Glori Energy (GLRI) Inactive 10-K12 Mar 152014 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Mar. 09, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	Glori Energy Inc.
Trading Symbol	GLRI
Entity Central Index Key	1597131
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		31,571,357
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Public Float			$146,974

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$29,751	$20,867
Accounts receivable, less allowance for doubtful accounts of $80 and $0 as of December 31, 2013 and 2014, respectively	1,371	307
Commodity derivatives	2,905	0
Prepaid expenses and other current assets	242	71
Inventory	2	24
Total current assets	34,271	21,269
Property and equipment:
Proved oil and gas properties - successful efforts	45,694	3,141
Other property and equipment	5,941	4,892
Total property and equipment and proved oil and gas properties, gross	51,635	8,033
Less: accumulated depreciation, depletion and amortization	-22,822	-5,223
Total property and equipment and proved oil and gas properties, net	28,813	2,810
Commodity derivatives	2,891	0
Deferred offering costs	0	378
Deferred loan costs	490	162
Deferred tax asset	970	0
Total assets	67,435	24,619
Current liabilities:
Accounts payable	2,251	534
Deferred revenues	653	1,753
Accrued expenses	1,792	417
Current portion of long-term debt	2,380	3,499
Current deferred tax liability	970	0
Total current liabilities	8,046	6,203
Long-term liabilities:
Long-term debt, less current portion	16,845	1,771
Other long-term liabilities	1,329	449
Total long-term liabilities	18,174	2,220
Total liabilities	26,220	8,423
Commitments and contingencies
Stockholders' equity:
Common stock, $.0001 par value, 100,000,000 shares authorized, 22,450,688 and 31,499,303 shares issued and outstanding as of December 31, 2013 and 2014, respectively	3	2
Additional paid-in capital	105,383	61,609
Accumulated deficit	-64,171	-45,415
Total stockholders' equity	41,215	16,196
Total liabilities and stockholders' equity	$67,435	$24,619

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$0	$80
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	31,499,303	22,450,688
Common stock, shares outstanding	31,499,303	22,450,688

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues:
Oil and gas revenues	$11,724	$576	$463
Service revenues	4,135	2,643	1,718
Total revenues	15,859	3,219	2,181
Operating expenses:
Oil and gas operations	10,777	2,211	1,768
Service operations	3,528	2,281	2,115
Science and technology	1,868	1,682	1,459
Selling, general and administrative	5,920	4,279	3,411
Write-off of deferred offering costs	0	126	1,492
Impairment of oil and gas properties	13,160	2,190	0
Depreciation, depletion and amortization of property and equipment	4,624	622	578
Total operating expenses	39,877	13,391	10,823
Loss from operations	-24,018	-10,172	-8,642
Other (expense) income:
Interest expense	-3,023	-959	-480
(Loss) gain on change in fair value of warrants	2,454	592	-506
Gain on commodity derivatives	6,023	0	0
Loss on change in fair value of derivative liability	0	0	-2,317
Other income (expense)	17	-70	5
Total other (expense) income, net	5,471	-437	-3,298
Net loss before taxes on income	-18,547	-10,609	-11,940
Income tax expense	209	0	0
Net (loss) income	($18,756)	($10,609)	($11,940)
Net loss per common share, basic and diluted (in dollars per share)	($0.65)	($9.61)	($11.32)
Weighted average common shares outstanding, basic and diluted	28,855	1,104	1,055

Consolidated_Statements_of_Sto

Consolidated Statements of Stockholders' Equity (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Deficit [Member]	Series C Preferred Stock [Member]	Series C Preferred Stock [Member]	Series C Preferred Stock [Member]	Series C-1 Preferred Shares And Preferred Warrants [Member]	Series C-1 Preferred Shares And Preferred Warrants [Member]	Series C-1 Preferred Shares And Preferred Warrants [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]
In Thousands, except Share data, unless otherwise specified	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)	Common Stock [Member]	Additional Paid-in Capital [Member]	USD ($)	Common Stock [Member]	Additional Paid-in Capital [Member]	USD ($)	Common Stock [Member]	Additional Paid-in Capital [Member]
							USD ($)		USD ($)	USD ($)		USD ($)	USD ($)
Beginning balance at Dec. 31, 2011	$11,111	$2	$33,975	($22,866)
Beginning balance (in shares) at Dec. 31, 2011	16,168,502	16,168,502
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock based compensation	291		291
Change in fair value of warrant liability	701		701
Conversion to common stock	227		227
Conversion to common stock (in shares)	19,680	19,680
Share issuance					11,786		11,786
Share issuance (in shares)		57,071				3,226,691
Net loss	-11,940			-11,940
Ending balance at Dec. 31, 2012	12,176	2	46,980	-34,806
Ending balance (in shares) at Dec. 31, 2012		19,414,873
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock based compensation	774		774
Change in fair value of warrant liability	1,347		1,347
Termination of derivative liability	2,329		2,329
Fair value of preferred shares in excess of proceeds	-1,938		-1,938
Conversion to common stock	17	0	17
Conversion to common stock (in shares)	79,003	79,003
Share issuance								12,100	0	12,100
Share issuance (in shares)		229,108							2,956,812
Net loss	-10,609			-10,609
Ending balance at Dec. 31, 2013	16,196	2	61,609	-45,415
Ending balance (in shares) at Dec. 31, 2013	22,450,688	22,450,688
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock based compensation	296		296
Issuance, repurchase and cancellation of common shares	-30		-30
Change in fair value of warrant liability	-2,454		-2,454
Conversion to common stock	2,000		2,000
Conversion to common stock (in shares)		250,000
Share issuance											5,049	0	5,049
Share issuance (in shares)												1,133,869
Recapitalization due to merger	34,726	1	34,725
Recapitalization due to merger (in shares)		6,658,449
Warrants exchanged for common shares (in shares)		583,010
Warrant exercises	4,188		4,188
Warrant exercises (in shares)		423,287
Net loss	-18,756			-18,756
Ending balance at Dec. 31, 2014	$41,215	$3	$105,383	($64,171)
Ending balance (in shares) at Dec. 31, 2014	31,499,303	31,499,303

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net loss
Net loss	($18,756)	($10,609)	($11,940)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization of property and equipment	4,624	622	578
Bad debt expense	0	80	0
Stock-based compensation	296	774	291
Amortization of deferred loan costs and other	439	156	57
Accretion of end-of-term charge	96	96	48
Loss on disposal of property and equipment	0	25	0
Loss (gain) on change in fair value of warrant liabilities	-2,454	-592	506
Accretion of discount on long-term debt	67	67	34
Loss on change in fair value of derivative liabilities	0	0	2,317
Unrealized gain on change in fair value of commodity derivatives	-5,796	0	0
Write-off of deferred offering costs	0	126	1,492
Impairment of oil and gas properties	13,160	2,190	0
Changes in operating assets and liabilities:
Accounts receivable	-1,087	-156	141
Prepaid expenses	-171	51	-106
Inventory	22	21	-7
Accounts payable	1,339	-125	-761
Deferred revenues	-1,100	758	362
Accrued expenses	1,135	-37	121
Net cash used in operating activities	-8,186	-6,553	-6,867
Cash flows from investing activities:
Purchase of proved oil and gas property	-41,353	-60	-1,370
Purchase of other property and equipment	-1,009	-470	-962
Net cash used in investing activities	-42,362	-530	-2,332
Cash flows from financing activities:
Proceeds from issuance of common stock, preferred stock and preferred warrants	5,019	12,118	12,038
Proceeds from issuance of long-term debt	24,035	0	7,557
Proceeds from exercise of warrants and stock options	4,188	0	0
Proceeds from merger with Infinity Corp. including private placement of common stock	38,441	0	0
Payments on long-term debt	-8,147	-2,676	-1
Payments for deferred offering costs	-3,337	-163	-534
Payments for deferred loan costs	-767	-36	0
Net cash provided by financing activities	59,432	9,243	19,060
Net increase in cash and cash equivalents	8,884	2,160	9,861
Cash and cash equivalents, beginning of period	20,867	18,707	8,846
Cash and cash equivalents, end of period	29,751	20,867	18,707
Non-cash financing and investing activities:
Contribution of capital equal to fair value of derivative due to termination of derivative liability	0	2,329	0
Fair value of preferred stock and preferred warrants in excess of proceeds	0	-1,938	0
Asset retirement obligation assumed	883	0
Issuance of preferred stock in settlement of accrued expense	0	0	170
Supplemental cash flow information:
Interest paid	$2,990	$732	$271

Organization_Nature_of_Busines

Organization, Nature of Business and Liquidity	12 Months Ended
Organization, Nature of Business and Liquidity	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Nature of Business and Liquidity	ORGANIZATION, NATURE OF BUSINESS AND LIQUIDITY

	Glori Energy Technology Inc., a Delaware corporation (formerly Glori Energy Inc.) ("GETI"), was incorporated in November 2005 (as successor in interest to Glori Oil LLC) to increase production and recovery from mature oil wells using state of the art biotechnology solutions.

	In January 2014, GETI entered into a merger and share exchange agreement with Infinity Cross Border Acquisition Corporation ("INXB") and certain of its affiliates, Glori Acquisition Corp., Glori Merger Subsidiary, Inc., and Infinity-C.S.V.C. Management Ltd., an INXB Representative. On April 14, 2014, the merger and share exchange agreement was closed and the merger was consummated. As a result of this transaction, Infinity Cross Border Acquisition Corporation merged with and into Glori Acquisition Corp., with Glori Acquisition Corp. surviving the merger. Following that merger, Glori Merger Subsidiary, Inc. merged with and into GETI, with GETI surviving the merger. Following both of these mergers (collectively referred to herein as the "Merger"), GETI became the wholly-owned subsidiary of Glori Acquisition Corp., and Glori Acquisition Corp. adopted the name "Glori Energy Inc."

	In March 2014, GETI incorporated Glori Energy Production Inc., a wholly-owned subsidiary of Glori Holdings Inc., to purchase the Coke Field Assets (see NOTE 4) and incur the associated acquisition debt.

	Glori Energy Inc., GETI, Glori Oil (Argentina) Limited, Glori Oil S.R.L., Glori Canada Ltd., Glori Holdings Inc., Glori California Inc., OOO Glori Energy and Glori Energy Production Inc. are collectively referred to as the “Company” in the consolidated financial statements.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

	Principles of Consolidation

	The accompanying consolidated financial statements include the accounts of Glori Energy Inc. and its wholly-owned subsidiaries. Intercompany balances and transactions have been eliminated in consolidation.

	Use of Estimates

	The preparation of the consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

	Cash and Cash Equivalents

	The Company considers all highly liquid investments with original maturities of three months or less when purchased to be cash equivalents.

	Concentrations of Credit Risk

	The Company maintains its cash in bank deposits with financial institutions. These bank deposits, at times, exceed Federal Deposit Insurance Corporation limits of $250,000 per depositor. The Company monitors the financial condition of the financial institutions and has not experienced any losses on such accounts. The Company is not party to any financial instruments which would have off-balance sheet credit or interest rate risk.

	The Company derived service revenues from eight customers during 2012, eleven customers during 2013, and fifteen customers during 2014. The following is a reconciliation of the customers that exceeded 10% of total service revenues in each of those periods:



			Percentage of service revenues
			Year ended December 31,
	Customer		2012			2013		2014
	A		12	%		14	%	*

	B		16	%		*		36	%

	C		15	%		—		—

	D		19	%		20	%	17	%
	E		12	%		*		—

	F		11	%		—		—

	G		*			20	%	—

	H		—			16	%	—

	I		*			—		10	%

	J		—			*		10	%

	* Revenues were less than 10% for the period.

	Management does not believe that these customers constitute a significant credit risk.

	The Company had outstanding receivables related to service revenues from seven customers as of December 31, 2013 and four customers as of December 31, 2014. The following is a reconciliation of the customers that exceeded 10% of total accounts receivable from service revenues as of each of these dates:



			Percentage of outstanding
			accounts receivable from service revenues December 31,
	Customer		2013		2014
	A		13%		—
	B		10%		—
	D		19%		—
	I		—		19%
	J		20%		—
	K		—		54%
	L		*		27%
	M		23%		—
	* Receivables were less than 10% for the period.

Oil and natural gas sales are made on a monthly basis or under short-term contracts at the current area market price. The Company would not expect that the loss of any purchaser would have a material adverse effect upon its operations. Additionally management does not believe any of our purchasers constitute a significant credit risk. For the year ended December 31, 2014, there were two purchasers that accounted for 57% and 39% of total oil revenue. For the years ended December 31, 2012 and 2013, all of the Company’s oil production was bought by a single purchaser. The Company sells its natural gas to a different purchaser than that of its oil sales. Natural gas sales did not exceeded 10% of total oil and gas revenues for the year ended 2014. Prior to 2014, the Company had no natural gas sales. At December 31, 2014, the Company had a $900,000 receivable for December oil sales from a single oil purchaser.

The Company also engages in NYMEX swaps with a third party company (See NOTE 8).

Accounts Receivable

Accounts receivable consists of amounts due in the ordinary course of business, from companies engaged in the exploration of oil and gas and from third party purchasers of the Company's oil and natural gas production. The Company performs ongoing credit evaluation of its customers and generally does not require collateral. Allowances are maintained for potential credit issues as they arise through management’s analysis of factors such as amount of time outstanding, customer payment history and customer financial condition. The Company has incurred inconsequential credit losses since inception.

Inventory

Inventory is stated at average cost and consists primarily of raw materials in the form of chemicals and finished goods that have been blended as part of the Company’s AERO nutrient system.

Oil and Natural Gas Properties

The Company follows the successful efforts method of accounting for oil and gas operations whereby the cost to acquire mineral investments in oil and gas properties, to drill successful exploratory wells, to drill and equip development wells and to install production facilities are capitalized. Certain exploration costs, including unsuccessful exploratory wells and geological and geophysical costs, are charged to operations as incurred. The Company’s acquisition and development costs of proved oil and gas properties are amortized using the units-of-production method, at the field level, based on total proved reserves and proved developed reserves as estimated by independent petroleum engineers.

Other Property and Equipment

Property and equipment are recorded at cost. Expenditures for major additions and improvements are capitalized and depreciated over the remaining useful lives of the associated assets, and repairs and maintenance costs are charged to expense as incurred. When property and equipment are retired or otherwise disposed, the cost and accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in the results of operations for the respective period.

Depreciation and amortization for long-lived assets are recognized over the estimated useful lives of the respective assets by the straight-line method as follows:



Laboratory and manufacturing facility		5 years or the remaining term of the lease, whichever is shorter

Laboratory and field service equipment, office equipment and trucks		5 years

Computer equipment		3 years

Impairment of Long-Lived Assets

The Company reviews the recoverability of its long-lived assets, such as property, equipment and oil and gas properties, when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable. The assessment of possible impairment is based on the Company’s ability to recover the carrying value of the asset or asset group from the expected future pre-tax cash flows (undiscounted) of the related operations. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, generally on a field-by-field basis for oil and gas properties. If these cash flows are less than the carrying value of such asset, an impairment loss is recognized for the difference between estimated fair value and carrying value.

The Company deferred costs incurred for a planned initial public offering (“IPO”) of common stock prior to and during 2012, including legal and other professional fees. The registration statement was withdrawn in 2012 due to market conditions, and as a result, the Company recorded a write-off of the deferred costs of $1,492,000 during 2012.

During 2013, the Company had deferred offering costs for a C-1 preferred stock offering initially planned for the fourth quarter 2013. These costs, in the amount of $126,000, were written off as the Company abandoned the offering in pursuit of alternate financing through the Merger (see NOTE 3).

The Company impaired its proved-oil and gas properties for the fiscal years ended December 31, 2013 and 2014. The Company uses a discounted future cash flow approach based on the proved and probable reserves at estimated future prices based on the futures commodities prices less regional discounts to calculate the value of the reserves at fiscal year-end to perform the impairment analysis. The write off during the fiscal year ended December 31, 2013 was the result of a decline in proved reserves on the Company’s 2013 fiscal year end reserve report from the 2012 fiscal year end reserve report for the Etzold Field. The decline arose from the Company’s decision to abandon the development of proved undeveloped reserves in the field as results indicated these reserves would be uneconomic to produce. The impairment in 2014 was a result in a sharp decline in oil prices. The reduction in asset value of proved oil and gas properties of $2,190,000 and $13,160,000 represents the impairment amounts incurred in 2013 and 2014, respectively, which are shown as impairment of oil and gas properties on the consolidated statement of operations.

Derivatives

The Company uses derivative instruments in the form of commodity price swaps to manage price risks resulting from fluctuations in commodity prices of oil associated with future production. These derivative instruments are recorded on the balance sheet at fair value as assets or liabilities and the changes in the fair value of derivatives are recorded each period in current earnings. Fair value is assessed, measured and estimated by obtaining the NYMEX futures oil commodity pricing. Gains and losses on the valuation of derivatives and settlement of matured commodity derivatives contracts are included in gain (loss) on commodity derivatives in other income within the period in which they occur.

Asset Retirement Obligation

The Company recognizes the present value of the estimated future abandonment costs of its oil and gas properties in both assets and liabilities. If a reasonable estimate of the fair value can be made, the Company will record a liability for legal obligations associated with the future retirement of long-lived assets that result from the acquisition, construction, development and/or normal operation of the assets. The fair value of a liability for an asset retirement obligation is recognized in the period in which the liability is incurred. The fair value is measured using expected future cash outflows (estimated using current prices that are escalated by an assumed inflation rate) discounted at the Company’s credit-adjusted risk-free interest rate. The liability is then accreted each period until it is settled or the asset is sold, at which time the liability is reversed and any gain or loss resulting from the settlement of the obligation is recorded. The initial fair value of the asset retirement obligation is capitalized and subsequently depreciated or amortized as part of the carrying amount of the related asset. The Company has recorded asset retirement obligations related to its oil and gas properties. There are no assets legally restricted for the purpose of settling asset retirement obligations.

