UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

Form 10-Q

(Mark One)



þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~March~~June 3130, 2016



o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 000-55261

GLORI ENERGY INC.

(Exact name of registrant as specified in its charter)



Delaware		46-4527741
(State or Other Jurisdiction of		(I.R.S. Employer
Incorporation or Organization)		Identification No.)

4315 South Drive
Houston, Texas		77053
(Address of Principal Executive Offices)		(Zip Code)

Registrant’s telephone number, including area code: (713) 237-8880

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. þ Yes o No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). þ Yes o No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12-b2 of the Exchange Act). o Yes þ No

There were 32,~~764~~382,~~938~~111 common shares outstanding on ~~May~~August 109, 2016.

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INDEX TO FINANCIAL STATEMENTS

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		Page
PART I: FINANCIAL INFORMATION		4
Item 1.	Financial Statements	4
	Condensed Consolidated Balance Sheets	4
	Condensed Consolidated Statements of Operations	5
	Condensed Consolidated Statement of Stockholders' Equity	6
	Condensed Consolidated Statements of Cash Flows	7
	Notes to Condensed Consolidated Financial Statements	8
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	1820
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	2830
Item 4.	Controls and Procedures	3031
PART II: OTHER INFORMATION		3132
Item 1.	Legal Proceedings	3132
Item 1A.	Risk Factors	3132
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3132
Item 3.	Defaults Upon Senior Securities	3132
Item 4.	Mine Safety Disclosures	3132
Item 6.	Exhibits	3233
Signature		3334

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements provide our current expectations or forecasts of future events. Forward-looking statements include statements:


•	containing a projection of revenues, income (including income loss), earnings (including earnings loss) per share, capital expenditures, dividends, capital structure, or other financial items;


•	of the plans and objectives of management for future operations, including plans or objectives relating to the products or services of Glori;


•	of future economic performance, including any such statement contained in a discussion and analysis of financial condition by the management or in the results of operations included pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”);


•	of the assumptions underlying or relating to any statement described above; or


•	containing a projection or estimate of such other items as may be specified by rule or regulation of the SEC.

Forward-looking statements may also include any report issued by an outside reviewer retained by Glori, to the extent that the report assesses a forward-looking statement made by Glori. Forward-looking statements may include statements about our expectations, strategy, beliefs, plans, objectives, intentions, assumptions, prospects, estimates, projections, the future of our industry, our future profitability, estimates and projections of future activity and trends in the oil and natural gas industry, and other statements that are not historical facts. Words or phrases such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “intend,” “may,” “ongoing,” “plan,” “potential,” “predict,” “encouraging,” “project,” “will” or similar words or phrases, or the negatives of those words or phrases, may identify forward-looking statements, but the absence of these words does not necessarily mean that a statement is not forward-looking. Examples of forward-looking statements in this Quarterly Report on Form 10-Q include, but are not limited to, statements regarding our disclosure concerning Glori's proposed operations, cash flows, and financial position.

These forward-looking statements are neither historical facts nor are they guarantees of future performance. These statements are based on management’s expectations that involve a number of business risks and uncertainties, any of which could cause actual results to differ materially from those expressed in or implied by the forward-looking statements. These statements involve known and unknown risks, uncertainties and other factors, most of which are difficult to predict and many of which are beyond our control, including the factors described under “Risk Factors”, that may cause our actual results and performance to be materially different from any future results or performance expressed or implied by these forward-looking statements. Such risks and uncertainties include, among other things:

• ~~the~~our ~~sustained~~ability orto ancontinue ~~increased~~as ~~decline~~a ofgoing ~~oil and gas commodity prices~~concern;


•	the potential delisting of our common stock from NASDAQ;

• our ability to ~~comply~~secure ~~with~~additional ~~debt~~capital ~~covenants,~~to ~~service~~fund ~~our debt, and make future required payments~~operations;

• ~~the~~our ~~increase~~ability into ~~oil~~service ~~production~~our ~~rate~~debt and ~~ultimate~~make ~~quantity~~future ofrequired ~~oil recovered using our AERO System~~payments;


•	the sustained or an increased decline of oil and gas commodity prices;


•	increase in oil production rate and ultimate quantity of oil recovered using our AERO System;


•	the percentage of the world’s reservoirs that are suitable for our AERO System;


•	our ability to prove our technology and develop and maintain positive relationships with our customers and prospective customers;


•	competition and competitive factors in the markets in which we operate;


•	demand for our AERO System and our expectations regarding future projects;


•	adaptability of our AERO System and our development of additional capabilities that will expand the types of oil fields to which we can apply our technology;


•	our plans and ability to acquire and develop additional currently producing mature oil fields and the AERO System’s impact on these fields;


•	our plans to develop some abandoned and low producing mature oil fields;


•	the expected cost of recovering oil using our AERO System in our projects;


•	potential environmental or other liabilities associated with our acquired properties;


•	any projections, including earnings, revenues, expenses or any other financial items;


•	the impact of legislation and regulations on our operations;


•	our ability to compete with other enhanced oil recovery methods;


•	our ability to generate positive cash flows, including from the acquisition of oil producing properties, increases in oil prices, and improvement in our AERO System revenues;


•	our cash needs and expectations regarding cash flow from operations;

• our ability to manage and grow our business and execution of our business strategy;

• our financial performance;

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•	our ability to manage and grow our business and execution of our business strategy;


•	our financial performance;


•	our estimates of oil reserves; and


•	the costs associated with being a public company.

We undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events, changed circumstances or otherwise, except to the extent law requires.

MARKET, INDUSTRY AND OTHER DATA

Unless otherwise indicated, information contained in this Quarterly Report on Form 10-Q concerning Glori’s industry and the markets in which Glori operates, including its general expectations and market position, market opportunity and market size, is based on information from various sources, on assumptions that it has made that are based on that information and other similar sources and on Glori’s knowledge of the markets for its services. That information involves a number of assumptions and limitations, and you are cautioned not to give undue weight to such estimates. While Glori believes that information from third-party sources used in this Quarterly Report on Form 10-Q is generally reliable, it has not independently verified the accuracy or completeness of this information. In addition, projections, assumptions and estimates of Glori’s future performance and the future performance of the industry in which Glori operates are necessarily subject to a high degree of uncertainty and risk due to a variety of factors, including those described in “Risk Factors” and elsewhere in this Quarterly Report on Form 10-Q. These and other factors could cause results to differ materially from those expressed in the estimates made by the independent parties and by Glori.

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PART I - FINANCIAL INFORMATION

Item 1: Financial Statements

GLORI ENERGY INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share data)

	December 31, 2015			~~March~~June 3130, 2016
				(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	8,380		$	53,~~045~~144
Accounts receivable	1,456			~~935~~792
Commodity derivatives	3,411			21,~~404~~243
Prepaid expenses and other current assets	314			~~385~~297
Total current assets	13,561			85,~~769~~476
Property and equipment:
Proved oil and gas properties - successful efforts	48,454			49,~~435~~772
Other property and equipment	6,439			6,~~455~~522
	54,893			5556,~~890~~294
Less: accumulated depreciation, depletion and amortization	(47,578		)	(48,~~040~~497		)
Total property and equipment, net	7,315			7,~~850~~797
Deferred charges	—			85228
Deferred tax asset	1,161			—
Total assets	$	22,037		$	1613,~~704~~501
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	1,430		$	~~1,097~~644
Accrued expenses	1,180			~~648~~1,214
Current portion of long-term debt shown net of unamortized deferred loan costs of $191 and $211 as of December 31, 2015 and March 31, 2016, respectively	289			10,079
Current portion of long-term debt shown net of unamortized deferred loan costs of $191 and $156 as of December 31, 2015 and June 30, 2016, respectively	289			10,067
Current deferred tax liability	1,161			—
Total current liabilities	4,060			11,~~824~~925
Long-term liabilities:
Long-term debt, less current portion shown net of unamortized deferred loan costs of $36 as of December 31, 2015	10,009			3937
Asset retirement obligation	1,457			1,~~498~~403
Total long-term liabilities	11,466			1,~~537~~440
Total liabilities	15,526			13,~~361~~365
Commitments and contingencies (Note 9)
Commitments and contingencies (Note 10)
Stockholders' equity:
Preferred stock, $.0001 par value, 5,000,000 shares authorized, no shares issued and outstanding as of December 31, 2015 and March 31, 2016	—			—
Preferred stock, $.0001 par value, 5,000,000 shares authorized, no shares issued and outstanding as of December 31, 2015 and June 30, 2016	—			—
Common stock, $.0001 par value, 100,000,000 shares authorized, 31,861,357 and 32,001,203 shares issued and outstanding as of December 31, 2015 and March 31, 2016, respectively	3			3
Common stock, $.0001 par value, 100,000,000 shares authorized, 31,861,357 and 32,115,998 shares issued and outstanding as of December 31, 2015 and June 30, 2016, respectively	3			3
Additional paid-in capital	106,934			107,~~167~~207
Accumulated deficit	(100,426		)	(~~103~~107,~~827~~074		)
Total stockholders' equity	6,511			~~3,343~~136
Total liabilities and stockholders' equity	$	22,037		$	1613,~~704~~501

The accompanying notes are an integral part of these consolidated financial statements.

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GLORI ENERGY INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

	Three Months Ended March 31,
	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2016			2015			2016
	(Unaudited)						(Unaudited)
Revenues:
Oil and gas revenues	$	2,~~000~~136		$	1,~~024~~163		$	4,136		$	2,187
Service revenues	~~567~~496			~~174~~72			1,063			246
Total revenues	2,~~567~~632			1,~~198~~235			5,199			2,433
Operating expenses:
Oil and gas operations	2,~~392~~500			1,~~891~~240			4,892			3,131
Service operations	~~521~~534			~~273~~213			1,055			486
Science and technology	~~474~~629			~~334~~309			1,103			643
Selling, general and administrative	1,~~718~~534			1,~~418~~403			3,252			2,821
Depreciation, depletion and amortization	1,~~068~~039			~~506~~496			2,107			1,002
Total operating expenses	6,~~173~~236			43,~~422~~661			12,409			8,083
Loss from operations	(3,~~606~~604		)	(32,~~224~~426		)	(7,210		)	(5,650		)
Other income (expense):
Interest expense	(~~715~~530		)	(~~343~~392		)	(1,245		)	(735		)
Gain on commodity derivatives	1,369			155
(Loss) gain on commodity derivatives	(980		)	(437		)	389			(282		)
Other (expense) income	(15		)	11
Other income (expense)	10			2			(5		)	13
Total other income (expense), net	639			(177		)
Total other expense, net	(1,500		)	(827		)	(861		)	(1,004		)
Net loss before taxes on income	(25,~~967~~104		)	(3,~~401~~253		)	(8,071		)	(6,654		)
Income tax expense	17			—
Income tax benefit	(188		)	(6		)	(171		)	(6		)
Net loss	(24,~~984~~916		)	(3,~~401~~247		)	$	(7,900	)	$	(6,648	)
Net loss per common share, basic and diluted	$	(0.0915	)	$	(0.1110	)	$	(0.25	)	$	(0.21	)
Weighted average common shares outstanding,basic and diluted	31,~~563~~803			3132,~~940~~050			31,684			32,026

The accompanying notes are an integral part of these consolidated financial statements.

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GLORI ENERGY INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDERS’ EQUITY

(in thousands, except share data)

	Stockholders' equity
	(Unaudited)
				Additional					Total
	Common stock			paid-in		Accumulated			stockholders'
	Shares	Par value		capital		deficit			equity
Balances as of December 31, 2015	31,861,357	$	3	$	106,934	$	(100,426	)	$	6,511
Stock based compensation	~~139~~254,~~846~~641	—		~~233~~273		—			~~233~~273
Net loss	—	—		—		(36,~~401~~648		)	(36,~~401~~648		)
Balances as of March 31, 2016	32,001,203	$	3	$	107,167	$	(103,827	)	$	3,343
Balances as of June 30, 2016	32,115,998	$	3	$	107,207	$	(107,074	)	$	136

The accompanying notes are an integral part of these consolidated financial statements.

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GLORI ENERGY INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

	Three Months Ended March 31,
	Six Months Ended June 30,
	2015			2016
	(Unaudited)
Cash flows from operating activities:
Net loss	$	(27,~~984~~900	)	$	(36,~~401~~648	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization of property and equipment	12,~~068~~107			~~506~~1,002
Stock-based compensation	~~432~~838			~~233~~273
Bad debt expense	36			—66
Amortization of deferred loan costs	~~139~~194			56110
Accretion of end-of-term charge	40			—
Unrealized (gain) loss on change in fair value of commodity derivatives	(223		)	1,007
Unrealized loss on change in fair value of commodity derivatives	1,382			2,168
Non-cash increase in debt (paid-in-kind interest)	—			52
Accretion of discount on long-term debt	28			—
Changes in operating assets and liabilities:
Accounts receivable	92186			~~521~~598
Prepaid expenses and other current assets	(~~133~~101		)	~~(71~~17		)
Accounts payable	(1,~~658~~437		)	(~~441~~786		)
Deferred revenues	(~~308~~620		)	—
Accrued expenses	(~~457~~587		)	(~~445~~116		)
Net cash used in operating activities	(35,~~928~~834		)	(23,~~035~~264		)
Cash flows from investing activities:
Purchase of proved oil and gas property	(204		)	(963		)
Purchase of and additions to proved oil and gas property	(4,403		)	(1,305		)
Purchase of other property and equipment	(~~220~~312		)	(1683		)
Net cash used in investing activities	(~~424~~4,715		)	(~~979~~1,388		)
Cash flows from financing activities:
Proceeds from the exercise of stock options	130			—
Payments on long-term debt	(2,~~054~~216		)	(~~196~~316		)
Payments for deferred loan costs and deferred charges	—(40		)	(~~125~~268		)
Net cash used in financing activities	(12,~~924~~126		)	(~~321~~584		)
Net decrease in cash and cash equivalents	(612,~~276~~675		)	(35,~~335~~236		)
Cash and cash equivalents, beginning of period	29,751			8,380
Cash and cash equivalents, end of period	$	2317,~~475~~076		$	53,~~045~~144
Non-cash financing and investing activities:
Asset retirement obligation assumed	432			13
Non-cash increase in debt (paid-in-kind interest)	—			52
Supplemental cash flow information:
Interest paid	$	~~823~~1,338		$	~~517~~805

The accompanying notes are an integral part of these consolidated financial statements.

