		401
Proved undeveloped reserve	594		'		419
Natural Gas Liquids [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Ending Balance	'		'		7,401
Proved developed reserve	2,253		'		1,627
Proved undeveloped reserve	4,092		'		5,774
Company [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	1,659	[1]	'		2,163	[1]
Revisions of quantity estimate	643	[1]	'		557	[1]
Extensions and discoveries	'		'		25	[1]
Production	-139	[1]	'		-667	[1]
Ending Balance	2,163	[1]	'		2,078	[1]
Proved developed reserve	1,875	[1]	'		2,078	[1]
Proved undeveloped reserve	288	[1]	'		0	[1]
Company [Member] | Natural Gas [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0		'		446
Revisions of quantity estimate	456		'		460
Extensions and discoveries	'		'		9
Production	-10		'		-253
Ending Balance	446		0		662
Proved developed reserve	158		'		662
Proved undeveloped reserve	288		'		0
Base Pricing, before adjustments for contractual differentials	2.56	[2]	2.75	[2]	'
Company [Member] | Oil [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	277		'		286
Revisions of quantity estimate	31		'		16
Extensions and discoveries	'		'		3
Production	-22		'		-69
Ending Balance	286		277		236
Proved developed reserve	286		'		236
Proved undeveloped reserve	0		'		0
Base Pricing, before adjustments for contractual differentials	91.21	[2]	90.85	[2]	96.91	[2]
Company [Member] | Natural Gas Liquids [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0		'		0
Revisions of quantity estimate	0		'		0
Extensions and discoveries	'		'		0
Production	0		'		0
Ending Balance	0		'		0
Proved developed reserve	0		'		0
Proved undeveloped reserve	0		'		0
Base Pricing, before adjustments for contractual differentials	'		'		3.53	[2]
Company's Share of Piceance Energy [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0	[1]	'		165,700	[1]
Transfer from investees	112,639	[1],[3]	'		'
Revisions of quantity estimate	10,621	[1]	'		90,387	[1]
Extensions and discoveries	44,151	[1]	'		-6,643	[1]
Production	-1,711	[1]	'		-14,935	[1]
Ending Balance	165,700	[1]	'		234,509	[1]
Proved developed reserve	63,617	[1]	'		55,829	[1]
Proved undeveloped reserve	102,083	[1]	'		178,680	[1]
Company's Share of Piceance Energy [Member] | Natural Gas [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0		'		122,650
Transfer from investees	83,915	[3]	'		'
Revisions of quantity estimate	8,053		'		72,436
Extensions and discoveries	32,073		'		3,599
Production	-1,391		'		-12,088
Ending Balance	122,650		'		186,597
Proved developed reserve	48,680		'		45,072
Proved undeveloped reserve	73,970		'		141,525
Base Pricing, before adjustments for contractual differentials	2.56	[2]	'		'
Company's Share of Piceance Energy [Member] | Oil [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0		'		831
Transfer from investees	560	[3]	'		'
Revisions of quantity estimate	41		'		174
Extensions and discoveries	236		'		-374
Production	-6		'		-47
Ending Balance	831		'		584
Proved developed reserve	237		'		165
Proved undeveloped reserve	594		'		419
Base Pricing, before adjustments for contractual differentials	91.21	[2]	'		96.91	[2]
Company's Share of Piceance Energy [Member] | Natural Gas Liquids [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	0		'		6,345
Transfer from investees	4,228	[3]	'		'
Revisions of quantity estimate	387		'		2,818
Extensions and discoveries	1,778		'		-1,334
Production	-48		'		-428
Ending Balance	6,345		'		7,401
Proved developed reserve	2,253		'		1,627
Proved undeveloped reserve	4,092		'		5,774
Base Pricing, before adjustments for contractual differentials	'		'		3.53	[2]
Predecessor [Member] | Company [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	'		90,173	[1],[4]	'
Revisions of quantity estimate	'		512	[1]	'
Sale/disposition of properties	'		-83,770	[1],[5]	'
Production	'		-5,256	[1]	'
Predecessor [Member] | Company [Member] | Natural Gas [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	'		87,209	[4]	'
Revisions of quantity estimate	'		0		'
Sale/disposition of properties	'		-82,357		'
Production	'		-4,852		'
Predecessor [Member] | Company [Member] | Oil [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	'		494	[4]	'
Revisions of quantity estimate	'		85		'
Sale/disposition of properties	'		-235	[5]	'
Production	'		-67		'
Predecessor [Member] | Company [Member] | Natural Gas Liquids [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning Balance	'		0	[4]	'
Revisions of quantity estimate	'		0		'
Sale/disposition of properties	'		0	[5]	'
Production	'		0		'
[1]	MMcfe is based on a ratio of 6 Mcf to 1 barrel.
[2]	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.
[3]	On AugustB 31, 2012, certain reserves held by Delta Petroleum and by Laramie were transferred to Piceance Energy in exchange for a 33.34% and a 66.66% equity ownership interest, respectively (See Note 3 - Investment in Piceance Energy)
[4]	At January 1, 2012, gas is based on 70,982 MMcf of natural gas and 4,057 MBbl of natural gas liquids, with liquids converted to gas using a ratio of 4 Mcf to 1 barrel.
[5]	On August 31, 2012, substantially all of the reserves of the Company were transferred to Piceance Energy in exchange for a 33.34% equity ownership interest (See Note 4).