Financial Instruments

Financial instruments consist of cash and cash equivalents, accounts receivable, accounts payables, long-term debt, derivatives, and warrants. The carrying values of cash and cash equivalents and accounts receivable and payables approximate fair value due to their short-term nature. Derivatives are recorded at fair value (see NOTE 7 and NOTE 8).

Net Loss Per Share

Basic net loss per share is computed using the weighted-average number of shares of common stock outstanding during the period. In periods that have income, basic net earnings per common share is computed under the two-class method per guidance in Accounting Standards Codification (ASC) 260, Earnings per Share. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock and participating security according to dividends declared (or accumulated) and participation rights in undistributed earnings. Under the two-class method, basic earnings per common share is computed by dividing net earnings attributable to common shares after allocation of earnings to participating securities by the weighted-average number of common shares outstanding during the year. However, in periods of net loss, participating securities other than common stock are not included in the calculation of basic loss per share because there is no contractual obligation for owners of these securities to share in the Company’s losses, and the effect of their inclusion would be anti-dilutive. Diluted earnings (loss) per common share is computed using the two-class method or the if-converted method, whichever is more dilutive (see NOTE 10).

Diluted net loss per share is the same as basic net loss per share for all periods presented because any potentially dilutive common shares were anti-dilutive. Such potentially dilutive shares are excluded from the computation of diluted net loss per share when the effect would be to reduce net loss per share. Therefore, in periods when a loss is reported, the calculation of basic and diluted loss per share results in the same value.

Revenue Recognition

Oil and natural gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectibility of the revenue is probable. Revenues from natural gas production are recorded using the sales method. When sales volumes exceed the Company’s entitled share, production imbalance occurs. If production imbalance exceeds the Company’s share of the remaining estimated proved natural gas reserves for a given property, the Company records a liability. The Company has no significant gas imbalances as of December 31, 2013 and 2014.

Service revenues are recognized when all services are concluded in accordance with the contract. The Company’s service contracts typically include a single contract for each phase of service. During the initial phase known as Reservoir Analysis and Treatment Design (the “Analysis Phase”), the Company samples the target field and evaluates project feasibility and nutrient formulation by assessing field characteristics such as geology, microbial environment and geochemistry of the oil and water. The completion of the Analysis Phase contract typically coincides with the delivery of a report of findings to the customer at which point the Analysis Phase revenues are recognized. Once the viability of the AERO System is demonstrated in the Analysis Phase, a new contract is executed for the Field Deployment Phase. During the Field Deployment Phase the AERO System is initiated in the oil field to stimulate the indigenous microbes in the oil bearing reservoir. The Field Deployment Phase revenues are recognized ratably over the Field Deployment Phase injection work timeline.

Previous to 2014, the majority of the Company’s revenues for AERO services were executed under a single contract which covered both Analysis Phase and Field Deployment Phase work. The single contract for both services resulted in lack of commercial evidence that the Analysis Phase services provided value on a stand-alone basis and thus both services were viewed as a single unit-of-accounting under ASC 605, Revenue Recognition: Multiple-Element Arrangements. In accordance with this guidance, the Company deferred revenue received in the Analysis Phase and recognize this revenue and the Field Deployment Phase revenue uniformly over the Field Deployment Phase injection timeline. Any termination of the project after the completion of the Analysis Phase would result in the immediate recognition of that portion of the revenues outlined in the contract.
As of December 31, 2013 and 2014, the Company had deferred revenues of approximately $1,753,000 and $653,000 respectively, pursuant to contracts requiring substantial future performance.

Science and Technology

The Company expenses all science and technology costs as incurred. The science and technology work performed predominantly relates to the Analysis Phase and the fees are primarily made up of employee compensation, lab supplies and materials, legal fees, and corporate overhead allocations.

Income Taxes

The Company accounts for income taxes using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and to net operating loss carry forwards, measured by enacted tax rates for years in which taxes are expected to be paid, recovered or settled. A valuation allowance is established to reduce deferred tax assets if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred tax assets will not be realized.

The Company follows ASC 740, Income Taxes (“ASC 740”), which creates a single model to address accounting for the uncertainty in income tax positions and prescribes a minimum recognition threshold a tax position must meet before recognition in the consolidated financial statements.

The Company’s tax years 2005 through 2014 remain open and subject to examination by the Internal Revenue Service (“IRS”) and are open for examination until the expiration of statute of limitations under the IRS Code.

Stock-Based Compensation

Since the initiation of the 2006 Stock Option and Grant Plan, the Company has recorded all share-based payment expense associated with option awards in accordance with ASC 718, Compensation - Stock Compensation. Accordingly, the Company selected the Black-Scholes option-pricing model as the most appropriate method to value option awards and recognizes compensation cost, as determined on the grant date, on a straight-line basis over the option awards’ vesting period.
Fair Value of Financial Instruments

FASB standards define fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. The standard also establishes a fair value hierarchy that requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair value:
Level 1 – Quoted prices in active markets for identical assets or liabilities.

Level 2 – Observable inputs other than Level 1 prices, such as quoted prices for similar assets or liabilities; or other inputs that are observable or can be corroborated by observable market data.

Level 3 – Unobservable inputs that are supported by little or no market activity and that are financial instruments whose values are determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant judgment or estimation.

If the inputs used to measure the financial assets and liabilities fall within more than one level described above, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument.

Accounting for Sales Tax

The Company uses the net method for accounting for sales taxes charged to customers and accordingly does not include sales or similar taxes as revenues; the Company does include sales and similar taxes paid as part of the cost of goods or services acquired.

Deferred Offering Costs

The Company has capitalized certain costs such as legal fees incurred related to the merger with Infinity Cross Border Acquisition Group (see NOTE 3).

Reclassifications

Certain 2012 and 2013 amounts related to oil and gas revenues, service revenues, oil and gas operations, service operations and depreciation, depletion and amortization have been reclassified for comparative purposes.

Merger_with_Infinity_Cross_Bor

Merger with Infinity Cross Border Acquisition Corporation	12 Months Ended
Merger with Infinity Cross Border Acquisition Corporation	Dec. 31, 2014
Business Combinations [Abstract]
Merger with Infinity Cross Border Acquisition Corporation	MERGER WITH INFINITY CROSS BORDER ACQUISITION CORPORATION

	On January 8, 2014, GETI executed the Merger with Infinity Cross Border Acquisition Corporation (“Infinity Corp.” - a special purpose acquisition company or blank check company publicly traded on NASDAQ) and certain of its affiliates. On April 14, 2014, the Merger was consummated. Pursuant to the terms of the Merger, in exchange for all of GETI's outstanding shares and warrants, Infinity Corp. issued 23,584,557 shares of common stock on a pro rata basis to the stockholders and warrant holders of GETI. GETI obtained effective control of Infinity Corp. subsequent to the Merger and thus the Merger was accounted as a reverse acquisition and recapitalization of GETI in accordance with ASC 805 - Business Combinations. Subsequent to the Merger, the GETI shareholders retained a substantial majority of voting interest and positions on the Board of Directors. Additionally GETI's management is retained and GETI's operations comprise the ongoing operations post-Merger.

	In the consolidated financial statements, the number of shares of common stock attributable to the Company is reflected retroactive to January 1, 2012 to facilitate comparability to prior periods. Accordingly, the number of shares of common stock presented as outstanding as of January 1, 2012 totals 16,168,502 which represents the number of common shares that were received for pre-Merger GETI preferred stock, common stock and warrants as of January 1, 2012.

	The following table (in thousands, except share amounts) presents the consolidated statements of temporary equity and stockholders' equity as if the Merger had occurred on January 1, 2012. The beginning balances as of January 1, 2012, shown in the table below, represent the Company's pre-Merger temporary equity and stockholders' equity previously stated as of January 1, 2012. The balances as of January 1, 2012, as converted, represent the post-Merger stockholders' equity received in exchange for the pre-Merger temporary equity and stockholders' equity at January 1, 2012.



		Temporary equity - convertible redeemable preferred stock																					Stockholders' equity


																				Total								Additional						Total
		Series A Preferred					Series B Preferred					Series C Preferred					Series C-1 Preferred			temporary			Common stock					paid-in			Accumulated			stockholders'
		Shares		Amount			Shares		Amount			Shares		Amount			Shares	Amount		equity			Shares		Par value			capital			deficit			equity
	Balances as of January 1, 2012	475,541		$	12,709		2,901,052		$	21,990		28,776,041		$	7,888		—	$	—	$	42,587		3,009,592		$	1		$	—		$	(31,477	)	$	(31,476	)
	Balances as of January 1, 2012	475,541		$	12,709		2,901,052		$	21,990		28,776,041		$	7,888		—	$	—	$	42,587		3,009,592		$	1		$	—		$	(31,477	)	$	(31,476	)
	Reversal of pre-Merger temporary equity	(475,541	)	(12,709		)	(2,901,052	)	(21,990		)	(28,776,041	)	(7,888		)	—	—		(42,587		)	—		—			—			42,587			42,587
	Reversal of pre-Merger temporary equity	(475,541	)	(12,709		)	(2,901,052	)	(21,990		)	(28,776,041	)	(7,888		)	—	—		(42,587		)	—		—			—			42,587			42,587
	Reversal of pre-Merger common shares	—		—			—		—			—		—			—	—		—			(3,009,592	)	(1		)	1			—			—
	Reversal of pre-Merger common shares	—		—			—		—			—		—			—	—		—			(3,009,592	)	(1		)	1			—			—
	Conversion of pre-Merger shares to post Merger shares	—		—			—		—			—		—			—	—		—			16,168,502		2			(2		)	—			—
	Conversion of pre-Merger shares to post Merger shares	—		—			—		—			—		—			—	—		—			16,168,502		2			(2		)	—			—
	Segregate historical accumulated deficit from additional paid-in capital	—		—			—		—			—		—			—	—		—			—		—			33,976			(33,976		)	—
		—		—			—		—			—		—			—	—		—			—		—			33,976			(33,976		)	—
	Balances as of January 1, 2012, as converted	—		$	—		—		$	—		—		$	—		—	$	—	$	—		16,168,502		$	2		$	33,975		$	(22,866	)	$	11,111
	Balances as of January 1, 2012, as converted	—		$	—		—		$	—		—		$	—		—	$	—	$	—		16,168,502		$	2		$	33,975		$	(22,866	)	$	11,111

	Not shown in the above table is the pre-Merger issuance by GETI of common shares, preferred shares and warrants. On January 19, 2012, GETI issued 4,420,566 C preferred shares. These shares were exchanged for 3,226,691 shares of common stock in the Merger. During 2012, there were 57,071 common shares issued which were exchanged for 19,680 shares of common stock in the Merger. On April 30, 2013, GETI issued 4,462,968 C-1 preferred shares and 3,975,718 C-1 preferred warrants. These shares and warrants were exchanged for 2,956,812 shares of common stock in the Merger. During 2013, there were 229,108 common shares issued which were exchanged for 79,003 shares of common stock in the Merger. On March 13, 2014, GETI issued 1,842,028 C-2 preferred shares and 1,640,924 C-2 preferred warrants. These shares and warrants were exchanged for 1,133,869 shares of common stock in the Merger.
	The following table shows the number of common stock of the Company issued and outstanding related to the consummation of the Merger:



					Number of Shares


	Ordinary shares issued to Infinity Corp. founder shareholders				1,437,500
					1,437,500
	Ordinary shares issued to Infinity Corp. shareholders				5,750,000
	Ordinary shares issued to Infinity Corp. shareholders				5,750,000
	Less: Ordinary shares redeemed				(2,351,533	)
	Ordinary shares issued underwriter for UPO warrant conversion				100,000
					100,000
	Ordinary shares issued for PIPE Investment (excluding Petro-Hunt portion of the PIPE Investment)				812,500
					812,500
	Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)				250,000
					250,000
	Ordinary shares issued for the optional PIPE Investment				909,982
	Ordinary shares issued for the optional PIPE Investment				909,982
	Ordinary shares issued to Glori Energy Inc. shareholders				23,584,557
	Ordinary shares issued to Glori Energy Inc. shareholders				23,584,557
					30,493,006
					30,493,006

	In connection with the Merger, the Company received approximately $24.7 million, net of certain expenses and fees, and approximately $13.7 million in cash from the private placement of 1,722,482 shares of common stock at $8.00 per share from Infinity Group, Hicks Equity Partners LLC and other investors. All of GETI’s previously outstanding common shares, preferred shares and warrants were exchanged for approximately 23,584,557 common shares in the newly merged entity, and accordingly, the Company no longer has liabilities for the fair value of such warrants and temporary equity previously reported in the Company's consolidated balance sheets. Additionally on April 14, 2014 Petro-Hunt L.L.C. ("Petro-Hunt") exercised its option to convert their $2.0 million receivable from the Company to common shares at $8.00 per share or 250,000 shares (see NOTE 9).

	In addition to the common stock issued in the Merger the Company has 5,321,700 warrants outstanding at December 31, 2014 to purchase common stock of the Company at a per share price of $10 which expire on July 19, 2017.

Property_and_Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property and Equipment	PROPERTY AND EQUIPMENT

	Property and equipment consists of the following (in thousands):


		December 31,
		2013				2014

	Proved oil and gas properties - successful efforts	$	3,141			$	45,694

	Construction in progress	902				589

	Laboratory and warehouse facility	591				640

	Laboratory and field service equipment	2,968				3,158

	Office equipment, computer equipment, vehicles and other	431				1,554

		8,033				51,635


	Less: accumulated depreciation, depletion and amortization (1)	(5,223		)		(22,822		)
	Total property and equipment, net	$	2,810			$	28,813

	(1) Includes impairment and excludes accretion of asset retirement obligation.

	Depreciation, depletion and amortization consists of the following (in thousands):


		Year ended December 31,
		2012				2013				2014
	Depreciation and amortization expense	$	457			$	426			$	523

	Depletion expense	103				177				3,960

	Accretion of asset retirement obligation	18				19				141

	Total depreciation, depletion, and amortization of property and equipment	$	578			$	622			$	4,624


	On March 14, 2014, a subsidiary of the Company, Glori Energy Production Inc., acquired certain oil, gas and mineral leases in Wood County Texas (the “Coke Field Assets”) from Petro-Hunt L.L.C. (“Petro-Hunt”) for (i) $38.0 million in cash and a $2.0 million convertible note payable (see NOTE 9) to Petro-Hunt, subject to certain purchase price adjustments primarily for net revenues in excess of direct operating expenses of the property from January 1, 2014 through the closing date, March 14, 2014, and (ii) the assumption of the asset retirement obligation related to plugging and abandoning the Coke Field Assets.

	Of the total $39.2 million total purchase price of the Coke Field Assets, the Company recognized, at approximate fair market value, assets such as office equipment and trucks included in property and equipment on the Company’s consolidated balance sheet of approximately $310,000 and items such as tubular stock of $327,000 classified in other property and equipment on the Company’s consolidated balance sheet. The remaining purchase price balance was allocated to proved oil and gas properties in property and equipment on the Company’s consolidated balance sheet. Also included in proved oil and gas properties, the Company recognized an asset associated with the asset retirement obligation (plugging and abandonment of wells) of $745,000 and an offsetting liability included in other long-term liabilities on the Company’s consolidated balance sheet.

	In September 2014, the Company purchased additional oil, gas and mineral leases adjacent to the Coke Field Assets (the "Southwest Operating Assets"). The Company purchased the Southwest Operating Assets for $2,000,000 and assumed an asset retirement obligation of an estimated $138,000.

	The Company has included revenues and expenses related to the Coke Field Assets for the period from March 14 through December 31, 2014 in the consolidated statement of operations for the year ended December 31, 2014 and for the acquisition of the Southwest Operating Assets September 1 through December 31, 2014. For this period, the revenues and net loss attributable to the Coke Field Assets and Southwest Operating Assets were $11,398,000 and $(7,061,000), respectively. The net loss includes a $6,023,000 gain on commodity derivatives related to the Company's volume based production swaps (see NOTE 8) and loss on impairment of oil and gas properties of $12,707,000.


	The following summary presents unaudited pro forma information for the Company for the year ended December 31, 2013 and 2014, as if the Coke Field acquisition had been consummated at January 1, 2012, 2013 and 2014, respectively (in thousands, except per share amounts):



		Year ended December 31,
		2012				2013				2014

	Total revenues	$	13,270			$	14,308			$	18,604

	Net loss	(10,528		)		(9,197		)		(19,111		)

	Net loss per common shares, basic and diluted	$	(9.98	)		$	(8.33	)		$	(0.66	)

	Weighted average shares outstanding:

Basic	1,055				1,104				28,855

Diluted	1,055				1,104				28,855

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	ASSET RETIREMENT OBLIGATION

	The Company accounts for its asset retirement obligation (“ARO”) in accordance with ASC 410, Asset Retirement and Environmental Obligations. The ARO liability reflects the estimated present value of the amount of dismantlement, removal, site
	reclamation, and similar activities associated with our oil and gas properties. The fair value of a liability for an ARO is required to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made and the associated retirement costs can be capitalized as part of the carrying amount of the long-lived asset. The Company determined its ARO by calculating the present value of the estimated cash flows related to the liability based upon estimates derived from management and external consultants familiar with the requirements of the retirement, and the ARO is reflected in the accompanying consolidated balance sheets as an other long-term liability. The Company has not funded nor dedicated any assets to the retirement obligation.

	The liability is periodically adjusted to reflect (1) new liabilities incurred; (2) liabilities settled during the period; (3) accretion expense; and (4) revisions to estimated future plugging and abandonment costs.