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GLORI ENERGY INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 1 - ORGANIZATION, AND NATURE OF BUSINESS ~~AND LIQUIDITY~~

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

Glori Energy Inc., GETI, Glori Canada Ltd., Glori Holdings Inc., Glori California Inc., OOO Glori Energy and Glori Energy Production Inc. ("GEP") are collectively referred to as the “Company” in the condensed consolidated financial statements.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

We have prepared the condensed consolidated financial statements included herein pursuant to the rules and regulations of the U.S. Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to these rules and regulations. In the opinion of management, these condensed consolidated financial statements contain all adjustments necessary to present fairly the Company’s condensed consolidated balance sheets as of December 31, 2015 and ~~March~~June 3130, 2016 (unaudited), condensed consolidated statements of operations for the three and six months ending ~~March~~June 3130, 2015 and ~~March~~June 3130, 2016 (unaudited), condensed consolidated statement of stockholders’ equity for the ~~three~~six months ended ~~March~~June 3130, 2016 (unaudited) and condensed consolidated statements of cash flows for the ~~three~~six months ended ~~March~~June 3130, 2015 and ~~March~~June 3130, 2016 (unaudited). All such adjustments represent normal recurring items. The financial information contained in this report for the three and six months ended ~~March~~June 3130, 2015 and ~~March~~June 3130, 2016, and as of ~~March~~June 3130, 2016, is unaudited. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements as of and for the year ended December 31, 2015 and the notes thereto.

Principles of Consolidation

The accompanying condensed 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 condensed 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.

Recently Adopted Accounting Pronouncements

In the first quarter of 2016, ASU No. 2015-03, "Interest--Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs" became effective for the Company. The standard moved the presentation of the Company's deferred loan costs from an asset to a contra-liability account thus reducing the liability balance of loans by the amount of the deferred loan costs. The deferred loan costs are amortized to interest expense over the life of the loan. The standard was applied retrospectively and accordingly the December 31, 2015 previously reported total current and non-current loan principal balance of $10,525,000 is now shown net of total deferred loan costs of $227,000 and the ~~March 31~~June 30, 2016 total current and non-current loan principal balance of $10,~~329~~260,000 is now shown net of total deferred loan costs of $~~211~~156,000. The change did not have an impact to net income.

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~~During~~date the ~~first~~financial ~~quarter~~statements ofare ~~2016~~issued ~~the~~raise ~~Company~~substantial ~~also~~doubt ~~chose~~about ~~to adopt Accounting Standards Update No. 2015-17: Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes ("ASU 2015-17" or the "Standard"). ASU 2015-17 is part of~~ an ~~initiative to reduce complexity in accounting standards. Current GAAP requires an~~ entity’s ability to ~~separate~~continue ~~deferred~~as ~~income tax liabilities and assets into current and noncurrent amounts in~~ a ~~classified~~going ~~statement of financial position. However~~concern, ~~this~~disclosures ~~classification~~are ~~does~~required ~~not~~which ~~generally~~will ~~align~~enable ~~with~~users ~~the~~of ~~time period in which~~ the ~~recognized~~financial ~~deferred~~statements ~~tax amounts are expected~~ to beunderstand ~~recovered or settled. To simplify~~ the ~~presentation~~conditions ofor ~~the~~events ~~deferred~~as ~~income~~well ~~taxes, ASU 2015-17 requires that deferred tax liabilities and assets be classified~~ as ~~noncurrent~~management’s inevaluation ~~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~~plan. ~~For~~ ~~public entities,~~ ASU ~~2015~~2014-1715 is effective for ~~financial~~the ~~statements~~annual ~~issued~~period ~~for~~ending ~~fiscal years beginning~~ after December 15, 2016, and ~~interim~~for ~~periods~~annual ~~within~~and ~~those~~interim ~~fiscal~~periods ~~years~~thereafter; early application is permitted. ~~Because~~Glori ~~the~~adopted ~~Company~~this ~~has~~standard ~~applied~~during ~~a 100% valuation allowance to its net deferred tax asset, there are no deferred tax accounts reported in~~ the ~~consolidated~~second ~~balance~~quarter ~~sheet as~~ of ~~March 31,~~ 2016. ~~This~~Early ~~Standard~~adoption ~~would~~did not have ~~otherwise~~an ~~been~~impact ~~effective~~on ~~for~~ the ~~Company’s fiscal year beginning January 1, 2017, but Management believes that the revised presentation more realistically reflects the Company’s~~ financial ~~position related to deferred income taxes~~statements. AsSee ~~allowed~~NOTE by3 ~~the~~of ~~Standard,~~this ~~the~~report ~~company~~for ~~has~~a ~~elected~~discussion toabout ~~apply~~liquidity ~~the~~considerations ~~provisions prospectively,~~ and ~~accordingly,~~Glori's ~~has~~ability ~~not~~to ~~adjusted~~continue ~~deferred~~as ~~tax~~a ~~accounts~~going ~~retrospectively for any earlier periods~~concern.

NOTE 3 - ~~RISKS~~LIQUIDITY CONSIDERATIONS AND ~~UNCERTAINTIES~~ABILITY TO CONTINUE AS A GOING CONCERN

As a small company with an emerging technology, the Company has generated negative cash flows from operations since inception. The ~~Company continues to generate negative cash flows and the~~ downturn in the oil market has ~~adversely~~resulted ~~affected~~in ~~its~~a ~~results~~decrease ~~from~~in ~~operations~~oil ~~and~~revenues ~~cash flows. Cash has decreased~~ from ~~$8.4~~Company-owned ~~million~~oil ~~at December 31~~properties, ~~2015~~and toa ~~$5.0~~decrease ~~million at March 31, 2016 due to the net cash used~~ in ~~operating~~AERO ~~activities~~services ofrevenues ~~$2.0~~as ~~million,~~ the ~~repayment~~exploration of& ~~debt~~production of("E&P") ~~$196~~industry ~~thousand,~~significantly ~~and~~reduced its capital expenditures ~~of $979 thousand~~. As ~~Based~~a onresult ~~its~~of ~~cash~~these ~~balance and forecasted cash flows from operating activities~~factors, the Company ~~expects~~continues to begenerate ~~able~~negative tocash ~~fund~~flows ~~planned~~from ~~capital~~operations. ~~expenditures,~~The ~~meet~~significant ~~debt~~decrease ~~service~~in ~~requirements,~~oil ~~and~~prices ~~fund~~has ~~other~~also ~~commitments~~made ~~and~~it ~~obligations~~difficult for ~~2016.~~the AsCompany ofto ~~May~~execute ~~10,~~on ~~2016,~~its ~~the~~strategy ~~Company~~of ~~does~~acquiring ~~not~~producing ~~have~~properties, ~~lines~~which ofwould ~~credit~~contribute ~~available~~ to ~~it.~~its Asrevenues aand ~~result~~cash offlows, ~~the~~due ~~negative~~to ~~cash~~potential ~~flows~~sellers' ~~and~~reluctance ~~the~~to ~~decrease~~sell inat ~~oil~~distressed prices. Additionally, the ~~Company~~current ~~will~~oil ~~need~~price toenvironment ~~raise~~has ~~capital~~negatively ~~over~~affected the ~~next~~availability ~~twelve~~of ~~months~~capital to ~~fund~~Glori ~~its operations~~ and tothe ~~repay~~E&P orindustry ~~refinance~~in ~~its term note of $10~~general.3 These ~~million~~factors ~~which matures March of 2017. The Company may~~ have ~~difficulty~~also ~~obtaining~~resulted ~~such~~in ~~additional financing as~~ a ~~result~~dramatic ~~of the~~ decrease in ~~oil prices, its negative cash flows from operations and~~ the ~~significant~~Company's ~~decrease in its~~ share price., ~~Failure~~which toalso ~~obtain~~impacts ~~additional financing would have a material adverse effect on~~ the ~~Company’s~~ability ~~business~~to ~~operations~~raise ~~and~~new ~~financial condition~~capital.

~~The~~Cash ~~significant~~has ~~decrease~~decreased infrom ~~oil~~$8.4 ~~prices~~million ~~has~~at ~~made~~December it31, ~~difficult~~2015 ~~for~~to ~~the~~$3.1 ~~Company~~million at June 30, 2016 due to ~~execute~~the onnet ~~its~~cash ~~strategy~~used ofin ~~acquiring~~operating ~~producing~~activities ~~properties~~of ~~which~~$3.3 ~~would~~million, ~~contribute~~the torepayment ~~its~~of ~~revenues~~debt ~~and~~of ~~cash~~$316 ~~flows~~thousand, ~~due~~capital toexpenditures ~~potential~~of ~~sellers’~~$1.4 ~~reluctance~~million toand ~~sell~~other atuses ~~depressed~~of ~~prices~~$300 thousand. As ~~Additionally~~of August 2016, the ~~current~~Company ~~oil~~does ~~price~~not ~~environment~~have ~~has~~lines ~~negatively~~of ~~affected~~credit available to it. As a result of the ~~Company's~~negative operating cash ~~flow~~flows, the ~~availability~~Company ofwill need to raise capital over the next six to ~~Glori~~nine months to fund its operations and to repay or refinance the ~~E&P~~term ~~industry~~note inof ~~general~~$10.2 ~~These~~million, ~~factors~~owed by GEP, which matures March 2017. The Company may have ~~also~~difficulty ~~resulted~~obtaining insuch additional financing as a ~~dramatic~~result of the decrease in ~~the~~oil ~~Company's~~prices, ~~stock~~its ~~price,~~negative ~~which~~cash ~~also~~flows ~~impacts~~from operations and the ~~ability~~significant todecrease ~~raise~~in ~~new~~its ~~equity~~share ~~capital~~price.

In order to address this challenging environment, the Company made significant cost reductions, both in its administrative and professional staff, and lease operating expenses. The Company ~~also~~has limited its capital ~~expenditures~~spending primarily to ~~those~~the ~~required~~implementation toof ~~implement~~its AERO technology at the Coke field., most of which was completed in the first quarter of 2016. Additionally, the Company is ~~exploring~~actively pursuing alternatives to raise capital in order to ~~bolster~~funds its ~~liquidity~~operations and ~~build~~position athe ~~larger~~Company ~~asset~~to ~~base.~~take advantage of identified opportunities to acquire abandoned fields which the Company believes have significant economic quantities of oil remaining and are compatible with its AERO technology. 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 increase production from more of the field than was impacted by the first injector.

~~Finally~~Additionally, 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. ~~The~~In ~~Company~~May is2016, in the ~~process~~Company ofsubmitted ~~submitting~~ Part II of the application, however, the ultimate outcome of the application and whether a loan guarantee will be issued cannot be predicted. It is currently anticipated that the loan guarantee, if issued, will fund up to 8075% of project costs. The ~~with~~balance ~~the~~would ~~balance~~need to be raised and contributed by the Company. If the loan guarantee is ultimately not issued by the LPO, or if the final terms of the loan guarantee are not advantageous, the Company plans to seek alternative financing to enable it to acquire and redevelop certain identified abandoned fields which fit its criteria.

On October 23, 2015, the Company received a notice from the Listing Qualifications Department of the NASDAQ Stock Market LLC indicating that, for the previous 30 consecutive business days, the bid price for our common stock had closed below the minimum $1.00 per share required for continued inclusion on The NASDAQ Capital Market under NASDAQ Listing Rule 5550(a)(2). The Company was afforded 180 calendar days, or until April 20, 2016, to regain compliance with the minimum bid price requirement. In order to regain compliance, shares of the Company’s common stock must maintain a minimum bid closing price of at least $1.00 per share for a minimum of ten consecutive business days, subject to NASDAQ's discretion to increase such ten-day period. On April 25, 2016, the Company received a letter from NASDAQ granting the Company an additional 180 days to regain compliance with the minimum bid price requirement. The Company has until October 17, 2016 to regain compliance with the bid price requirement. In addition, the Company must continue to meet the

