Glori Energy (GLRI) 10-K 23 Mar 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Mar. 21, 2016	Jun. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Glori Energy Inc.
Trading Symbol	GLRI
Entity Central Index Key	1,597,131
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		32,655,949
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Public Float			$ 20,337

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 8,380	$ 29,751
Accounts receivable	1,456	1,371
Commodity derivatives	3,411	2,905
Prepaid expenses and other current assets	314	244
Total current assets	13,561	34,271
Property and equipment:
Proved oil and gas properties - successful efforts	48,454	45,694
Other property and equipment	6,439	5,941
Total property and equipment and proved oil and gas properties, gross	54,893	51,635
Less: accumulated depreciation, depletion and amortization	(47,578)	(22,822)
Total property and equipment, net	7,315	28,813
Commodity derivatives	0	2,891
Deferred loan costs	227	490
Deferred tax asset	1,161	970
Total assets	22,264	67,435
Current liabilities:
Accounts payable	1,430	2,251
Deferred revenues	0	653
Accrued expenses	1,180	1,792
Current portion of long-term debt	480	2,380
Current deferred tax liability	1,161	970
Total current liabilities	4,251	8,046
Long-term liabilities:
Long-term debt, less current portion	10,045	16,845
Asset retirement obligation, less current portion	1,457	1,329
Total long-term liabilities	11,502	18,174
Total liabilities	$ 15,753	$ 26,220
Commitments and contingencies
Stockholders' equity:
Preferred stock, $.0001 par value, 5,000,000 shares authorized, no shares issued and outstanding as of December 31, 2014 and 2015	$ 0	$ 0
Common stock, $.0001 par value, 100,000,000 shares authorized, 31,499,303 and 31,861,357 shares issued and outstanding as of December 31, 2014 and 2015, respectively	3	3
Additional paid-in capital	106,934	105,383
Accumulated deficit	(100,426)	(64,171)
Total stockholders' equity	6,511	41,215
Total liabilities and stockholders' equity	$ 22,264	$ 67,435

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Preferred Stock, par value (in USD per share)	$ 0.0001	$ 0.0001
Preferred Stock, shares authorized	5,000,000	5,000,000
Preferred Stock, shares issued	0	0
Preferred Stock, shares outstanding	0	0
Common stock, par value (in USD per share)	$ 0.0001	$ 0.0001
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	31,861,357	31,499,303
Common stock, shares outstanding	31,861,357	31,499,303

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Revenues:
Oil and gas revenues	$ 7,397	$ 11,724
Service revenues	1,605	4,135
Total revenues	9,002	15,859
Operating expenses:
Oil and gas operations	9,974	10,777
Service operations	1,771	3,528
Science and technology	1,940	1,868
Selling, general and administrative	5,884	5,920
Impairment of oil and gas properties	22,600	13,160
Depreciation, depletion and amortization of property and equipment	5,507	4,624
Total operating expenses	47,676	39,877
Loss from operations	(38,674)	(24,018)
Other income (expense):
Interest expense	(2,169)	(3,023)
Gain on change in fair value of warrants	0	2,454
Gain on commodity derivatives	3,961	6,023
Other income	445	17
Total other income, net	2,237	5,471
Net loss before taxes on income	(36,437)	(18,547)
Income tax expense (benefit)	(182)	209
Net loss	$ (36,255)	$ (18,756)
Net loss per common share, basic and diluted (in dollars per share)	$ (1.14)	$ (0.65)
Weighted average common shares outstanding, basic and diluted	31,769	28,855

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Deficit [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]Common Stock [Member]	Series C-2 Preferred Stock and Preferred Warrants [Member]Additional Paid-in Capital [Member]
Beginning balance at Dec. 31, 2013	$ 16,196	$ 2	$ 61,609	$ (45,415)
Beginning balance (in shares) at Dec. 31, 2013		22,450,688
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock based compensation	$ 296		296
Stock option exercises (in shares)	9,397
Issuance, repurchase and cancellation of common shares	$ (30)		(30)
Change in fair value of warrant liability	(2,454)		(2,454)
Share issuance, as converted (formerly C-2 preferred shares and warrants)					$ 5,049	$ 0	$ 5,049
Share issuance, as converted (formerly C-2 preferred shares and warrants) (in shares)						1,133,869
Recapitalization due to merger	34,726	$ 1	34,725
Recapitalization due to merger (in shares)		6,658,449
Conversion to common stock	2,000		2,000
Conversion to common stock (in shares)		250,000
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
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock based compensation	$ 1,412		1,412
Stock based compensation (in shares)		150,808
Stock option exercises (in shares)	211,246	211,246
Stock Issued During Period, Value, Stock Options Exercised	$ 139		139
Net loss	(36,255)			(36,255)
Ending balance at Dec. 31, 2015	$ 6,511	$ 3	$ 106,934	$ (100,426)
Ending balance (in shares) at Dec. 31, 2015	31,861,357	31,861,357

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Statement of Cash Flows [Abstract]
Net loss	$ (36,255)	$ (18,756)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization of property and equipment	5,507	4,624
Exploration expenses	102	0
Stock-based compensation	1,412	296
Bad debt expense	56	0
Amortization of deferred loan costs and other	326	439
Accretion of end-of-term charge	40	96
Unrealized gain on change in fair value of commodity derivatives	(340)	(5,796)
Gain on change in fair value of warrant liabilities	0	(2,454)
Accretion of discount on long-term debt	28	67
Loss on disposal of property and equipment	75	0
Gain on the sale of Etzold	(422)	0
Settlement of asset retirement obligations	(44)	0
Impairment of oil and gas properties	22,600	13,160
Changes in operating assets and liabilities:
Accounts receivable	(141)	(1,087)
Prepaid expenses and other current assets	(70)	(149)
Accounts payable	(1,126)	1,339
Deferred revenues	(653)	(1,100)
Accrued expenses	(806)	1,135
Net cash used in operating activities	(9,711)	(8,186)
Cash flows from investing activities:
Purchase of proved oil and gas property	(5,220)	(41,353)
Purchase of other property and equipment	(588)	(1,009)
Proceeds from the sale of long-term commodity derivatives	2,725	0
Proceeds from the sale of Etzold	75	0
Net cash used in investing activities	(3,008)	(42,362)
Cash flows from financing activities:
Proceeds from issuance of common stock, preferred stock and preferred warrants	0	5,019
Proceeds from issuance of long-term debt	52	24,035
Proceeds from exercise of warrants and stock options	139	4,188
Proceeds from merger with Infinity Corp. including private placement of common stock	0	38,441
Payments on long-term debt	(8,780)	(8,147)
Payments for deferred offering costs	(63)	(3,337)
Payments for deferred loan costs	0	(767)
Net cash provided by (used in) financing activities	(8,652)	59,432
Net increase (decrease) in cash and cash equivalents	(21,371)	8,884
Cash and cash equivalents, beginning of period	29,751	20,867
Cash and cash equivalents, end of period	8,380	29,751
Non-cash financing and investing activities:
Asset retirement obligation assumed	517	883
Supplemental cash flow information:
Interest paid	$ 2,240	$ 2,990

Organization

Organization	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	ORGANIZATION 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. ("GEP"), a wholly-owned subsidiary of Glori Holdings Inc., to purchase the Coke Field Assets (see NOTE 5 ) and incur the associated acquisition debt. The dissolution of Glori Oil S.R.L and Glori Oil (Argentina) Limited were effective on August 24, 2015. During the year ended December 31, 2014 and 2015 there were no revenues and no assets associated with Glori Oil S.R.L and Glori Oil (Argentina) Limited. Glori Energy Inc., GETI, 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 Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
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 fifteen customers during 2014 , and four customers during 2015 . The following is a reconciliation of the customers that exceeded 10% of total service revenues in each of those periods: Percentage of service revenues Customer 2014 2015 A 36 % — B 17 % 20 % C 10 % 65 % D 10 % — Management does not believe that these customers constitute a significant credit risk. The Company had outstanding receivables related to service revenues from four customers as of December 31, 2014 and one customer as of December 31, 2015 . 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 Customer 2014 2015 C — 100% D 19% — E 54% — F 27% — 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 year ended December 31, 2015 there was one purchaser that accounted for 93% of the total oil revenue. 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 years ended year ended December 31, 2014 and 2015 . As of December 31, 2014 and 2015 , the Company had a $ 900,000 and $436,000 receivable, respectively, for December oil sales from a single oil purchaser. The Company also engages in NYMEX swaps with a third party company (see NOTE 9 ). 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. As of December 31, 2014 and December 31, 2015 the Company had no allowance for doubtful accounts. 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, periodically and when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable. The initial 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 impaired its proved-oil and gas properties for the fiscal years ended December 31, 2014 and 2015 . To determine the remaining value of the net assets, the Company typically uses a discounted future cash flow approach based on the proved and probable reserves at estimated future commodities prices less regional discounts to calculate the value of the reserves at fiscal year-end. At December 31, 2015 there was no economic value assigned to any proved undeveloped reserves. The Company believes this estimate to approximate fair value. The impairments in 2014 and 2015 were a result of a sharp decline in oil prices. The reduction in asset value of proved oil and gas properties of $ 13,160,000 and $ 22,600,000 represents the impairment amounts incurred in 2014 and 2015 , 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 8 and NOTE 9 ). 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 11 ). 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. 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, 2014 and 2015 , the Company had deferred revenues of approximately $653,000 and $0 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 expenses 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 2006 through 2015 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 The Company has issued stock options, restricted shares, performance based options and market based options. The Company records 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. Stock-based compensation cost for restricted shares is estimated at the grant date based on the awards' fair value, which is equal to the prior day's closing stock price. Such fair value is recognized as expense over the requisite service 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. Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board (IASB) issued a comprehensive new revenue recognition standard that will supersede existing revenue recognition guidance under United States generally accepted accounting principles (U.S. GAAP) and International Financial Reporting Standards (IFRS). The issuance of this guidance completes the joint effort by the FASB and the IASB to improve financial reporting by creating common revenue recognition guidance for U.S. GAAP and IFRS. The core principle of the new guidance is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The standard creates a five-step model that requires companies to exercise judgment when considering the terms of a contract and all relevant facts and circumstances. The standard allows for several transition methods: (a) a full retrospective adoption in which the standard is applied to all of the periods presented, or (b) a modified retrospective adoption in which the standard is applied only to the most current period presented in the financial statements, including additional disclosures of the standard’s application impact to individual financial statement line items.This standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. We are currently evaluating this standard and the impact it will have on our future revenue recognition policies. In August 2014, the FASB issued Accounting Standards Update No. 2014-15: Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15). ASU 2014-15 asserts that management should evaluate whether there are relevant condition or events that are known and reasonably knowable that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued or are available to be issued when applicable. If conditions or events at the date the financial statements are issued raise substantial doubt about an entity’s ability to continue as a going concern, disclosures are required which will enable users of the financial statements to understand the conditions or events as well as management’s evaluation and plan. ASU 2014-15 is effective for the annual period ending after December 15, 2016, and for annual and interim periods thereafter; early application is permitted. We are currently evaluating this standard and the impact it will have on our consolidated financial statements. In April 2015, the FASB issued ASU No. 2015-03, "Interest—Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs" (ASU 2015-03). ASU 2015-03 is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015 and early adoption is permitted. Prior GAAP guidance mandates recognizing debt issuance costs as a deferred charge. Such treatment is different from the guidance in International Financial Reporting Standards (IFRS), which requires that transaction costs be deducted from the carrying value of the financial liability and not recorded as separate assets. Additionally, the requirement to recognize debt issuance costs as deferred charges conflicts with the guidance in FASB Concepts Statement No. 6, Elements of Financial Statements, which states that debt issuance costs are similar to debt discounts and in effect reduce the proceeds of borrowing, thereby increasing the effective interest rate. Concepts Statement 6 further states that debt issuance costs cannot be an asset because they provide no future economic benefit. To simplify presentation of debt issuance costs, the amendments in this Update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this Update. We are currently evaluating this standard and the impact it will have on our consolidated financial statements. In November 2015, the FASB issued Accounting Standards Update No. 2015-17: Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes (ASU 2015-17). ASU 2015-17 is part of an initiative to reduce complexity in accounting standards. Current GAAP requires an entity to separate deferred income tax liabilities and assets into current and noncurrent amounts in a classified statement of financial position. However, this classification does not generally align with the time period in which the recognized deferred tax amounts are expected to be recovered or settled. To simplify the presentation of the deferred income taxes, ASU 2015-17 requires that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The current requirement that deferred tax liabilities and assets of an entity be offset and presented as a single amount is not affected by the amendments of ASU 2015-17. For public entities, ASU 2015-17 is effective for financial statements issued for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years; early application is permitted. The provisions of this accounting update are not anticipated to have a material impact on the Company’s financial position or results of operations. Reclassifications Certain 2014 amounts related to inventory and prepaid expenses and other current assets have been reclassified for comparative purposes.