	The following is a reconciliation of the liability as of December 31, 2013 and 2014 (in thousands):



		December 31,
		2013		2014
	Balance at the beginning of period	$	228	$	305

	Liabilities acquired during the period	—		883

	Accretion expense	19		141

	Revision in expected cash flows	58		—

	Balance at the end of the period	$	305	$	1,329

Accrued_Expenses

Accrued Expenses	12 Months Ended
	Dec. 31, 2014
Payables and Accruals [Abstract]
Accrued Expenses	ACCRUED EXPENSES

	As of December 31, 2013 and 2014, the significant components of accrued expenses reported in the accompanying consolidated balance sheets are as follows (in thousands):



		December 31,
		2013		2014
	Accrued compensation and benefits	$	158	$	892

	Accrued end-of-term charge (See Note 9)	—		240

	Accrued interest	46		15

	Accrued taxes	46		223

	Accrued legal and professional fees	61		—

	Accrued royalties	—		164

	Accrued other	106		258

		$	417	$	1,792

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS

	The following table summarizes the financial assets measured at fair value, on a recurring basis as of December 31, 2014 (in thousands):


		Fair value measurements using
		Level 1		Level 2		Level 3		Total
	December 31, 2014
	Short-term commodity derivatives, asset	$	—	$	2,905	$	—	$	2,905

	Long-term commodity derivatives, asset	—		2,891		—		2,891

		$	—	$	5,796	$	—	$	5,796


	The Level 2 instruments presented in the table above consists of derivative instruments made up of commodity price swaps. The fair values of the Company's commodity derivative instruments are based upon the NYMEX futures value of oil less the contracted per barrel rate to be received. The Company records a liability associated with the futures contracts when the futures price of oil is greater than the contracted per barrel rate to be received and an asset when the futures price of oil is less than the contracted per barrel rate to be received.

Derivative_Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS

	The Company utilizes derivative financial instruments to manage risks related to changes in oil prices. The Company is currently engaged in oil commodity price swaps where a fixed price is received for a portion of the Company's oil production. In return, the Company pays a floating price based upon NYMEX oil prices. Although these arrangements are designed to reduce the downside risk of a decline in oil prices on the covered production, they conversely limit potential income from increases in oil prices and expose the Company to the credit risk of counterparties. The Company manages the default risk of counterparties by engaging in these agreements with only high credit quality multinational energy companies and through the continuous monitoring of their performance.

	As of December 31, 2014 the Company had the following open positions on its outstanding commodity derivative contracts:



	Period	Volume/Month (Bbls)		Price/Unit		Fair Value - Asset


	January 2015 - March 2015	8,400		$	94.11	1,013,000

	April 2015 - March 2016	7,300		$	86.5	2,447,000

	April 2016 - March 2017	6,550		$	82.46	1,421,000

	April 2017 - March 2018	5,800		$	80.53	915,000


	The derivative contracts are carried at fair value on the consolidated balance sheet as assets or liabilities. The Company has not elected to designate any of these as derivative contracts for hedge accounting. Accordingly, for each reporting period the contracts are marked-to-market and the resulting unrealized changes in the fair value of the assets and liabilities are recognized on the consolidated statements of operations. The payables and receivables resulting from the closed derivative contracts result in realized gains and losses recorded on the Company's consolidated statements of operations. The unrealized and realized gains and losses on derivative instruments are recognized in the gain on commodity derivatives line item located in other (expense) income. As of December 31, 2014 the Company had a current asset for commodity derivatives of $2,905,000 and a long-term asset for commodity derivatives of $2,891,000.

	The following tables summarize the unrealized and realized gain on commodity derivatives (in thousands):



			Year ended December 31,
			2014
	Unrealized gain on commodity derivatives		5,796

	Realized gain on commodity derivatives		227

			6,023

Long_Term_Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long Term Debt	LONG TERM DEBT

	On June 11, 2012, the Company entered into a secured term promissory note in the amount of $8.0 million. The note contains a 10.0% annual interest rate subject to increase based upon an increase in the prime rate. The loan is secured by substantially all assets of the Company, with the exception of the Coke Field Assets. The lender also received a warrant to purchase shares of the Company’s stock, which was exchanged for 18,208 common shares upon consummation of the Merger. Equal monthly principal payments are due over 27 months beginning in April 2013 through June 2015, plus an end of term charge of $280,000. As of December 31, 2013 and 2014, the ratable liability for the end of term charge was $144,000 and $240,000, respectively, and it is included in other long-term liabilities and accrued expenses in current liabilities on the accompanying 2013 and 2014 consolidated balance sheets, respectively. The loan agreement contains covenants which place restrictions on the incurrence of debt, liens and capital expenditures. As of December 31, 2013 and December 31, 2014 the outstanding loan balance was $5,238,000 and $1,750,000, respectively. The Company is in compliance with all the covenants as of December 31, 2014. Subsequent to December 31, 2014, all remaining principal and interest on the note was paid (See NOTE 16).

	On March 14, 2014 in connection with the closing of the acquisition of the Coke Field Assets, the Company entered into two financing agreements of $18.0 million and $4.0 million in order to fund a portion of the $38.0 million in cash required for the acquisition.

	The $18.0 million note is a senior secured term loan facility of Glori Energy Production Inc. and is secured by the Coke Field Assets and shares of common stock of Glori Energy Production Inc. The loan has a three year term bearing interest at 11.0% per annum, subject to increase upon a LIBOR rate increase above 1%. The credit agreement requires quarterly principal payments equal to 50% of the excess cash flows, as defined, from the Coke Field Assets during the first year and 75% thereafter subject to a minimum quarterly principal payment of $112,500 plus interest.
	The loan was funded net of closing costs of 2%, or $360,000, which is included in deferred loan costs on the consolidated balance sheets and is being amortized over the loan term. The loan agreement contains covenants which place restrictions on Glori Energy Production’s ability to incur additional debt, incur other liens, make other investments, capital expenditures and the sale of assets.

	Commencing with the quarter ended June 30, 2014, Glori Energy Production is also required to maintain certain financial ratios related to debt, working capital and proved reserves, all as defined in the loan agreement. In May and November of each year, in accordance with a procedure outlined in the loan agreement, the value of the collateral securing the note is redetermined based on engineering reserve reports submitted by Glori Energy Production. As of December 31, 2014, the outstanding loan balance was $17,428,000. Glori Energy Production Inc. is in compliance with all covenants as of December 31, 2014.

	The $4.0 million note has a two year term bearing interest at 12.0% per annum and is secured by the assets of the Company but is subordinated to existing Company debt. The loan was funded net of closing costs of 2%, or $80,000, which were initially included in deferred loan costs on the consolidated balance sheet. The $4.0 million note principal and a $400,000 prepayment penalty plus accrued interest was paid in full on May 13, 2014, and the related remaining deferred loan costs were expensed.

	On March 14, 2014, in connection with the purchase of the Coke Field Assets, a subsidiary of the Company, Glori Energy Production Inc., issued to Petro-Hunt an unsecured, subordinated convertible promissory note for $2.0 million bearing interest at 6.0% per annum. On April 14, 2014 the note was converted into 250,000 shares of post-Merger common stock.

	Maturities on long-term debt during the next three years are as follows (in thousands):



	Year ended December 31,	Amount

	2015	$	2,380

	2016	472

	2017	16,373

		$	19,225

Loss_Per_Share

Loss Per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Loss Per Share	LOSS PER SHARE

	The Company follows current guidance for share-based payments which are considered as participating securities. Share-based payment awards that contain non-forfeitable rights to dividends, whether paid or unpaid, are designated as participating securities and are included in the computation of basic earnings per share. However, in periods of net loss, participating securities other than common stock are not included in the calculation of basic loss per share because there is not a contractual obligation for owners of these securities to share in the Company’s losses, and the effect of their inclusion would be anti-dilutive.

	The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share data):



		Year ended December 31,
		2012				2013			2014

	Numerator:

	Net loss	$	(11,940	)		$	(10,609	)	$	(18,756	)

	Denominator:

	Weighted-average common shares outstanding - basic	1,055				1,104			28,855

	Effect of dilutive securities	—				—			—

	Weighted-average common shares - diluted	1,055				1,104			28,855


	Net loss per common share - basic and diluted	$	(11.32	)		$	(9.61	)	$	(0.65	)

	The following weighted average securities outstanding during the periods below were not included in the calculation of diluted shares outstanding as they would have been anti-dilutive (in thousands):



		Year ended December 31,
		2012			2013			2014

	Common stock warrants	—			—			4,895

	Common stock options	1,738			1,898			2,311

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES

	At December 31, 2013 and 2014, the Company had operating loss carryforwards for federal income tax reporting purposes of approximately $36.9 million and $51.9 million, respectively, which will begin to expire in the year 2025, net operating losses for state income tax reporting purposes of approximately $5.3 million and $5.7 million, respectively, which will begin to expire in 2021, and tax credits of approximately $450,000 which will begin to expire in 2027. The Net Operating Loss ("NOL") carry forward has been reduced by approximately $5.4 million because management estimates such amount of the loss carry forwards will expire due to limitations from changes in control.

	Income tax benefit for the periods presented differs from the U.S. Federal benefit calculated at the statutory income tax rate due to the following (in thousands):



		Year ended December 31,
		2012				2013			2014

	Federal benefit at statutory income tax rate	$	(4,059	)		$	(3,607	)	$	(6,692	)
	R&D credits	—				(118		)	(83		)

	Non-deductible (taxable) expenses & other items	596				(17		)	(380		)

	State income taxes - net of federal benefit	(25		)		(19		)	(221		)
	Foreign income taxes	—				—			209

	Embedded derivative cancellation	—				797			—

	Change in valuation allowance	3,488				2,964			7,376

	Taxes on income	$	—			$	—		$	209


	The tax effects of temporary differences that give rise to significant portions of the Company’s net deferred tax assets at December 31, 2013 and 2014 are as follows (in thousands):



		Year ended December 31,
		2013				2014

	Current deferred tax asset

	Deferred revenue and other	$	410			$	248

	Allowance for doubtful accounts	27				—

		437				248

	Less Valuation allowance	(437		)		(225		)
		—				23


	Current deferred tax liability

	Current portion of swap asset	—				993


	Current deferred tax liability, net	—				970


	Non-current deferred tax asset

	NOL carryforwards (long-term)	10,737				16,077

	R&D credits	367				450

	Other accrued expenses	22				—

	Stock compensation	129				154

	Depreciable property basis	556				740

Oil and gas properties	104				4,040

	11,915				21,461

Less Valuation allowance	(11,915		)		(19,503		)
	—				1,958


Non-current deferred tax liability

Non-current portion of swap asset	—				988

Non-current deferred tax asset, net	—				970


Total deferreds, net	$	—			$	—


The provision (benefit) for income taxes from continuing operations for the periods indicated are comprised of the following (in thousands):


	Year ended December 31,
	2013				2014

Current tax provision (benefit):
Federal	—				—

Foreign	—				209

State	—				—

Total	$	—			$	209


Deferred tax provision (benefit):
Federal	—				—

Foreign	—				—

State	—				—

Total	$	—			$	—


Total tax provision (benefit):
Federal	—				—

Foreign	—				209

State	—				—

Total	$	—			$	209


The valuation allowance for deferred tax assets increased by $7.4 million in 2014. In determining the carrying value of a deferred tax asset, accounting standards provide for the weighing of evidence in estimating whether and how much of a deferred tax asset may be recoverable. As we have incurred net operating losses in 2014 and prior years, relevant accounting guidance suggests that cumulative losses in recent years constitute significant negative evidence, and that future expectations about income are insufficient to overcome a history of such losses. Therefore, with the before-mentioned adjustment of $7.4 million, we have reduced the carrying value of our net deferred tax asset to zero. The valuation allowance has no impact on our net operating loss position for tax purposes, and if we generate taxable income in future periods, we will be able to use our NOLs to offset taxes due at that time. We will continue to assess the valuation allowance against deferred tax assets considering all available evidence obtained in future reporting periods.

Internal Revenue Code Section 382 places a limitation (the “Section 382 Limitation”) on the amount of taxable income that can be offset by an NOL after a change in control (typically, a greater than 50% change in ownership) of a loss corporation. Generally, after a control change, loss corporations cannot deduct NOL carryforwards in excess of the Section 382 Limitation.

Management believes that the issuance of Series B Preferred Stock on October 15, 2009 has resulted in the Section 382 Limitation, and thereby the federal net operating loss carryovers have been reduced by the estimated effect.

As of December 31, 2013 the Company had an uncertain tax position related to not filing Form 926 Return by a U.S. Transferor of Property to a Foreign Corporation in the amount of approximately $31,000, for the tax years 2010 and 2011 and these forms would have reported cash transfers to support the operations of its subsidiary Glori Oil S.R.L. The Company has amended these returns and believes any liability will be abated and no longer has an uncertain tax position; accordingly, the Company has not recognized any liability in the accompanying consolidated financial statements. The Company does not expect a material change to the consolidated financial statements related to uncertain tax positions in the next 12 months. The Company recognizes interest and penalties accrued related to unrecognized tax benefits in income tax expense.

Employee_Retirement_Savings_Pl

Employee Retirement Savings Plan	12 Months Ended
Employee Retirement Savings Plan	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Employee Retirement Savings Plan	EMPLOYEE RETIREMENT SAVINGS PLAN

	The Company sponsors an employee retirement saving plan (the “401(k) Plan”) that is intended to qualify under Section 401(k) of the Internal Revenue Code. The 401(k) Plan is designed to provide eligible employees with an opportunity to make regular voluntary contributions into a long-term investment and saving program. There is no minimum age or service requirement to participate, and the Company may make discretionary matching contributions. For the years ended December 31, 2012 and 2013, the Company made no discretionary matching contributions. For the year ended December 31, 2014 the Company made matching contributions of $67,000.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES

	Litigation

	From time to time, the Company may be subject to legal proceedings and claims that arise in the ordinary course of business. The Company is not a party to any material litigation or proceedings and is not aware of any material litigation or proceedings, pending or threatened against it.

	Commitments

	The Company leases two buildings in Houston, Texas and a warehouse facility in Gull Lake, Saskatchewan under operating leases. The Company has a two-year lease agreement for 7,805 square feet of office space in Houston's Westchase District for $18,498 per month, with a one-year extension option at a 4% increase in rent and two one-year extension options at a to be mutually agreed upon market rate with the lessor. The Company's original Houston building lease, which contains office space, warehouse space and a laboratory, expires in May 2017 and is leased for $10,586 per month. The Saskatchewan warehouse is a month-to-month lease which rents for $1,000 per month CDN and is cancelable with 30 days’ notice.

	Approximate minimum future rental payments under these noncancelable operating leases as of December 31, 2014 are as follows (in thousands):


		Year ended December 31,

	2015	$	356

	2016	295

	2017	53

		$	704


	Total rent expense for the years ended December 31, 2012, 2013, and 2014, was $181,000, $265,000, and $291,000, respectively.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	STOCK-BASED COMPENSATION

	Stock Incentive Plan

	As a result of the Merger with Infinity Corp. which consummated on April 14, 2014, the issued and outstanding stock options were canceled and reissued as stock options in the newly merged entity at a conversion ratio of 2.9 to 1.0 pre-Merger stock options to post-Merger stock options. The exercise price of the Glori stock options also increased by the same factor of 2.9. All option disclosures in the note below are shown as converted using these factors. As of December 31, 2013, the total common stock available for issuance pursuant to the Glori Oil Limited 2006 Stock Option and Grant Plan (the “Plan”) was 2,581,190, as converted. As of April 14, 2014, the plan was amended such that no further options would be issued.

	In December 2014, the Company approved the adoption of the 2014 Long Term Incentive Plan ("the 2014 Plan") which authorized 2,000,000 shares to be available for issuance to officers, directors, employees, and affiliates of the Company. Options are issued at an exercise price equal to the fair market value of the Company’s common stock at the grant date. Generally, the options vest 25 percent after one year, and thereafter ratably by month over the following 36 months, and may be exercised for a period of 10 years subject to vesting.

	Stock-based compensation expense is included primarily in selling, general and administrative expense and was $291,000, $774,000, and $296,000 for the years ended December 31, 2012, 2013, and 2014, respectively.
	The Company has future unrecognized compensation expense for nonvested shares at December 31, 2014 of $246,000 which are maintaining weighted average vesting period of 1.6 years.

	The following table summarizes the activity of the Company’s plan related to stock options:



		Number			Weighted		Weighted	Aggregate intrinsic value
		of options			average		average
					exercise		remaining
					price per share		contractual
							term (years)
	Outstanding - January 1, 2012, as converted	1,453,534			$	1.02	8.4

	Awarded	301,026			3.34

	Forfeited or Expired (1)	(16,927	)		1.13

	Outstanding as of December 31, 2012	1,737,633			1.42		7.7	$	3,339,000

	Awarded	913,853			1.16

	Exercised	(79,003	)		0.23			74,000

	Forfeited or Expired (1)	(250,303	)		1.86

	Outstanding as of December 31, 2013	2,322,180			0.81		7.7	782,000

	Awarded	7,103			1.16

	Exercised	(9,397	)		1.16			70,000

	Forfeited or Expired (1)	(19,836	)		1.16

	Outstanding as of December 31, 2014	2,300,050			$	0.82	6.72	$	7,725,000

	Exercisable as of December 31, 2014 (2)	2,099,345			$	0.79	6.6	$	7,119,000



	-1	Management considers the circumstances generating these forfeitures to be unusual and nonrecurring in nature; accordingly, no allowance for forfeitures of options to purchase shares has been considered in determining future vesting or expense.

	-2	The employee options shown as exercisable are subject to a one year lock up agreement pursuant to the terms of the Merger whereby these options, although fully vested, cannot be exercised until April 15, 2015, the day after the first anniversary of the Merger.

	The weighted-average grant date fair value for equity options granted during the year was $0.22 and $1.16 for the year ended December 31, 2013 and 2014, respectively. The total fair value of options vested during the years ended December 31, 2012, 2013, and 2014 was $223,000, $818,000, and $303,000, respectively.