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Oncontinued ~~October~~listing 23criteria, ~~2015,~~including ~~the~~maintaining ~~Company~~stockholders' ~~received~~equity aof ~~notice~~at ~~from~~least ~~the~~$2.5 ~~Listing~~million. ~~Qualifications~~As ~~Department~~a result of its net losses, including the ~~NASDAQ~~impairment ~~Stock~~of ~~Market~~oil ~~LLC~~and ~~indicating~~gas ~~that,~~properties ~~for~~incurred ~~the~~in ~~previous~~2014 30and ~~consecutive~~2015 ~~business~~as ~~days,~~a result of the ~~bid~~decrease ~~price~~in ~~for~~oil ~~our~~prices, ~~common~~the ~~stock~~Company's ~~had~~stockholders' ~~closed~~equity was below the ~~minimum~~required $12.005 ~~per~~million ~~share~~as ~~required~~of ~~for~~June ~~continued~~30, ~~inclusion~~2016. In onorder ~~The~~to maintain its NASDAQ ~~Capital~~listing, ~~Market~~the ~~under~~Company ~~NASDAQ~~will ~~Listing~~need ~~Rule~~to ~~5550(a)(2).~~raise ~~The~~equity ~~Company~~in ~~was~~the ~~afforded~~near-term ~~180~~in ~~calendar~~amounts ~~days,~~sufficient orto ~~until~~satisfy ~~April~~the ~~20,~~$2.5 ~~2016,~~million tostockholders' ~~regain~~equity ~~compliance~~requirement. Additionally, ~~with~~based on the ~~minimum~~Company's ~~bid~~recent share price, ~~requirement.~~in In order to ~~regain~~meet ~~compliance,~~the ~~shares~~minimum of$1.00 bid price per share requirement, the Company’s ~~common~~would ~~stock~~most ~~must~~likely ~~maintain~~have to implement a ~~minimum~~reverse ~~bid~~stock ~~closing~~split ~~price~~which requires the approval of shareholders at ~~least~~a $1shareholder meeting.00 In ~~per~~light ~~share~~of ~~for~~the aCompany's ~~minimum~~non-compliance ofwith ~~ten~~these ~~consecutive~~continuing ~~business~~listing ~~days~~requirements, ~~subject~~the toCompany ~~NASDAQ's~~may ~~discretion~~elect to ~~increase~~voluntarily ~~such~~delist ~~ten-day~~from ~~period~~the NASDAQ. The OnCompany ~~April~~is ~~25,~~currently ~~2016,~~evaluating weits ~~received~~alternatives. If athe ~~letter~~Company's ~~from~~common ~~NASDAQ~~stock ~~granting~~is ~~the~~delisted, ~~Company~~it anwould ~~additional~~likely ~~180~~trade ~~days~~in tothe ~~regain~~over-the-counter ~~compliance~~market. In ~~with~~ the ~~minimum~~event ~~bid~~of ~~price~~termination ~~requirement.~~of ~~The~~the Company's ~~has~~NASDAQ ~~until~~listing, ~~October~~the ~~17,~~Company ~~2016~~may determine to ~~regain~~re-apply ~~compliance~~to ~~with~~re-establish ~~the~~its ~~bid~~NASDAQ ~~price~~listing ~~requirement.~~at Insuch ~~addition,~~later date as the Company ~~must~~is ~~continue~~able to meet the ~~continued~~initial listing ~~criteria,~~requirements. Such ~~including~~NASDAQ ~~maintaining~~delisting ~~stockholders'~~or ~~equity~~further ofdeclines atin ~~least~~our ~~$2.5~~stock ~~million.~~price Ifcould ~~the~~impair ~~Company~~our ~~continues~~ability to ~~have~~raise ~~net~~additional ~~losses,~~capital itto ~~will~~finance ~~need~~our tooperations ~~sell~~and ~~equity~~additional incapital ~~order~~expenditures toand ~~continue~~could tosignificantly ~~meet~~increase ~~this~~the ~~requirement.~~ownership ~~The~~dilution ~~notification~~to ~~letter~~shareholders ~~has~~caused noby ~~immediate~~our ~~effect~~issuing onequity or other transactions. Glori’'s listing ~~or trading of common stock,~~ does not affect the Company’s business operations or its SEC reporting requirements and does not cause a default under any material agreement.

The significant risks, uncertainties, significant working capital deficit, historical operating losses and resulting cash used in operations described above raise substantial doubt about the Company's ability to continue as a going concern. The consolidated financial statements have been prepared on the going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments, in the normal course of business. The consolidated financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty.

NOTE 4 - PROPERTY AND EQUIPMENT

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

	December 31, 2015			~~March~~June 3130, 2016
				(Unaudited)
Proved oil and gas properties - successful efforts	$	48,454		$	49,~~435~~772
Unproved oil and gas properties	443			~~459~~531
Construction in progress	594			594
Laboratory and warehouse facility	648			648
Laboratory and field service equipment	3,355			3,355
Office equipment, computer equipment, vehicles and other	1,399			1,~~399~~394
	54,893			5556,~~890~~294
Less: accumulated depreciation, depletion and amortization (1)	(47,578		)	(48,~~040~~497		)
Total property and equipment, net	$	7,315		$	7,~~850~~797

(1) Excludes accretion of asset retirement obligation.

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




	Three Months Ended June 30,
	2015		2016
Depreciation and amortization expense	$	159	144
Depletion expense	840		312
Accretion of asset retirement obligation	40		40
Total depreciation, depletion and amortization of property and equipment	$	1,039	$	496

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



	Six Months Ended June 30,
	2015		2016
	(Unaudited)

Depreciation and amortization expense	$	314	$	295
Depletion expense	1,717		624
Accretion of asset retirement obligation	76		83
Total depreciation, depletion and amortization of property and equipment	$	2,107	$	1,002

	Three Months Ended March 31,
	2015		2016
	(Unaudited)
Depreciation and amortization expense	$	155	$	151
Depletion expense	877		312
Accretion of asset retirement obligation	36		43
Total depreciation, depletion and amortization of property and equipment	$	1,068	$	506

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 12). 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. For the three months and six months ended June 30, 2015, the Company had revenues of $41 thousand and $57 thousand, respectively, and a net loss of $20 thousand and $104 thousand, respectively, associated with the Etzold Field.

On ~~July~~June 1, 2015 ~~the Company sold its mineral interests in the "Etzold Field" located in Seward County~~, ~~Kansas.~~GEP ~~The~~executed ~~Etzold~~a ~~Field~~purchase ~~was~~and ~~originally~~sale ~~purchased~~agreement ~~in 2010 as a greenfield lab~~ to ~~advance~~acquire ~~the~~certain ~~development~~proved ofoil ~~the Company's AERO technology,~~ and ~~the~~gas ~~operations~~mineral ~~have~~leases ~~historically been included~~ in ~~the~~Refugio ~~Company's~~County, ~~Oil~~Texas ~~and Gas Segment~~ (~~see NOTE 12). With~~ the ~~purchase~~“Bonnie ofView ~~the larger Coke~~ Field”) ~~and~~from ~~with~~a ~~the~~third ~~Company's~~party ~~future~~seller ~~acquisition~~for ~~plans, the Company made the strategic decision to divest the Etzold Field. Prior to the sale the Company had associated net assets of~~ $892,~~000~~644,000. ~~which~~The ~~were~~carrying ~~composed~~value ~~primarily~~ of the ~~purchase~~Bonnie ~~and~~View ~~development~~Field ~~charges~~assets ~~less~~is ~~accumulated~~also ~~depreciation~~increased ~~and~~by ~~depletion~~an ~~and~~asset ~~associated~~retirement ~~liabilities of $435,000 related to the plugging and abandonment~~ obligation associated with ~~the~~plugging ~~Etzold~~and ~~Field.~~abandoning ~~In exchange for~~ the ~~leasehold~~Bonnie ~~interest~~View inField ~~the~~assets ~~field,~~of ~~the Company received~~ $75432,000. ~~and~~The ~~the~~effective ~~purchaser's~~date ~~assumption~~ of the ~~related~~purchase ~~asset~~was ~~retirement~~May ~~obligation~~1, 2015. The ~~Company~~Bonnie ~~recognized~~View aField ~~gain~~does onnot ~~the~~meet ~~sale of $422,000. For~~ the ~~three~~definition ~~months ended March 31, 2015, the Company had revenues~~ of ~~$16 thousand and~~ a ~~net~~significant ~~loss~~acquisition ofwhich ~~$97~~would ~~thousand~~require ~~associated~~pro ~~with~~forma ~~the~~financial ~~Etzold Field~~information.

On June 1, 2015, a subsidiary of the Company, Glori Energy Production Inc., 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 assets is also increased by an asset retirement obligation associated with plugging and abandoning the Bonnie View Field assets of $432,000. The effective date of the purchase was May 1, 2015. The Bonnie View Field does not meet the definition of a significant acquisition which would require pro forma financial information.

NOTE 5 – FAIR VALUE MEASUREMENTS

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.

The following table summarizes the financial assets measured at fair value, on a recurring basis as of December 31, 2015 and June 30, 2016 (in thousands):



	Fair value measurements using
	Level 1		Level 2		Level 3		Total

December 31, 2015
Short-term commodity derivatives, asset	$	—	$	3,411	$	—	$	3,411

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The following table summarizes the financial assets measured at fair value, on a recurring basis as of December 31, 2015 and March 31, 2016 (in thousands):



	Fair value measurements using
	Level 1		Level 2		Level 3		Total
	(Unaudited)

June 30, 2016
Short-term commodity derivatives, asset	$	—	$	1,243	$	—	$	1,243

	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 at December 31, 2015 and commodity swaps and put and call options at June 30, 2016. The fair values of the Company's commodity derivative instruments are based upon the NYMEX futures prices of oil compared to the contracted per barrel rate to be received or paid. For the swaps, 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. For the oil put and call options (collars), the Company records a liability when the futures price of oil is greater than the contracted ceiling price to be received and an asset when the futures prices of oil is lower than the contracted floor to be received.

	Fair value measurements using
	Level 1	Level 2		Level 3	Total
	(Unaudited)
March 31, 2016
Short-term commodity derivatives, asset	—	$	2,404	—	$	2,404

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 compared to 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.

NOTE 6 - 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 from the counterparty for a portion of the Company's oil production. In return the Company pays a floating price based upon NYMEX oil prices. In June 2016, Glori executed option contracts including oil call agreements as well as oil put agreements covering certain portions of our anticipated 2017 oil production. No net premiums were paid as a result of these option agreements. 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 endeavors to manage the default risk of counterparties by engaging in these agreements with only high credit quality companies and through the continuous monitoring of their performance.

As of ~~March~~June 3130, 2016, the Company had the following open positions on outstanding commodity derivative contracts:

Period	~~Volume/Month~~Notional Amount (~~Bbls~~Bbl)	~~Price~~Swap ($/~~Unit~~Bbl)		~~Fair~~Floor ~~Value - Asset~~($/Bbl)		Ceiling ($/Bbl)
(Unaudited)
July 2016 - December 2016	39,300	$	82.46
April 2016 - December 2016	6,550	$	82.46	2,404,000
January 2017 - June 2017	18,100			$	42.50	$	55.60

The derivative contracts are carried at fair value on the condensed consolidated balance sheet as assets or liabilities. ~~The~~Derivatives ~~Company~~for ~~has~~oil ~~not~~are ~~elected~~netted toon ~~designate~~the ~~any~~Consolidated ofBalance ~~these~~Sheets as ~~derivative~~they ~~contracts~~are ~~for~~all ~~hedge accounting. Accordingly, for each reporting period the~~ contracts ~~are~~with ~~marked-to-market and~~ the ~~resulting~~same ~~unrealized~~counterparty. The ~~changes~~following intable presents the fair value ~~of the assets~~ and ~~liabilities~~balance ~~are~~sheet ~~recognized~~location ~~on the condensed consolidated statements~~ of ~~operations.~~each ~~The~~classification ~~settlements~~ of ~~the~~commodity ~~closed~~ derivative contracts ~~result in realized gains and losses recorded~~ on ~~the~~a ~~Company's~~gross ~~condensed~~basis ~~consolidated~~without ~~statements~~regard ofto ~~operations.~~same-counterparty ~~The unrealized and realized gains and losses on derivative instruments are recognized in the (loss) gain on commodity derivatives line item located in other income (expense).~~netting:



	Fair value as of
	December 31, 2015	June 30, 2016
Asset commodity derivatives:
Current assets	3,411	1,278
Current liabilities	—	(35	)
Total commodity derivatives	3,411	1,243

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 condensed consolidated statements of operations. The settlements of the closed derivative

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contracts result in realized gains and losses recorded on the Company's condensed consolidated statements of operations. The unrealized and realized gains and losses on derivative instruments are recognized in the (loss) gain on commodity derivatives line item located in other income (expense).

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

	Three Months Ended March 31,
	Three Months Ended June 30,
	2015			2016
	(Unaudited)
Unrealized gain (loss) on commodity derivatives	$	223		$	(1,007	)
Unrealized loss on commodity derivatives	$	(1,605	)	$	(1,161	)
Realized gain on commodity derivatives	~~1,146~~625			~~1,162~~724
	$	~~1,369~~(980	)	$	~~155~~(437	)



	Six Months Ended June 30,
	2015			2016
	(Unaudited)

Unrealized loss on commodity derivatives	$	(1,382	)	$	(2,168	)
Realized gain on commodity derivatives	1,771			1,886
	$	389		$	(282	)

NOTE 7 - 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 was secured by substantially all assets of the Company with the exception of the Coke Field Assets. The lender also received a warrant to purchase shares of the Company’s stock which was exchanged for 18,208 common shares upon consummation of the Merger. Equal monthly principal payments were due over 27 months beginning in April 2013 through June 2015 plus an end of term charge of $280,000. The loan agreement contained covenants which place restrictions on the incurrence of debt, liens and capital expenditures. On March 2, 2015 the Company elected to prepay the entire remaining indebtedness. The payment included remaining principal of $888,000 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, the Company entered into a financing agreement of $18.0 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 of ~~Glori~~GEP ~~Energy Production Inc.~~ and is secured by the Coke Field and shares of common stock of ~~Glori Energy Production Inc~~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~~required quarterly principal payments equal to 50% of the excess cash flows, as defined, from ~~the~~GEP's ~~Coke~~oil ~~Field~~properties 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 shown on the condensed consolidated balance sheets as a reduction of proceeds and amortized over the loan term. The loan agreement contains covenants which place restrictions on ~~Glori Energy Production~~GEP’s ability to incur additional debt, incur other liens, make other investments, capital expenditures and the sale of assets.

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 previously required financial ratio covenants and 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%. The additional 2.0% may be “paid in kind”, and added to the principal amount, or paid in cash at the election of the Company. 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. For the three months ending June 30, 2016, the Company elected the additional 2.0% interest to be paid in kind and debt increased by $52,000. As of December 31, 2015 and ~~March~~June 3130, 2016 the outstanding loan balance was $10.5 million and $10.32 million, respectively.

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

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



Year ending June 30,	Amount
	(Unaudited)

2017	10,223
2018	8
2019	9
2020	9
2021	10
Thereafter	1
	$	10,260

Year ending March 31,	Amount
	(Unaudited)
2017	10,290
2018	8
2019	8
2020	9
2021	9
Thereafter	5
	$	10,329

The maturities above are presented on the June 30, 2016 condensed consolidated balance sheet net of debt issuance costs of $156 thousand.