Risks and Uncertainties

Risks and Uncertainties	12 Months Ended
	Dec. 31, 2015
Risks and Uncertainties [Abstract]
Risks and Uncertainties	RISKS AND UNCERTAINTIES As a small company with an emerging technology the Company has generated negative cash flows since inception. The Company continues to generate negative cash flows and the downturn in the oil market has adversely affected its results from operations and cash flows. Cash has decreased from $29.8 million at December 31, 2014 to $8.4 million at December 31, 2015 due to the net cash used in operating activities of $9.7 million , the repayment of debt of $8.8 million net, and capital expenditures of $3.0 million , net of the proceeds from the sale of the long-term derivatives of $2.7 million . As of December 31, 2015 the Company has working capital of $9.3 million . Based on its cash balance and forecasted cash flows from operating activities, the Company expects to be able to fund planned capital expenditures, meet debt service requirements, and fund other commitments and obligations for 2016. As of March 21, 2015, the Company does not have lines of credit available to it. As a result of the negative cash flows and the decrease in oil prices, the Company will likely need to raise capital over the next twelve months to fund its operations and to repay or refinance its term note of $10.5 million which matures March of 2017. The Company may have difficulty obtaining such additional financing as a result of the decrease in oil prices, its negative cash flows from operations and the significant decrease in its share price. Failure to obtain additional financing would have a material adverse effect on the Company’s business operations and financial condition. On October 23, 2015, the Company received a deficiency letter (the “Notice Letter”) from The NASDAQ Stock Market LLC (“NASDAQ”) indicating that the Company’s common stock for the last 30 consecutive business days had closed below the minimum $1.00 per share requirement under NASDAQ Listing Rule 5550(a)(2) (the “Minimum Bid Price Requirement”). The Notification Letter states that Glori has 180 calendar days, until April 20, 2016 (the “Initial Compliance Period”), to regain compliance with the Minimum Bid Price Requirement. In accordance with NASDAQ Listing Rule 5810(c)(3)(A), the Company can regain compliance if the closing bid price of its common stock is at least $1.00 for a minimum of 10 consecutive business days. If the Company does not achieve compliance with the Minimum Bid Price Requirement by the end of the Initial Compliance Period, it may be granted a second 180 day compliance period, as long as (a) on the last day of the Compliance Period the Company is in compliance with the market value requirement for continued listing as well as all other listing standards and (b) the Company provides written notice of its intention to cure the deficiency during a second compliance period. The significant decrease in oil prices has made it difficult for the Company to execute on its strategy of acquiring producing properties which would contribute to its revenues and cash flows due to potential sellers’ reluctance to sell at depressed prices. Additionally, the current oil price environment has negatively affected the Company's cash flow and has affected the availability of capital to Glori and the E&P industry in general. These factors have also resulted in a dramatic decrease in the Company's stock price, which also impacts the ability to raise new equity capital. In order to address this challenging environment, the Company has retained a financial advisory firm with experience in the energy industry to actively explore alternatives for mergers and acquisitions with potential partners, investors and asset sellers with the goal of bolstering its liquidity and enabling the Company to build a larger asset base. Additionally, the Company made significant cost reductions, both in its administrative and professional staff, and lease operating expenses. The cost reductions were implemented both in 2015 and in the first quarter of 2016. The Company also limited capital expenditures to those required to fully implement AERO technology at the Coke field. The Company believes demonstrated AERO technology results at the Coke field will enhance revenues and cash flows and will improve its ability to raise additional capital. In August 2015, the Company implemented the first phase of AERO at the Coke field. In March 2016 it completed installation of phase II of AERO implementation. Phase II incorporates the addition of two AERO injection wells to increase the proportion of the field that is impacted by AERO technology. The Company now has three injection wells running in total. Phase II implementation commenced after data from Phase I limited trial demonstrated encouraging indication of AERO performance. The wells are located on the periphery of the Coke field and are designed to stimulate production from more of the field than was impacted by the first injector. Finally, the Company applied to the United States Department of Energy’s Loan Programs Office (“LPO”) for a $150 million loan guarantee in connection with a project applying AERO to previously abandoned reservoirs in the U. S. Based on LPO’s evaluation of Part I of the application, in March 2016, LPO invited the Company to submit Part II of its application. However, the ultimate outcome of the application and whether a loan guarantee will be issued cannot be predicted. On March 18, 2016, GEP entered into an amendment to the credit agreement on the senior secured term loan facility with its lender, Stellus Capital Investment Corporation, which had the effect of removing the financial ratio covenants and the semi-annual collateral value redetermination until maturity in March 2017 (see NOTE 10 ). Without this amendment the Company likely would not have been able to meet all financial covenants in the future.

Merger with Infinity Cross Bord

Merger with Infinity Cross Border Acquisition Corporation	12 Months Ended
	Dec. 31, 2015
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, 2014 to facilitate comparability to prior periods. Accordingly, the number of shares of common stock presented as outstanding as of January 1, 2014 totals 22,450,688 which represents the number of post-Merger common shares that were received for pre-Merger GETI preferred stock, common stock and warrants outstanding as of January 1, 2014 . 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, 2014 . The beginning balances as of January 1, 2014 , shown in the table below, represent the Company's pre-Merger temporary equity and stockholders' equity previously stated as of January 1, 2014 . The balances as of January 1, 2014 , as converted, represent the post-Merger stockholders' equity received in exchange for the pre-Merger temporary equity and stockholders' equity at January 1, 2014 . 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, 2014 475,541 $ 13,762 2,901,052 $ 31,900 7,296,607 $ 29,773 4,462,968 $ 3,234 $ 78,669 3,295,771 $ 1 $ — $ (76,379 ) $ (76,378 ) Reversal of pre-Merger temporary equity (475,541 ) (13,762 ) (2,901,052 ) (31,900 ) (7,296,607 ) (29,773 ) (4,462,968 ) (3,234 ) $ (78,669 ) — — — 78,669 78,669 Reversal of pre-Merger common shares — — — — — — — — — (3,295,771 ) (1 ) 1 — — Reclassification of pre-Merger warrants from liability to additional paid-in capital — — — — — — — — — — — 13,905 — 13,905 Conversion of pre-Merger shares to post-Merger shares — — — — — — — — — 22,450,688 2 (2 ) — — Segregate historical accumulated deficit from additional paid-in capital — — — — — — — — — — — 47,705 (47,705 ) — Balances as of January 1, 2014, as converted — $ — — $ — — $ — — $ — $ — 22,450,688 $ 2 $ 61,609 $ (45,415 ) $ 16,196 Not shown in the above table is the pre-Merger issuance by GETI of common shares, preferred shares and warrants. 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 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 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 10 ). In addition to the common stock issued in the Merger, the Company has 5,321,700 warrants outstanding at December 31, 2014 and December 31, 2015 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, 2015
Property, Plant and Equipment [Abstract]
Property and Equipment	PROPERTY AND EQUIPMENT Property and equipment consists of the following ( in thousands ): December 31, 2014 2015 Proved oil and gas properties - successful efforts $ 45,694 $ 48,454 Unproved oil and gas properties 196 443 Construction in progress 589 594 Laboratory and warehouse facility 640 648 Laboratory and field service equipment 3,158 3,355 Office equipment, computer equipment, vehicles and other 1,358 1,399 51,635 54,893 Less: accumulated depreciation, depletion and amortization (1) (22,822 ) (47,578 ) Total property and equipment, net $ 28,813 $ 7,315 (1) Includes impairment and excludes accretion of asset retirement obligation. Depreciation, depletion and amortization consists of the following ( in thousands ): Year ended December 31, 2014 2015 Depreciation and amortization expense $ 523 $ 628 Depletion expense 3,960 4,723 Accretion of asset retirement obligation 141 156 Total depreciation, depletion, and amortization of property and equipment $ 4,624 $ 5,507 On March 14, 2014, a subsidiary of the Company, GEP, acquired certain oil, gas and mineral leases in Wood County Texas (the “Coke Field”) 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 10 ) 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, 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 (the "Southwest Operating Field"). The Company purchased the Southwest Operating Field 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 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 Field September 1 through December 31, 2014. For this period, the revenues and net loss attributable to the Coke Field and Southwest Operating Field 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 9 ) 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, 2014 , as if the Coke Field acquisition had been consummated at January 1, 2014 ( in thousands, except per share amounts ): Year ended December 31, 2014 Total revenues $ 18,604 Net loss (19,111 ) Net loss per common shares, basic and diluted $ (0.66 ) Weighted average shares outstanding: Basic 28,855 Diluted 28,855 On July 1, 2015 the Company sold its mineral interests in the "Etzold Field" located in Seward County, Kansas. The Etzold Field was originally purchased in 2010 as a greenfield lab to advance the development of the Company's AERO technology, and the operations have historically been included in the Company's Oil and Gas Segment (see NOTE 16 ). With the purchase of the larger Coke Field and with the Company's future acquisition plans, the Company made the strategic decision to divest the Etzold Field. Prior to the sale, the Company had associated net assets of $89,000 , which were composed primarily of the purchase and development charges less accumulated depreciation and depletion and associated liabilities of $435,000 related to the plugging and abandonment obligation associated with the Etzold Field. In exchange for the leasehold interest in the field, the Company received $75,000 and the purchaser's assumption of the related asset retirement obligation. The Company recognized a gain on the sale of $422,000 . The following table is a summarized operational history of the Etzold Field (in thousands) : Year ended December 31, 2014 2015 Revenue $ 327 $ 57 Expenses 433 200 Net loss from operations (106 ) (143 ) Income taxes — — Net loss $ (106 ) $ (143 ) On June 1, 2015, a subsidiary of the Company, GEP, executed a purchase and sale agreement to acquire certain proved oil and gas mineral leases in Refugio County, Texas (the “Bonnie View Field”) from a third party seller for $2,644,000 . The carrying value of the Bonnie View Field is also increased by an asset retirement obligation associated with plugging and abandoning the Bonnie View Field of $432,000 . The effective date of the purchase was May 1, 2015. The Company included revenues and expenses related to the Bonnie View Field from June 1, 2015 to December 31, 2015 on our consolidated income statement. For this period, the revenues and net loss attributable to the Bonnie View Field was $447,000 and $3,208,000 , respectively. The net loss includes a loss on impairment of oil and gas properties of $2,400,000 . The Bonnie View Field does not meet the definition of a significant acquisition which would require pro forma financial information.