	The Company has computed the fair value of all options granted during the years ended December 31, 2012, 2013 and 2014 using the Black-Scholes option pricing model using the following assumptions:



		Year ended December 31,
		2012		2013		2014

	Risk-free interest rate	0.87%		2.23%		2.44%
	Expected volatility	89%		55%		55%
	Expected dividend yield	—		—		—
Expected life (in years)	4.47		7.09		7
Expected forfeiture rate	—		—		—

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION

	The Company generates revenues through the production and sale of oil and natural gas (the “Oil and Gas Segment”) and through the Company’s services provided to third party oil companies (the “AERO Services Segment”). The Oil and Gas Segment produces and develops the Company’s acquired oil and natural gas interests and the revenues derived from this segment are from sales to the first purchaser.

	The Company currently uses three such arrangements, one for the Etzold Field located in Seward County, Kansas and one for natural gas and one for oil for the Coke and Quitman Fields located in Wood County, Texas.

	The AERO Services Segment derives revenues from external customers by providing the Company’s biotechnology solutions of enhanced oil recovery through a two-step process consisting of (1) the Analysis Phase and (2) the Field Deployment Phase.

	The Analysis Phase work is a reservoir screening process whereby the Company obtains field samples and evaluates the Company’s potential for AERO Services Segment success. This process is performed at the Company’s Houston laboratory facilities. The Science and Technology expenses shown on the Company’s consolidated statements of operations are the expenses that are directly attributable to the Analysis Phase and expenses associated with the Company’s on-going research and development of its technology.

	In the Field Deployment Phase, the Company deploys skid mounted injection equipment used to inject nutrient solution in the oil reservoir. The work in this phase is performed in oil fields of customers located in the United States and internationally and in the Company’s own oil fields. The service operations expense shown on the Company’s consolidated statements of operations are the expenses that are directly attributable to the Field Deployment Phase.

	Earnings of industry segments exclude income taxes, interest income, interest expense and unallocated corporate expenses.

	Although the AERO Services Segment provides enhanced oil recovery services to the Oil and Gas Segment, the Company does not utilize intercompany charges. The direct costs of the services such as the injection solution, transportation of the solution and expenses associated with the injection are charged directly to the Oil and Gas Segment. All of the AERO Services Segment capital expenditures and depreciation associated with injection equipment is viewed as part of the AERO Services Segment.

	The following tables set forth summary financial data by operating segments (in thousands):



		Oil and Gas				AERO Services				Corporate				Total
	Year ended December 31, 2012
	Revenues	$	463			$	1,718			$	—			$	2,181


	Operating expenses	1,768				2,115				4,870				8,753

	Write-off of deferred offering costs	—				—				1,492				1,492

	Depreciation, depletion and amortization	130				398				50				578

	Loss from operations	(1,435		)		(795		)		(6,412		)		(8,642		)

	Other expense	—				—				(3,298		)		(3,298		)

	Net loss	$	(1,435	)		$	(795	)		$	(9,710	)		$	(11,940	)

	Property, plant and equipment, net	$	2,957			$	2,007			$	76			$	5,040

	Total assets	$	2,957			$	2,283			$	19,237			$	24,477





		Oil and Gas				AERO Services				Corporate				Total
	Year ended December 31, 2013
	Revenues	$	576			$	2,643			$	—			$	3,219


	Operating expenses	2,211				2,281				5,961				10,453

	Impairment of oil and gas properties	2,190				—				—				2,190

	Write-off of deferred offering costs	—				—				126				126

	Depreciation, depletion and amortization	200				387				35				622

	Loss from operations	(4,025		)		(25		)		(6,122		)		(10,172		)

	Other expense	—				—				(437		)		(437		)

	Net loss	$	(4,025	)		$	(25	)		$	(6,559	)		$	(10,609	)

Property, plant and equipment, net	$	658			$	2,090			$	62			$	2,810

Total assets	$	658			$	2,421			$	21,540			$	24,619




	Oil and Gas (1)				AERO Services				Corporate				Total
Year ended December 31, 2014
Revenues	$	11,724			$	4,135			$	—			$	15,859


Operating expenses	10,777				3,528				7,788				22,093

Impairment of oil and gas property	13,160				—				—				13,160

Depreciation, depletion and amortization	4,188				404				32				4,624

(Loss) income from operations	(16,401		)		203				(7,820		)		(24,018		)


Other income (expense)	6,023				—				(552		)		5,471


Taxes on income	—				—				209				209

Net loss	$	(10,378	)		$	203			$	(8,581	)		$	(18,756	)


Property, plant and equipment, net	$	27,078			$	1,636			$	99			$	28,813

Total assets	$	34,163			$	1,789			$	31,483			$	67,435



-1	The Oil and Gas Segment for the year ended December 31, 2014 includes direct revenues and expenses not previously included in prior years related to the Coke Field Assets and the Southwest Operating Assets. Included in 2014 are revenues of $11,398,000, operating expenses (including severance taxes) of $7,873,000, depreciation, depletion and amortization of $3,902,000 and gain on commodity derivatives of $6,023,000 (included in other income (expense)) related to these acquisitions and impairment of oil and gas properties of $12,707,000 which are not included in the year ended December 31, 2013 or year ended December 31, 2012.
The following table shows the total revenue by geography (in thousands):


	Year ended December 31,
	2012				2013				2014
Revenues
United States	$	1,957			$	2,201			$	13,233

Canada	224				952				2,220

Other foreign countries	—				66				406

Total revenues	$	2,181			$	3,219			$	15,859

Subsequent_Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS

	On March 2, 2015, the Company elected to prepay its entire remaining indebtedness to Hercules. The total payment was approximately $900,000 which included the end-of-term charge of $280,000.

Supplemental_Information_for_O

Supplemental Information for Oil and Gas Producing Activities	12 Months Ended
	Dec. 31, 2014
Extractive Industries [Abstract]
Supplemental Information for Oil and Gas Producing Activities	SUPPLEMENTAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES (Unaudited)

	Reserve Quantity Information

	For all years presented, the estimate of proved reserves and related valuations were based on reports prepared by the Company’s independent petroleum engineers.

	Proved reserve estimates included herein conform to the definitions prescribed by the U.S. Securities and Exchange Commission. The estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes and other factors.

	Proved reserves are estimated quantities of crude oil, natural gas and natural gas liquids, which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under economic and operating conditions existing as of the end of each respective year. Proved developed reserves are those that are expected to be recovered through existing wells with existing equipment and operating methods.

	The Company presents the volume disclosures below on an MBoe basis as the Company believes it's natural gas revenues and volumes are immaterial to it's overall oil and gas operations.

	Presented below is a summary of the changes in estimated proved reserves of the Company, all of which are located in the United States, for the years ended December 31, 2013 and 2014:

	Quantities of Proved Reserves:



		Crude Oil
		(MBoe)

	Proved Developed Reserves, December 31, 2012	160

	Production	(5	)
	Purchase of minerals in place (1)	75

	Revisions of previous estimates (2)	(127	)
	Proved Developed Reserves, December 31, 2012	103

	Production	(6	)
	Revisions of previous estimates (3)	(79	)
	Proved Developed Reserves, December 31, 2013	18

	Purchase of minerals in place (4)	1,792

	Production	(145	)
	Revisions of previous estimates (5)	(254	)
	Proved Developed Reserves, December 31, 2014	1,411



	-1	In September 2012, the Company acquired a 100% working interest in a property adjacent to the Company’s previously leased property in Kansas, the Etzold Field.

	-2	The Etzold field was developed in phases. During 2011 only the initial phase was operating and thus the reserves for the second phase were based on the results achieved in the initial phase. These reserve estimates declined as of December 31, 2012 since the second phase production results were not as economically favorable as the initial phase.

	-3	Unfavorable production results on wells achieved in 2013 led to the Company's decision to abandon the proved developed behind pipe reserves as recent results indicated these reserves would be uneconomic to produce.

	-4	Purchase of the Coke Field Assets on March 14, 2014 and the Southwest Operating Assets on September 1, 2014.

	-5	The reserves revision is due to an increase in costs over our prior year reserve report.

	Proved Developed and Undeveloped Reserves:



		Crude Oil
		(MBoe)

	31-Dec-12
	Proved developed reserves	103

	Proved undeveloped reserves	—

	Total	103


December 31, 2013

Proved developed reserves	18

Proved undeveloped reserves	—

Total	18



December 31, 2014

Proved developed reserves	1,411

Proved undeveloped reserves	—

Total	1,411


Capitalized Costs Related to Oil and Gas Producing Activities

The following table presents the Company’s capitalized costs related to oil and gas producing activities at December 31, 2013 and 2014 (in thousands):



	December 31,
	2013			2014

Unproved properties	$	—		$	196

Proved properties	3,141			45,694

Total	3,141			45,890

Less - accumulated depreciation, depletion and amortization (1)	(2,493		)	(19,612		)
Net capitalized costs	$	648		$	26,278



-1	Accumulated depreciation, depletion and amortization includes the 2013 oil and gas property impairment of $2,190,000 and the 2014 impairment of $13,160,000.

Costs Incurred in Oil and Gas Producing Activities

The following table presents the net costs incurred in property acquisition, exploration and development activities for the years ended December 31, 2013 and 2014 (in thousands):



	Year ended December 31,
	2012			2013			2014
Acquisition of properties	$	139		$	—		$	42,788


Development	1,227			84			—


Total costs incurred	$	1,366		$	84		$	42,788


Results of Operations from Oil and Gas Producing Activities

The following table presents the Company’s results of operations from oil and gas producing activities for the years ended December 31, 2012, 2013 and 2014 (in thousands):



	For the Year ended December 31,
	2012			2013			2014

Revenues from oil and gas producing activities	$	463		$	576		$	11,724


Production costs	513			433			6,631

Ad valorem taxes	15			42			438

State severance taxes	21			26			547

Impairment of oil and gas property	—			2,190			13,160

Depreciation, depletion and amortization	111			177			3,960

Total expenses	660			2,868			24,736


Pre-tax loss from producing activities	(197		)	(2,292		)	(13,012		)

Income tax expense	—			—			—


Results of oil and gas producing activities	$	(197	)	$	(2,292	)	$	(13,012	)

Standardized Measure of Discounted Future Net Cash Flows

The standardized measure of discounted future net cash flows relating to proved oil and gas reserves and the changes in standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves were prepared in accordance with ASC 932, Extractive Activities – Oil and Gas. Future cash inflows as of December 31, 2013 and 2014, were computed by applying average fiscal-year prices (calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month periods ended December 31, 2013 and 2014) to estimated future production. Future production and development costs are computed by estimating the expenditures to be incurred in developing and producing the proved oil and natural gas reserves at year-end, based on year-end costs and assuming the continuation of existing economic conditions.

Future income tax expense is calculated by applying appropriate year-end tax rates to future pretax net cash flows relating to proved oil and natural gas reserves, less the tax basis of the properties involved. Future income tax expense gives effect to permanent differences, tax credits and loss carry forwards relating to the proved oil and natural gas reserves. Future net cash flows are discounted at a rate of 10% annually to derive the standardized measure of discounted future net cash flows. This calculation does not necessarily result in an estimate of the fair value of the Company’s oil and gas properties.

Presented below is the standardized measure of discounted future net cash flows (in thousands):




	Year ended December 31,
	2012			2013			2014
Future cash inflows	$	9,087		$	1,603		$	133,235

Future production and development costs

Production	(5,203		)	(896		)	(86,032		)
Development	(721		)	—			—

Future cash flows before income taxes	3,163			707			47,203

Future income taxes	(225		)	—			—

Future net cash flows after income taxes	2,938			707			47,203

10% annual discount for estimated timing of cash flows	(1,150		)	(146		)	(17,111		)
Standardized measure of discounted future net cash flows	$	1,788		$	561		$	30,092


The following reconciles the changes in the standardized measure of discounted future net cash flows (in thousands):



	Year ended December 31,
	2012			2013			2014

Balance, beginning of year	$	1,020		$	1,788		$	561

Changes from:

Sales, net of production costs	65			(101		)	(4,108		)

Net changes in prices and production costs	(1,233		)	(15		)	2,445

Changes in estimated future development costs	(596		)	(655		)	—

Development costs incurred during the year, previously estimated	1,031			—			—

Revisions to quantity estimates	(770		)	(638		)	(8,044		)
Accretion of discount	245			56			56

Purchases of reserves in place	1,351			—			38,211

Net changes in income taxes	(164		)	(65		)	—

Changes in timing of cash flows and other	839			191			971

Balance, end of year	$	1,788		$	561		$	30,092

Selected_Quarterly_Financial_R

Selected Quarterly Financial Results	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Results	SELECTED QUARTERLY FINANCIAL RESULTS (Unaudited)

	Unaudited quarterly operating results were as follows (in thousands; except per share data):


		2013 (Quarter ended)
		31-Mar			30-Jun			30-Sep			31-Dec
		(Unaudited)
	Net revenues	$	724		$	935		$	775		$	785

	Loss from operations	(2,028		)	(1,821		)	(1,766		)	(4,557		)
	Net loss applicable to stockholders	(2,308		)	(2,074		)	(825		)	(5,402		)
	Net loss per common share, basic and diluted (1)	$	(2.17	)	$	(1.92	)	$	(0.73	)	$	(4.76	)
	Weighted average shares outstanding, basic and diluted (2)	1,064			1,078			1,136			1,136


		2014 (Quarter ended)
		31-Mar			30-Jun			30-Sep			31-Dec
		(Unaudited)
	Net revenues	$	1,002		$	5,556		$	5,458		$	3,843

	Loss from operations	(2,796		)	(1,880		)	(1,633		)	(17,709		)
	Net loss applicable to stockholders	(684		)	(6,060		)	(356		)	(11,656		)
	Net loss per common share, basic and diluted (1)	$	(0.60	)	$	(0.20	)	$	(0.01	)	$	(0.37	)
	Weighted average shares outstanding, basic and diluted (2)	1,137			29,642			31,475			31,499


	1) Quarterly loss per share is based on the weighted average number of shares outstanding during the quarter. Because of changes in the number of shares outstanding during the quarters, due to the exercise of stock options and issuance of common stock, the sum of quarterly losses per share may not equal loss per share for the year.

	2) As a result of the Merger with Infinity Corp., which consummated on April 14, 2014, the issued and outstanding common stock was canceled and reissued as common stock in the newly merged entity at a conversion ratio of 2.9 pre-Merger common stock to 1 post-Merger common stock. For the periods prior to the Merger, the above table reflects the common stock as converted to post-Merger common stock using this ratio.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation

	The accompanying consolidated financial statements include the accounts of Glori Energy Inc. and its wholly-owned subsidiaries. Intercompany balances and transactions have been eliminated in consolidation.
Use of Estimates	Use of Estimates

	The preparation of the consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents

	The Company considers all highly liquid investments with original maturities of three months or less when purchased to be cash equivalents.
Concentrations of Credit Risk	Concentrations of Credit Risk

	The Company maintains its cash in bank deposits with financial institutions. These bank deposits, at times, exceed Federal Deposit Insurance Corporation limits of $250,000 per depositor. The Company monitors the financial condition of the financial institutions and has not experienced any losses on such accounts. The Company is not party to any financial instruments which would have off-balance sheet credit or interest rate risk.
Accounts Receivable	Accounts Receivable

	Accounts receivable consists of amounts due in the ordinary course of business, from companies engaged in the exploration of oil and gas and from third party purchasers of the Company's oil and natural gas production. The Company performs ongoing credit evaluation of its customers and generally does not require collateral. Allowances are maintained for potential credit issues as they arise through management’s analysis of factors such as amount of time outstanding, customer payment history and customer financial condition. The Company has incurred inconsequential credit losses since inception.
Inventory	Inventory

	Inventory is stated at average cost and consists primarily of raw materials in the form of chemicals and finished goods that have been blended as part of the Company’s AERO nutrient system.
Other Property and Equipment	Other Property and Equipment

	Property and equipment are recorded at cost. Expenditures for major additions and improvements are capitalized and depreciated over the remaining useful lives of the associated assets, and repairs and maintenance costs are charged to expense as incurred. When property and equipment are retired or otherwise disposed, the cost and accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in the results of operations for the respective period.