The maturities above are presented on the March 31, 2016 condensed consolidated balance sheet net of debt issuance costs of $211 thousand.

NOTE 8 - 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):

	Three Months Ended March 31,
	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2016			2015			2016
	(Unaudited)						(Unaudited)
Numerator:
Net loss	$	(24,~~984~~916	)	$	(3,~~401~~247	)	$	(7,900	)	$	(6,648	)
Denominator:
Weighted-average common shares outstanding - basic	31,~~563~~803			3132,~~940~~050			31,684			32,026
Effect of dilutive securities	—			—			—			—
Weighted-average common shares - diluted	31,~~563~~803			3132,~~940~~050			31,684			32,026
Net loss per common share - basic and diluted	$	(0.0915	)	$	(0.1110	)	$	(0.25	)	$	(0.21	)

The following weighted average securities outstanding during the three and six months ended June 30, 2015 and June 30, 2016 were not included in the calculation of diluted shares outstanding as they would have been anti-dilutive (in thousands):



	Three Months Ended June 30,		Six Months Ended June 30,
	2015	2016	2015	2016
	(Unaudited)		(Unaudited)

Common stock warrants ($10 strike price)	5,321	5,321	5,321	5,321
Common stock options	2,048	2,714	2,154	2,754
Restricted shares	132	427	102	565

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The following weighted average securities outstanding during the three months ended March 31, 2015 and March 31, 2016 were not included in the calculation of diluted shares outstanding as they would have been anti-dilutive (in thousands):

	Three Months Ended March 31,
	2015	2016
	(Unaudited)
Common stock warrants ($10 strike price)	5,321	5,321
Common stock options	2,240	2,793
Restricted shares	469	720

NOTE 9 - INCOME TAXES

At December 31, 2015 and ~~March~~June 3130, 2016, the Company has net operating loss carryforwards for federal income tax reporting purposes of approximately $64.53 million and $6871.43 million, respectively, which will begin to expire in the year 2025, and tax credits of approximately $~~508~~504,000 ~~and $521~~,~~000,~~ ~~respectively,~~ which will begin to expire in 2027. The NOL carry forward has been reduced by approximately $5.4 million of loss carryforwards that management estimates will expire due to limitations from changes in control.

The Company has recorded a valuation allowance against the Company's deferred tax assets. The effective tax rate for the three and six months ended ~~March~~June 3130, 2015 and 2016 varies from the statutory rate primarily due to the effect of the valuation allowance. For the three and six months ended ~~March~~June 3130, 2015 the Company had an income tax ~~expense~~benefit of $17188,000 and $171,000, respectively, due to a reduction in taxes payable on foreign income as the Company revised its methodology for service fee applications charged to foreign subsidiaries. For the three ~~months~~and ~~ended~~six ~~March~~months 31ended June 30, 2016 the Company had noan income tax ~~expense~~benefit of $6,000 due to the utilization of net operating losses to recover previously paid foreign income taxes.

NOTE 10 - 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 currently 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 2014, for 7,805 square feet of office space in Houston's Westchase District for approximately $18,000 per month. The Company does not intend to renew this lease upon expiration in October 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 C$1,000 per month and is cancelable with 30 days' notice.

Approximate minimum future rental payments under these noncancelable operating leases as of ~~March~~June 3130, 2016 are as follows (in thousands):

	Year Ending March 31,
	Year Ending June 30,
	(Unaudited)
2017	~~240~~$	165
2018	21
	$	165
	$	261

Total rent expense was approximately $71120,000 and $90180,000 for the three and six months ended ~~March~~June 3130, 2015 and ~~March~~$90,000 and $180,000 for the three and six months ended and June 3130, 2016, respectively.

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NOTE 11 - STOCK-BASED COMPENSATION

Stock Incentive Plan

In December 2014, the Company shareholders 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 consultants 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 1 year, and thereafter ratably each month over the following 36 months, and may be exercised for a period of 10 years subject to vesting.

Stock-based compensation expense, included primarily in selling, general and administrative expense, was $~~432~~417,000 and $~~233~~40,000 for the three months ended ~~March~~June 30, 2015 and June 3130, 2016 and $838,000 and $273,000 for the six months ended June 30, 2015 and ~~March~~June 3130, 2016, respectively. The Company has future unrecognized compensation expense for nonvested shares at ~~March~~June 3130, 2016 of $1.81 million with a weighted average vesting period of 2.75 years.

Stock Option Awards:

The Company has computed the fair value of all options granted during the year ended December 31, 2015, using the Black-Scholes option pricing model using the following assumptions:



	Year ended December 31,
	2015


Risk-free interest rate	1.55	%
Expected volatility	66	%
Expected dividend yield	—
Expected life (in years)	6.00
Expected forfeiture rate	—

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

	Numberof options		Weightedaverageexerciseprice per share		Weightedaverageremainingcontractualterm (years)	Aggregate intrinsic value
Outstanding as of December 31, 2015	2,834,635		$	1.01	6.9	$	89,000
Awarded (unaudited)	—
Exercised (unaudited)	—
Forfeited or Expired (unaudited)	(61151,~~864~~515	)	2.8618
Outstanding as of March 31, 2016 (unaudited)	2,772,771		$	0.96	6.57	$	—
Outstanding as of June 30, 2016 (unaudited)	2,683,120		$	0.94	5.2	$	—
Exercisable as of December 31, 2015	1,934,605		$	0.84	5.7	$	89,000
Exercisable as of March 31, 2016 (unaudited)	1,999,231		$	0.91	5.5	$	—
Exercisable as of June 30, 2016 (unaudited)	1,949,161		$	0.89	3.7	$	—

The weighted-average grant date fair value for equity options granted during the ~~three~~six months ended ~~March~~June 3130, 2015 and June 30, 2016 was $2.40 and $2.40, respectively. There were no option awards issued in the three months ended ~~March~~June 30, 2015 and June 3130, 2016. The total fair value of options vested during the three months ended ~~March~~June 3130, 2015 and ~~March~~June 3130, 2016 was $6095,000 and $~~127~~33,000, respectively. The total fair value of options vested during both the six months ended June 30, 2015 and June 30, 2016 was $160,000.

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Restricted Share Awards:

In addition to options the Company has 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 ~~three~~six months ended ~~March~~June 3130, 2016:

	Shares		Weighted-average grant date fair value
Non-vested awards outstanding, December 31, 2015	844,592		$	2.67
Vested	(~~157~~284,~~387~~682	)	2.9952
Forfeited	(38293,~~265~~797	)	12.9655
Non-vested awards outstanding, March 31, 2016	648,940		$	2.64
Non-vested awards outstanding, June 30, 2016	266,113		$	2.97

NOTE 12 – 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 AERO 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. The revenues derived from the segment are from sales to the first purchaser. The Company uses two such arrangements for oil sales, one for the Coke ~~Field~~ and Quitman ~~Fields~~fields located in Wood County, Texas and one for the Bonnie View Field in Refugio County, Texas.

The AERO Services Segment derives revenues from external customers by providing the Company’s biotechnology solution 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 condensed 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 condensed consolidated statements of operations are the expenses that are directly attributable to the Field Deployment Phase and 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. 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 expenses associated with injection equipment isare viewed as part of the AERO Services Segment.

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The following table sets forth the operating segments of the Company and the associated revenues and expenses (in thousands):

	Oil and Gas			AERO Services			Corporate			Total
	(Unaudited)
Three Months Ended March 31, 2015
Three months ended June 30, 2015
Revenues	$	2,~~000~~136		$	~~567~~496		$	—		$	2,~~567~~632
Total operating expenses	2,~~392~~500			~~521~~534			2,~~192~~163			5,~~105~~197
Depreciation, depletion and amortization	~~953~~912			~~100~~109			1518			1,~~068~~039
Loss from operations	(1,~~345~~276		)	(54147		)	(2,~~207~~181		)	(3,~~606~~604		)
Other income (expense), net	1,369			—			(730		)	639
Other expense, net	(980		)	—			(520		)	(1,500		)
Income tax expense	—			—			17			17
Income tax benefit	—			—			(188		)	(188		)
Net income (loss)	24			(54		)	(2,954		)	(2,984		)
Net loss	$	(2,256	)	$	(147	)	$	(2,513	)	$	(4,916	)

	Oil and Gas			AERO Services			Corporate			Total
	(Unaudited)
Three Months Ended March 31, 2016
Three months ended June 30, 2016
Revenues	$	1,~~024~~163		$	~~174~~72		$	—		$	1,~~198~~235
Total operating expenses	1,~~891~~240			~~273~~213			1,~~752~~712			3,~~916~~165
Depreciation, depletion and amortization	~~375~~372			9057			4167			~~506~~496
Loss from operations	(~~1,242~~449		)	(~~189~~198		)	(1,~~793~~779		)	(32,~~224~~426		)
Other income (expense), net	155			—			(332		)	(177		)
Other expense, net	(437		)	—			(390		)	(827		)
Income tax benefit	—			—			—(6		)	—(6		)
Net loss	~~(1,087~~$	(886	)	~~(189~~$	(198	)	~~(2,125~~$	(2,163	)	~~(3,401~~$	(3,247	)



	Oil and Gas			AERO Services			Corporate			Total
	(Unaudited)
Six Months Ended June 30, 2015
Revenues	$	4,136		$	1,063		$	—		$	5,199
Total operating expenses	4,892			1,055			4,355			10,302
Depreciation, depletion and amortization	1,865			209			33			2,107
Loss from operations	(2,621		)	(201		)	(4,388		)	(7,210		)

Other income (expense), net	389			—			(1,250		)	(861		)

Income tax benefit	—			—			(171		)	(171		)

Net loss	(2,232		)	(201		)	(5,467		)	(7,900		)

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	Oil and Gas			AERO Services			Corporate			Total
	(Unaudited)
Six Months Ended June 30, 2016
Revenues	$	2,187		$	246		$	—		$	2,433
Total operating expenses	3,131			486			3,464			7,081
Depreciation, depletion and amortization	747			147			108			1,002
Loss from operations	(1,691		)	(387		)	(3,572		)	(5,650		)

Other expense, net	(282		)	—			(722		)	(1,004		)

Income tax benefit	—			—			(6		)	(6		)

Net loss	(1,973		)	(387		)	(4,288		)	(6,648		)

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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the accompanying unaudited condensed consolidated financial statements as of ~~March~~June 3130, 2016 and for the three and six months ended ~~March~~June 3130, 2016 and 2015 included elsewhere herein, and with our annual report on Form 10-K for the year ended December 31, 2015. The following discussion and analysis contains forward-looking statements that involve risks and uncertainties. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, including those set forth under “Risk Factors” in Item 1A of our annual report and elsewhere in this quarterly report. See “Cautionary Note Regarding Forward-Looking Statements” above.

Overview

We are a Houston-based energy technology and oil production company that deploys ~~our~~its proprietary AERO technology to increase the amount of oil that can be produced from conventional fields at a substantially lower cost than traditional enhanced oil recovery methods ("AERO System"). Only about one-third of the oil discovered in a typical reservoir is recoverable using conventional oil production technology, leaving the remaining two-thirds trapped in the reservoir rock. Our AERO System technology stimulates the native microorganisms that reside in the reservoir to improve the recoverability of this trapped oil. ~~The~~We believe the AERO System can reverse production declines and significantly increase ultimate reserve recovery at a low incremental cost per barrel. Glori owns and operates oil fields onshore in the U.S. where we deploy our technology, and additionally ~~market~~provides the AERO System as a technology service to exploration and production ("E&P") companies ~~globally~~. We derive revenues from fees earned as a service provider of our technology to third party E&P companies, and we also use our technology to increase oil production in fields that we acquire and operate in the United States.

~~Our~~Glori's goal is also to acquire ~~and~~fields ~~redevelop~~which ~~additional~~may ~~mature~~have ~~oil~~no ~~fields~~current ~~with~~production ~~historically~~but ~~long-lived,~~have ~~predictable~~excellent ~~production~~reservoir ~~profiles~~qualities, ~~that~~are ~~fit~~compatible with our ~~criteria for the~~ AERO ~~System.~~technology, Weand ~~target~~have ~~mature~~significant ~~sandstone~~original ~~assets~~oil ~~onshore~~ in ~~North~~place ~~America with good permeability and production supported by waterflood or waterdrive systems, or with clear potential for waterflooding~~remaining. We believe ~~our~~there ~~acquisition~~are ~~strategy~~significant ~~can~~opportunities ~~enhance~~onshore ~~the~~U.S. ~~revenues,~~to ~~cash~~acquire ~~flows~~ and ~~returns~~reconstitute ~~from~~ such ~~oil~~previously abandoned fields ~~through~~and ~~waterflood~~capture ~~optimization~~significant ~~and~~economic ~~implementation~~quantities of ~~our~~oil ~~AERO~~which ~~System~~have ofbeen ~~enhanced~~left ~~oil~~behind ~~recovery.~~by Wethe ~~believe~~industry. ~~this~~Our ~~strategy~~focus ~~will~~is ~~enable~~on ussandstone toreservoirs ~~further~~with ~~demonstrate~~good ~~the~~permeability ~~efficacy~~and ofclear ~~our~~potential ~~AERO~~for ~~System~~waterflooding, ~~while~~which ~~allowing~~are ustherefore toare ~~capture~~good ~~the~~candidates ~~increase~~to inbenefit ~~revenues~~from ~~and~~our ~~ultimate~~AERO ~~recovery~~technology. ~~The~~We ~~decrease~~believe inby ~~oil~~introducing ~~prices~~AERO ~~over~~at the ~~past~~initiation 18of ~~months~~a ~~has~~waterflood, ~~made~~we itcan ~~difficult~~improve ~~to acquire~~ oil ~~assets~~recovery asand ~~potential~~reduce ~~sellers~~water ~~are~~use ~~hesitant~~over tothe ~~sell~~life atof ~~depressed~~a ~~prices~~field. Additionally, ~~lenders~~since ~~and~~these ~~investors~~inactive ~~have~~fields ~~tended~~may tonot ~~limit~~have ~~new~~produced ~~financings~~any oil for ~~the~~many ~~E&P industry. Therefore~~years, ~~Glori's~~they ~~ability~~can tobe ~~execute~~acquired onor ~~its~~leased ~~acquisition~~at ~~strategy~~low ~~will depend on relative stability in oil~~ prices, ~~and~~when oncompared ~~its ability~~ to ~~raise~~producing ~~capital~~assets.