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2015
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. 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 for the years ended December 31, 2014 and 2015 ( in thousands ): Year ended December 31, 2014 2015 Balance at the beginning of period $ 305 $ 1,329 Liabilities acquired during the period 883 451 Liabilities settled during the period — (44 ) Accretion expense 141 156 Sold — (435 ) Revisions in estimates — 65 Balance at the end of the period $ 1,329 $ 1,522 The increase in liabilities acquired during the year ended December 31, 2014 , was due to the acquisition of the Coke Field and the Southwest Operating Assets. The increase in liabilities acquired during the year ended December 31, 2015 , was due to the acquisition of the Bonnie View Field and drilling activity at the Coke Field. The decreases due to sold wells were due to the sale of the Etzold Field. Additionally, estimated plug date revisions and well plugging and abandonment during the year ended December 31, 2015 caused the changes in the revisions in estimates and liabilities settled during the period, respectively. The asset retirement obligation is included in the consolidated balance sheets as follows (in thousands) : December 31, 2014 2015 Accrued liabilities $ — $ 65 Asset retirement obligation 1,329 1,457 $ 1,329 $ 1,522

Accrued Expenses

Accrued Expenses	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Accrued Expenses	ACCRUED EXPENSES As of December 31, 2014 and 2015 , the significant components of accrued expenses reported in the accompanying consolidated balance sheets are as follows ( in thousands ): December 31, 2014 2015 Accrued compensation and benefits $ 892 $ 91 Accrued end-of-term charge (see NOTE 10) 240 — Accrued interest 15 386 Accrued taxes 223 47 Accrued royalties 164 134 Asset retirement obligations — 65 Accrued lease operating expenses and other 258 457 $ 1,792 $ 1,180

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
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 and 2015 ( 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 Fair value measurements using Level 1 Level 2 Level 3 Total December 31, 2015 Short-term commodity derivatives, asset $ — $ 3,411 $ — $ 3,411 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, 2015
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, 2015 the Company had the following open positions on its outstanding commodity derivative contracts: Period Volume/Month (Bbls) Price/Unit Fair Value - Asset January 2016 - March 2016 7,300 $ 86.50 $ 1,053,000 April 2016 - December 2016 6,550 $ 82.46 $ 2,358,000 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. The Company settled its long-term commodity derivative assets on December 23, 2015 in exchange for $2,725,000 . At the time of the sale the NYMEX value for the sold portion of the commodity swaps was $3,192,000 . Accordingly the sale resulted in a $467,000 loss on commodity derivatives which is included in the gain on commodity derivatives line item on the Company's consolidated statements of operations. As of December 31, 2014 and 2015 the Company had a current asset for commodity derivatives of $2,905,000 and $3,411,000 . The following tables summarize the unrealized and realized gain on commodity derivatives ( in thousands ): Year ended December 31, 2014 2015 Unrealized gain on commodity derivatives $ 5,796 $ 340 Early termination of long-term commodity derivatives — (2,725 ) Realized gain on commodity derivatives 227 6,346 $ 6,023 $ 3,961

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2015
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 contained 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 were exchanged for 18,208 common shares upon consummation of the Merger. Equal monthly principal payments were due over 27 months beginning in April 2013 through June 2015, plus an end of term charge of $280,000 . As of December 31, 2014 , the ratable liability for the end of term charge was $240,000 and it is included in other long-term liabilities and accrued expenses in current liabilities on the accompanying 2014 consolidated balance sheet. The loan agreement contains covenants which place restrictions on the incurrence of debt, liens and capital expenditures. As of December 31, 2014 the outstanding loan balance was $1,750,000 . On March 2, 2015 the Company elected to prepay the entire remaining indebtedness. The payment included remaining principal of $888,888 and the end of term charge of $280,000 . 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 GEP and is secured by the Coke Field and Bonnie View and shares of common stock of GEP. Glori Energy Inc does not guarantee the debt of GEP. 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 GEP’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 , GEP 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 GEP. As of December 31, 2014 and December 31, 2015 , the outstanding loan balance was $17,428,000 and $10,452,000 , respectively. GEP is in compliance with all covenants as of December 31, 2015 . On March 18, 2016, GEP entered into an amendment to the credit agreement on the senior secured term loan facility with its lender, Stellus Capital Investment Corporation, which had the effect of removing the financial ratio covenants and the semi-annual collateral value redetermination until maturity in March 2017. In connection with the amendment, the interest rate on the loan increased to 13.0% per annum from 11.0% , with the additional 2.0% increase to be “paid in kind”, or added to the principal amount. In addition, principal of $37,500 plus interest is payable monthly compared to the minimum principal payments of $112,500 plus interest which was previously payable quarterly. Without this amendment we likely would not have been able to meet all of our financial covenants in the future. The $4.0 million note had a two year term bearing interest at 12.0% per annum and is secured by the assets of the Company but was 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, GEP, 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 five years are as follows ( in thousands ): Year ended December 31, Amount 2016 $ 480 2017 10,012 2018 9 2019 9 2020 9 Thereafter 6 $ 10,525

Loss Per Share

Loss Per Share	12 Months Ended
	Dec. 31, 2015
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, 2014 2015 Numerator: Net loss $ (18,756 ) $ (36,255 ) Denominator: Weighted-average common shares outstanding - basic 28,855 31,769 Effect of dilutive securities — — Weighted-average common shares - diluted 28,855 31,769 Net loss per common share - basic and diluted $ (0.65 ) $ (1.14 ) 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, 2014 2015 Common stock warrants ($10 strike price) 4,895 5,321 Common stock options 2,311 2,039 Restricted shares — 82

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES At December 31, 2014 and 2015 , the Company had operating loss carryforwards for federal income tax reporting purposes of approximately $45.7 million and $64.5 million , respectively, which will begin to expire in the year 2025, net operating losses for state income tax reporting purposes of approximately $6.6 million and $6.7 million , respectively, which will begin to expire in 2021, and tax credits of approximately $508,000 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, 2014 2015 Federal benefit at statutory income tax rate $ (6,692 ) $ (12,374 ) R&D credits (83 ) (58 ) Non-deductible (taxable) expenses & other items (380 ) 422 State income taxes - net of federal benefit (221 ) (33 ) Foreign income taxes 209 (182 ) Change in valuation allowance 7,376 12,043 Taxes on income $ 209 $ (182 ) The tax effects of temporary differences that give rise to significant portions of the Company’s net deferred tax assets at December 31, 2014 and 2015 are as follows ( in thousands ): Year ended December 31, 2014 2015 Current deferred tax asset Deferred revenue and other $ 248 $ 9 Less valuation allowance (225 ) (9 ) 23 — Current deferred tax liability Current portion of swap asset 993 1,161 Current deferred tax liability, net 970 1,161 Non-current deferred tax asset NOL carryforwards (long-term) 16,077 22,233 R&D credits 450 508 Stock compensation 154 346 Depreciable property basis 740 450 Oil and gas properties 4,040 9,386 21,461 32,923 Less valuation allowance (19,503 ) (31,762 ) 1,958 1,161 Non-current deferred tax liability Non-current portion of swap asset 988 — Non-current deferred tax asset, net 970 1,161 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, 2014 2015 Current tax provision (benefit): Federal — — Foreign 209 (182 ) State — — Total $ 209 $ (182 ) Deferred tax provision (benefit): Federal — — Foreign — — State — — Total $ — $ — Total tax provision (benefit): Federal — — Foreign 209 (182 ) State — — Total $ 209 $ (182 ) The valuation allowance for deferred tax assets increased by $12.0 million in 2015. 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 2015 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 $12.0 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. 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. 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. The Company's $22.2 million deferred tax asset related to the NOL carryforwards is net of $87,000 of unrealized excess tax benefits related to stock based compensation. The impact of the excess tax benefit will be recognized in additional paid-in capital upon utilization of the Company's NOL and tax credit carryforwards.

Employee Retirement Savings Pla

Employee Retirement Savings Plan	12 Months Ended
	Dec. 31, 2015
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, 2014 and 2015 the Company made matching contributions of $67,000 and $71,000 , respectively.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
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 entered into a two -year lease agreement in October of 2014 for 7,805 square feet of office space in Houston's Westchase District for $18,000 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 does not intend to renew this lease upon expiration in 2016. The Company's original Houston building lease, which contains office space, warehouse space and a laboratory, expires in May 2017 and is leased for $11,000 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, 2015 are as follows ( in thousands ): Year ended December 31, 2016 $ 295 2017 53 $ 348 Total rent expense for the years ended December 31, 2014 , and 2015 , was $291,000 and $340,000 , respectively.

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2015
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 pre-Merger option disclosures in the note below are shown as converted using these factors. As of December 31, 2014 , 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. As of December 31, 2015 , the total common stock available for issuance pursuant to the 2014 Plan was 40,667 . Stock-based compensation expense is included primarily in selling, general and administrative expense and was $296,000 and $1,412,000 for the years ended December 31, 2014 , and 2015 , respectively. The Company has future unrecognized compensation expense for nonvested shares at December 31, 2015 of $2,228,000 which have a weighted average vesting period of 2.8 years . Stock Option Awards: The following table summarizes the activity of the Company’s plan related to stock options: Number Weighted Weighted Aggregate intrinsic value Outstanding as of January 1, 2014 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 6.7 7,725,000 Awarded 924,234 1.54 Exercised (211,246 ) 0.66 456,000 Forfeited or Expired (1) (178,403 ) 1.80 Outstanding as of December 31, 2015 2,834,635 1.01 6.9 89,000 Exercisable as of December 31, 2015 1,934,605 0.84 5.7 89,000 (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. The weighted-average grant date fair value for option awards granted during the year was $0.66 and $0.96 for the year ended December 31, 2014 and 2015 , respectively. The total fair value of equity awards vested during the year ended December 31, 2014 and 2015 was $303,000 , and $249,000 , respectively. The Company has computed the fair value of all options granted during the years ended December 31, 2014 and 2015 using the Black-Scholes option pricing model using the following assumptions: Year ended December 31, 2014 2015 Risk-free interest rate 2.44% 1.55% Expected volatility 55% 66% Expected dividend yield — — Expected life (in years) 7.00 6.00 Expected forfeiture rate — — Restricted Share Awards: In addition to options during the year ended December 31, 2015 the Company granted restricted share awards to certain executives and members of the board of directors. The following table shows a summary of restricted stock activity for the year ended December 31, 2015 : Shares Weighted-average grant date fair value Non-vested awards outstanding, December 31, 2014 — — Granted 1,040,540 $ 2.65 Vested (150,808 ) 2.65 Forfeited (45,140 ) 2.13 Non-vested awards outstanding, December 31, 2015 844,592 $ 2.67