	Depreciation and amortization for long-lived assets are recognized over the estimated useful lives of the respective assets by the straight-line method as follows:



	Laboratory and manufacturing facility	5 years or the remaining term of the lease, whichever is shorter

	Laboratory and field service equipment, office equipment and trucks	5 years

	Computer equipment	3 years
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets

	The Company reviews the recoverability of its long-lived assets, such as property, equipment and oil and gas properties, when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable. The assessment of possible impairment is based on the Company’s ability to recover the carrying value of the asset or asset group from the expected future pre-tax cash flows (undiscounted) of the related operations. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, generally on a field-by-field basis for oil and gas properties. If these cash flows are less than the carrying value of such asset, an impairment loss is recognized for the difference between estimated fair value and carrying value.
Derivatives	Derivatives

	The Company uses derivative instruments in the form of commodity price swaps to manage price risks resulting from fluctuations in commodity prices of oil associated with future production. These derivative instruments are recorded on the balance sheet at fair value as assets or liabilities and the changes in the fair value of derivatives are recorded each period in current earnings. Fair value is assessed, measured and estimated by obtaining the NYMEX futures oil commodity pricing. Gains and losses on the valuation of derivatives and settlement of matured commodity derivatives contracts are included in gain (loss) on commodity derivatives in other income within the period in which they occur.
Asset Retirement Obligation	Asset Retirement Obligation

	The Company recognizes the present value of the estimated future abandonment costs of its oil and gas properties in both assets and liabilities. If a reasonable estimate of the fair value can be made, the Company will record a liability for legal obligations associated with the future retirement of long-lived assets that result from the acquisition, construction, development and/or normal operation of the assets. The fair value of a liability for an asset retirement obligation is recognized in the period in which the liability is incurred. The fair value is measured using expected future cash outflows (estimated using current prices that are escalated by an assumed inflation rate) discounted at the Company’s credit-adjusted risk-free interest rate. The liability is then accreted each period until it is settled or the asset is sold, at which time the liability is reversed and any gain or loss resulting from the settlement of the obligation is recorded. The initial fair value of the asset retirement obligation is capitalized and subsequently depreciated or amortized as part of the carrying amount of the related asset. The Company has recorded asset retirement obligations related to its oil and gas properties. There are no assets legally restricted for the purpose of settling asset retirement obligations.
	The Company accounts for its asset retirement obligation (“ARO”) in accordance with ASC 410, Asset Retirement and Environmental Obligations. The ARO liability reflects the estimated present value of the amount of dismantlement, removal, site
	reclamation, and similar activities associated with our oil and gas properties. The fair value of a liability for an ARO is required to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made and the associated retirement costs can be capitalized as part of the carrying amount of the long-lived asset. The Company determined its ARO by calculating the present value of the estimated cash flows related to the liability based upon estimates derived from management and external consultants familiar with the requirements of the retirement, and the ARO is reflected in the accompanying consolidated balance sheets as an other long-term liability. The Company has not funded nor dedicated any assets to the retirement obligation.
Financial Instruments	Financial Instruments

	Financial instruments consist of cash and cash equivalents, accounts receivable, accounts payables, long-term debt, derivatives, and warrants. The carrying values of cash and cash equivalents and accounts receivable and payables approximate fair value due to their short-term nature.
Net Loss Per Share	Net Loss Per Share

	Basic net loss per share is computed using the weighted-average number of shares of common stock outstanding during the period. In periods that have income, basic net earnings per common share is computed under the two-class method per guidance in Accounting Standards Codification (ASC) 260, Earnings per Share. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock and participating security according to dividends declared (or accumulated) and participation rights in undistributed earnings. Under the two-class method, basic earnings per common share is computed by dividing net earnings attributable to common shares after allocation of earnings to participating securities by the weighted-average number of common shares outstanding during the year. However, in periods of net loss, participating securities other than common stock are not included in the calculation of basic loss per share because there is no contractual obligation for owners of these securities to share in the Company’s losses, and the effect of their inclusion would be anti-dilutive. Diluted earnings (loss) per common share is computed using the two-class method or the if-converted method, whichever is more dilutive (see NOTE 10).

	Diluted net loss per share is the same as basic net loss per share for all periods presented because any potentially dilutive common shares were anti-dilutive. Such potentially dilutive shares are excluded from the computation of diluted net loss per share when the effect would be to reduce net loss per share. Therefore, in periods when a loss is reported, the calculation of basic and diluted loss per share results in the same value.
Revenue Recognition	Revenue Recognition

	Oil and natural gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectibility of the revenue is probable. Revenues from natural gas production are recorded using the sales method. When sales volumes exceed the Company’s entitled share, production imbalance occurs. If production imbalance exceeds the Company’s share of the remaining estimated proved natural gas reserves for a given property, the Company records a liability. The Company has no significant gas imbalances as of December 31, 2013 and 2014.

	Service revenues are recognized when all services are concluded in accordance with the contract. The Company’s service contracts typically include a single contract for each phase of service. During the initial phase known as Reservoir Analysis and Treatment Design (the “Analysis Phase”), the Company samples the target field and evaluates project feasibility and nutrient formulation by assessing field characteristics such as geology, microbial environment and geochemistry of the oil and water. The completion of the Analysis Phase contract typically coincides with the delivery of a report of findings to the customer at which point the Analysis Phase revenues are recognized. Once the viability of the AERO System is demonstrated in the Analysis Phase, a new contract is executed for the Field Deployment Phase. During the Field Deployment Phase the AERO System is initiated in the oil field to stimulate the indigenous microbes in the oil bearing reservoir. The Field Deployment Phase revenues are recognized ratably over the Field Deployment Phase injection work timeline.

	Previous to 2014, the majority of the Company’s revenues for AERO services were executed under a single contract which covered both Analysis Phase and Field Deployment Phase work. The single contract for both services resulted in lack of commercial evidence that the Analysis Phase services provided value on a stand-alone basis and thus both services were viewed as a single unit-of-accounting under ASC 605, Revenue Recognition: Multiple-Element Arrangements. In accordance with this guidance, the Company deferred revenue received in the Analysis Phase and recognize this revenue and the Field Deployment Phase revenue uniformly over the Field Deployment Phase injection timeline. Any termination of the project after the completion of the Analysis Phase would result in the immediate recognition of that portion of the revenues outlined in the contract.
Science and Technology	Science and Technology

	The Company expenses all science and technology costs as incurred. The science and technology work performed predominantly relates to the Analysis Phase and the fees are primarily made up of employee compensation, lab supplies and materials, legal fees, and corporate overhead allocations.
Income Taxes	Income Taxes

	The Company accounts for income taxes using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and to net operating loss carry forwards, measured by enacted tax rates for years in which taxes are expected to be paid, recovered or settled. A valuation allowance is established to reduce deferred tax assets if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred tax assets will not be realized.

	The Company follows ASC 740, Income Taxes (“ASC 740”), which creates a single model to address accounting for the uncertainty in income tax positions and prescribes a minimum recognition threshold a tax position must meet before recognition in the consolidated financial statements.
Stock-Based Compensation	Stock-Based Compensation

	Since the initiation of the 2006 Stock Option and Grant Plan, the Company has recorded all share-based payment expense associated with option awards in accordance with ASC 718, Compensation - Stock Compensation. Accordingly, the Company selected the Black-Scholes option-pricing model as the most appropriate method to value option awards and recognizes compensation cost, as determined on the grant date, on a straight-line basis over the option awards’ vesting period.
Accounting for Sales Tax	Accounting for Sales Tax

	The Company uses the net method for accounting for sales taxes charged to customers and accordingly does not include sales or similar taxes as revenues; the Company does include sales and similar taxes paid as part of the cost of goods or services acquired.
Deferred Offering Costs	Deferred Offering Costs

	The Company has capitalized certain costs such as legal fees incurred related to the merger with Infinity Cross Border Acquisition Group (see NOTE 3).

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Schedules of Concentration of Risk, by Risk Factor	The following is a reconciliation of the customers that exceeded 10% of total accounts receivable from service revenues as of each of these dates:



			Percentage of outstanding
			accounts receivable from service revenues December 31,
	Customer		2013		2014
	A		13%		—
	B		10%		—
	D		19%		—
	I		—		19%
	J		20%		—
	K		—		54%
	L		*		27%
	M		23%		—
	* Receivables were less than 10% for the period.
	The following is a reconciliation of the customers that exceeded 10% of total service revenues in each of those periods:



			Percentage of service revenues
			Year ended December 31,
	Customer		2012			2013			2014
	A		12	%		14	%		*

	B		16	%		*			36	%

	C		15	%		—			—

	D		19	%		20	%		17	%
	E		12	%		*			—

	F		11	%		—			—

	G		*			20	%		—

	H		—			16	%		—

	I		*			—			10	%

	J		—			*			10	%

	* Revenues were less than 10% for the period.

Property, Plant and Equipment	Depreciation and amortization for long-lived assets are recognized over the estimated useful lives of the respective assets by the straight-line method as follows:



	Laboratory and manufacturing facility		5 years or the remaining term of the lease, whichever is shorter

	Laboratory and field service equipment, office equipment and trucks		5 years

	Computer equipment		3 years
	Property and equipment consists of the following (in thousands):


		December 31,
		2013				2014

	Proved oil and gas properties - successful efforts	$	3,141			$	45,694

	Construction in progress	902				589

	Laboratory and warehouse facility	591				640

	Laboratory and field service equipment	2,968				3,158

	Office equipment, computer equipment, vehicles and other	431				1,554

		8,033				51,635


	Less: accumulated depreciation, depletion and amortization (1)	(5,223		)		(22,822		)
	Total property and equipment, net	$	2,810			$	28,813

	(1) Includes impairment and excludes accretion of asset retirement obligation.

	Depreciation, depletion and amortization consists of the following (in thousands):


		Year ended December 31,
		2012				2013				2014
	Depreciation and amortization expense	$	457			$	426			$	523

	Depletion expense	103				177				3,960

	Accretion of asset retirement obligation	18				19				141

	Total depreciation, depletion, and amortization of property and equipment	$	578			$	622			$	4,624

Merger_with_Infinity_Cross_Bor1

Merger with Infinity Cross Border Acquisition Corporation (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Summary of Temporary Equity and Stockholders' Equity	The following table (in thousands, except share amounts) presents the consolidated statements of temporary equity and stockholders' equity as if the Merger had occurred on January 1, 2012. The beginning balances as of January 1, 2012, shown in the table below, represent the Company's pre-Merger temporary equity and stockholders' equity previously stated as of January 1, 2012. The balances as of January 1, 2012, as converted, represent the post-Merger stockholders' equity received in exchange for the pre-Merger temporary equity and stockholders' equity at January 1, 2012.



		Temporary equity - convertible redeemable preferred stock																					Stockholders' equity


																				Total								Additional						Total
		Series A Preferred					Series B Preferred					Series C Preferred					Series C-1 Preferred			temporary			Common stock					paid-in			Accumulated			stockholders'
		Shares		Amount			Shares		Amount			Shares		Amount			Shares	Amount		equity			Shares		Par value			capital			deficit			equity
	Balances as of January 1, 2012	475,541		$	12,709		2,901,052		$	21,990		28,776,041		$	7,888		—	$	—	$	42,587		3,009,592		$	1		$	—		$	(31,477	)	$	(31,476	)
	Balances as of January 1, 2012	475,541		$	12,709		2,901,052		$	21,990		28,776,041		$	7,888		—	$	—	$	42,587		3,009,592		$	1		$	—		$	(31,477	)	$	(31,476	)
	Reversal of pre-Merger temporary equity	(475,541	)	(12,709		)	(2,901,052	)	(21,990		)	(28,776,041	)	(7,888		)	—	—		(42,587		)	—		—			—			42,587			42,587
	Reversal of pre-Merger temporary equity	(475,541	)	(12,709		)	(2,901,052	)	(21,990		)	(28,776,041	)	(7,888		)	—	—		(42,587		)	—		—			—			42,587			42,587
	Reversal of pre-Merger common shares	—		—			—		—			—		—			—	—		—			(3,009,592	)	(1		)	1			—			—
	Reversal of pre-Merger common shares	—		—			—		—			—		—			—	—		—			(3,009,592	)	(1		)	1			—			—
	Conversion of pre-Merger shares to post Merger shares	—		—			—		—			—		—			—	—		—			16,168,502		2			(2		)	—			—
	Conversion of pre-Merger shares to post Merger shares	—		—			—		—			—		—			—	—		—			16,168,502		2			(2		)	—			—
	Segregate historical accumulated deficit from additional paid-in capital	—		—			—		—			—		—			—	—		—			—		—			33,976			(33,976		)	—
		—		—			—		—			—		—			—	—		—			—		—			33,976			(33,976		)	—
	Balances as of January 1, 2012, as converted	—		$	—		—		$	—		—		$	—		—	$	—	$	—		16,168,502		$	2		$	33,975		$	(22,866	)	$	11,111
	Balances as of January 1, 2012, as converted	—		$	—		—		$	—		—		$	—		—	$	—	$	—		16,168,502		$	2		$	33,975		$	(22,866	)	$	11,111
Summary of Common Stock Issued and Outstanding	The following table shows the number of common stock of the Company issued and outstanding related to the consummation of the Merger:



					Number of Shares


	Ordinary shares issued to Infinity Corp. founder shareholders				1,437,500
					1,437,500
	Ordinary shares issued to Infinity Corp. shareholders				5,750,000
	Ordinary shares issued to Infinity Corp. shareholders				5,750,000
	Less: Ordinary shares redeemed				(2,351,533	)
	Ordinary shares issued underwriter for UPO warrant conversion				100,000
					100,000
	Ordinary shares issued for PIPE Investment (excluding Petro-Hunt portion of the PIPE Investment)				812,500
					812,500
	Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)				250,000
					250,000
	Ordinary shares issued for the optional PIPE Investment				909,982
	Ordinary shares issued for the optional PIPE Investment				909,982
	Ordinary shares issued to Glori Energy Inc. shareholders				23,584,557
	Ordinary shares issued to Glori Energy Inc. shareholders				23,584,557
					30,493,006
					30,493,006

Property_and_Equipment_Tables

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Depreciation and amortization for long-lived assets are recognized over the estimated useful lives of the respective assets by the straight-line method as follows:



	Laboratory and manufacturing facility		5 years or the remaining term of the lease, whichever is shorter

	Laboratory and field service equipment, office equipment and trucks		5 years

	Computer equipment		3 years
	Property and equipment consists of the following (in thousands):


		December 31,
		2013			2014

	Proved oil and gas properties - successful efforts	$	3,141		$	45,694

	Construction in progress	902			589

	Laboratory and warehouse facility	591			640

	Laboratory and field service equipment	2,968			3,158

	Office equipment, computer equipment, vehicles and other	431			1,554

		8,033			51,635


	Less: accumulated depreciation, depletion and amortization (1)	(5,223		)	(22,822		)
	Total property and equipment, net	$	2,810		$	28,813

	(1) Includes impairment and excludes accretion of asset retirement obligation.

	Depreciation, depletion and amortization consists of the following (in thousands):


		Year ended December 31,
		2012			2013			2014
	Depreciation and amortization expense	$	457		$	426		$	523

	Depletion expense	103			177			3,960

	Accretion of asset retirement obligation	18			19			141

	Total depreciation, depletion, and amortization of property and equipment	$	578		$	622		$	4,624

Business Acquisition, Pro Forma Information	The following summary presents unaudited pro forma information for the Company for the year ended December 31, 2013 and 2014, as if the Coke Field acquisition had been consummated at January 1, 2012, 2013 and 2014, respectively (in thousands, except per share amounts):



		Year ended December 31,
		2012			2013			2014

	Total revenues	$	13,270		$	14,308		$	18,604

	Net loss	(10,528		)	(9,197		)	(19,111		)

	Net loss per common shares, basic and diluted	$	(9.98	)	$	(8.33	)	$	(0.66	)

	Weighted average shares outstanding:

	Basic	1,055			1,104			28,855

	Diluted	1,055			1,104			28,855

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following is a reconciliation of the liability as of December 31, 2013 and 2014 (in thousands):



		December 31,
		2013		2014
	Balance at the beginning of period	$	228	$	305

	Liabilities acquired during the period	—		883

	Accretion expense	19		141

	Revision in expected cash flows	58		—

	Balance at the end of the period	$	305	$	1,329

Accrued_Expenses_Tables

Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2014
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities	As of December 31, 2013 and 2014, the significant components of accrued expenses reported in the accompanying consolidated balance sheets are as follows (in thousands):



		December 31,
		2013		2014
	Accrued compensation and benefits	$	158	$	892

	Accrued end-of-term charge (See Note 9)	—		240

	Accrued interest	46		15

	Accrued taxes	46		223

	Accrued legal and professional fees	61		—

	Accrued royalties	—		164

	Accrued other	106		258

		$	417	$	1,792

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Summary of financial liabilities measured at fair value	The following table summarizes the financial assets measured at fair value, on a recurring basis as of December 31, 2014 (in thousands):


		Fair value measurements using
		Level 1		Level 2		Level 3		Total
	December 31, 2014
	Short-term commodity derivatives, asset	$	—	$	2,905	$	—	$	2,905

	Long-term commodity derivatives, asset	—		2,891		—		2,891

		$	—	$	5,796	$	—	$	5,796

Derivative_Instruments_Tables

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of December 31, 2014 the Company had the following open positions on its outstanding commodity derivative contracts:



	Period	Volume/Month (Bbls)		Price/Unit		Fair Value - Asset


	January 2015 - March 2015	8,400		$	94.11	1,013,000

	April 2015 - March 2016	7,300		$	86.5	2,447,000

	April 2016 - March 2017	6,550		$	82.46	1,421,000

	April 2017 - March 2018	5,800		$	80.53	915,000

Gain (Loss) on Derivatives	The following tables summarize the unrealized and realized gain on commodity derivatives (in thousands):



			Year ended December 31,
			2014
	Unrealized gain on commodity derivatives		5,796

	Realized gain on commodity derivatives		227

			6,023

Long_Term_Debt_Tables

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Maturities of Long-term Debt	Maturities on long-term debt during the next three years are as follows (in thousands):



	Year ended December 31,	Amount

	2015	$	2,380

	2016	472

	2017	16,373

		$	19,225

Loss_Per_Share_Tables

Loss Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share data):



		Year ended December 31,
		2012				2013			2014

	Numerator:

	Net loss	$	(11,940	)		$	(10,609	)	$	(18,756	)

	Denominator:

	Weighted-average common shares outstanding - basic	1,055				1,104			28,855

	Effect of dilutive securities	—				—			—

	Weighted-average common shares - diluted	1,055				1,104			28,855


	Net loss per common share - basic and diluted	$	(11.32	)		$	(9.61	)	$	(0.65	)
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following weighted average securities outstanding during the periods below were not included in the calculation of diluted shares outstanding as they would have been anti-dilutive (in thousands):



		Year ended December 31,
		2012			2013			2014

	Common stock warrants	—			—			4,895

	Common stock options	1,738			1,898			2,311

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	Income tax benefit for the periods presented differs from the U.S. Federal benefit calculated at the statutory income tax rate due to the following (in thousands):



		Year ended December 31,
		2012			2013			2014

	Federal benefit at statutory income tax rate	$	(4,059	)	$	(3,607	)	$	(6,692	)
	R&D credits	—			(118		)	(83		)

	Non-deductible (taxable) expenses & other items	596			(17		)	(380		)