Information_Regarding_Proved_O3

Information Regarding Proved Oil and Gas Reserves (Details 1) (USD $)	4 Months Ended		12 Months Ended		4 Months Ended		12 Months Ended		8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2013		Aug. 31, 2012
	Company [Member]		Company [Member]		Company's Share of Piceance Energy [Member]		Company's Share of Piceance Energy [Member]		Predecessor [Member]
									Company [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'		'		'		'		'
Future net cash flows	$30,444		$26,861		$568,706		$984,205		$28,691
Future costs: Production	20,596		21,999		199,277		430,506		19,973
Future costs: Development and abandonment	319		319		154,054		234,905		319
Income taxes	0	[1]	0	[1]	0	[1]	0	[1]	0	[1]
Future net cash flows	9,529		4,543		215,375		318,794		8,399
10% discount factor	-1,519		-1,006		-143,416		-229,469		-1,176
Standardized measure of discounted future net cash flows	8,010		3,537		71,959		89,325		7,223
Total Company and Company share of equity investee in the standardized measure of discounted future net revenues	'		'		$79,969		$92,862		'
[1]	No income tax provision is included in the standardized measure calculation shown above as the Company does 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) (USD $)	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	4 Months Ended	12 Months Ended	8 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Aug. 31, 2012
			Company	Company	Company's Share of Piceance Energy [Member]	Company's Share of Piceance Energy [Member]	Predecessor [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'	'	'	'	'
Beginning of the period	$7,223	$79,969	$7,223	$8,010	$0	$71,959	$129,695
Transfer from investees	55,253	'	0	'	55,253	'	0
Sales of oil and gas production during the period, net of production costs	-4,095	-12,522	-456	-2,044	-3,639	-10,478	-5,954
Net change in prices and production costs	-806	-6,421	-667	-3,833	-139	-2,588	378
Changes in estimated future development costs	5	8,831	0	0	5	8,831	0
Extensions, discoveries and improved recovery	1,332	15,618	763	147	569	15,471	0
Revisions of previous quantity estimates, estimated timing of development and other	14,356	-4,553	648	395	13,708	-4,948	-7,439
Previously estimated development and abandonment costs incurred during the period	'	3,142	'	0	'	3,142	'
Sales/disposition of reserves in place	0	'	0	'	0	'	-118,104
Other	4,618	801	258	61	4,360	740	0
Accretion of discount	2,083	7,997	241	801	1,842	7,196	8,647
End of period	$79,969	$92,862	$8,010	$3,537	$71,959	$89,325	$7,223

Information_Regarding_Proved_O5

Information Regarding Proved Oil and Gas Reserves (Details Textual)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2011

Aug. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2012

MMcf

Piceance Energy [Member]

Piceance Energy [Member]

Natural Gas [Member]

Natural Gas Liquids [Member]

Weighted Average [Member]

Weighted Average [Member]

Reorganized Delta Petroleum [Member]

Laramie [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

Company's Share of Piceance Energy [Member]

MMcf

MBbls

Natural Gas [Member]

Natural Gas Liquids [Member]

Piceance Energy [Member]

Piceance Energy [Member]

MMcf

MMcf

MMcf

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

MMcf

MMcf

MMcf

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

MMcf

MBbls

MMcf

MMcf

MMcf

MBbls

MBbls

MBbls

MMcf

MMcf

MMcf

MBbls

MBbls

MBbls

Reserve Quantities [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest held in Piceance Energy, percentage

'

'

33.34%

33.34%

'

'

'

'

33.34%

66.66%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discount Rate Used To Present Value Future Net Revenues From Proved Reserves

'

10.00%

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proved Developed And Undeveloped Reserves Net

236,587

[1]

'

'

'

187,259

7,401

70,982

4,057

'

'

2,078

[1]

2,163

[1]

1,659

[1]

662

446

0

0

0

0

234,509

[1]

165,700

[1]

0

[1]

186,597

122,650

0

7,401

6,345

0

[1]

MMcfe is based on a ratio of 6 Mcf to 1 barrel.