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2015
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. During 2015, the Company used three such arrangements for oil sales, one for the Etzold Field located in Seward County, Kansas and one for oil for the Coke Field located in Wood County, Texas and one for the Bonnie View Field located in Refugio 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 facility. 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 and are included in the "Corporate Segment". 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 and are included in the AERO Services Segment. 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 for these services. 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, 2014 Revenues $ 11,724 $ 4,135 $ — $ 15,859 Operating expenses 10,777 3,528 7,788 22,093 Impairment of oil and gas properties 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) income (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 Oil and Gas AERO Services Corporate Total Year ended December 31, 2015 Revenues $ 7,397 $ 1,605 $ — $ 9,002 Operating expenses 9,974 1,771 7,824 19,569 Impairment of oil and gas property 22,600 — — 22,600 Depreciation, depletion and amortization 4,953 327 227 5,507 Loss from operations (30,130 ) (493 ) (8,051 ) (38,674 ) Other income (expense) 4,382 — (2,145 ) 2,237 Taxes on income — — (182 ) (182 ) Net loss $ (25,748 ) $ (493 ) $ (10,014 ) $ (36,255 ) Property, plant and equipment, net $ 5,741 $ 1,294 $ 280 $ 7,315 Total assets $ 10,098 $ 1,816 $ 10,350 $ 22,264 The following table shows the total revenue by geography ( in thousands ): Year Ended December 31, 2014 2015 Revenues United States $ 13,233 $ 7,640 Canada 2,220 317 Brazil 406 1,045 Total revenues $ 15,859 $ 9,002

Supplemental Information for Oi

Supplemental Information for Oil and Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Supplemental Information for Oil and Gas Producing Activities (Unaudited)	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. 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, 2014 and 2015 : Quantities of Proved Reserves: Crude Oil and Condensate Natural Gas (Mbbls) (Mmcf) Proved Developed Reserves, January 1, 2014 18 — Purchase of minerals in place (1) 1,728 384 Production (133 ) (72 ) Revisions of previous estimates (2) (211 ) (258 ) Proved Developed Reserves, December 31, 2014 1,402 54 Purchase of minerals in place (3) 74 68 Sale of minerals in place (4) (14 ) — Production (155 ) (90 ) Revisions of Previous Estimates (5) (612 ) 19 Proved Developed Reserves, December 31, 2015 695 51 (1) Purchase of the Coke Field Assets on March 14, 2014 and the Southwest Operating Assets on September 1, 2014. (2) The reserves revision is due to an increase in costs over our prior year reserve report. (3) Purchase of the Bonnie View Field on June 1, 2015. (4) Sale of the Etzold Field on July 1, 2015, (5) The oil reserves revision is due to a decline in oil prices throughout 2015. Proved Developed and Undeveloped Reserves: Crude oil and condensate Natural gas (Mbbls) (Mmcf) December 31, 2014 Proved developed reserves 1,402 54 Proved undeveloped reserves — — Total 1,402 54 December 31, 2015 Proved developed reserves 695 51 Proved undeveloped reserves — — Total 695 51 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, 2014 and 2015 (in thousands) : December 31, 2014 2015 Unproved properties $ 196 $ 443 Proved properties 45,694 48,454 Total 45,890 48,897 Less - accumulated depreciation, depletion and amortization (1) (19,612 ) (44,181 ) Net capitalized costs $ 26,278 $ 4,716 (1) Accumulated depreciation, depletion and amortization includes the 2014 oil and gas property impairment of $13,160,000 and the 2015 impairment of $22,600,000 . 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, 2014 and 2015 (in thousands) : Year ended December 31, 2014 2015 Acquisition of properties $ 42,788 $ 3,705 Development — 2,534 Total costs incurred $ 42,788 $ 6,239 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, 2013 , 2014 and 2015 (in thousands) : For the Year ended December 31, 2014 2015 Revenues from oil and gas producing activities $ 11,724 $ 7,397 Production costs 6,631 6,588 Exploration expense — 102 Ad valorem taxes 438 420 State severance taxes 547 343 Impairment of oil and gas property 13,160 22,600 Depreciation, depletion and amortization 3,960 4,723 Total expenses 24,736 34,776 Pre-tax loss from producing activities (13,012 ) (27,379 ) Income tax expense — — Results of oil and gas producing activities $ (13,012 ) $ (27,379 ) 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, 2014 and 2015 , 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, 2014 and 2015 ) 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, 2014 2015 Future cash inflows $ 133,235 $ 33,926 Future production and development costs Production (86,032 ) (26,442 ) Development — (136 ) Future cash flows before income taxes 47,203 7,348 Future income taxes — — Future net cash flows after income taxes 47,203 7,348 10% annual discount for estimated timing of cash flows (17,111 ) (2,586 ) Standardized measure of discounted future net cash flows $ 30,092 $ 4,762 The following reconciles the changes in the standardized measure of discounted future net cash flows (in thousands) : Year ended December 31, 2014 2015 Balance, beginning of year $ 561 $ 30,092 Changes from: Sales, net of production costs (4,108 ) (46 ) Net changes in prices and production costs 2,445 (12,882 ) Extensions — 544 Divestiture of reserves — (337 ) Revisions to quantity estimates (8,044 ) (16,436 ) Accretion of discount 56 3,009 Purchases of reserves in place 38,211 1,188 Net changes in income taxes — — Changes in timing of cash flows and other 971 (370 ) Balance, end of year $ 30,092 $ 4,762

Selected Quarterly Financial Re

Selected Quarterly Financial Results (Unaudited)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Selected Quarterly Financial Results (Unaudited)	SELECTED QUARTERLY FINANCIAL RESULTS (Unaudited) Unaudited quarterly operating results were as follows ( in thousands; except per share data ): 2014 (Quarter ended) March 31 June 30 September 30 December 31 (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 2015 (Quarter ended) March 31 June 30 September 30 December 31 (Unaudited) Net revenues $ 2,567 $ 2,632 $ 2,019 $ 1,784 Loss from operations (3,606 ) (3,604 ) (3,867 ) (27,597 ) Net loss applicable to stockholders (2,984 ) (4,916 ) (1,303 ) (27,052 ) Net loss per common share, basic and diluted (1) $ (0.09 ) $ (0.15 ) $ (0.04 ) $ (0.85 ) Weighted average shares outstanding, basic and diluted 31,563 31,803 31,845 31,859 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 Accoun25

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
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.
Oil and Natural Gas Properties	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	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, periodically and when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable. The initial 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. 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. 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 11 ). 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. 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 expenses 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 The Company has issued stock options, restricted shares, performance based options and market based options. The Company records 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. Stock-based compensation cost for restricted shares is estimated at the grant date based on the awards' fair value, which is equal to the prior day's closing stock price. Such fair value is recognized as expense over the requisite service period.
Fair Value of Financial Instruments	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	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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board (IASB) issued a comprehensive new revenue recognition standard that will supersede existing revenue recognition guidance under United States generally accepted accounting principles (U.S. GAAP) and International Financial Reporting Standards (IFRS). The issuance of this guidance completes the joint effort by the FASB and the IASB to improve financial reporting by creating common revenue recognition guidance for U.S. GAAP and IFRS. The core principle of the new guidance is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The standard creates a five-step model that requires companies to exercise judgment when considering the terms of a contract and all relevant facts and circumstances. The standard allows for several transition methods: (a) a full retrospective adoption in which the standard is applied to all of the periods presented, or (b) a modified retrospective adoption in which the standard is applied only to the most current period presented in the financial statements, including additional disclosures of the standard’s application impact to individual financial statement line items.This standard is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. We are currently evaluating this standard and the impact it will have on our future revenue recognition policies. In August 2014, the FASB issued Accounting Standards Update No. 2014-15: Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15). ASU 2014-15 asserts that management should evaluate whether there are relevant condition or events that are known and reasonably knowable that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued or are available to be issued when applicable. If conditions or events at the date the financial statements are issued raise substantial doubt about an entity’s ability to continue as a going concern, disclosures are required which will enable users of the financial statements to understand the conditions or events as well as management’s evaluation and plan. ASU 2014-15 is effective for the annual period ending after December 15, 2016, and for annual and interim periods thereafter; early application is permitted. We are currently evaluating this standard and the impact it will have on our consolidated financial statements. In April 2015, the FASB issued ASU No. 2015-03, "Interest—Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs" (ASU 2015-03). ASU 2015-03 is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015 and early adoption is permitted. Prior GAAP guidance mandates recognizing debt issuance costs as a deferred charge. Such treatment is different from the guidance in International Financial Reporting Standards (IFRS), which requires that transaction costs be deducted from the carrying value of the financial liability and not recorded as separate assets. Additionally, the requirement to recognize debt issuance costs as deferred charges conflicts with the guidance in FASB Concepts Statement No. 6, Elements of Financial Statements, which states that debt issuance costs are similar to debt discounts and in effect reduce the proceeds of borrowing, thereby increasing the effective interest rate. Concepts Statement 6 further states that debt issuance costs cannot be an asset because they provide no future economic benefit. To simplify presentation of debt issuance costs, the amendments in this Update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this Update. We are currently evaluating this standard and the impact it will have on our consolidated financial statements. In November 2015, the FASB issued Accounting Standards Update No. 2015-17: Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes (ASU 2015-17). ASU 2015-17 is part of an initiative to reduce complexity in accounting standards. Current GAAP requires an entity to separate deferred income tax liabilities and assets into current and noncurrent amounts in a classified statement of financial position. However, this classification does not generally align with the time period in which the recognized deferred tax amounts are expected to be recovered or settled. To simplify the presentation of the deferred income taxes, ASU 2015-17 requires that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The current requirement that deferred tax liabilities and assets of an entity be offset and presented as a single amount is not affected by the amendments of ASU 2015-17. For public entities, ASU 2015-17 is effective for financial statements issued for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years; early application is permitted. The provisions of this accounting update are not anticipated to have a material impact on the Company’s financial position or results of operations.
Reclassifications	Reclassifications Certain 2014 amounts related to inventory and prepaid expenses and other current assets have been reclassified for comparative purposes.

Summary of Significant Accoun26

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Schedules of Concentration of Risk, by Risk Factor	The following is a reconciliation of the customers that exceeded 10% of total service revenues in each of those periods: Percentage of service revenues Customer 2014 2015 A 36 % — B 17 % 20 % C 10 % 65 % D 10 % — 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 Customer 2014 2015 C — 100% D 19% — E 54% — F 27% —
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, 2014 2015 Proved oil and gas properties - successful efforts $ 45,694 $ 48,454 Unproved oil and gas properties 196 443 Construction in progress 589 594 Laboratory and warehouse facility 640 648 Laboratory and field service equipment 3,158 3,355 Office equipment, computer equipment, vehicles and other 1,358 1,399 51,635 54,893 Less: accumulated depreciation, depletion and amortization (1) (22,822 ) (47,578 ) Total property and equipment, net $ 28,813 $ 7,315 (1) Includes impairment and excludes accretion of asset retirement obligation. Depreciation, depletion and amortization consists of the following ( in thousands ): Year ended December 31, 2014 2015 Depreciation and amortization expense $ 523 $ 628 Depletion expense 3,960 4,723 Accretion of asset retirement obligation 141 156 Total depreciation, depletion, and amortization of property and equipment $ 4,624 $ 5,507

Merger with Infinity Cross Bo27

Merger with Infinity Cross Border Acquisition Corporation (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 . The beginning balances as of January 1, 2014 , shown in the table below, represent the Company's pre-Merger temporary equity and stockholders' equity previously stated as of January 1, 2014 . The balances as of January 1, 2014 , as converted, represent the post-Merger stockholders' equity received in exchange for the pre-Merger temporary equity and stockholders' equity at January 1, 2014 . 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, 2014 475,541 $ 13,762 2,901,052 $ 31,900 7,296,607 $ 29,773 4,462,968 $ 3,234 $ 78,669 3,295,771 $ 1 $ — $ (76,379 ) $ (76,378 ) Reversal of pre-Merger temporary equity (475,541 ) (13,762 ) (2,901,052 ) (31,900 ) (7,296,607 ) (29,773 ) (4,462,968 ) (3,234 ) $ (78,669 ) — — — 78,669 78,669 Reversal of pre-Merger common shares — — — — — — — — — (3,295,771 ) (1 ) 1 — — Reclassification of pre-Merger warrants from liability to additional paid-in capital — — — — — — — — — — — 13,905 — 13,905 Conversion of pre-Merger shares to post-Merger shares — — — — — — — — — 22,450,688 2 (2 ) — — Segregate historical accumulated deficit from additional paid-in capital — — — — — — — — — — — 47,705 (47,705 ) — Balances as of January 1, 2014, as converted — $ — — $ — — $ — — $ — $ — 22,450,688 $ 2 $ 61,609 $ (45,415 ) $ 16,196
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 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 30,493,006