	State income taxes - net of federal benefit	(25		)	(19		)	(221		)
	Foreign income taxes	—			—			209

	Embedded derivative cancellation	—			797			—

	Change in valuation allowance	3,488			2,964			7,376

	Taxes on income	$	—		$	—		$	209

Schedule of Deferred Tax Assets and Liabilities	The tax effects of temporary differences that give rise to significant portions of the Company’s net deferred tax assets at December 31, 2013 and 2014 are as follows (in thousands):



		Year ended December 31,
		2013			2014

	Current deferred tax asset

	Deferred revenue and other	$	410		$	248

	Allowance for doubtful accounts	27			—

		437			248

	Less Valuation allowance	(437		)	(225		)
		—			23


	Current deferred tax liability

	Current portion of swap asset	—			993


	Current deferred tax liability, net	—			970


	Non-current deferred tax asset

	NOL carryforwards (long-term)	10,737			16,077

	R&D credits	367			450

	Other accrued expenses	22			—

	Stock compensation	129			154

	Depreciable property basis	556			740

	Oil and gas properties	104			4,040

		11,915			21,461

	Less Valuation allowance	(11,915		)	(19,503		)
		—			1,958


	Non-current deferred tax liability

	Non-current portion of swap asset	—			988

	Non-current deferred tax asset, net	—			970


	Total deferreds, net	$	—		$	—

Schedule of Components of Income Tax Expense (Benefit)	The provision (benefit) for income taxes from continuing operations for the periods indicated are comprised of the following (in thousands):


		Year ended December 31,
		2013			2014

	Current tax provision (benefit):
	Federal	—			—

	Foreign	—			209

	State	—			—

	Total	$	—		$	209


	Deferred tax provision (benefit):
	Federal	—			—

	Foreign	—			—

	State	—			—

	Total	$	—		$	—


	Total tax provision (benefit):
	Federal	—			—

	Foreign	—			209

	State	—			—

	Total	$	—		$	209

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule of Minimum Future Capital Lease Payments	Approximate minimum future rental payments under these noncancelable operating leases as of December 31, 2014 are as follows (in thousands):


		Year ended December 31,

	2015	$	356

	2016	295

	2017	53

		$	704

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Stock Option Activity	The following table summarizes the activity of the Company’s plan related to stock options:



		Number			Weighted		Weighted	Aggregate intrinsic value
		of options			average		average
					exercise		remaining
					price per share		contractual
							term (years)
	Outstanding - January 1, 2012, as converted	1,453,534			$	1.02	8.4

	Awarded	301,026			3.34

	Forfeited or Expired (1)	(16,927	)		1.13

	Outstanding as of December 31, 2012	1,737,633			1.42		7.7	$	3,339,000

	Awarded	913,853			1.16

	Exercised	(79,003	)		0.23			74,000

	Forfeited or Expired (1)	(250,303	)		1.86

	Outstanding as of December 31, 2013	2,322,180			0.81		7.7	782,000

	Awarded	7,103			1.16

	Exercised	(9,397	)		1.16			70,000

	Forfeited or Expired (1)	(19,836	)		1.16

	Outstanding as of December 31, 2014	2,300,050			$	0.82	6.72	$	7,725,000

	Exercisable as of December 31, 2014 (2)	2,099,345			$	0.79	6.6	$	7,119,000



	-1	Management considers the circumstances generating these forfeitures to be unusual and nonrecurring in nature; accordingly, no allowance for forfeitures of options to purchase shares has been considered in determining future vesting or expense.

	-2	The employee options shown as exercisable are subject to a one year lock up agreement pursuant to the terms of the Merger whereby these options, although fully vested, cannot be exercised until April 15, 2015, the day after the first anniversary of the Merger.
Schedule of Fair Value Assumptions	The Company has computed the fair value of all options granted during the years ended December 31, 2012, 2013 and 2014 using the Black-Scholes option pricing model using the following assumptions:



		Year ended December 31,
		2012		2013		2014

	Risk-free interest rate	0.87%		2.23%		2.44%
	Expected volatility	89%		55%		55%
	Expected dividend yield	—		—		—
	Expected life (in years)	4.47		7.09		7
	Expected forfeiture rate	—		—		—

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables set forth summary financial data by operating segments (in thousands):



		Oil and Gas				AERO Services				Corporate				Total
	Year ended December 31, 2012
	Revenues	$	463			$	1,718			$	—			$	2,181


	Operating expenses	1,768				2,115				4,870				8,753

	Write-off of deferred offering costs	—				—				1,492				1,492

	Depreciation, depletion and amortization	130				398				50				578

	Loss from operations	(1,435		)		(795		)		(6,412		)		(8,642		)

	Other expense	—				—				(3,298		)		(3,298		)

	Net loss	$	(1,435	)		$	(795	)		$	(9,710	)		$	(11,940	)

	Property, plant and equipment, net	$	2,957			$	2,007			$	76			$	5,040

	Total assets	$	2,957			$	2,283			$	19,237			$	24,477





		Oil and Gas				AERO Services				Corporate				Total
	Year ended December 31, 2013
	Revenues	$	576			$	2,643			$	—			$	3,219


	Operating expenses	2,211				2,281				5,961				10,453

	Impairment of oil and gas properties	2,190				—				—				2,190

	Write-off of deferred offering costs	—				—				126				126

	Depreciation, depletion and amortization	200				387				35				622

	Loss from operations	(4,025		)		(25		)		(6,122		)		(10,172		)

	Other expense	—				—				(437		)		(437		)

	Net loss	$	(4,025	)		$	(25	)		$	(6,559	)		$	(10,609	)

	Property, plant and equipment, net	$	658			$	2,090			$	62			$	2,810

	Total assets	$	658			$	2,421			$	21,540			$	24,619




		Oil and Gas (1)				AERO Services				Corporate				Total
	Year ended December 31, 2014
	Revenues	$	11,724			$	4,135			$	—			$	15,859


	Operating expenses	10,777				3,528				7,788				22,093

	Impairment of oil and gas property	13,160				—				—				13,160

Depreciation, depletion and amortization	4,188				404				32				4,624

(Loss) income from operations	(16,401		)		203				(7,820		)		(24,018		)


Other income (expense)	6,023				—				(552		)		5,471


Taxes on income	—				—				209				209

Net loss	$	(10,378	)		$	203			$	(8,581	)		$	(18,756	)


Property, plant and equipment, net	$	27,078			$	1,636			$	99			$	28,813

Total assets	$	34,163			$	1,789			$	31,483			$	67,435



-1	The Oil and Gas Segment for the year ended December 31, 2014 includes direct revenues and expenses not previously included in prior years related to the Coke Field Assets and the Southwest Operating Assets. Included in 2014 are revenues of $11,398,000, operating expenses (including severance taxes) of $7,873,000, depreciation, depletion and amortization of $3,902,000 and gain on commodity derivatives of $6,023,000 (included in other income (expense)) related to these acquisitions and impairment of oil and gas properties of $12,707,000 which are not included in the year ended December 31, 2013 or year ended December 31, 2012.
Revenue from External Customers by Geographic Areas	The following table shows the total revenue by geography (in thousands):


		Year ended December 31,
		2012				2013				2014
	Revenues
	United States	$	1,957			$	2,201			$	13,233

	Canada	224				952				2,220

	Other foreign countries	—				66				406

	Total revenues	$	2,181			$	3,219			$	15,859

Supplemental_Information_for_O1

Supplemental Information for Oil and Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Extractive Industries [Abstract]
Summary of changes in estimated proved reserves	Presented below is a summary of the changes in estimated proved reserves of the Company, all of which are located in the United States, for the years ended December 31, 2013 and 2014:

	Quantities of Proved Reserves:



		Crude Oil
		(MBoe)

	Proved Developed Reserves, December 31, 2012	160

	Production	(5	)
	Purchase of minerals in place (1)	75

	Revisions of previous estimates (2)	(127	)
	Proved Developed Reserves, December 31, 2012	103

	Production	(6	)
	Revisions of previous estimates (3)	(79	)
	Proved Developed Reserves, December 31, 2013	18

	Purchase of minerals in place (4)	1,792

	Production	(145	)
	Revisions of previous estimates (5)	(254	)
	Proved Developed Reserves, December 31, 2014	1,411



	-1	In September 2012, the Company acquired a 100% working interest in a property adjacent to the Company’s previously leased property in Kansas, the Etzold Field.

	-2	The Etzold field was developed in phases. During 2011 only the initial phase was operating and thus the reserves for the second phase were based on the results achieved in the initial phase. These reserve estimates declined as of December 31, 2012 since the second phase production results were not as economically favorable as the initial phase.

	-3	Unfavorable production results on wells achieved in 2013 led to the Company's decision to abandon the proved developed behind pipe reserves as recent results indicated these reserves would be uneconomic to produce.

	-4	Purchase of the Coke Field Assets on March 14, 2014 and the Southwest Operating Assets on September 1, 2014.

	-5	The reserves revision is due to an increase in costs over our prior year reserve report.

	Proved Developed and Undeveloped Reserves:



		Crude Oil
		(MBoe)

	31-Dec-12
	Proved developed reserves	103

	Proved undeveloped reserves	—

	Total	103


	December 31, 2013

	Proved developed reserves	18

	Proved undeveloped reserves	—

	Total	18



December 31, 2014

Proved developed reserves	1,411

Proved undeveloped reserves	—

Total	1,411

Summary of capitalized costs related to oil and gas producing activities	The following table presents the Company’s capitalized costs related to oil and gas producing activities at December 31, 2013 and 2014 (in thousands):



		December 31,
		2013			2014

	Unproved properties	$	—		$	196

	Proved properties	3,141			45,694

	Total	3,141			45,890

	Less - accumulated depreciation, depletion and amortization (1)	(2,493		)	(19,612		)
	Net capitalized costs	$	648		$	26,278



	-1	Accumulated depreciation, depletion and amortization includes the 2013 oil and gas property impairment of $2,190,000 and the 2014 impairment of $13,160,000.
Summary of costs incurred in oil and gas producing activities	The following table presents the net costs incurred in property acquisition, exploration and development activities for the years ended December 31, 2013 and 2014 (in thousands):



		Year ended December 31,
		2012			2013			2014
	Acquisition of properties	$	139		$	—		$	42,788


	Development	1,227			84			—


	Total costs incurred	$	1,366		$	84		$	42,788

Results of operations from oil and gas producing activities	The following table presents the Company’s results of operations from oil and gas producing activities for the years ended December 31, 2012, 2013 and 2014 (in thousands):



		For the Year ended December 31,
		2012			2013			2014

	Revenues from oil and gas producing activities	$	463		$	576		$	11,724


	Production costs	513			433			6,631

	Ad valorem taxes	15			42			438

	State severance taxes	21			26			547

	Impairment of oil and gas property	—			2,190			13,160

	Depreciation, depletion and amortization	111			177			3,960

	Total expenses	660			2,868			24,736


	Pre-tax loss from producing activities	(197		)	(2,292		)	(13,012		)

	Income tax expense	—			—			—


	Results of oil and gas producing activities	$	(197	)	$	(2,292	)	$	(13,012	)
Standardized measure of discounted future net cash flows	Presented below is the standardized measure of discounted future net cash flows (in thousands):




		Year ended December 31,
		2012			2013			2014
	Future cash inflows	$	9,087		$	1,603		$	133,235

	Future production and development costs

	Production	(5,203		)	(896		)	(86,032		)
	Development	(721		)	—			—

	Future cash flows before income taxes	3,163			707			47,203

	Future income taxes	(225		)	—			—

	Future net cash flows after income taxes	2,938			707			47,203

	10% annual discount for estimated timing of cash flows	(1,150		)	(146		)	(17,111		)
	Standardized measure of discounted future net cash flows	$	1,788		$	561		$	30,092

Summary of changes in standardized measure of discounted future net cash flows	The following reconciles the changes in the standardized measure of discounted future net cash flows (in thousands):



		Year ended December 31,
		2012			2013			2014

	Balance, beginning of year	$	1,020		$	1,788		$	561

	Changes from:

	Sales, net of production costs	65			(101		)	(4,108		)

	Net changes in prices and production costs	(1,233		)	(15		)	2,445

	Changes in estimated future development costs	(596		)	(655		)	—

	Development costs incurred during the year, previously estimated	1,031			—			—

	Revisions to quantity estimates	(770		)	(638		)	(8,044		)
	Accretion of discount	245			56			56

	Purchases of reserves in place	1,351			—			38,211

	Net changes in income taxes	(164		)	(65		)	—

	Changes in timing of cash flows and other	839			191			971

	Balance, end of year	$	1,788		$	561		$	30,092

Selected_Quarterly_Financial_R1

Selected Quarterly Financial Results (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Unaudited quarterly operating results were as follows (in thousands; except per share data):


		2013 (Quarter ended)
		31-Mar			30-Jun			30-Sep			31-Dec
		(Unaudited)
	Net revenues	$	724		$	935		$	775		$	785

	Loss from operations	(2,028		)	(1,821		)	(1,766		)	(4,557		)
	Net loss applicable to stockholders	(2,308		)	(2,074		)	(825		)	(5,402		)
	Net loss per common share, basic and diluted (1)	$	(2.17	)	$	(1.92	)	$	(0.73	)	$	(4.76	)
	Weighted average shares outstanding, basic and diluted (2)	1,064			1,078			1,136			1,136


		2014 (Quarter ended)
		31-Mar			30-Jun			30-Sep			31-Dec
		(Unaudited)
	Net revenues	$	1,002		$	5,556		$	5,458		$	3,843

	Loss from operations	(2,796		)	(1,880		)	(1,633		)	(17,709		)
	Net loss applicable to stockholders	(684		)	(6,060		)	(356		)	(11,656		)
	Net loss per common share, basic and diluted (1)	$	(0.60	)	$	(0.20	)	$	(0.01	)	$	(0.37	)
	Weighted average shares outstanding, basic and diluted (2)	1,137			29,642			31,475			31,499

Summary_of_Significant_Account3

Summary of Significant Accounting Policies Concentrations of Credit Risk (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	customer	customer	customer
Oil Purchaser 4 [Member]
Concentration Risk [Line Items]
Accounts receivable	900
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member]
Concentration Risk [Line Items]
Number of customers revenues are derived from	15	11	8
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer A [Member]
Concentration Risk [Line Items]
Concentration risk, percent		14.00%	12.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer B [Member]
Concentration Risk [Line Items]
Concentration risk, percent	36.00%		16.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer C [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	0.00%	15.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer D [Member]
Concentration Risk [Line Items]
Concentration risk, percent	17.00%	20.00%	19.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer E [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%		12.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer F [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	0.00%	11.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer G [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	20.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer H [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	16.00%	0.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer I [Member]
Concentration Risk [Line Items]
Concentration risk, percent	10.00%	0.00%
Customer Concentration Risk [Member] \| Sales Revenue, Services, Net [Member] \| Customer J [Member]
Concentration Risk [Line Items]
Concentration risk, percent	10.00%		0.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member]
Concentration Risk [Line Items]
Number of customers revenues are derived from	4	7
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer A [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	13.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer B [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	10.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer D [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	19.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer I [Member]
Concentration Risk [Line Items]
Concentration risk, percent	19.00%	0.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer J [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	20.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer K [Member]
Concentration Risk [Line Items]
Concentration risk, percent	54.00%	0.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer L [Member]
Concentration Risk [Line Items]
Concentration risk, percent	27.00%
Customer Concentration Risk [Member] \| Accounts Receivable [Member] \| Customer M [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	23.00%
Customer Concentration Risk [Member] \| Oil And Gas Sales Revenue [Member] \| Oil Purchaser 1 [Member]
Concentration Risk [Line Items]
Concentration risk, percent	57.00%
Customer Concentration Risk [Member] \| Oil And Gas Sales Revenue [Member] \| Oil Purchaser 2 [Member]
Concentration Risk [Line Items]
Concentration risk, percent	39.00%
Customer Concentration Risk [Member] \| Oil And Gas Sales Revenue [Member] \| Oil Purchaser 3 [Member]
Concentration Risk [Line Items]
Concentration risk, percent		100.00%	100.00%

Summary_of_Significant_Account4

Summary of Significant Accounting Policies Estimated Useful Life (Details)	12 Months Ended
	Dec. 31, 2014
Laboratory and manufacturing facility [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	5 years
Laboratory and field service equipment, office equipment and trucks [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	5 years
Computer equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	3 years

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Narrative (Details) (USD $)	12 Months Ended			3 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Impaired Long-Lived Assets Held and Used [Line Items]
Write-off of deferred offering costs	$0	$126	$1,492
Impairment of oil and gas properties	13,160	2,190	0
Deferred revenues	653	1,753		1,753
Series C-1 Preferred Stock [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Write-off of deferred offering costs				126
IPO [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Write-off of deferred offering costs			$1,492