~~Glori’s~~Our goal is also to acquire ~~fields~~and ~~which~~redevelop ~~may~~mature ~~have~~oil nofields ~~current~~with ~~production~~historically ~~but~~long-lived, ~~have~~predictable ~~excellent~~production ~~reservoir~~profiles ~~qualities,~~that ~~are~~fit ~~compatible with~~ our ~~AERO~~criteria ~~technology,~~for ~~and~~the ~~have~~AERO ~~significant original oil in place remaining~~System. We believe ~~there~~our ~~are~~acquisition ~~significant~~strategy ~~opportunities~~can ~~onshore~~enhance ~~U.S.~~the torevenues, ~~acquire~~cash flows and ~~reconstitute~~returns from such ~~previously~~oil ~~abandoned~~ fields ~~and~~through ~~capture~~waterflood ~~significant~~optimization ~~economic~~and ~~quantities~~implementation of ~~oil~~our ~~which~~AERO ~~have~~System ~~been~~of ~~left~~enhanced ~~behind~~oil ~~by the industry~~recovery. ~~Additionally,~~The ~~since~~decrease ~~these~~in ~~inactive fields may not have produced any~~ oil ~~for~~prices ~~many~~over ~~years,~~the ~~they~~past ~~can~~18 beto ~~acquired~~20 atmonths ~~low~~has ~~prices,~~made ~~when~~it ~~compared~~difficult to acquire producing oil assets. Inas ~~connection~~potential ~~with~~sellers ~~this~~are ~~initiative~~hesitant to ~~regenerate~~sell ~~and~~at ~~enhance~~depressed ~~abandoned~~prices. ~~mature fields~~Additionally, welenders ~~applied~~and toinvestors ~~the~~have ~~United~~tended ~~States~~to ~~Department~~limit ofnew ~~Energy’s~~financings ~~Loan Programs Office (“LPO”)~~ for ~~a $150 million loan guarantee in connection with projects to apply AERO technology to previously abandoned reservoirs in~~ the ~~U.S.~~E&P ~~We have identified several candidate reservoirs as potential project sites~~industry. ~~Based~~Therefore, ~~on LPO’~~Glori's ~~evaluation~~ability ofto ~~Part~~execute ~~I of our application,~~ on ~~March~~its 1,acquisition ~~2016,~~strategy ~~LPO~~depends ~~invited~~on ~~Glori~~relative tostability ~~submit Part II of its application. We are currently~~ in ~~the~~oil ~~process~~prices ofand ~~submitting~~on ~~Part~~our IIability ofto ~~the~~raise ~~application~~capital. ~~We cannot, however, predict the ultimate outcome of the application or whether a loan guarantee eventually will be issued.~~

In connection with this initiative to regenerate and enhance abandoned mature fields, we applied to the United States Department of Energy’s Loan Programs Office (“LPO”) for a $150 million loan guarantee in connection with projects to apply AERO technology to previously abandoned reservoirs in the U.S. We have identified several attractive candidate reservoirs that fit our criteria as potential projects. Based on LPO’s evaluation of Part I of our application, on March 1, 2016, LPO invited Glori to submit Part II of its application. In May 2016 we submitted Part II of the application. We cannot, however, predict the ultimate outcome of the application or whether a loan guarantee eventually will be issued. If a loan guarantee is ultimately not approved, or if the final terms of the loan guarantee are not advantageous, the Company plans to seek alternative financing to enable it to acquire and redevelop certain identified abandoned fields which fit its criteria.

On January 8, 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., as INXB Representative (such transaction, the "Merger"). On April 14, 2014, the Merger was consummated. We obtained effective control of INXB subsequent to the Merger and thus the Merger was accounted for as a reverse acquisition and recapitalization of the Company. Subsequent to the Merger, our shareholders retained a substantial majority of voting interest and positions on the Board of Directors. Additionally our management was retained and our operations comprise the ongoing operations post-Merger. In connection with the Merger, we received approximately $24.7 million, net of certain ~~expenses and fees, and approximately $13.7 million in cash from the private placement of common stock for total proceeds of $38.4 million.~~

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On March 14, 2014, we acquired the Coke Field from Petro-Hunt for (i) $38.0 million in cash and a $2.0 million convertible note payable to Petro-Hunt, and (ii) the assumption of the asset retirement obligation related to plugging and abandoning the Coke Field. Subsequent to the Merger the note payable to Petro-Hunt was converted into common stock.

On June 1, 2015, a subsidiary of the Company, Glori Energy Production Inc., 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 $2.6 million. The carrying value of the Bonnie View Field assets is also increased by an asset retirement obligation associated with plugging and abandoning the Bonnie View Field assets of $432 thousand.

Net loss for the first quarter of 2016 was $3.4 million or $0.11 per share. This compares to a first quarter 2015 net loss of $3.0 million, or a loss of $0.09 per share.

Revenues for the first quarter of 2016 were $1.2 million, reflecting a decrease of $1.4 million from the first quarter of 2015. Oil and gas revenues decreased to $1.0 million from $2.0 million in the first quarter 2015 due to a 38% decrease in average oil prices received and a 17% decrease in oil volumes produced and sold in the first quarter of 2016. Revenues from our AERO technology services segment decreased to $174 thousand in the first quarter of 2016 from $567 thousand, a decrease of 69% from the first quarter of 2015 due to a decline in the number of new projects in the 2016 period. Although our AERO System is a low cost enhanced oil recovery solution, our 2016 service revenues have been adversely affected by the continued suspension of E&P industry spending on new projects as a result of the sharp drop in oil prices.

During the first quarter of 2016, we produced 36,101 net barrels of oil equivalents ("BOE") or approximately 397 net BOE per day, including 32,728 barrels of oil and 20,236 thousand cubic feet of natural gas, and received an average realized price of $30.65 per barrel and $1.11 per thousand cubic foot. We utilized 8,740 thousand cubic feet of natural gas production in operations at the Bonnie View field during the quarter. After the effect of oil price swap settlements, our oil price per barrel for the quarter was approximately $65.86 per barrel. Production from liquids (oil and condensate) represented approximately 91% of total production. Total production in the first quarter of 2016 decreased approximately 15% from fourth quarter 2015 production primarily due to shutting in certain marginally profitable wells in the Coke Field in order to reduce lease operating expenses. First quarter 2015 production was 481 net BOE per day with an average realized price of $49.43 per barrel and $1.53 per thousand cubic foot. Including the effect of oil price swap settlements, the average realized oil price per barrel was $78.21 in the first quarter of 2015.

We had price swap derivatives in place covering approximately 67% of our oil and condensate production for the first quarter of 2016. We continue to maintain price swaps covering a portion of our estimated future production. In the first quarter ended March 31, 2016, we recorded a net gain on commodity derivatives of approximately $155 thousand, which was net of a $1.0 million unrealized loss due to an increase in NYMEX oil futures prices from the beginning to the end of the quarter. In the previous year's first quarter, we recorded a gain on commodity derivatives of $1.4 million, which included $223 thousand in realized cash settlements received.

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expenses and fees, and approximately $13.7 million in cash from the private placement of common stock for total proceeds of $38.4 million.

On March 14, 2014, a subsidiary of the Company, Glori Energy Production Inc. ("GEP"), acquired the Coke Field from Petro-Hunt for (i) $38.0 million in cash and a $2.0 million convertible note payable to Petro-Hunt, and (ii) the assumption of the asset retirement obligation related to plugging and abandoning the Coke Field. Subsequent to the Merger the note payable to Petro-Hunt was converted into common stock.

On June 1, 2015, 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 $2.6 million. The carrying value of the Bonnie View Field assets is also increased by an asset retirement obligation associated with plugging and abandoning the Bonnie View Field assets of $432 thousand.

Net loss for the second quarter of 2016 was $3.2 million, or $0.10 per share. This compares to a second quarter 2015 net loss of $4.9 million, or a loss of $0.15 per share.

Revenues for the second quarter of 2016 were $1.2 million, reflecting a decrease of $1.4 million from the second quarter of 2015. Oil and gas revenues decreased 46% to $1.2 million from $2.1 million in the second quarter 2015 due to a 25% decrease in average oil prices received and a 26% decrease in oil volumes produced and sold in the second quarter of 2016. Revenues from our AERO technology services segment decreased to $72 thousand in the second quarter of 2016 from $496 thousand, a decrease of 86% from the second quarter of 2015 due to a decline in the number of new projects in the 2016 period. Although our AERO System is a low cost enhanced oil recovery solution, our 2016 service revenues have been adversely affected by continued low oil prices and decreased capital spending by the E&P industry.

During the second quarter of 2016, we produced 29,003 net barrels of oil equivalents ("BOE") or approximately 319 net BOE per day, including 27,150 barrels of oil and 11,116 thousand cubic feet of natural gas, and received an average realized oil price of $42.64 per barrel. We utilize certain volumes of natural gas production in operations at the Bonnie View field each month. After the effect of oil price swap settlements, our oil price per barrel for the quarter was approximately $69.18 per barrel. Production from liquids (oil and condensate) represented approximately 94% of total production. Total production in the second quarter of 2016 decreased approximately 20% from the first quarter of 2016 production primarily due to shutting in certain uneconomic wells in the Coke Field in order to reduce lease operating expenses. Second quarter 2015 production was 441 net BOE per day with an average realized price of $57.06 per barrel and $1.47 per thousand cubic foot. Including the effect of oil price swap settlements, the average realized oil price per barrel was $73.99 in the second quarter of 2015.

We had price swap derivatives in place covering approximately 72% of our oil and condensate production for the second quarter of 2016. We continue to maintain price swaps covering a portion of our estimated future production through December 2016, and have added costless collars (a combination of put and call options to sell and buy oil) to cover a portion of our estimated future production in the first half of 2017. In the three months ended June 30, 2016, we recorded a net loss on commodity derivatives of approximately $437 thousand, which was net of a $724 thousand realized gain on cash settlements received. In the previous year's second quarter, we recorded a loss on commodity derivatives of $980 thousand, which was net of a $625 thousand realized gain on cash settlements received. See NOTE 6 in the Notes to the Condensed Consolidated Financial Statements in Part I, Item 1 of this report for additional information regarding our commodity derivative activities.

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Results of Operations

Historical Results of Operations for Glori

The following table sets forth selected financial data for the periods indicated (in thousands):

	Three months ended March 31,
	Three Months Ended June 30,						Six months ended June 30,
	2015			2016			2015			2016
Revenues:
Oil and gas revenues	$	2,~~000~~136		$	1,~~024~~163		$	4,136		$	2,187
Service revenues	~~567~~496			~~174~~72			1,063			246
Total revenues	2,~~567~~632			1,~~198~~235			5,199			2,433
Operating expenses:
Oil and gas operations	2,~~392~~500			1,~~891~~240			4,892			3,131
Service operations	~~521~~534			~~273~~213			1,055			486
Science and technology	~~474~~629			~~334~~309			1,103			643
Selling, general and administrative	1,~~718~~534			1,~~418~~403			3,252			2,821
Depreciation, depletion and amortization	1,~~068~~039			~~506~~496			2,107			1,002
Total operating expenses	6,~~173~~236			43,~~422~~661			12,409			8,083
Loss from operations	(3,~~606~~604		)	(32,~~224~~426		)	(7,210		)	(5,650		)
Other income (expense):
Interest expense	(~~715~~530		)	(~~343~~392		)	(1,245		)	(735		)
Gain on commodity derivatives	1,369			155
(Loss) gain on commodity derivatives	(980		)	(437		)	389			(282		)
Other (expense) income	(15		)	11
Other income (expense)	10			2			(5		)	13
Total other income (expense), net	639			(177		)
Total other expense, net	(1,500		)	(827		)	(861		)	(1,004		)
Income tax expense	17			—
Income tax benefit	(188		)	(6		)	(171		)	(6		)
Net loss	$	(24,~~984~~916	)	$	(3,~~401~~247	)	$	(7,900	)	$	(6,648	)

2122

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The following table sets forth selected production data for the periods indicated:

	Three Months Ended March 31,
	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2016		2015		2016
Revenues (in thousands):
Oil revenues	$	12,~~968~~108	$	1,~~011~~163	$	4,075	$	2,175
Natural gas revenues	3228		13—		61		12
Total oil and gas revenues	$	2,~~000~~136	$	1,~~024~~163	$	4,136	$	2,187
Sales volumes:
Oil volumes (MBbls)	4037		3327		77		60
Gas volumes (MMcf)	2119		11—		40		13
Gas volumes (MBoe)	3		2—		7		2
Total volumes (MBoe)	4340		3527		84		62
Price:
Average oil price received per Bbl	$	4957.4306	$	3042.6560	$	53.05	$	36.08
Average oil price per Bbl including price swap settlements	$	7873.2199	$	6569.8618	$	76.18	$	67.36
Average gas price per Mcf	$	1.5347	$	~~1.11~~—	$	1.53	$	0.96

The following table details oil and gas operations expense for the periods indicated (in thousands):

	Three months ended March 31,
	Three months ended June 30,				Six months ended June 30,
	2015		2016		2015		2016
Lease operating expense	$	1,~~422~~664	$	~~1,281~~768	$	3,086	$	2,049
Ad valorem taxes	~~138~~36		4774		174		122
Severance taxes	9299		4854		192		101
Acquisition expenses	2618		2522		44		48
Oil and gas overhead expense	~~714~~683		~~490~~322		1,396		811
Oil and gas operations expense	$	2,~~392~~500	$	1,~~891~~240	$	4,892	$	3,131

Three Months Ended ~~March~~June 3130, 2015 and 2016

Oil and gas revenues. Oil and gas revenues decreased by $1.0 million, or 4946%, from $2.01 million in the three months ended ~~March~~June 3130, 2015 to $1.02 million in the three months ended ~~March~~June 3130, 2016. The decrease was primarily the result of a 3825% decrease in average oil prices received and a 1726% decrease in oil ~~volumes~~production ~~produced~~sold. Production decreased primarily due to a cost reduction plan to improve field profitability at the Coke Field by shutting in uneconomic wells in the low price environment and by reducing overall field expenses. Production from the Bonnie View field, acquired in June 2015, partially offset the overall decrease in revenues and resulted in the inclusion of an additional 2,130 barrels of oil sold in the 2016 period.