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 2015 Proved oil and gas properties - successful efforts $ 45,694 $ 48,454 Unproved oil and gas properties 196 443 Construction in progress 589 594 Laboratory and warehouse facility 640 648 Laboratory and field service equipment 3,158 3,355 Office equipment, computer equipment, vehicles and other 1,358 1,399 51,635 54,893 Less: accumulated depreciation, depletion and amortization (1) (22,822 ) (47,578 ) Total property and equipment, net $ 28,813 $ 7,315 (1) Includes impairment and excludes accretion of asset retirement obligation. Depreciation, depletion and amortization consists of the following ( in thousands ): Year ended December 31, 2014 2015 Depreciation and amortization expense $ 523 $ 628 Depletion expense 3,960 4,723 Accretion of asset retirement obligation 141 156 Total depreciation, depletion, and amortization of property and equipment $ 4,624 $ 5,507
Business Acquisition, Pro Forma Information	The following summary presents unaudited pro forma information for the Company for the year ended December 31, 2014 , as if the Coke Field acquisition had been consummated at January 1, 2014 ( in thousands, except per share amounts ): Year ended December 31, 2014 Total revenues $ 18,604 Net loss (19,111 ) Net loss per common shares, basic and diluted $ (0.66 ) Weighted average shares outstanding: Basic 28,855 Diluted 28,855
Summary of Etzold Field Operations	The following table is a summarized operational history of the Etzold Field (in thousands) : Year ended December 31, 2014 2015 Revenue $ 327 $ 57 Expenses 433 200 Net loss from operations (106 ) (143 ) Income taxes — — Net loss $ (106 ) $ (143 )

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation [Table Text Block]	The following is a reconciliation of the liability for the years ended December 31, 2014 and 2015 ( in thousands ): Year ended December 31, 2014 2015 Balance at the beginning of period $ 305 $ 1,329 Liabilities acquired during the period 883 451 Liabilities settled during the period — (44 ) Accretion expense 141 156 Sold — (435 ) Revisions in estimates — 65 Balance at the end of the period $ 1,329 $ 1,522
Schedule of Asset Retirement Obligations [Table Text Block]	The asset retirement obligation is included in the consolidated balance sheets as follows (in thousands) : December 31, 2014 2015 Accrued liabilities $ — $ 65 Asset retirement obligation 1,329 1,457 $ 1,329 $ 1,522

Accrued Expenses (Tables)

Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities	As of December 31, 2014 and 2015 , the significant components of accrued expenses reported in the accompanying consolidated balance sheets are as follows ( in thousands ): December 31, 2014 2015 Accrued compensation and benefits $ 892 $ 91 Accrued end-of-term charge (see NOTE 10) 240 — Accrued interest 15 386 Accrued taxes 223 47 Accrued royalties 164 134 Asset retirement obligations — 65 Accrued lease operating expenses and other 258 457 $ 1,792 $ 1,180

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
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 and 2015 ( 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 Fair value measurements using Level 1 Level 2 Level 3 Total December 31, 2015 Short-term commodity derivatives, asset $ — $ 3,411 $ — $ 3,411

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of December 31, 2015 the Company had the following open positions on its outstanding commodity derivative contracts: Period Volume/Month (Bbls) Price/Unit Fair Value - Asset January 2016 - March 2016 7,300 $ 86.50 $ 1,053,000 April 2016 - December 2016 6,550 $ 82.46 $ 2,358,000
Gain (Loss) on Derivatives	The following tables summarize the unrealized and realized gain on commodity derivatives ( in thousands ): Year ended December 31, 2014 2015 Unrealized gain on commodity derivatives $ 5,796 $ 340 Early termination of long-term commodity derivatives — (2,725 ) Realized gain on commodity derivatives 227 6,346 $ 6,023 $ 3,961

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Schedule of Maturities of Long-term Debt	Maturities on long-term debt during the next five years are as follows ( in thousands ): Year ended December 31, Amount 2016 $ 480 2017 10,012 2018 9 2019 9 2020 9 Thereafter 6 $ 10,525

Loss Per Share (Tables)

Loss Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 2015 Numerator: Net loss $ (18,756 ) $ (36,255 ) Denominator: Weighted-average common shares outstanding - basic 28,855 31,769 Effect of dilutive securities — — Weighted-average common shares - diluted 28,855 31,769 Net loss per common share - basic and diluted $ (0.65 ) $ (1.14 )
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, 2014 2015 Common stock warrants ($10 strike price) 4,895 5,321 Common stock options 2,311 2,039 Restricted shares — 82

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 2015 Federal benefit at statutory income tax rate $ (6,692 ) $ (12,374 ) R&D credits (83 ) (58 ) Non-deductible (taxable) expenses & other items (380 ) 422 State income taxes - net of federal benefit (221 ) (33 ) Foreign income taxes 209 (182 ) Change in valuation allowance 7,376 12,043 Taxes on income $ 209 $ (182 )
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, 2014 and 2015 are as follows ( in thousands ): Year ended December 31, 2014 2015 Current deferred tax asset Deferred revenue and other $ 248 $ 9 Less valuation allowance (225 ) (9 ) 23 — Current deferred tax liability Current portion of swap asset 993 1,161 Current deferred tax liability, net 970 1,161 Non-current deferred tax asset NOL carryforwards (long-term) 16,077 22,233 R&D credits 450 508 Stock compensation 154 346 Depreciable property basis 740 450 Oil and gas properties 4,040 9,386 21,461 32,923 Less valuation allowance (19,503 ) (31,762 ) 1,958 1,161 Non-current deferred tax liability Non-current portion of swap asset 988 — Non-current deferred tax asset, net 970 1,161 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, 2014 2015 Current tax provision (benefit): Federal — — Foreign 209 (182 ) State — — Total $ 209 $ (182 ) Deferred tax provision (benefit): Federal — — Foreign — — State — — Total $ — $ — Total tax provision (benefit): Federal — — Foreign 209 (182 ) State — — Total $ 209 $ (182 )

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 are as follows ( in thousands ): Year ended December 31, 2016 $ 295 2017 53 $ 348

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
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 Outstanding as of January 1, 2014 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 6.7 7,725,000 Awarded 924,234 1.54 Exercised (211,246 ) 0.66 456,000 Forfeited or Expired (1) (178,403 ) 1.80 Outstanding as of December 31, 2015 2,834,635 1.01 6.9 89,000 Exercisable as of December 31, 2015 1,934,605 0.84 5.7 89,000 (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.
Schedule of Fair Value Assumptions	The Company has computed the fair value of all options granted during the years ended December 31, 2014 and 2015 using the Black-Scholes option pricing model using the following assumptions: Year ended December 31, 2014 2015 Risk-free interest rate 2.44% 1.55% Expected volatility 55% 66% Expected dividend yield — — Expected life (in years) 7.00 6.00 Expected forfeiture rate — —
Nonvested Restricted Stock Shares Activity	In addition to options during the year ended December 31, 2015 the Company granted restricted share awards to certain executives and members of the board of directors. The following table shows a summary of restricted stock activity for the year ended December 31, 2015 : Shares Weighted-average grant date fair value Non-vested awards outstanding, December 31, 2014 — — Granted 1,040,540 $ 2.65 Vested (150,808 ) 2.65 Forfeited (45,140 ) 2.13 Non-vested awards outstanding, December 31, 2015 844,592 $ 2.67

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 Revenues $ 11,724 $ 4,135 $ — $ 15,859 Operating expenses 10,777 3,528 7,788 22,093 Impairment of oil and gas properties 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) income (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 Oil and Gas AERO Services Corporate Total Year ended December 31, 2015 Revenues $ 7,397 $ 1,605 $ — $ 9,002 Operating expenses 9,974 1,771 7,824 19,569 Impairment of oil and gas property 22,600 — — 22,600 Depreciation, depletion and amortization 4,953 327 227 5,507 Loss from operations (30,130 ) (493 ) (8,051 ) (38,674 ) Other income (expense) 4,382 — (2,145 ) 2,237 Taxes on income — — (182 ) (182 ) Net loss $ (25,748 ) $ (493 ) $ (10,014 ) $ (36,255 ) Property, plant and equipment, net $ 5,741 $ 1,294 $ 280 $ 7,315 Total assets $ 10,098 $ 1,816 $ 10,350 $ 22,264
Revenue from External Customers by Geographic Areas	The following table shows the total revenue by geography ( in thousands ): Year Ended December 31, 2014 2015 Revenues United States $ 13,233 $ 7,640 Canada 2,220 317 Brazil 406 1,045 Total revenues $ 15,859 $ 9,002

Supplemental Information for 39

Supplemental Information for Oil and Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2014 and 2015 : Quantities of Proved Reserves: Crude Oil and Condensate Natural Gas (Mbbls) (Mmcf) Proved Developed Reserves, January 1, 2014 18 — Purchase of minerals in place (1) 1,728 384 Production (133 ) (72 ) Revisions of previous estimates (2) (211 ) (258 ) Proved Developed Reserves, December 31, 2014 1,402 54 Purchase of minerals in place (3) 74 68 Sale of minerals in place (4) (14 ) — Production (155 ) (90 ) Revisions of Previous Estimates (5) (612 ) 19 Proved Developed Reserves, December 31, 2015 695 51 (1) Purchase of the Coke Field Assets on March 14, 2014 and the Southwest Operating Assets on September 1, 2014. (2) The reserves revision is due to an increase in costs over our prior year reserve report. (3) Purchase of the Bonnie View Field on June 1, 2015. (4) Sale of the Etzold Field on July 1, 2015, (5) The oil reserves revision is due to a decline in oil prices throughout 2015. Proved Developed and Undeveloped Reserves: Crude oil and condensate Natural gas (Mbbls) (Mmcf) December 31, 2014 Proved developed reserves 1,402 54 Proved undeveloped reserves — — Total 1,402 54 December 31, 2015 Proved developed reserves 695 51 Proved undeveloped reserves — — Total 695 51
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, 2014 and 2015 (in thousands) : December 31, 2014 2015 Unproved properties $ 196 $ 443 Proved properties 45,694 48,454 Total 45,890 48,897 Less - accumulated depreciation, depletion and amortization (1) (19,612 ) (44,181 ) Net capitalized costs $ 26,278 $ 4,716 (1) Accumulated depreciation, depletion and amortization includes the 2014 oil and gas property impairment of $13,160,000 and the 2015 impairment of $22,600,000 .
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, 2014 and 2015 (in thousands) : Year ended December 31, 2014 2015 Acquisition of properties $ 42,788 $ 3,705 Development — 2,534 Total costs incurred $ 42,788 $ 6,239
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, 2013 , 2014 and 2015 (in thousands) : For the Year ended December 31, 2014 2015 Revenues from oil and gas producing activities $ 11,724 $ 7,397 Production costs 6,631 6,588 Exploration expense — 102 Ad valorem taxes 438 420 State severance taxes 547 343 Impairment of oil and gas property 13,160 22,600 Depreciation, depletion and amortization 3,960 4,723 Total expenses 24,736 34,776 Pre-tax loss from producing activities (13,012 ) (27,379 ) Income tax expense — — Results of oil and gas producing activities $ (13,012 ) $ (27,379 )
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, 2014 2015 Future cash inflows $ 133,235 $ 33,926 Future production and development costs Production (86,032 ) (26,442 ) Development — (136 ) Future cash flows before income taxes 47,203 7,348 Future income taxes — — Future net cash flows after income taxes 47,203 7,348 10% annual discount for estimated timing of cash flows (17,111 ) (2,586 ) Standardized measure of discounted future net cash flows $ 30,092 $ 4,762
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, 2014 2015 Balance, beginning of year $ 561 $ 30,092 Changes from: Sales, net of production costs (4,108 ) (46 ) Net changes in prices and production costs 2,445 (12,882 ) Extensions — 544 Divestiture of reserves — (337 ) Revisions to quantity estimates (8,044 ) (16,436 ) Accretion of discount 56 3,009 Purchases of reserves in place 38,211 1,188 Net changes in income taxes — — Changes in timing of cash flows and other 971 (370 ) Balance, end of year $ 30,092 $ 4,762