Merger_with_Infinity_Cross_Bor2

Merger with Infinity Cross Border Acquisition Corporation (Details) (USD $)	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2014	Apr. 14, 2014	Dec. 31, 2013	Dec. 31, 2012
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance	$0
Ending balance	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	16,168,502	31,499,303	30,493,006	22,450,688
Beginning balance	11,111	41,215		16,196	12,176
Ending balance (in shares)	16,168,502	31,499,303	30,493,006	22,450,688
Ending balance	11,111	41,215		16,196	12,176
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	16,168,502	31,499,303		22,450,688	19,414,873
Beginning balance	2	3		2	2
Ending balance (in shares)	16,168,502	31,499,303		22,450,688	19,414,873
Ending balance	2	3		2	2
Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	33,975	105,383		61,609	46,980
Ending balance	33,975	105,383		61,609	46,980
Accumulated Deficit [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	-22,866	-64,171		-45,415	-34,806
Ending balance	-22,866	-64,171		-45,415	-34,806
Series A Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	0
Beginning balance	0
Ending balance (in shares)	0
Ending balance	0
Series B Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	0
Beginning balance	0
Ending balance (in shares)	0
Ending balance	0
Series C Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	0
Beginning balance	0
Ending balance (in shares)	0
Ending balance	0
Series C-1 Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	0
Beginning balance	0
Ending balance (in shares)	0
Ending balance	0
Scenario, Previously Reported [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance	42,587
Ending balance	42,587
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	-31,476
Ending balance	-31,476
Scenario, Previously Reported [Member] \| Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	3,009,592
Beginning balance	1
Ending balance (in shares)	3,009,592
Ending balance	1
Scenario, Previously Reported [Member] \| Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	0
Ending balance	0
Scenario, Previously Reported [Member] \| Accumulated Deficit [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	-31,477
Ending balance	-31,477
Scenario, Previously Reported [Member] \| Series A Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	475,541
Beginning balance	12,709
Ending balance (in shares)	475,541
Ending balance	12,709
Scenario, Previously Reported [Member] \| Series B Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	2,901,052
Beginning balance	21,990
Ending balance (in shares)	2,901,052
Ending balance	21,990
Scenario, Previously Reported [Member] \| Series C Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	28,776,041
Beginning balance	7,888
Ending balance (in shares)	28,776,041
Ending balance	7,888
Scenario, Previously Reported [Member] \| Series C-1 Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares)	0
Beginning balance	0
Ending balance (in shares)	0
Ending balance	0
Scenario, Adjustment [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre-Merger temporary equity	42,587
Scenario, Adjustment [Member] \| Common Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares)	-3,009,592
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reversal of pre-Merger common shares	-1
Conversion of pre Merger shares to post Merger shares (in shares)	16,168,502
Conversion of pre-Merger shares to post Merger shares	2
Scenario, Adjustment [Member] \| Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reversal of pre-Merger common shares	1
Conversion of pre-Merger shares to post Merger shares	-2
Segregate historical accumulated deficit from additional paid-in capital	33,976
Scenario, Adjustment [Member] \| Accumulated Deficit [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre-Merger temporary equity	42,587
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Segregate historical accumulated deficit from additional paid-in capital	-33,976
Scenario, Adjustment [Member] \| Series A Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares)	-475,541
Reversal of pre-Merger temporary equity	-12,709
Scenario, Adjustment [Member] \| Series B Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares)	-2,901,052
Reversal of pre-Merger temporary equity	-21,990
Scenario, Adjustment [Member] \| Series C Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares)	-28,776,041
Reversal of pre-Merger temporary equity	-7,888
Scenario, Adjustment [Member] \| Series C-1 Preferred Stock [Member] \| Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares)	0
Reversal of pre-Merger temporary equity	$0

Merger_with_Infinity_Cross_Bor3

Merger with Infinity Cross Border Acquisition Corporation Summary of Common Stock Issued and Outstanding (Details)	0 Months Ended
	Apr. 14, 2014	Dec. 31, 2014	Apr. 14, 2014	Dec. 31, 2013	Dec. 31, 2011
Business Combinations [Abstract]
Ordinary shares issued to Infinity Corp. founder shareholders	1,437,500
Ordinary shares issued to Infinity Corp. shareholders	5,750,000
Less: Ordinary shares redeemed	-2,351,533
Ordinary shares issued underwriter for UPO warrant conversion	100,000
Ordinary shares issued for PIPE Investment (excluding Petro-Hunt portion of the PIPE Investment)	812,500
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)	250,000
Ordinary shares issued for the optional PIPE Investment	909,982
Ordinary shares issued to Glori Energy Inc. shareholders	23,584,557
Common stock, shares outstanding		31,499,303	30,493,006	22,450,688	16,168,502

Merger_with_Infinity_Cross_Bor4

Merger with Infinity Cross Border Acquisition Corporation Narrative (Details) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 14, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014	Apr. 14, 2014	Dec. 31, 2011	Jan. 19, 2012	Apr. 30, 2013	Mar. 13, 2014
Business Acquisition [Line Items]
Common stock, shares outstanding	30,493,006	22,450,688		31,499,303	30,493,006	16,168,502
Ordinary shares issued to Glori Energy Inc. shareholders	23,584,557
Conversion to common stock (in shares)		79,003	19,680
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)	250,000
Warrants outstanding				5,321,700
Warrant exercise price (in usd per share)				10
Common Stock [Member]
Business Acquisition [Line Items]
Common stock, shares outstanding		22,450,688	19,414,873	31,499,303		16,168,502
Ordinary shares issued to Glori Energy Inc. shareholders		229,108	57,071
Conversion to common stock (in shares)		79,003	19,680	250,000
Infinity Cross Border Acquisition Corporation [Member]
Business Acquisition [Line Items]
Consideration received				24.7
Consideration received from private placement				13.7
Private Placement [Member]
Business Acquisition [Line Items]
Number of shares issued in private placement				1,722,482
Price per common share (in usd per share)				8
Infinity Cross Border Acquisition Corporation [Member] \| Infinity Corp. [Member]
Business Acquisition [Line Items]
Common stock, shares outstanding	23,584,557
Convertible Subordinated Debt [Member] \| 6% Subordinated Convertible Promissory Note [Member]
Business Acquisition [Line Items]
Principal amount	2
Conversion price per common share (in usd per share)	8				$8
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)					250,000
Series C Preferred Stock [Member]
Business Acquisition [Line Items]
Shares issued upon conversion	3,226,691				3,226,691
Series C Preferred Stock [Member] \| Preferred Stock [Member]
Business Acquisition [Line Items]
Preferred shares issued							4,420,566
Series C Preferred Stock [Member] \| Common Stock [Member]
Business Acquisition [Line Items]
Ordinary shares issued to Glori Energy Inc. shareholders			3,226,691
Series C-1 Preferred Stock [Member] \| Preferred Stock [Member]
Business Acquisition [Line Items]
Preferred shares issued								4,462,968
Series C-1 Preferred Warrants [Member] \| Warrant [Member]
Business Acquisition [Line Items]
Preferred warrants issued								3,975,718
Series C-1 Preferred Shares And Preferred Warrants [Member]
Business Acquisition [Line Items]
Shares issued upon conversion	2,956,812				2,956,812
Series C-1 Preferred Shares And Preferred Warrants [Member] \| Common Stock [Member]
Business Acquisition [Line Items]
Ordinary shares issued to Glori Energy Inc. shareholders		2,956,812
Series C-2 Preferred Shares [Member] \| Preferred Stock [Member]
Business Acquisition [Line Items]
Preferred shares issued									1,842,028
Series C-2 Preferred Warrants [Member] \| Warrant [Member]
Business Acquisition [Line Items]
Preferred warrants issued									1,640,924
Series C-2 Preferred Stock and Preferred Warrants [Member]
Business Acquisition [Line Items]
Shares issued upon conversion	1,133,869				1,133,869
Series C-2 Preferred Stock and Preferred Warrants [Member] \| Common Stock [Member]
Business Acquisition [Line Items]
Ordinary shares issued to Glori Energy Inc. shareholders				1,133,869

Property_and_Equipment_Summary

Property and Equipment Summary of Plant and Equipment (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Proved oil and gas properties - successful efforts	$45,694	$3,141
Property and equipment, gross	5,941	4,892
Total property and equipment and proved oil and gas properties, gross	51,635	8,033
Less: accumulated depreciation, depletion and amortization (1)	-22,822	-5,223
Total property and equipment and proved oil and gas properties, net	28,813	2,810	5,040
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	589	902
Laboratory and warehouse facility [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	640	591
Laboratory and field service equipment [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	3,158	2,968
Office equipment, computer equipment, vehicles and other [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	$1,554	$431

Property_and_Equipment_Depreci

Property and Equipment Depreciation, Depletion, and Amortization (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Abstract]
Depreciation and amortization expense	$523	$426	$457
Depletion expense	3,960	177	103
Accretion of asset retirement obligation	141	19	18
Total depreciation, depletion, and amortization of property and equipment	$4,624	$622	$578

Property_and_Equipment_Pro_For

Property and Equipment Pro Forma Information (Details) (Coke Field Assets [Member], Glori Energy Production, Inc. [Member], USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Coke Field Assets [Member] \| Glori Energy Production, Inc. [Member]
Business Acquisition [Line Items]
Total revenues	$18,604	$14,308	$13,270
Net loss	($19,111)	($9,197)	($10,528)
Net loss per common shares, basic (in dollars per share)	($0.66)	($8.33)	($9.98)
Net loss per common share, diluted (in dollars per share)	($0.66)	($8.33)	($9.98)
Weighted average shares outstanding:
Weighted-average common shares outstanding - basic	28,855	1,104	1,055
Weighted-average common shares outstanding - diluted	28,855	1,104	1,055

Property_and_Equipment_Narrati

Property and Equipment Narrative (Details) (USD $)	3 Months Ended								12 Months Ended			1 Months Ended	0 Months Ended
Property and Equipment Narrative (Details) (USD $)	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2014	Mar. 14, 2014
Business Acquisition [Line Items]
Revenues	$3,843,000	$5,458,000	$5,556,000	$1,002,000	$785,000	$775,000	$935,000	$724,000	$15,859,000	$3,219,000	$2,181,000
Net loss									-18,756,000	-10,609,000	-11,940,000
Gain on commodity derivatives									6,023,000	0	0
Impairment of oil and gas properties									13,160,000	2,190,000	0
Southwest Operating Assets [Member]
Business Acquisition [Line Items]
Payments to acquire businesses												2,000,000
Southwest Operating Assets [Member] \| Other Noncurrent Liabilities [Member]
Business Acquisition [Line Items]
Asset retirement obligation acquired		138,000										138,000
Glori Energy Production, Inc. [Member] \| Coke Field Assets [Member]
Business Acquisition [Line Items]
Cash consideration													38,000,000
Convertible note payable assumed													2,000,000
Total purchase price													39,200,000
Property and equipment acquired during acquisition													310,000
Inventory acquired during acquisition													327,000
Revenues									11,398,000
Net loss									-7,061,000
Gain on commodity derivatives									6,023,000
Impairment of oil and gas properties									12,707,000
Glori Energy Production, Inc. [Member] \| Coke Field Assets [Member] \| Other Noncurrent Assets [Member]
Business Acquisition [Line Items]
Asset retirement cost acquired													745,000
Glori Energy Production, Inc. [Member] \| Coke Field Assets [Member] \| Other Noncurrent Liabilities [Member]
Business Acquisition [Line Items]
Asset retirement obligation acquired													$745,000

Asset_Retirement_Obligation_Re

Asset Retirement Obligation Reconciliation of Asset Retirement Obligation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at the beginning of period	$305	$228
Liabilities acquired during the period	883	0
Accretion expense	141	19	18
Revision in expected cash flows	0	58
Balance at the end of the period	$1,329	$305	$228

Accrued_Expenses_Summary_of_Ac

Accrued Expenses Summary of Accrued Expenses (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Payables and Accruals [Abstract]
Accrued compensation and benefits	$892	$158
Accrued end-of-term charge	240	0
Accrued interest	15	46
Accrued taxes	223	46
Accrued legal and professional fees	0	61
Accrued royalties	164	0
Accrued other	258	106
Accrued expenses	$1,792	$417

Fair_Value_Measurements_Assets

Fair Value Measurements Assets Measured at Fair Value on a Recurring Basis (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	$2,905
Long-term commodity derivatives, asset	2,891
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	2,905
Long-term commodity derivatives, asset	2,891
Derivative asset	5,796
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	0
Long-term commodity derivatives, asset	0
Derivative asset	0
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	2,905
Long-term commodity derivatives, asset	2,891
Derivative asset	5,796
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	0
Long-term commodity derivatives, asset	0
Derivative asset	$0

Derivative_Instruments_Outstan

Derivative Instruments Outstanding Commodity Derivative Contracts (Details) (Not Designated as Hedging Instrument [Member], Commodity Contract [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014
	bbl
January 2015 - March 2015 [Member]
Derivative [Line Items]
Volume per month (Bbls)	8,400
Price (usd per barrel)	94.11
Fair value	$1,013
April 2015 - March 2016 [Member]
Derivative [Line Items]
Volume per month (Bbls)	7,300
Price (usd per barrel)	86.5
Fair value	2,447
April 2016 - March 2017 [Member]
Derivative [Line Items]
Volume per month (Bbls)	6,550
Price (usd per barrel)	82.46
Fair value	1,421
April 2017 - March 2018 [Member]
Derivative [Line Items]
Volume per month (Bbls)	5,800
Price (usd per barrel)	80.53
Fair value	$915

Derivative_Instruments_Realize

Derivative Instruments Realized and Unrealized Gain (Loss) on Derivatives (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain on commodity derivatives	$5,796	$0	$0
Commodity Contract [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain on commodity derivatives	5,796
Realized gain on commodity derivatives	227
Gain on oil and natural gas derivatives	$6,023

Derivative_Instruments_Narrati

Derivative Instruments Narrative (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Short-term commodity derivatives, asset	$2,905
Long-term commodity derivatives, asset	$2,891

Long_Term_Debt_Maturities_on_L

Long Term Debt Maturities on Long-Term Debt (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified	Dec. 31, 2014
Debt Disclosure [Abstract]
2015	$2,380
2016	472
2017	16,373
Total	$19,225

Long_Term_Debt_Narrative_Detai

Long Term Debt Narrative (Details) (USD $)	0 Months Ended
	Apr. 14, 2014	Mar. 14, 2014	Jun. 11, 2012	13-May-14	Apr. 14, 2014	Dec. 31, 2014	Dec. 31, 2013
	Apr. 14, 2014	agreement	Jun. 11, 2012	13-May-14	Apr. 14, 2014	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Warrants exchanged for common shares (in shares)	100,000
Long-term debt						$19,225,000
Number of financing agreements		2
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)	250,000
Secured Debt [Member] \| 10% Secured Term Promissory Note [Member]
Debt Instrument [Line Items]
Principal amount			8,000,000
Interest rate (percent)			10.00%
Warrants exchanged for common shares (in shares)	18,208
Repayment period			27 months
Liability for end of term charge			280,000
Long-term debt						1,750,000	5,238,000
Secured Debt [Member] \| 10% Secured Term Promissory Note [Member] \| Other Noncurrent Liabilities [Member]
Debt Instrument [Line Items]
End of term charge recognized							144,000
Secured Debt [Member] \| 10% Secured Term Promissory Note [Member] \| Accrued Liabilities [Member]
Debt Instrument [Line Items]
End of term charge recognized						240,000
Subordinated Debt [Member] \| 12% Subordinated Note [Member]
Debt Instrument [Line Items]
Principal amount		4,000,000
Interest rate (percent)		12.00%
Loan term		2 years
Issuance cost (percent)		2.00%
Issuance cost		80,000
Repurchase amount				4,000,000
Prepayment penalty				400,000
Convertible Subordinated Debt [Member] \| 6% Subordinated Convertible Promissory Note [Member]
Debt Instrument [Line Items]
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)					250,000
Glori Energy Production, Inc. [Member] \| Coke Field Assets [Member]
Debt Instrument [Line Items]
Cash consideration		38,000,000
Glori Energy Production, Inc. [Member] \| Senior Notes [Member] \| 11% Senior Secured Term Loan [Member]
Debt Instrument [Line Items]
Principal amount		18,000,000
Long-term debt						17,428,000
Loan term		3 years
Issuance cost (percent)		2.00%
Issuance cost		360,000
Minimum stated interest rate (percent)		11.00%
Percentage of excess cash flows for principal payment, year one		50.00%
Percentage of excess cash flows for principal payment, year two and thereafter		75.00%
Glori Energy Production, Inc. [Member] \| Senior Notes [Member] \| 11% Senior Secured Term Loan [Member] \| Minimum [Member]
Debt Instrument [Line Items]
Principal payment		112,500
Glori Energy Production, Inc. [Member] \| Senior Notes [Member] \| 11% Senior Secured Term Loan [Member] \| London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Variable interest rate (percent)		1.00%
Glori Energy Production, Inc. [Member] \| Convertible Subordinated Debt [Member] \| 6% Subordinated Convertible Promissory Note [Member]
Debt Instrument [Line Items]
Principal amount		2,000,000
Interest rate (percent)		6.00%

Loss_Per_Share_Summary_of_Earn

Loss Per Share Summary of Earnings Per Share (Details) (USD $)	3 Months Ended																12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Numerator:
Net loss																	($18,756)	($10,609)	($11,940)
Denominator:
Weighted-average common shares outstanding - basic																	28,855	1,104	1,055
Effect of dilutive securities																	$0	$0	$0
Weighted-average common shares - diluted																	28,855	1,104	1,055
Net loss per common share, basic and diluted (in dollars per share)	($0.37)	[1]	($0.01)	[1]	($0.20)	[1]	($0.60)	[1]	($4.76)	[1]	($0.73)	[1]	($1.92)	[1]	($2.17)	[1]	($0.65)	($9.61)	($11.32)

[1]	Quarterly loss per share is based on the weighted average number of shares outstanding during the quarter. Because of changes in the number of shares outstanding during the quarters, due to the exercise of stock options and issuance of common stock, the sum of quarterly losses per share may not equal loss per share for the year.