Service revenues. Service revenues decreased by $~~393~~424 thousand, or 6986%, from $~~567~~496 thousand in the three months ended ~~March~~June 3130, 2015 to $~~174~~72 thousand in the three months ended ~~March~~June 3130, 2016. The decrease was ~~due~~primarily attributable to ~~several~~a ~~field~~decrease of $416 thousand in Field Deployment Phase services due to two projects ~~that~~which concluded ~~during~~in July 2015 and one project which ~~were~~concluded ~~ongoing~~in ~~during~~February ~~all~~2016. orAnalysis ~~part~~Phase ofrevenues decreased $8 thousand from the prior year period. Service revenues have continued to be adversely impacted by the decrease in oil prices which resulted in significant decreases in spending by our exploration and production customers and prospects.

Table of Contents

Oil and gas operations. Oil and gas operating expenses decreased by $501 thousand, or 21%, from $2.4 million in the three months ended March 31, 2015 to $1.9 million in the three months ended March 31, 2016. Overhead expenses decreased $224 thousand due to decreases in third party consulting fees and a reduction in salaries and benefits. Lease operating expenses ("LOE") decreased by a net $141 thousand primarily due to a $250 thousand decrease in Coke Field expenses due to cost reduction efforts including the shutting in of uneconomic wells in the lower oil price environment. LOE also decreased by $96 thousand due to the sale of the Etzold Field in July 2015. These decreases in LOE were partially offset by the addition of $205 thousand in expenses for the Bonnie View Field, which was purchased in June 2015. The overall decrease in oil and gas operating expenses also included a decrease of $91 thousand in ad valorem tax expense due to a revised tax assessment and a $44 thousand reduction in severance taxes due to sustained lower oil prices and revenues.

Service operations. Service operations expense decreased by $248 thousand, or 48%, from $521 thousand in the first quarter of 2015 to $273 thousand in the first quarter 2016. Approximately $137 thousand of the decrease is attributable to reduced project costs related to two domestic field projects, which concluded during February and July 2015. The remaining decrease is primarily attributable to reduced project costs related to a Canadian project which concluded during July 2015 and a decrease in service operations headcount.

Science and technology. Science and technology expenses decreased by $140 thousand from $474 thousand in the three months ended March 31, 2015 to $334 thousand in the three months ended March 31, 2016 mostly due to a decrease of $84 thousand in compensation and benefits due to a decreased headcount and a decrease of $47 thousand in lab supplies and travel related to a decrease in Analysis Phase services projects.

Selling, general and administrative ("SG&A"). SG&A expenses decreased by $300 thousand, or 17%, from $1.7 million in the three months ended March 31, 2015 to $1.4 million in the three months ended March 31, 2016. The decrease was primarily attributable to a decrease of $492 thousand from cost cutting measures in salaries, benefits, travel and certain other back office expenses. Increases in consulting and other third party professional fees expenses partially offset the overall decrease in SG&A.

Depreciation, depletion and amortization ("DD&A"). DD&A decreased from $1.1 million in the three months ended March 31, 2015 to $506 thousand in the three months ended March 31, 2016. The overall decrease was due to a decrease in depletion expense of $565 thousand related to the December 2015 impairment of the Coke Field as a result of the oil price decline. Depletion expense for the first quarter of 2016 was calculated based on a lower asset value as compared to the first quarter of 2015 as a result of impairment during the fourth quarter of 2015.

Total other income (expense), net. Total other income (expense), net, decreased $816 thousand from an income of $639 thousand in the three months ended March 31, 2015 to an expense of $177 thousand in the three months ended March 31, 2016. Our commodity price swaps that were entered into in connection with the acquisition of the Coke Field in March 2014 resulted in a net gain of $155 thousand in the three months ended March 31, 2016 compared to a gain of $1.4 million in the prior year period. In the 2016 period, the derivative gain consisted of an $1.2 million realized gain on price swap settlements, which was offset by a $1.0 million unrealized loss on the change in fair value of future settlements due to an increase in NYMEX oil futures prices from the beginning to the end of the quarter. In the 2015 period, the commodity derivative gain consisted of a $1.1 million realized gain on price swap settlements and a $223 thousand unrealized gain on the change in fair value of future settlements. Interest expense also decreased $372 thousand compared to the first quarter of 2015 due to the repayment of debt, including debt used to partially fund the Coke Field acquisition and the $8.0 million secured term promissory note which was prepaid in March 2015.

Liquidity and Capital Resources

Our primary sources of liquidity and capital since our formation have been proceeds from equity issuances and borrowings. To date, our primary use of capital has been to fund acquisitions, principally the purchase of the Coke Field, to fund our operations and for payments on debt.

As of May 10, 2016, the Company does not have any lines of credit available to it. At March 31, 2016, we had a working capital deficit of $3.1 million, made up of current assets of $8.8 million and current liabilities of $11.8 million. The current asset balance is comprised of cash and cash equivalents of $5.0 million, accounts receivable of $935 thousand, commodity derivative contracts receivable of $2.4 million, and prepaid expenses and other current assets of $385 thousand. Included in current liabilities is $1.1 million in accounts payable, $648 thousand in accrued expenses, and $10.1 million in current portion of long-term debt.

Table of Contents

OnOil ~~October~~and ~~23,~~gas ~~2015,~~operations. weOil ~~received~~and agas ~~notice~~operating ~~from~~expenses ~~the~~decreased ~~Listing~~by ~~Qualifications~~$1.3 ~~Department~~million, ofor ~~the~~50%, ~~NASDAQ~~from ~~Stock~~$2.5 ~~Market~~million ~~LLC~~in ~~indicating that, for~~ the ~~previous~~three 30months ~~consecutive~~ended ~~business~~June ~~days~~30, ~~the~~2015 ~~bid~~to ~~price for our common stock had closed below the minimum~~ $1.002 ~~per~~million ~~share~~in ~~required~~the ~~for~~three ~~continued~~months ~~inclusion~~ended onJune ~~The~~30, ~~NASDAQ Capital Market under NASDAQ Listing Rule 5550(a)(2)~~2016. ~~The~~Overhead ~~Company~~expenses ~~was~~decreased ~~afforded~~$361 ~~180 calendar days~~thousand, or ~~until April 20~~53%, ~~2016,~~due to ~~regain~~decreases ~~compliance~~in ~~with~~third ~~the~~party ~~minimum~~consulting ~~bid~~fees ~~price~~and ~~requirement.~~a Inreduction ~~order~~in tocompensation ~~regain~~and ~~compliance,~~benefits ~~shares~~as ~~of the Company’s common stock must maintain~~ a ~~minimum~~result ~~bid closing price~~ of atdecreased ~~least $1~~headcount.00 ~~per~~Lease ~~share~~operating ~~for~~expenses a("LOE") ~~minimum~~decreased ofby ~~ten~~a ~~consecutive~~net ~~business~~$896 ~~days,~~thousand ~~subject~~primarily todue ~~NASDAQ's discretion~~ to ~~increase~~a ~~such~~$925 ~~ten-day~~thousand, ~~period.~~or ~~On April 25~~59%, ~~2016,~~decrease wein ~~received~~Coke aField ~~letter~~expenses ~~from~~due ~~NASDAQ granting the Company an additional 180 days~~ to ~~regain~~cost ~~compliance~~reduction ~~with the minimum bid price requirement~~efforts. ~~The~~LOE ~~Company~~also ~~has~~decreased ~~until~~by ~~October~~$59 ~~17,~~thousand ~~2016~~due to ~~regain~~the ~~compliance~~sale ~~with~~of the ~~bid~~Etzold ~~price~~Field ~~requirement~~in July 2015. InThese ~~addition,~~decreases ~~the~~in ~~Company~~LOE ~~must~~were ~~continue~~partially tooffset ~~meet~~by the ~~listing~~addition ~~criteria, including maintaining stockholders' equity~~ of at$88 ~~least~~thousand ~~$2.5~~in ~~million.~~expenses Iffor the ~~Company~~Bonnie ~~continues~~View toField, ~~have~~which ~~net~~was ~~losses,~~purchased itin ~~will~~June ~~need~~2015. toThe ~~sell~~overall ~~equity~~decrease in ~~order~~oil toand ~~continue~~gas tooperating ~~meet~~expenses ~~this~~also ~~requirement.~~included ~~The~~a ~~notification~~decrease ~~letter~~of ~~has~~$45 nothousand ~~immediate~~in ~~effect~~severance ontaxes ~~Glori’s~~due ~~listing~~to orsustained ~~trading~~lower ofoil ~~common~~prices ~~stock,~~and ~~does~~revenues. ~~not~~Ad ~~affect~~valorem ~~the~~tax ~~Company’s~~expense ~~business~~increased ~~operations~~$38 orthousand ~~its~~due ~~SEC~~to ~~reporting~~an ~~requirements~~adjustment ~~and~~to ~~does~~the ~~not~~annualized ~~cause~~estimate aof ~~default~~the ~~under~~2015 ~~any~~period ~~material~~tax ~~agreement~~assessment.

~~The~~Service ~~Company~~operations. ~~will~~Service ~~continue~~operations toexpense ~~execute~~decreased ~~its~~by ~~business~~$321 ~~strategy and~~thousand, ifor ~~necessary~~60%, ~~will~~from ~~consider~~$534 ~~implementing~~thousand ~~available~~in ~~options to attempt to regain compliance with~~ the ~~minimum~~second ~~bid~~quarter ~~price requirement~~ of ~~NASDAQ~~2015 ~~Listing~~to ~~Rule~~$213 ~~5810(c)(3)(A),~~thousand ~~including~~in athe ~~reverse~~second ~~stock~~quarter ~~split~~2016. ~~and~~Approximately to$107 ~~continue~~thousand toof ~~maintain~~the ~~its~~decrease ~~stockholders'~~is ~~equity~~attributable ~~requirement.~~to Ifreduced ~~our~~project ~~common~~costs ~~stock~~related isto ~~delisted,~~a itdomestic ~~would~~field ~~likely~~project ~~trade~~which inconcluded ~~the~~during ~~over-the-counter~~July ~~market~~2015. ~~Such~~Compensation ~~NASDAQ~~and ~~delisting~~benefits ordecreased ~~further~~$97 ~~declines~~thousand indue ~~our~~to ~~stock~~decreased ~~price~~headcount. ~~could~~The ~~greatly~~remaining ~~impair~~decrease ~~our~~is ~~ability~~attributable to ~~raise~~reduced ~~additional~~project ~~capital~~costs related to ~~finance~~projects ~~additional~~in ~~capital~~Canada ~~expenditures~~ and ~~could~~Brazil, ~~significantly~~which ~~increase~~concluded ~~the~~during ~~ownership~~July ~~dilution~~2015 toand ~~shareholders~~first ~~caused~~quarter by2016, ~~our issuing equity in financing or other transactions~~respectively.

~~Contingent~~Science onand ~~our~~technology. ~~ability~~Science toand ~~obtain~~technology ~~financing,~~expenses wedecreased ~~intend~~by to$320 ~~pursue~~thousand, ~~additional~~or ~~acquisitions~~51%, offrom ~~oil~~$629 ~~assets~~thousand in ~~which~~the tothree ~~deploy~~months ~~the~~ended ~~AERO~~June ~~System.~~30, ~~Planned~~2015 ~~capital~~to ~~expenditures~~$309 ~~for~~thousand in the ~~next~~three ~~twelve~~ months ~~consist~~ended ofJune ~~approximately~~30, ~~$200~~2016 ~~thousand~~mostly due to a decrease of $~~500~~162 thousand ~~for~~in ~~existing~~compensation ~~field~~and ~~operations. We~~benefits ~~will~~due ~~adjust~~to ~~the~~decreased ~~amount~~headcount and ~~timing~~a decrease of ~~our~~$85 ~~capital~~thousand ~~spending~~related ~~dependent~~to a ~~upon~~core ~~our~~flood ~~cash~~research onproject ~~hand,~~in ~~our~~the ~~cash~~prior ~~flow~~year ~~from~~period. ~~operations~~Supplies and travel expenses decreased $61 thousand due to a decline in the ~~availability~~number of ~~capital.~~Analysis AsPhase ofservices ~~March 31,~~projects ~~2016,~~and wecost ~~did~~reduction ~~not~~efforts. ~~have~~The ~~any~~remaining ~~commitments~~decrease ~~for~~is ~~the~~attributable ~~acquisition~~to ofa ~~oil~~reduction ~~properties~~in orfees ~~any~~for ~~other~~recurring ~~significant~~third ~~capital~~party ~~commitments~~research consulting.