Selected Quarterly Financial 40

Selected Quarterly Financial Results (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Unaudited quarterly operating results were as follows ( in thousands; except per share data ): 2014 (Quarter ended) March 31 June 30 September 30 December 31 (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 2015 (Quarter ended) March 31 June 30 September 30 December 31 (Unaudited) Net revenues $ 2,567 $ 2,632 $ 2,019 $ 1,784 Loss from operations (3,606 ) (3,604 ) (3,867 ) (27,597 ) Net loss applicable to stockholders (2,984 ) (4,916 ) (1,303 ) (27,052 ) Net loss per common share, basic and diluted (1) $ (0.09 ) $ (0.15 ) $ (0.04 ) $ (0.85 ) Weighted average shares outstanding, basic and diluted 31,563 31,803 31,845 31,859 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.

Organization Organization (Deta

Organization Organization (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Net assets	$ 22,264,000	$ 67,435,000
Glori Oil S.R.L. [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Revenue	0	0
Net assets	0	0
Glori Oil (Argentina) Limited [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Revenue	0	0
Net assets	$ 0	$ 0

Summary of Significant Accoun42

Summary of Significant Accounting Policies - Concentrations of Credit Risk (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)customer	Dec. 31, 2014USD ($)customer
Oil Purchaser 4 [Member]
Concentration Risk [Line Items]
Accounts receivable | $	$ 436	$ 900
Customer Concentration Risk [Member] | Sales Revenue, Services, Net [Member]
Concentration Risk [Line Items]
Number of customers revenues are derived from	4	15
Customer Concentration Risk [Member] | Sales Revenue, Services, Net [Member] | Customer A [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	36.00%
Customer Concentration Risk [Member] | Sales Revenue, Services, Net [Member] | Customer B [Member]
Concentration Risk [Line Items]
Concentration risk, percent	20.00%	17.00%
Customer Concentration Risk [Member] | Sales Revenue, Services, Net [Member] | Customer C [Member]
Concentration Risk [Line Items]
Concentration risk, percent	65.00%	10.00%
Customer Concentration Risk [Member] | Sales Revenue, Services, Net [Member] | Customer D [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	10.00%
Customer Concentration Risk [Member] | Accounts Receivable [Member]
Concentration Risk [Line Items]
Number of customers revenues are derived from	1	4
Customer Concentration Risk [Member] | Accounts Receivable [Member] | Customer C [Member]
Concentration Risk [Line Items]
Concentration risk, percent	100.00%	0.00%
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 E [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	54.00%
Customer Concentration Risk [Member] | Accounts Receivable [Member] | Customer F [Member]
Concentration Risk [Line Items]
Concentration risk, percent	0.00%	27.00%
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	93.00%

Summary of Significant Accoun43

Summary of Significant Accounting Policies - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Impaired Long-Lived Assets Held and Used [Line Items]
Allowance for doubtful accounts	$ 0	$ 0
Impairment of oil and gas property	22,600,000	13,160,000
Legally restricted assets	0
Deferred revenues	$ 0	$ 653,000

Summary of Significant Accoun44

Summary of Significant Accounting Policies - Estimated Useful Life (Details)	12 Months Ended
	Dec. 31, 2015
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

Risks and Uncertainties (Detail

Risks and Uncertainties (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Mar. 23, 2016injection_well	Dec. 31, 2013USD ($)
Risks and Uncertainties [Abstract]
Cash and cash equivalents	$ 8,380	$ 29,751		$ 20,867
Net cash used in operating activities	(9,711)	(8,186)
Payments on long-term debt	8,780	8,147
Capital expenditures	3,000
Proceeds from the sale of long-term commodity derivatives	2,725	0
Capital	9,300
Long-term Debt	10,525
United States Department of Energy Loan [Member]
Debt Instrument [Line Items]
Principal amount	150,000
Glori Energy Production, Inc. [Member] | 11% Senior Secured Term Loan [Member] | Senior Notes [Member]
Risks and Uncertainties [Abstract]
Long-term Debt	$ 10,452	$ 17,428
Subsequent Event [Member]
Debt Instrument [Line Items]
Injection wells added in Phase II | injection_well			2
Total number of running injection wells | injection_well			3

Merger with Infinity Cross Bo46

Merger with Infinity Cross Border Acquisition Corporation - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Apr. 14, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	Mar. 13, 2014	Jan. 01, 2014
Business Acquisition [Line Items]
Common stock, shares outstanding	30,493,006	31,499,303		31,861,357		22,450,688
Ordinary shares issued to Glori Energy Inc. shareholders	23,584,557
Conversion to common stock (in shares)			79,003
Preferred shares issued		0		0
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment)	250,000
Warrants outstanding		5,321,700		5,321,700
Warrant exercise price (in usd per share)		$ 10		$ 10
Common Stock [Member]
Business Acquisition [Line Items]
Common stock, shares outstanding		31,499,303	22,450,688	31,861,357
Ordinary shares issued to Glori Energy Inc. shareholders			229,108
Conversion to common stock (in shares)		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 issued in acquisition	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
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
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

Merger with Infinity Cross Bo47

Merger with Infinity Cross Border Acquisition Corporation - Statements of Temporary Equity and Stockholders' Equity (Details) $ in Thousands	Jan. 01, 2014USD ($)shares
Increase (Decrease) in Temporary Equity [Roll Forward]
Ending balance	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ 16,196
Ending balance (in shares) | shares	22,450,688
Ending balance	$ 16,196
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares) | shares	22,450,688
Beginning balance	$ 2
Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	61,609
Ending balance	61,609
Accumulated Deficit [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(45,415)
Ending balance	$ (45,415)
Series A Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Ending balance (in shares) | shares	0
Ending balance	$ 0
Series B Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Ending balance (in shares) | shares	0
Ending balance	$ 0
Series C Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Ending balance (in shares) | shares	0
Ending balance	$ 0
Series C-1 Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Ending balance (in shares) | shares	0
Ending balance	$ 0
Scenario, Previously Reported [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance	78,669
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ (76,378)
Scenario, Previously Reported [Member] | Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares) | shares	3,295,771
Beginning balance	$ 1
Scenario, Previously Reported [Member] | Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	0
Scenario, Previously Reported [Member] | Accumulated Deficit [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ (76,379)
Scenario, Previously Reported [Member] | Series A Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares) | shares	475,541
Beginning balance	$ 13,762
Scenario, Previously Reported [Member] | Series B Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares) | shares	2,901,052
Beginning balance	$ 31,900
Scenario, Previously Reported [Member] | Series C Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares) | shares	7,296,607
Beginning balance	$ 29,773
Scenario, Previously Reported [Member] | Series C-1 Preferred Stock [Member] | Preferred Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance (in shares) | shares	4,462,968
Beginning balance	$ 3,234
Scenario, Adjustment [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre-Merger temporary equity	(78,669)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reversal of pre-Merger common shares	0
Reclassification of pre-Merger warrants from liability to additional paid-in capital	0
Adjustments To Additional Paid In Capital, Reclassification Of Warrants	13,905
Conversion of pre-Merger shares to post-Merger shares	$ 0
Scenario, Adjustment [Member] | Common Stock [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre Merger temporary equity (in shares) | shares	(3,295,771)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reversal of pre-Merger common shares	$ (1)
Reclassification of pre-Merger warrants from liability to additional paid-in capital | shares	22,450,688
Reclassification of pre-Merger warrants from liability to additional paid-in capital	$ 2
Scenario, Adjustment [Member] | Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Reversal of pre-Merger common shares	1
Reclassification of pre-Merger warrants from liability to additional paid-in capital	(2)
Adjustments To Additional Paid In Capital, Reclassification Of Warrants	13,905
Conversion of pre-Merger shares to post-Merger shares	47,705
Scenario, Adjustment [Member] | Accumulated Deficit [Member]
Increase (Decrease) in Temporary Equity [Roll Forward]
Reversal of pre-Merger temporary equity	(78,669)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Conversion of pre-Merger shares to post-Merger shares	$ (47,705)
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) | shares	(475,541)
Reversal of pre-Merger temporary equity	$ (13,762)
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) | shares	(2,901,052)
Reversal of pre-Merger temporary equity	$ (31,900)
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) | shares	(7,296,607)
Reversal of pre-Merger temporary equity	$ (29,773)
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) | shares	(4,462,968)
Reversal of pre-Merger temporary equity	$ (3,234)

Merger with Infinity Cross Bo48

Merger with Infinity Cross Border Acquisition Corporation - Summary of Common Stock Issued and Outstanding (Details) - shares	Apr. 14, 2014	Dec. 31, 2015	Dec. 31, 2014	Jan. 01, 2014
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	30,493,006	31,861,357	31,499,303	22,450,688

Property and Equipment - Summar

Property and Equipment - Summary of Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Proved oil and gas properties - successful efforts	$ 48,454	$ 45,694
Unproved oil and gas properties	443	196
Property and equipment, gross	6,439	5,941
Total property and equipment and proved oil and gas properties, gross	54,893	51,635
Less: accumulated depreciation, depletion and amortization	(47,578)	(22,822)
Total property and equipment, net	7,315	28,813
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	594	589
Laboratory and warehouse facility [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	648	640
Laboratory and field service equipment [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	3,355	3,158
Office equipment, computer equipment, vehicles and other [Member]
Property, Plant and Equipment [Line Items]
Property and equipment, gross	$ 1,399	$ 1,358

Property and Equipment - Deprec

Property and Equipment - Depreciation, Depletion, and Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Depreciation and amortization expense	$ 628	$ 523
Depletion expense	4,723	3,960
Accretion of asset retirement obligation	156	141
Total depreciation, depletion, and amortization of property and equipment	$ 5,507	$ 4,624