Loss_Per_Share_Summary_of_Anti

Loss Per Share Summary of Antidilutive Securities (Details)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Stock Warrants [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Securities excluded in the calculation of diluted shares outstanding	4,895	0	0
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Securities excluded in the calculation of diluted shares outstanding	2,311	1,898	1,738

Income_Taxes_Narrative_Details

Income Taxes Narrative (Details) (USD $)	12 Months Ended
Income Taxes Narrative (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Tax credit carryforward	$450,000
Reduction to NOL carryforward	5,400,000
Increase in valuation allowance	7,400,000
Net deferred tax assets	0	0
Domestic Tax Authority [Member]
Income Tax Contingency [Line Items]
Operating loss carryforward	51,900,000	36,900,000
Domestic Tax Authority [Member] \| Tax Years 2010 And 2011 [Member]
Income Tax Contingency [Line Items]
Uncertain tax position		31,000
State and Local Jurisdiction [Member]
Income Tax Contingency [Line Items]
Operating loss carryforward	$5,700,000	$5,300,000

Income_Taxes_Effective_Income_

Income Taxes Effective Income Tax Rate Reconciliation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Federal benefit at statutory income tax rate	($6,692)	($3,607)	($4,059)
R&D credits	-83	-118	0
Non-deductible (taxable) expenses	-380	-17	596
State income taxes	-221	-19	-25
Foreign income taxes	209	0	0
Embedded derivative cancellation	0	797	0
Change in valuation allowance	7,376	2,964	3,488
Taxes on income	$209	$0	$0

Income_Taxes_Schedule_of_Defer

Income Taxes Schedule of Deferred Tax Assets and Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current deferred tax asset
Deferred revenue and other	$248,000	$410,000
Allowance for doubtful accounts	0	27,000
Current deferred tax assets, gross	248,000	437,000
Less Valuation allowance	-225,000	-437,000
Current deferred tax assets, net	23,000	0
Current deferred tax liability
Current portion of swap asset	993,000	0
Current deferred tax liability, net	970,000	0
Non-current deferred tax asset
NOL carryforwards (long-term)	16,077,000	10,737,000
R&D credits	450,000	367,000
Other accrued expenses	0	22,000
Stock compensation	154,000	129,000
Depreciable property basis	740,000	556,000
Oil and gas properties	4,040,000	104,000
Noncurrent deferred tax assets, gross	21,461,000	11,915,000
Less Valuation allowance	-19,503,000	-11,915,000
Noncurrent deferred tax assets, net	1,958,000	0
Non-current deferred tax liability
Non-current portion of swap asset	988,000	0
Non-current deferred tax asset, net	970,000	0
Total deferreds, net	$0	$0

Income_Taxes_Components_of_Inc

Income Taxes Components of Income Tax Provision (Benefit) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current tax provision (benefit):
Federal	$0	$0
Foreign	209	0
State	0	0
Total	209	0
Deferred tax provision (benefit):
Federal	0	0
Foreign	0	0
State	0	0
Total	0	0
Total tax provision (benefit):
Federal	0	0
Foreign	209	0
State	0	0
Taxes on income	$209	$0	$0

Employee_Retirement_Savings_Pl1

Employee Retirement Savings Plan Narrative (Details) (401(k) Plan [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
401(k) Plan [Member]
Defined Contribution Plan Disclosure [Line Items]
Discretionary matching contributions	$67,000	$0	$0

Commitments_and_Contingencies_1

Commitments and Contingencies Summary of Minimum Future Capital Lease Payments (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
2015	$356
2016	295
2017	53
Total	$704

Commitments_and_Contingencies_2

Commitments and Contingencies Narrative (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	building	Dec. 31, 2013	Dec. 31, 2012
Operating Leased Assets [Line Items]
Number Of buildings	2
Rent expense	$291,000	$265,000	$181,000
Office, Laboratory, and Manufacturing [Member]
Operating Leased Assets [Line Items]
Monthly rental amount	10,586
Warehouse [Member]
Operating Leased Assets [Line Items]
Monthly rental amount	1,000
Notice required for lease termination	30 days
Office Building [Member]
Operating Leased Assets [Line Items]
Lease term	2 years
Square footage	7,805
Monthly rental amount	$18,498
One Year Extension Option at 4% Increase in Rent [Member] \| Office Building [Member]
Operating Leased Assets [Line Items]
Lease renewal term	1 year
Increase to monthly rental amount (percent)	0.04
Two One-Year Extension Options at a Mutually Agreed Market Rate [Member]
Operating Leased Assets [Line Items]
Lease renewal term	1 year
Two One-Year Extension Options at a Mutually Agreed Market Rate [Member] \| Office Building [Member]
Operating Leased Assets [Line Items]
Number of lease extensions	2

StockBased_Compensation_Summar

Stock-Based Compensation Summary of Stock Option Activity (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Number of Stock Options
Outstanding, beginning balance (in shares)	2,322,180		1,737,633		1,453,534
Awarded (in shares)	7,103		913,853		301,026
Exercised (in shares)	-9,397		-79,003
Forfeited or Expired (in shares)	-19,836	[1]	-250,303	[1]	-16,927	[1]
Outstanding, ending balance (in shares)	2,300,050		2,322,180		1,737,633		1,453,534
Exercisable (in shares)	2,099,345	[2]
Weighted Average Exercise Price
Outstanding as of December 31, 2013 (in dollars per share)	$0.81		$1.42		$1.02
Awarded (in dollars per share)	$1.16		$1.16		$3.34
Exercised (in dollars per share)	$1.16		$0.23
Forfeited or Expired (in dollars per share)	$1.16	[1]	$1.86	[1]	$1.13	[1]
Outstanding as of June 30, 2014 (in dollars per share)	$0.82		$0.81		$1.42		$1.02
Exercisable (in dollars per share)	$0.79	[2]
Weighted Average Remaining Contractual Term
Outstanding (in years)	6 years 8 months 19 days		7 years 8 months 12 days		7 years 8 months 12 days		8 years 4 months 24 days
Exercisable (in years)	6 years 7 months 5 days	[2]
Aggregate Intrinsic Value
Outstanding	$7,725		$782		$3,339
Exercised	70		74
Exercisable	$7,119	[2]

[1]	Management considers the circumstances generating these forfeitures to be unusual and nonrecurring in nature; accordingly, no allowance for forfeitures of options to purchase shares has been considered in determining future vesting or expense.
[2]	The employee options shown as exercisable are subject to a one year lock up agreement pursuant to the terms of the Merger whereby these options, although fully vested, cannot be exercised until April 15, 2015, the day after the first anniversary of the Merger.

StockBased_Compensation_Fair_V

Stock-Based Compensation Fair Value Assumptions (Details)	12 Months Ended
Stock-Based Compensation Fair Value Assumptions (Details)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	2.44%	2.23%	0.87%
Expected volatility	55.00%	55.00%	89.00%
Expected dividend yield	0.00%	0.00%	0.00%
Expected life (in years)	7 years	7 years 1 month 2 days	4 years 5 months 19 days
Expected forfeiture rate	0.00%	0.00%	0.00%

StockBased_Compensation_Narrat

Stock-Based Compensation Narrative (Details) (USD $)	0 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Apr. 14, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Glori stock option conversion ratio	2.9
Glori stock option exercise price increase	2.9
Future unrecognized compensation expense for nonvested shares		$246
Weighted-average grant date fair value		$1.16	$0.22
Total fair value of options vested		303	818	223
Selling, General and Administrative Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation		$296	$774	$291
Glori Oil Limited 2006 Stock Option And Grant Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for issuance			2,581,190
2014 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized		2,000,000
Award expiration period		10 years
2014 Long Term Incentive Plan [Member] \| Year One [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage		25.00%
Award vesting period		1 year
2014 Long Term Incentive Plan [Member] \| Years Two Through Four [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period		36 months
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average vesting period		1 year 7 months 6 days

Segment_Information_Summary_of

Segment Information Summary of Segment Information (Details) (USD $)	3 Months Ended									12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	arrangement		Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Number of first purchaser arrangements										3
Revenues	$3,843		$5,458	$5,556	$1,002	$785	$775	$935	$724	$15,859		$3,219	$2,181
Operating expenses										22,093		10,453	8,753
Impairment of oil and gas properties										13,160		2,190	0
Write-off of deferred offering costs										0		126	1,492
Depreciation, depletion and amortization										4,624		622	578
Gain on commodity derivatives										6,023		0	0
Loss from operations	-17,709		-1,633	-1,880	-2,796	-4,557	-1,766	-1,821	-2,028	-24,018		-10,172	-8,642
Other income (expense)										5,471		-437	-3,298
Income tax expense										209		0	0
Net (loss) income										-18,756		-10,609	-11,940
Property, plant and equipment, net	28,813					2,810				28,813		2,810	5,040
Total assets	67,435					24,619				67,435		24,619	24,477
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenues										0		0	0
Operating expenses										7,788		5,961	4,870
Impairment of oil and gas properties										0		0
Write-off of deferred offering costs												126	1,492
Depreciation, depletion and amortization										32		35	50
Loss from operations										-7,820		-6,122	-6,412
Other income (expense)										-552		-437	-3,298
Income tax expense										209
Net (loss) income										-8,581		-6,559	-9,710
Property, plant and equipment, net	99					62				99		62	76
Total assets	31,483					21,540				31,483		21,540	19,237
Oil And Gas [Member]
Segment Reporting Information [Line Items]
Revenues										11,724	[1]	576	463
Operating expenses										10,777	[1]	2,211	1,768
Impairment of oil and gas properties										13,160	[1]	2,190
Write-off of deferred offering costs												0	0
Depreciation, depletion and amortization										4,188	[1]	200	130
Loss from operations										-16,401	[1]	-4,025	-1,435
Other income (expense)										6,023	[1]	0	0
Income tax expense										0	[1]
Net (loss) income										-10,378	[1]	-4,025	-1,435
Property, plant and equipment, net	27,078	[1]				658				27,078	[1]	658	2,957
Total assets	34,163	[1]				658				34,163	[1]	658	2,957
Oil And Gas [Member] \| Coke Field Assets And Southwest Operating Assets [Member]
Segment Reporting Information [Line Items]
Revenues										11,398
Operating expenses										7,873
Impairment of oil and gas properties										12,707	[1]
Depreciation, depletion and amortization										3,902
Gain on commodity derivatives										-6,023
AERO Service [Member]
Segment Reporting Information [Line Items]
Revenues										4,135		2,643	1,718
Operating expenses										3,528		2,281	2,115
Impairment of oil and gas properties										0		0
Write-off of deferred offering costs												0	0
Depreciation, depletion and amortization										404		387	398
Loss from operations										203		-25	-795
Other income (expense)										0		0	0
Income tax expense										0
Net (loss) income										203		-25	-795
Property, plant and equipment, net	1,636					2,090				1,636		2,090	2,007
Total assets	$1,789					$2,421				$1,789		$2,421	$2,283

[1]	The Oil and Gas Segment for the year ended December 31, 2014 includes direct revenues and expenses not previously included in prior years related to the Coke Field Assets and the Southwest Operating Assets. Included in 2014 are revenues of $11,398,000, operating expenses (including severance taxes) of $7,873,000, depreciation, depletion and amortization of $3,902,000 and gain on commodity derivatives of $6,023,000 (included in other income (expense)) related to these acquisitions and impairment of oil and gas properties of $12,707,000 which are not included in the year ended December 31, 2013 or year ended December 31, 2012.

Segment_Information_Revenue_by

Segment Information Revenue by Geographic Location (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	$3,843	$5,458	$5,556	$1,002	$785	$775	$935	$724	$15,859	$3,219	$2,181
United States [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									13,233	2,201	1,957
Canada [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,220	952	224
Other Foreign Countries [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									$406	$66	$0

Subsequent_Events_Details

Subsequent Events (Details) (10% Secured Term Promissory Note [Member], Subsequent Event [Member], USD $)	0 Months Ended
	Mar. 02, 2015
10% Secured Term Promissory Note [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Repayments of debt	$900,000
End of term charge	$280,000

Supplemental_Information_for_O2

Supplemental Information for Oil and Gas Producing Activities Quantities of Proved Reserves (Details)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Sep. 30, 2012
	MBoe		MBoe		MBoe		Sep. 30, 2012
Proved Developed and Undeveloped Reserves [Abstract]
Working interest (percent)							100.00%
Oil [Member] \| United States [Member]
Proved Developed and Undeveloped Reserves [Abstract]
Proved developed reserves, beginning balance	18		103		160
Proved Developed and Undeveloped Reserve, Purchase of Mineral in Place (Energy)	1,792	[1]			75	[2]
Production	-145		-6		-5
Revisions of previous estimates	-254	[3]	-79	[4]	-127	[5]
Proved developed reserves, ending balance	1,411		18		103

[1]	Purchase of the Coke Field Assets on March 14, 2014 and the Southwest Operating Assets on September 1, 2014.
[2]	In September 2012, the Company acquired a 100% working interest in a property adjacent to the Companybs previously leased property in Kansas, the Etzold Field.
[3]	The reserves revision is due to an increase in costs over our prior year reserve report.
[4]	Unfavorable production results on wells achieved in 2013 led to the Company's decision to abandon the proved developed behind pipe reserves as recent results indicated these reserves would be uneconomic to produce.
[5]	The Etzold field was developed in phases. During 2011 only the initial phase was operating and thus the reserves for the second phase were based on the results achieved in the initial phase. These reserve estimates declined as of December 31, 2012 since the second phase production results were not as economically favorable as the initial phase.

Supplemental_Information_for_O3

Supplemental Information for Oil and Gas Producing Activities Proved Developed and Undeveloped Reserves (Details) (Oil [Member], United States [Member])	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MBoe	MBoe	MBoe	MBoe
Oil [Member] \| United States [Member]
Reserve Quantities [Line Items]
Proved developed reserves	1,411	18	103	160
Proved undeveloped reserves	0	0	0
Total	1,411	18	103

Supplemental_Information_for_O4

Supplemental Information for Oil and Gas Producing Activities Capitalized Costs Relating to Oil and Gas Producing Activities (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Extractive Industries [Abstract]
Unproved properties	$196		$0
Proved properties	45,694		3,141
Total	45,890		3,141
Less - accumulated depreciation, depletion and amortization	-19,612	[1]	-2,493	[1]
Net capitalized costs	26,278		648
Oil and gas property impairment	$13,160		$2,190		$0

[1]	Accumulated depreciation, depletion and amortization includes the 2013 oil and gas property impairment of $2,190,000 and the 2014 impairment of $13,160,000.

Supplemental_Information_for_O5

Supplemental Information for Oil and Gas Producing Activities Cost Incurred in Oil and Gas Producing Activities (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Extractive Industries [Abstract]
Acquisition of properties	$42,788	$0	$139
Development	0	84	1,227
Total costs incurred	$42,788	$84	$1,366

Supplemental_Information_for_O6

Supplemental Information for Oil and Gas Producing Activities Results of Operations for Oil and Gas Producing Activities (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Extractive Industries [Abstract]
Revenues from oil and gas producing activities	$11,724	$576	$463
Production costs	6,631	433	513
Ad valorem taxes	438	42	15
State severance taxes	547	26	21
Impairment of oil and gas property	13,160	2,190	0
Depreciation, depletion and amortization	3,960	177	111
Total expenses	24,736	2,868	660
Pre-tax loss from producing activites	-13,012	-2,292	-197
Income tax expense	0	0	0
Results of oil and gas producing activities	($13,012)	($2,292)	($197)

Supplemental_Information_for_O7

Supplemental Information for Oil and Gas Producing Activities Discounted Future Cash Flows Relating to Proved Reserves (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Extractive Industries [Abstract]
Future cash inflows	$133,235	$1,603	$9,087
Future production and development costs
Production	-86,032	-896	-5,203
Development	0	0	-721
Future cash flows before income taxes	47,203	707	3,163
Future income taxes	0	0	-225
Future net cash flows after income taxes	47,203	707	2,938
10% annual discount for estimated timing of cash flows	-17,111	-146	-1,150
Standardized measure of discounted future net cash flows	$30,092	$561	$1,788	$1,020

Supplemental_Information_for_O8

Supplemental Information for Oil and Gas Producing Activities Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning balance	$561	$1,788	$1,020
Changes from:
Sales, net of production costs	-4,108	-101	65
Net changes in prices and production costs	2,445	-15	-1,233
Changes in estimated future development costs	0	-655	-596
Development costs incurred during the year, previously estimated		0	1,031
Revisions to quantity estimates	-8,044	-638	-770
Accretion of discount	56	56	245
Purchases of reserves in place	38,211	0	1,351
Net changes in income taxes	0	-65	-164
Changes in timing of cash flows and other	971	191	839
Ending balance	$30,092	$561	$1,788

Selected_Quarterly_Financial_R2

Selected Quarterly Financial Results Summary of Results of Operations (Details) (USD $)	0 Months Ended	3 Months Ended																12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Apr. 14, 2014	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
Net revenues		$3,843		$5,458		$5,556		$1,002		$785		$775		$935		$724		$15,859	$3,219	$2,181
Loss from operations		-17,709		-1,633		-1,880		-2,796		-4,557		-1,766		-1,821		-2,028		-24,018	-10,172	-8,642
Net loss applicable to stockholders		($11,656)		($356)		($6,060)		($684)		($5,402)		($825)		($2,074)		($2,308)
Net loss per common share, basic and diluted (in dollars per share)		($0.37)	[1]	($0.01)	[1]	($0.20)	[1]	($0.60)	[1]	($4.76)	[1]	($0.73)	[1]	($1.92)	[1]	($2.17)	[1]	($0.65)	($9.61)	($11.32)
Weighted average shares outstanding, basic and diluted		31,499	[2]	31,475	[2]	29,642	[2]	1,137	[2]	1,136	[2]	1,136	[2]	1,078	[2]	1,064	[2]	28,855	1,104	1,055
Glori stock option conversion ratio	2.9

[1]	Quarterly loss per share is based on the weighted average number of shares outstanding during the quarter. Because of changes in the number of shares outstanding during the quarters, due to the exercise of stock options and issuance of common stock, the sum of quarterly losses per share may not equal loss per share for the year.
[2]	As a result of the Merger with Infinity Corp., which consummated on April 14, 2014, the issued and outstanding common stock was canceled and reissued as common stock in the newly merged entity at a conversion ratio of 2.9 pre-Merger common stock to 1 post-Merger common stock. For the periods prior to the Merger, the above table reflects the common stock as converted to post-Merger common stock using this ratio.