~~The~~Selling, ~~price~~general ofand ~~oil~~administrative ~~fluctuated~~("SG&A"). ~~during~~SG&A ~~the~~expenses ~~first~~decreased ~~quarter~~by of$131 ~~2016~~thousand, ~~and~~or ~~ultimately~~9%, ~~decreased~~from $1%.5 ~~based~~million onin the ~~Cushing~~three months ended June 30, ~~Oklahoma~~2015 -to ~~West~~$1.4 ~~Texas~~million ~~Intermediate~~in ~~spot~~the ~~prices~~three months ended June 30, 2016. The decrease was primarily attributable to a decrease of $~~37.13~~211 ~~per~~thousand ~~barrel~~from oncost ~~January~~cutting 1measures in salaries, ~~2016~~benefits, travel and ~~$36.94~~certain onother ~~March~~back 31office expenses, ~~2016.~~including ~~Subsequent~~a toreduction ~~March~~in ~~2016,~~fees paid to the ~~oil~~Board ~~price~~of ~~rose~~Directors. toIncreases ~~approximately~~in ~~$45~~consulting ~~per~~and ~~barrel~~other asthird ofparty ~~May~~professional 2,fees ~~2016. See~~expenses ~~ITEM~~partially 3offset the overall decrease in SG&A. ~~Quantitative~~SG&A ~~and~~decreased ~~Qualitative~~$457 ~~Disclosures~~thousand, ~~About~~or ~~Market~~30%, ~~Risk~~in ~~for~~the ~~discussion~~second onquarter of 2016 from the ~~potential~~second quarter of 2015, excluding the impact of anseverance ~~oil~~compensation ~~price~~liability ~~decline~~recognized in the three months ended June 30, 2016.

~~Revenues~~Depreciation, depletion and ~~cash~~amortization ~~flows~~("DD&A"). ~~from~~DD&A ~~our~~decreased ~~existing~~from ~~oil~~$1.0 ~~properties~~million ~~represent~~in the ~~majority~~three ofmonths ~~our~~ended ~~cash~~June ~~from~~30, ~~operating~~2015 ~~activities~~to ~~until~~$496 wethousand ~~complete~~in ~~other~~the ~~acquisitions~~three ofmonths ~~oil~~ended ~~producing~~June ~~assets~~30, ~~or experience significant growth in our services revenues~~2016. ~~Operating~~The ~~cash~~overall ~~flow~~decrease ~~from~~was ~~our~~due ~~existing~~to ~~oil~~a ~~properties,~~decrease ~~after~~in ~~direct~~depletion ~~operating~~expense ~~expenses~~of ~~and~~$527 thousand related ~~overhead costs, are principally dedicated~~ to ~~servicing~~ the ~~$10.3~~December ~~million~~2015 ~~term~~impairment ~~note.~~of Wethe ~~currently~~Coke ~~have~~and ~~hedges~~Bonnie inView ~~place~~Fields ~~totaling~~as ~~6,550~~a ~~barrels~~result ~~per~~of ~~month~~the atoil ~~$82~~price decline.46 ~~per~~Depletion ~~barrel~~expense for the ~~remainder~~second quarter of 2016. ~~While~~was wecalculated ~~have~~based ~~entered~~on ~~into~~lower ~~hedges~~asset ~~for~~values aas ~~portion~~compared ofto ~~our~~the ~~oil~~second ~~production~~quarter ~~during~~of ~~2016,~~2015 ~~revenues~~as ~~and~~a ~~cash~~result ~~flows~~of ~~from~~impairment ~~our~~during ~~oil~~the ~~properties~~fourth ~~and~~quarter ~~AERO~~of ~~services~~2015, ~~have~~and ~~been~~on ~~adversely~~lower ~~affected~~production byas ~~the depressed oil prices. As~~ a ~~small~~result ~~company~~of ~~with~~shutting anin ~~emerging~~or ~~technology~~reducing weflow ~~have~~rates ~~not~~for ~~historically~~certain ~~generated~~uneconomic ~~positive cash flows, and we do not currently generate positive cash flows from operations~~wells.

~~The~~Total ~~rapid~~other ~~drop~~expense, net. Total other expense, net, decreased $673 thousand from an expense of $1.5 million in ~~oil~~the ~~prices~~three ~~has~~months ~~made~~ended itJune ~~difficult~~30, 2015 to ~~execute~~an onexpense ~~our~~of ~~strategy~~$827 ofthousand ~~acquiring~~in ~~producing~~the ~~properties~~three months ended June 30, 2016. Our commodity derivatives, which ~~would~~include ~~contribute~~price toswaps ~~our~~that ~~revenues~~were entered into in connection with the acquisition of the Coke Field in March 2014 and ~~cash~~2017 ~~flows~~costless ~~due~~collars tothat ~~potential~~were ~~sellers’~~entered ~~reluctance~~into in June 2016, resulted in a net loss of $437 thousand in the three months ended June 30, 2016 compared to ~~sell~~a atnet ~~depressed~~loss ~~prices~~of $980 thousand in the prior year period. ~~Additionally~~In the 2016 period, the ~~current~~derivative ~~oil~~loss ~~price~~consisted ~~environment~~of ~~has~~a ~~negatively~~$1.2 ~~affected~~million unrealized loss on the ~~availability~~change in fair value of ~~capital~~future settlements due to ~~Glori~~an ~~and~~increase in NYMEX oil futures prices from the ~~E&P~~beginning ~~industry~~to inthe ~~general~~end of the quarter, ~~and~~which ~~has~~was ~~also~~partially ~~resulted~~offset inby a ~~dramatic~~$724 ~~decrease~~thousand inrealized ~~our~~gain ~~stock~~on price swap settlements. In the 2015 period, the commodity derivative loss consisted of a $1.6 million unrealized loss on the change in fair value of future settlements, which was partially offset by a $625 thousand realized gain on price swap settlements. Interest expense also ~~impacts~~decreased ~~our~~$138 ~~ability~~thousand compared to ~~raise~~the ~~new~~second ~~equity~~quarter ~~capital~~of 2015 due to the repayment of debt.

WeSix ~~have~~Months ~~made~~Ended ~~significant~~June ~~cost reductions~~30, ~~both in our administrative and professional staff, and our lease operating expenses. The cost reductions were implemented both in~~ 2015 and ~~in the first quarter of~~ 2016~~. We have also limited our capital expenditures to those required to fully implement our AERO technology at our Coke field.~~

WeOil ~~believe~~and ~~demonstrated~~gas ~~AERO~~revenues. Oil ~~technology~~and ~~results~~gas ~~at the Coke field will enhance~~ revenues decreased by $1.9 ~~and~~million from $4.1 ~~cash~~million in ~~flows~~the six ~~and~~months ~~will~~ended ~~improve~~June ~~our~~30, ~~ability~~ 2015 to $2.2 ~~raise~~million in ~~additional~~the six ~~capital.~~months Inended ~~August~~June ~~2015~~30, we2016. ~~implemented~~The ~~the~~decrease ~~first~~was ~~phase~~attributable ofto ~~AERO~~a at32% ~~the~~decrease ~~Coke~~in ~~field.~~average Inoil ~~March~~prices ~~2016~~received weand ~~completed~~a ~~installation~~21% ofdecrease ~~phase~~in IIoil ofproduction ~~our AERO implementation~~sold. ~~Phase~~Production IIdecreased ~~incorporates~~due ~~the~~to ~~addition~~a ofcost ~~two~~reduction ~~AERO~~plan ~~injection~~to ~~wells~~improve tofield ~~increase~~profitability at the ~~proportion~~Coke ofField ~~the~~shutting ~~field~~in ~~that~~certain isuneconomic ~~impacted~~wells byand ~~AERO~~due ~~technology.~~to ~~Glori~~the ~~now~~July ~~has~~1, ~~three~~2015 ~~injection~~sale ~~wells~~of ~~running~~the inEtzold ~~total~~Field. ~~Phase~~The IIdecrease ~~implementation~~in ~~commenced~~production ~~after~~from ~~data~~the ~~from~~Coke ~~phase~~and IEtzold ~~limited~~Fields ~~trial~~was ~~demonstrated~~partially ~~encouraging~~offset ~~indication~~by the purchase of ~~AERO~~the ~~performance.~~Bonnie ~~The~~View ~~wells~~Field ~~are~~which ~~located~~closed on ~~the~~June ~~periphery~~1, of2015 ~~the~~and ~~Coke~~resulted ~~field~~in ~~and~~the ~~are~~inclusion ~~designed~~of toan ~~stimulate~~additional ~~production~~6,980 ~~from~~barrels ~~more~~ of ~~the~~oil ~~field~~sold ~~than~~in ~~was impacted by~~ the ~~first~~2016 ~~injector~~period.

Table of Contents

~~Finally,~~Service werevenues. Service ~~applied~~revenues decreased by $817 tothousand, ~~the~~or 77%, ~~United~~from $1.1 ~~States~~million in ~~Department~~the six ofmonths ~~Energy’s~~ended ~~Loan~~June ~~Programs~~30, ~~Office~~2015 to $246 ~~(“LPO”)~~thousand in ~~for~~the six amonths ~~$150MM~~ended ~~loan~~June ~~guarantee~~30, 2016. The decrease in ~~connection~~revenues ~~with~~was ~~projects~~primarily ~~applying~~attributable ~~AERO~~ to ~~previously~~a ~~abandoned~~decrease ~~reservoirs~~of in$808 ~~the~~thousand U.in S.Field ~~Based~~Deployment onPhase ~~LPO’s~~services ~~evaluation~~due ofto ~~Part~~one Iproject ofwhich ~~our~~concluded ~~application,~~ in ~~March~~February ~~2016~~2015, ~~LPO~~two ~~invited~~projects ~~Glori~~which toconcluded ~~submit~~in ~~Part~~July II2015, ofand ~~its~~one ~~application.~~project Wewhich ~~are~~concluded ~~currently~~ in the ~~process~~first ofquarter ~~submitting~~2016. ~~the~~Analysis ~~Part~~Phase IIrevenues ~~portion~~decreased of$8 ~~its~~thousand ~~application,~~from ~~however, we cannot predict~~ the ~~ultimate~~prior ~~outcome~~year ofperiod. ~~our~~Service ~~application~~revenues ~~and~~have ~~whether~~continued ato ~~loan guarantee will~~ be ~~issued.~~adversely Itimpacted isby ~~currently anticipated that~~ the ~~loan~~decrease ~~guarantee,~~in ifoil ~~issued,~~prices ~~will~~which ~~fund~~resulted upin tosignificant ~~80%~~decreases ofin ~~project~~spending ~~costs~~by ~~with~~our ~~the~~exploration ~~balance~~and toproduction becustomers ~~raised~~ and ~~contributed by Glori~~prospects.

WeOil ~~will~~and ~~need~~gas tooperations. Oil ~~raise~~and ~~financing~~gas ~~over~~operating expense decreased by $1.8 million, or 36%, from $4.9 million in the six ~~next~~months ~~twelve~~ended June 30, 2015 to $3.1 million in the six months ended June 30, 2016. Overhead expenses decreased by $585 thousand due to ~~fund~~decreases ~~our~~in ~~operations~~third party consulting fees and toa ~~repay~~reduction orin ~~refinance~~compensation ~~the~~and ~~term~~benefits ~~note~~as ~~issued~~a result of decreased headcount. LOE decreased by ~~GEP~~a ofnet $101.30 million ~~which~~primarily ~~matures~~due to a $1.2 million, or 41%, decrease in ~~March~~Coke ~~2017~~Field expenses due to cost reduction efforts. WeLOE ~~have~~also ~~taken~~decreased ~~steps~~by ~~which,~~$155 ifthousand ~~successful,~~due weto ~~believe~~the ~~will~~sale ~~facilitate~~of ~~raising~~the ~~additional~~Etzold ~~financing.~~Field ~~However,~~in weJuly ~~may~~2015. ~~have~~These ~~difficulty~~decreases ~~obtaining~~in ~~such~~LOE ~~financing~~were aspartially aoffset ~~result~~by the addition of ~~the~~$293 ~~decrease~~thousand in ~~oil~~expenses ~~prices~~for the Bonnie View Field, ~~our~~which ~~negative~~was ~~cash~~purchased ~~flows~~in ~~from~~June ~~operations~~2015. The overall decrease in oil and ~~the~~gas ~~significant~~operating expenses also included a decrease inof ~~our~~$91 ~~share~~thousand ~~price.~~in ~~Failure~~severance taxes due to ~~obtain~~sustained ~~additional~~lower ~~financing~~oil ~~would~~prices ~~have~~and revenues and a ~~material~~decrease ~~adverse~~of ~~effect~~$52 onthousand ~~our~~in ~~business~~ad ~~operations~~valorem ~~and~~tax ~~financial~~expense ~~condition~~due to a revised tax assessment.

OnService ~~March~~operations. Service ~~18,~~operations ~~2016,~~expense ~~GEP~~decreased ~~entered~~by $569 ~~into an amendment (the “Amendment”) to the note purchase agreement dated as of March 14~~thousand, ~~2014 between GEP and Stellus Capital Investment Corporation~~or 54%, asfrom $1.1 ~~administrative agent (as amended and~~ million in ~~effect,~~ the six ~~“NPA”),~~months ~~governing~~ended ~~GEP’s~~June ~~senior secured first lien notes due March 2017 (the “Notes”). Among other things~~30, ~~the~~2015 to $486 ~~Amendment removed all financial covenants and collateral value redetermination requirements contained~~ thousand in the six ~~NPA.~~months Inended ~~connection~~June ~~with the Amendment~~30, ~~effective as of April 1,~~ 2016,. ~~the~~Approximately ~~interest~~$244 ~~rate~~thousand ~~payable~~of on the ~~Notes~~decrease ~~will~~is ~~increase~~attributable byto ~~200~~reduced ~~bps~~project tocosts ~~13.0%~~such ~~per~~as ~~annum,~~trucking ~~with~~and ~~the~~nutrient ~~increase~~solution related to betwo ~~“paid~~domestic infield ~~kind”~~projects, atwhich ~~GEP’s~~concluded ~~election,~~during byFebruary ~~increasing~~and ~~the~~July ~~outstanding principal amount of the Notes~~2015, and ~~principal~~$101 ~~and~~thousand ~~interest~~of ~~payments~~the ~~will~~decrease beresulted ~~payable monthly rather than quarterly. GEP also agreed to receive additional funds~~ from the ~~Company~~conclusion toof ~~meet~~a ~~its~~Canadian ~~payment~~field ~~obligations,~~project ifin ~~necessary,~~July ~~including~~2015. ~~monthly~~Compensation ~~principal~~ and ~~interest~~benefits ~~payments~~decreased on$169 ~~the~~thousand ~~Notes,~~due ~~but~~to ~~not~~a ~~the~~decrease ~~unpaid~~in ~~balance~~service ofoperations ~~the~~headcount ~~Notes~~resulting onfrom the ~~final~~decreased ~~maturity~~number ~~date~~of ~~thereof or upon any acceleration thereof~~projects. ~~Without~~The ~~this~~remaining ~~amendment~~decrease weis ~~likely~~attributable ~~would~~to ~~not~~the ~~have~~conclusion ~~been~~of ~~able~~a toproject ~~meet~~in ~~all~~Brazil ofduring ~~our~~the ~~financial~~six ~~covenants~~months inended ~~the~~June ~~future~~30, 2016.