Property and Equipment - Narrat

Property and Equipment - Narrative (Details) - USD ($) $ in Thousands	Jun. 01, 2015	Mar. 14, 2014	Sep. 30, 2014	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Revenues				$ 1,784	$ 2,019	$ 2,632	$ 2,567	$ 3,843	$ 5,458	$ 5,556	$ 1,002	$ 9,002	$ 15,859
Net loss												36,255	18,756
Gain on commodity derivatives												3,961	6,023
Impairment of oil and gas properties												22,600	13,160
Assumption of asset retirement obligation												75	0
Gain on sale of entity												422	0
Asset retirement obligation				$ 1,522				$ 1,329				1,522	1,329	$ 305
Southwest Operating Assets [Member]
Business Acquisition [Line Items]
Payments to acquire businesses			$ 2,000
Southwest Operating Assets [Member] | Other Noncurrent Liabilities [Member]
Business Acquisition [Line Items]
Asset retirement obligation acquired			$ 138						$ 138
Glori Energy Production, Inc. [Member] | Coke Field Assets [Member]
Business Acquisition [Line Items]
Cash consideration		$ 38,000
Convertible note payable assumed		2,000
Total purchase price		39,200
Property and equipment acquired during acquisition		310
Inventory acquired during acquisition		327
Revenues													11,398
Net loss													7,061
Gain on commodity derivatives													6,023
Impairment of oil and gas properties													$ 12,707
Glori Energy Production, Inc. [Member] | Coke Field Assets [Member] | Other Noncurrent Assets [Member]
Business Acquisition [Line Items]
Asset retirement cost acquired		$ 745
Glori Energy Production, Inc. [Member] | Bonnie View Assets [Member]
Business Acquisition [Line Items]
Total purchase price	$ 2,644
Asset retirement obligation	$ 432
Glori Energy Production, Inc. [Member] | Bonnie View Field [Member]
Business Acquisition [Line Items]
Revenues												447
Net loss												3,208
Impairment of oil and gas properties												2,400
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Etzold Field [Member]
Business Acquisition [Line Items]
Net assets						89
Liabilities						$ 435
Assumption of asset retirement obligation												75
Gain on sale of entity												$ 422

Property and Equipment - Pro Fo

Property and Equipment - Pro Forma Information (Details) - Coke Field Assets [Member] - Glori Energy Production, Inc. [Member] $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2014USD ($)$ / sharesshares
Business Acquisition [Line Items]
Total revenues | $	$ 18,604
Net loss | $	$ (19,111)
Net loss per common shares, basic (in dollars per share) | $ / shares	$ (0.66)
Weighted average shares outstanding:
Weighted-average common shares outstanding - basic | shares	28,855
Weighted-average common shares outstanding - diluted | shares	28,855

Property and Equipment - Summ53

Property and Equipment - Summary of Etzold Field Operations (Details) - Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] - Etzold Field [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenue	$ 57	$ 327
Expenses	200	433
Net loss from operations	(143)	(106)
Income taxes	0	0
Net loss	$ (143)	$ (106)

Asset Retirement Obligation - R

Asset Retirement Obligation - Reconciliation of Asset Retirement Obligation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at the beginning of period	$ 1,329	$ 305
Liabilities acquired during the period	451	883
Liabilities settled during the period	(44)	0
Accretion expense	156	141
Sold	(435)	0
Revisions in estimates	65	0
Balance at the end of the period	$ 1,522	$ 1,329

Asset Retirement Obligation - A

Asset Retirement Obligation - Asset Retirement Obligation in Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset retirement obligation	$ 1,522	$ 1,329	$ 305
Accrued liabilities [Member]
Asset retirement obligation	65	0
Asset retirement obligation [Member]
Asset retirement obligation	$ 1,457	$ 1,329

Accrued Expenses - Summary of A

Accrued Expenses - Summary of Accrued Expenses (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Payables and Accruals [Abstract]
Accrued compensation and benefits	$ 91	$ 892
Accrued end-of-term charge	0	240
Accrued interest	386	15
Accrued taxes	47	223
Accrued royalties	134	164
Asset retirement obligations	65	0
Accrued lease operating expenses and other	457	258
Accrued expenses	$ 1,180	$ 1,792

Fair Value Measurements - Asset

Fair Value Measurements - Assets Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 23, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term commodity derivatives, asset	$ 3,411		$ 2,905
Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		$ 3,192
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	3,411		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		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	3,411		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		0
Long-term commodity derivatives, asset			0
Derivative asset			$ 0

Derivative Instruments - Outsta

Derivative Instruments - Outstanding Commodity Derivative Contracts (Details) - Not Designated as Hedging Instrument [Member] - Commodity Contract [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)$ / bblbbl
January 2016 - March 2016 [Member]
Derivative [Line Items]
Volume per month (Bbls) | bbl	7,300
Price (usd per barrel) | $ / bbl	86.50
Fair value - Asset | $	$ 1,053
April 2016 - December 2016 [Member]
Derivative [Line Items]
Volume per month (Bbls) | bbl	6,550
Price (usd per barrel) | $ / bbl	82.46
Fair value - Asset | $	$ 2,358

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - USD ($) $ in Thousands	Dec. 23, 2015	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Proceeds from the sale of long-term commodity derivatives		$ 2,725	$ 0
Short-term commodity derivatives, asset		$ 3,411	$ 2,905
Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Proceeds from the sale of long-term commodity derivatives	$ 2,725
Value for the sold portion of commodity swaps	3,192
Loss on commodity derivatives	$ 467

Derivative Instruments - Realiz

Derivative Instruments - Realized and Unrealized Gain (Loss) on Derivatives (Details) - USD ($) $ in Thousands	Dec. 23, 2015	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain on commodity derivatives		$ 340	$ 5,796
Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain on commodity derivatives	$ (467)
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain on commodity derivatives		340	5,796
Early termination of long-term commodity derivatives		(2,725)	0
Realized gain on commodity derivatives		6,346	227
Gain on oil and natural gas derivatives		$ 3,961	$ 6,023

Long Term Debt - Narrative (Det

Long Term Debt - Narrative (Details)	Mar. 18, 2016USD ($)	May. 13, 2014USD ($)	Apr. 14, 2014shares	Mar. 14, 2014USD ($)agreement	Jun. 11, 2012USD ($)	Dec. 31, 2015USD ($)	Mar. 02, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Warrants exchanged for common shares (in shares) | shares			100,000
Long-term debt						$ 10,525,000
Number of financing agreements | agreement				2
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment) | shares			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) | shares			18,208
Repayment period					27 months
Liability for end of term charge					$ 280,000
Long-term debt								$ 1,750,000
Repurchase amount							$ 889,000
End of term charge							$ 280,000
Secured Debt [Member] | 10% Secured Term Promissory Note [Member] | Other Noncurrent 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%
Repurchase amount		$ 4,000,000
Loan term				2 years
Issuance cost (percent)				2.00%
Issuance cost				$ 80,000
Prepayment penalty		$ 400,000
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						$ 10,452,000		$ 17,428,000
Loan term				3 years
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%
Issuance cost (percent)				2.00%
Issuance cost				$ 360,000
Minimum stated interest rate (percent)				11.00%
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%
Ordinary shares issued for PIPE Investment (Petro-Hunt portion of PIPE Investment) | shares			250,000
Subsequent Event [Member] | Glori Energy Production, Inc. [Member] | Senior Notes [Member] | 11% Senior Secured Term Loan [Member]
Debt Instrument [Line Items]
Interest rate (percent)	13.00%
Paid in kind (percent)	2.00%
Subsequent Event [Member] | Glori Energy Production, Inc. [Member] | Senior Notes [Member] | 11% Senior Secured Term Loan [Member] | Minimum [Member]
Debt Instrument [Line Items]
Principal payment	$ 37,500

Long Term Debt - Maturities on

Long Term Debt - Maturities on Long-Term Debt (Details) $ in Thousands	Dec. 31, 2015USD ($)
Debt Disclosure [Abstract]
2,016	$ 480
2,017	10,012
2,018	9
2,019	9
2,020	9
Thereafter	6
Total	$ 10,525

Loss Per Share - Summary of Ear

Loss Per Share - Summary of Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Numerator:
Net loss									$ (36,255)	$ (18,756)
Denominator:
Weighted-average common shares outstanding - basic									31,769	28,855
Effect of dilutive securities									$ 0	$ 0
Weighted-average common shares - diluted									31,769	28,855
Net loss per common share, basic and diluted (in dollars per share)	$ (0.85)	$ (0.04)	$ (0.15)	$ (0.09)	$ (0.37)	$ (0.01)	$ (0.20)	$ (0.60)	$ (1.14)	$ (0.65)

Loss Per Share - Summary of Ant

Loss Per Share - Summary of Antidilutive Securities (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Warrant exercise price (in usd per share)	$ 10	$ 10
Stock Warrants [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Securities excluded in the calculation of diluted shares outstanding	5,321	4,895
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Securities excluded in the calculation of diluted shares outstanding	2,039	2,311
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Securities excluded in the calculation of diluted shares outstanding	82	0

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Tax credit carryforward	$ 508
Reduction to NOL carryforward	5,400
Increase in valuation allowance	12,000
Net deferred tax assets	0	$ 0
NOL carryforwards (long-term)	22,233	16,077
Unrealized excess tax benefits related to stock based compensation	87
Domestic Tax Authority [Member]
Income Tax Contingency [Line Items]
Operating loss carryforward	64,500	45,700
State and Local Jurisdiction [Member]
Income Tax Contingency [Line Items]
Operating loss carryforward	$ 6,700	$ 6,600
Tax Years 2010 And 2011 [Member] | Domestic Tax Authority [Member]
Income Tax Contingency [Line Items]
Uncertain Tax Position, Liability Not Recognized			$ 31

Income Taxes - Effective Income

Income Taxes - Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Federal benefit at statutory income tax rate	$ (12,374)	$ (6,692)
R&D credits	(58)	(83)
Non-deductible (taxable) expenses	422	(380)
State income taxes	(33)	(221)
Foreign income taxes	(182)	209
Change in valuation allowance	12,043	7,376
Taxes on income	$ (182)	$ 209

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current deferred tax asset
Deferred revenue and other	$ 9	$ 248
Less valuation allowance	(9)	(225)
Current deferred tax assets, net	0	23
Current deferred tax liability
Current portion of swap asset	1,161	993
Current deferred tax liability, net	1,161	970
Non-current deferred tax asset
NOL carryforwards (long-term)	22,233	16,077
R&D credits	508	450
Stock compensation	346	154
Depreciable property basis	450	740
Oil and gas properties	9,386	4,040
Noncurrent deferred tax assets, gross	32,923	21,461
Less valuation allowance	(31,762)	(19,503)
Noncurrent deferred tax assets, net	1,161	1,958
Non-current deferred tax liability
Non-current portion of swap asset	0	988
Non-current deferred tax asset, net	1,161	970
Total deferreds, net	$ 0	$ 0

Income Taxes - Components of In

Income Taxes - Components of Income Tax Provision (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Current tax provision (benefit):
Federal	$ 0	$ 0
Foreign	(182)	209
State	0	0
Total	(182)	209
Deferred tax provision (benefit):
Federal	0	0
Foreign	0	0
State	0	0
Total	0	0
Total tax provision (benefit):
Federal	0	0
Foreign	(182)	209
State	0	0
Taxes on income	$ (182)	$ 209

Employee Retirement Savings P69

Employee Retirement Savings Plan - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
401(k) Plan [Member]
Defined Contribution Plan Disclosure [Line Items]
Discretionary matching contributions	$ 71	$ 67

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) $ in Thousands	1 Months Ended	12 Months Ended
	Oct. 31, 2014USD ($)ft²extension	Dec. 31, 2015USD ($)building	Dec. 31, 2014USD ($)
Operating Leased Assets [Line Items]
Number Of buildings | building		2
Rent expense		$ 340	$ 291
Office Building [Member]
Operating Leased Assets [Line Items]
Lease term	2 years
Square footage | ft²	7,805
Monthly rental amount	$ 18
Office, Laboratory, and Manufacturing [Member]
Operating Leased Assets [Line Items]
Monthly rental amount		11
Warehouse [Member]
Operating Leased Assets [Line Items]
Monthly rental amount		$ 1
Notice required for lease termination		30 days
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)	4.00%
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 | extension	2

Commitments and Contingencies71

Commitments and Contingencies - Summary of Minimum Future Capital Lease Payments (Details) $ in Thousands	Dec. 31, 2015USD ($)
Commitments and Contingencies Disclosure [Abstract]
2,016	$ 295
2,017	53
Total	$ 348

Stock-Based Compensation - Narr

Stock-Based Compensation - Narrative (Details) $ / shares in Units, $ in Thousands	Apr. 14, 2014	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares
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 | $		$ 2,228
Weighted-average grant date fair value | $ / shares		$ 0.96	$ 0.66
Total fair value of options vested | $		$ 249	$ 303
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average vesting period		2 years 10 months
Selling, General and Administrative Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation | $		$ 1,412	$ 296
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 | shares			2,581,190
2014 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for issuance | shares		40,667
Number of shares authorized | shares			2,000,000
Award expiration period			10 years
2014 Long Term Incentive Plan [Member] | Share-based Compensation Award, Tranche 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-Based Compensation - Summ

Stock-Based Compensation - Summary of Stock Option Activity (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Number of Stock Options
Outstanding, beginning balance (in shares)	2,300,050	2,322,180
Awarded (in shares)	924,234	7,103
Exercised (in shares)	(211,246)	(9,397)
Forfeited or Expired (in shares)	(178,403)	(19,836)
Outstanding, ending balance (in shares)	2,834,635	2,300,050	2,322,180
Exercisable (in shares)	1,934,605
Weighted Average Exercise Price
Outstanding, beginning balance (in dollars per share)	$ 0.82	$ 0.81
Awarded (in dollars per share)	1.54	1.16
Exercised (in dollars per share)	0.66	1.16
Forfeited or Expired (in dollars per share)	1.80	1.16
Outstanding, ending balance (in dollars per share)	1.01	$ 0.82	$ 0.81
Exercisable (in dollars per share)	$ 0.84
Weighted Average Remaining Contractual Term
Outstanding (in years)	6 years 11 months	6 years 8 months 19 days	7 years 8 months 12 days
Exercisable (in years)	5 years 7 months 30 days
Aggregate Intrinsic Value
Outstanding	$ 89	$ 7,725	$ 782
Exercised	456	$ 70
Exercisable	$ 89

Stock-Based Compensation - Fair

Stock-Based Compensation - Fair Value Assumptions (Details) - Stock Option [Member]	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	1.55%	2.44%
Expected volatility	66.00%	55.00%
Expected dividend yield	0.00%	0.00%
Expected life (in years)	6 years	7 years
Expected forfeiture rate	0.00%	0.00%

Stock-Based Compensation - Rest

Stock-Based Compensation - Restricted Shares Activity (Details) - Restricted Stock [Member]	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Shares
Non-vested awards outstanding, December 31, 2014 | shares	0
Granted | shares	1,040,540
Vested | shares	(150,808)
Forfeited | shares	(45,140)
Non-vested awards outstanding, December 31, 2015 | shares	844,592
Weighted-average grant date fair value
Non-vested awards outstanding, December 31, 2014 (in USD per share) | $ / shares	$ 0
Granted (in USD per share) | $ / shares	2.65
Vested (in USD per share) | $ / shares	2.65
Forfeited (in USD per share) | $ / shares	2.13
Non-vested awards outstanding, December 31, 2015 (in USD per share) | $ / shares	$ 2.67

Segment Information - Summary o

Segment Information - Summary of Segment Information (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)arrangement	Dec. 31, 2014USD ($)
Segment Reporting Information [Line Items]
Number of first purchaser arrangements | arrangement									3
Revenues	$ 1,784	$ 2,019	$ 2,632	$ 2,567	$ 3,843	$ 5,458	$ 5,556	$ 1,002	$ 9,002	$ 15,859
Operating expenses									19,569	22,093
Impairment of oil and gas properties									22,600	13,160
Depreciation, depletion and amortization									5,507	4,624
Loss from operations	(27,597)	$ (3,867)	$ (3,604)	$ (3,606)	(17,709)	$ (1,633)	$ (1,880)	$ (2,796)	(38,674)	(24,018)
Other income (expense)									2,237	5,471
Taxes on income									(182)	209
Net loss									(36,255)	(18,756)
Property, plant and equipment, net	7,315				28,813				7,315	28,813
Total assets	22,264				67,435				22,264	67,435
Oil And Gas [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues									7,397	11,724
Operating expenses									9,974	10,777
Impairment of oil and gas properties									22,600	13,160
Depreciation, depletion and amortization									4,953	4,188
Loss from operations									(30,130)	(16,401)
Other income (expense)									4,382	6,023
Taxes on income									0	0
Net loss									(25,748)	(10,378)
Property, plant and equipment, net	5,741				27,078				5,741	27,078
Total assets	10,098				34,163				10,098	34,163
AERO Service [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues									1,605	4,135
Operating expenses									1,771	3,528
Impairment of oil and gas properties									0	0
Depreciation, depletion and amortization									327	404
Loss from operations									(493)	203
Other income (expense)									0	0
Taxes on income									0	0
Net loss									(493)	203
Property, plant and equipment, net	1,294				1,636				1,294	1,636
Total assets	1,816				1,789				1,816	1,789
Corporate [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues									0	0
Operating expenses									7,824	7,788
Impairment of oil and gas properties									0	0
Depreciation, depletion and amortization									227	32
Loss from operations									(8,051)	(7,820)
Other income (expense)									(2,145)	(552)
Taxes on income									(182)	209
Net loss									(10,014)	(8,581)
Property, plant and equipment, net	280				99				280	99
Total assets	$ 10,350				$ 31,483				$ 10,350	$ 31,483

Segment Information - Revenue b

Segment Information - Revenue by Geographic Location (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	$ 1,784	$ 2,019	$ 2,632	$ 2,567	$ 3,843	$ 5,458	$ 5,556	$ 1,002	$ 9,002	$ 15,859
United States [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									7,640	13,233
Canada [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									317	2,220
Brazil [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									$ 1,045	$ 406

Supplemental Information for 78

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Quantities of Proved Reserves (Details) - United States [Member]	12 Months Ended
	Dec. 31, 2015MBblsMMcf	Dec. 31, 2014MBblsMMcf
Crude oil and condensate [Member]
Proved Developed and Undeveloped Reserves [Abstract]
Proved developed reserves, beginning balance | MBbls	1,402	18
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | MBbls	74	1,728
Proved Developed and Undeveloped Reserves, Sale of Mineral in Place | MBbls	(14)
Proved Developed and Undeveloped Reserves, Production | MBbls	(155)	(133)
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | MBbls	(612)	(211)
Proved developed reserves, ending balance | MBbls	695	1,402
Natural Gas [Member]
Proved Developed and Undeveloped Reserves [Abstract]
Proved developed reserves, beginning balance | MMcf	54	0
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | MMcf	68	384
Proved Developed and Undeveloped Reserves, Sale of Mineral in Place | MMcf	0
Proved Developed and Undeveloped Reserves, Production | MMcf	(90)	(72)
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | MMcf	19	(258)
Proved developed reserves, ending balance | MMcf	51	54

Supplemental Information for 79

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Proved Developed and Undeveloped Reserves (Details) - United States [Member]	Dec. 31, 2015MBblsMMcf	Dec. 31, 2014MBblsMMcf	Dec. 31, 2013MBblsMMcf
Crude oil and condensate [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MBbls	695	1,402	18
Proved developed reserves | MBbls	0	0
Total | MBbls	695	1,402
Natural Gas [Member]
Reserve Quantities [Line Items]
Proved developed reserves | MMcf	51	54	0
Proved developed reserves | MMcf	0	0
Total | MMcf	51	54

Supplemental Information for 80

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Capitalized Costs Relating to Oil and Gas Producing Activities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Unproved properties	$ 443	$ 196
Proved properties	48,454	45,694
Total	48,897	45,890
Less - accumulated depreciation, depletion and amortization	(44,181)	(19,612)
Net capitalized costs	4,716	26,278
Oil and gas property impairment	$ 22,600	$ 13,160

Supplemental Information for 81

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Cost Incurred in Oil and Gas Producing Activities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Acquisition of properties	$ 3,705	$ 42,788
Development	2,534	0
Total costs incurred	$ 6,239	$ 42,788

Supplemental Information for 82

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Results of Operations for Oil and Gas Producing Activities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Revenues from oil and gas producing activities	$ 7,397	$ 11,724
Production costs	6,588	6,631
Exploration expense	102	0
Ad valorem taxes	420	438
State severance taxes	343	547
Impairment of oil and gas property	22,600	13,160
Depreciation, depletion and amortization	4,723	3,960
Total expenses	34,776	24,736
Pre-tax loss from producing activites	(27,379)	(13,012)
Income tax expense	0	0
Results of oil and gas producing activities	$ (27,379)	$ (13,012)

Supplemental Information for 83

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Discounted Future Cash Flows Relating to Proved Reserves (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Annual discount for estimated timing of cash flows	(10.00%)
Future cash inflows	$ 33,926	$ 133,235
Future production and development costs
Production	(26,442)	(86,032)
Development	(136)	0
Future cash flows before income taxes	7,348	47,203
Future income taxes	0	0
Future net cash flows after income taxes	7,348	47,203
10% annual discount for estimated timing of cash flows	(2,586)	(17,111)
Standardized measure of discounted future net cash flows	$ 4,762	$ 30,092	$ 561

Supplemental Information for 84

Supplemental Information for Oil and Gas Producing Activities (Unaudited) - Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning balance	$ 30,092	$ 561
Changes from:
Sales, net of production costs	(46)	(4,108)
Net changes in prices and production costs	(12,882)	2,445
Extensions	544	0
Divestiture of reserves	(337)	0
Revisions to quantity estimates	(16,436)	(8,044)
Accretion of discount	3,009	56
Purchases of reserves in place	1,188	38,211
Net changes in income taxes	0	0
Changes in timing of cash flows and other	(370)	971
Ending balance	$ 4,762	$ 30,092

Selected Quarterly Financial 85

Selected Quarterly Financial Results (Unaudited) - Summary of Results of Operations (Details) $ / shares in Units, shares in Thousands, $ in Thousands	Apr. 14, 2014	Dec. 31, 2015USD ($)$ / sharesshares	Sep. 30, 2015USD ($)$ / sharesshares	Jun. 30, 2015USD ($)$ / sharesshares	Mar. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Sep. 30, 2014USD ($)$ / sharesshares	Jun. 30, 2014USD ($)$ / sharesshares	Mar. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares
Quarterly Financial Information Disclosure [Abstract]
Net revenues		$ 1,784	$ 2,019	$ 2,632	$ 2,567	$ 3,843	$ 5,458	$ 5,556	$ 1,002	$ 9,002	$ 15,859
Loss from operations		(27,597)	(3,867)	(3,604)	(3,606)	(17,709)	(1,633)	(1,880)	(2,796)	$ (38,674)	$ (24,018)
Net loss applicable to stockholders		$ (27,052)	$ (1,303)	$ (4,916)	$ (2,984)	$ (11,656)	$ (356)	$ (6,060)	$ (684)
Net loss per common share, basic and diluted (in dollars per share) | $ / shares		$ (0.85)	$ (0.04)	$ (0.15)	$ (0.09)	$ (0.37)	$ (0.01)	$ (0.20)	$ (0.60)	$ (1.14)	$ (0.65)
Weighted average shares outstanding, basic and diluted | shares		31,859	31,845	31,803	31,563	31,499	31,475	29,642	1,137	31,769	28,855
Glori stock option conversion ratio	2.9