~~The~~Science ~~following~~and ~~table~~technology. ~~sets~~Science ~~forth~~and technology expenses decreased by $460 thousand, or 42%, from $1.1 million in the ~~major~~six ~~sources~~months ended June 30, 2015 to $643 thousand in the six months ended June 30, 2016 mostly due to a decrease of $245 thousand in compensation and ~~uses~~benefits due to decreased headcount and a decrease of ~~cash~~$85 ~~for~~thousand related to a core flood research project in the ~~periods~~prior ~~presented~~year (period. Supplies and travel expenses decreased $104 thousand due to a decline in ~~thousands):~~the number of Analysis Phase services projects and cost reduction efforts. The remaining decrease is attributable to a reduction in fees for recurring third party research consulting.

	Three Months Ended March 31,
	2015			2016
Net cash used in operating activities	$	(3,928	)	$	(2,035	)
Net cash used in investing activities	$	(424	)	$	(979	)
Net cash used in financing activities	$	(1,924	)	$	(321	)

Selling, general and administrative ("SG&A"). SG&A expenses decreased by $431 thousand, or 13%, from $3.3 million in the six months ended June 30, 2015 to $2.8 million in the six months ended June 30, 2016. The decrease was primarily attributable to a decrease of $699 thousand from cost cutting measures in salaries, benefits, travel and certain other back office expenses, including a reduction in fees paid to the Board of Directors. Increases in consulting and other third party professional fees expenses partially offset the overall decrease in SG&A. SG&A decreased $757 thousand, or 23%, in the six months ended June 30, 2016 from the six months ended June 30, 2015, excluding the impact of severance compensation liability, recognized in June 2016.

Depreciation, depletion and amortization ("DD&A"). DD&A decreased from $2.1 million in the six months ended June 30, 2015 to $1.0 million in the six months ended June 30, 2016. The overall decrease was due to a decrease in depletion expense of $1.1 million related to the December 2015 impairment of the Coke and Bonnie View fields as a result of the oil price decline. Depletion expense for the 2016 period was calculated based on lower asset values as compared to the 2015 period as a result of impairment during the fourth quarter of 2015, and on lower production as a result of shutting in or reducing flow rates for certain uneconomic wells.

Total other expense, net. Total other expense, net, increased $143 thousand from an expense of $861 thousand in the six months ended June 30, 2015 to an expense of $1.0 million in the six months ended June 30, 2016. Our commodity derivatives, which include price swaps that were entered into in connection with the acquisition of the Coke Field in March 2014 and 2017 costless collars that were entered into in June 2016, resulted in a net loss of $282 thousand in the six months ended June 30, 2016 compared to a net gain of $389 thousand in the prior year period. In the 2016 period, the derivative loss consisted of a $2.2 million unrealized loss on the change in fair value of future settlements due to an increase in NYMEX oil futures prices from the beginning to the end of the quarter, which was partially offset by a $1.9 million realized gain on price swap settlements. In the 2015 period, the derivative gain consisted of a $1.8 million realized gain on price swap settlements, which was partially offset by a $1.4 million unrealized loss on the change in fair value of future settlements. Interest expense decreased $510 thousand compared to the second quarter of 2015 due to the repayment of debt, including debt used to partially fund the Coke Field acquisition and the $8.0 million secured term promissory note which was prepaid in March 2015.

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Liquidity and Capital Resources

The significant risks, uncertainties, significant working capital deficit, historical operating losses and resulting cash used in operations discussed in Item 1. Condensed Notes to the Consolidated Financial Statements, NOTE 3 - Liquidity Considerations and Ability to Continue as a Going Concern raise substantial doubt about the Company's ability to continue as a going concern. The consolidated financial statements have been prepared on the going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments, in the normal course of business. The consolidated financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. The Company cannot offer any assurance that it will be successful in executing the plans described herein to continue as a going concern.

As of August 10, 2016, the Company does not have any lines of credit available to it. At June 30, 2016, we had a working capital deficit of $6.4 million, made up of current assets of $5.5 million and current liabilities of $11.9 million. The current asset balance is comprised of cash and cash equivalents of $3.1 million, accounts receivable of $792 thousand, commodity derivative contracts receivable of $1.2 million, and prepaid expenses and other current assets of $297 thousand. Included in current liabilities is $644 thousand in accounts payable, $1.2 million in accrued expenses, including $215 thousand in short-term asset retirement obligations, and $10.2 million in current portion of long-term debt, which is presented on the June 30, 2016 condensed consolidated balance sheet net of debt issuance costs of $156 thousand.

Contingent on our ability to obtain financing, we intend to acquire and redevelop previously abandoned fields and capture significant economic quantities of oil which have been left behind by the industry. We target fields which may have no current production but have excellent reservoir qualities and are compatible with our AERO technology. Since these inactive fields may not have produced oil for many years, they can be leased at favorable prices, when compared to producing assets. Planned capital expenditures for the next twelve months consist of approximately $100 thousand for existing field operations, and depending on the availability of capital, up to approximately $1.2 million for leasing acreage in specific abandoned oil fields we have targeted. We will adjust the amount and timing of our capital spending dependent upon our cash on hand, our cash flow from operations, and the availability of capital. As of June 30, 2016, we did not have any commitments for the acquisition of oil properties or any other significant capital commitments.

The price of oil increased 37% during the second quarter of 2016 based on the Cushing, Oklahoma - West Texas Intermediate spot prices of $35.36 per barrel on April 1, 2016 and $48.27 on June 30, 2016. Subsequent to June 2016, the oil price fell to $42.40 per barrel as of July 25, 2016. A sustained lower oil price through September 2016 will negatively impact third quarter oil revenues and profitability from our oil producing assets, which will be partially offset by other income realized from oil price swap settlements. Using an assumed average oil price of $40 per barrel, and assuming second quarter production volumes, oil and gas revenues would have decreased from $1.2 to $1.1 million, and the realized gain on monthly oil price swap settlements would have increased from $724 thousand in the second quarter to $834 thousand in the third quarter of 2016. See ITEM 3. Quantitative and Qualitative Disclosures About Market Risk for discussion on the potential impact of an oil price decline.

Revenues and cash flows from our existing oil properties represent the principal source of our cash from operating activities. Operating cash flow from our existing oil properties, after direct operating expenses and related overhead costs, are principally dedicated to servicing the $10.2 million term note. We currently have oil price swaps in place totaling 6,550 barrels per month at $82.46 per barrel for the remainder of 2016. In the three and six months periods ended June 30, 2016, we realized cash gains of $724 thousand and $1.9 million from our oil price swaps, respectively. Since our oil price swaps expire in December 2016, we will not realize cash gains from them after December 2016. However, we placed costless oil collars for the first six months of 2017 with a floor of $42.50 per barrel and a ceiling of $55.60 per barrel for 100 barrels of oil per day. While we have entered into swaps for a portion of our oil production during 2016 and collars for a portion of our oil production in the first half of 2017, revenues and cash flows from our oil properties and AERO services have been adversely affected by the depressed oil prices. As a small company with an emerging technology we have not historically generated positive cash flows, and we do not currently generate positive cash flows from operations.

The rapid drop in oil prices has made it difficult to execute on our strategy of acquiring producing properties which would contribute to our revenues and cash flows due to potential sellers’ reluctance to sell at depressed prices. Additionally, the current oil price environment has negatively affected the availability of capital to Glori and the E&P industry in general, and has also resulted in a dramatic decrease in our stock price, which also impacts our ability to raise new equity capital.

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We have made significant cost reductions, both in our administrative and professional staff, and our lease operating expenses. The cost reductions were implemented both in 2015 and in the first quarter of 2016.

In August 2015, we implemented the first phase of AERO at the Coke field. In March 2016 we completed installation of phase II of our 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. Glori 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.

We will need to raise financing over the next six to nine months to fund our operations and to repay or refinance the term note issued by GEP of $10.2 million which matures in March 2017, and to enable us to take advantage of identified opportunities to acquire abandoned oil fields which have a substantial amount of remaining oil in place. We have taken steps which, if successful, we believe will facilitate raising additional financing. However, we may have difficulty obtaining such financing as a result of the decrease in oil prices, our negative cash flows from operations and the significant decrease in our share price.

The following table sets forth the major sources and uses of cash for the periods presented (in thousands):



	Six Months Ended June 30,
	2015			2016
Net cash used in operating activities	$	(5,834	)	$	(3,264	)
Net cash used in investing activities	$	(4,715	)	$	(1,388	)
Net cash used in financing activities	$	(2,126	)	$	(584	)

Operating Activities

During the ~~three~~six months ended ~~March~~June 3130, 2016, our operating activities used $23.03 million in cash. Our net loss for the ~~three~~six months ended ~~March~~June 3130, 2016 was $36.46 million. Non-cash items totaled an expense of $13.87 million, consisting of $~~506~~1.0 ~~thousand~~million of depreciation, depletion and amortization, $12.02 million for an unrealized loss on the change in fair value of commodity derivatives, $~~233~~273 thousand for stock based compensation expense, ~~and~~ $56110 thousand for amortization of deferred loan costs, and $118 thousand for other non-cash expenses. Changes in operating assets and liabilities reduced net cash by $~~436~~287 thousand for the period. The cash decrease from changes in operating assets and liabilities was caused by a decrease in accounts payable of $~~441~~786 thousand, and a decrease in accrued expenses of $~~445~~116 thousand~~, and an increase in prepaid expenses and other current assets of $71 thousand~~. These uses of cash were partially offset by a decrease in accounts receivable of $~~521~~598 thousand and a decrease in prepaid expenses and other current assets of $17 thousand. The decrease in accounts payable and accrued expenses ~~was~~were due to ad valorem taxes payable which are paid out during the first quarter, invoices related to AERO phase II ~~which was concluded in early March,~~ and a reduction in accrued interest as we had three months of accrued interest for our long-term debt as of December 31, 2015 and only one month as of ~~March~~June 3130, 2016.

During the ~~three~~six months ended ~~March~~June 3130, 2015, our operating activities used $35.98 million in cash. Our net loss for the ~~three~~six months ended ~~March~~June 3130, 2015 was $37.09 million. Non-cash items totaled to an expense of $14.56 million, consisting of $12.1 million of depreciation, depletion and amortization, $~~432~~1.4 million for an unrealized loss on commodity swaps, $838 thousand for stock based compensation expense, $~~139~~194 thousand for amortization of deferred loan costs and other non-cash expenses totaling $104 thousand. ~~These non-cash expenses were partially offset by a $223 thousand gain on the change in fair value of the commodity price swap.~~ Changes in operating assets and liabilities reduced net cash by $2.56 million for the period. The cash decrease from changes in operating assets and liabilities was caused by a decrease in accounts payable of $1.74 million, a decrease in ~~accrued~~deferred ~~expenses~~revenues of $~~457~~620 thousand, ~~an increase in prepaid expenses~~ and ~~other current assets of $133 thousand and~~ a decrease in ~~deferred~~accrued ~~revenue~~expenses of $~~308~~587 thousand. These uses of cash were partially offset by a decrease in accounts receivable of $92186 thousand. The decrease in accounts payable and accrued expenses was due to the timing of payments for obligations which we recognized during our annual close, and the decrease in deferred revenue is due to recognition of previously unearned revenues which was triggered as certain services projects progressed ~~into~~through the Field Deployment Phase.

Our future cash flow from operations will depend on many factors including our ability to acquire oil fields, successfully deploy our AERO System technology on such oil fields, oil prices and our ability to reduce our expenses. Other variables affecting our cash flow from operations are the adoption rate of our technology and the demand for our services, which is also impacted by the level of oil prices and the capital expenditure budgets of our customers and potential customers.

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Investing Activities

Our capital expenditures were $~~979~~1.4 ~~thousand~~million for the ~~three~~six months ended ~~March~~June 3130, 2016 compared to $~~424~~4.7 ~~thousand~~million for the ~~three~~six months ended ~~March~~June 3130, 2015. For the ~~three~~six months ended ~~March~~June 3130, 2016, a majority of the capital expenditures were associated with implementing phase II of our AERO System technology at the Coke Field, including the drilling of a water source well and the re-entry of two plugged wells for the injection of AERO nutrients. ~~phase~~Phase II commenced during March 2016 with the injection of nutrients into two wells. AAdditional ~~majority~~expenditures ofwere made during the ~~capital~~2016 ~~expenditures~~period for ~~the~~unproved ~~three~~property leasing efforts. For the six months ended ~~March~~June 3130, 2015, ~~were~~capital ~~related~~expenditures toof ~~efforts~~$2.6 ~~directly~~million ~~associated~~were ~~with~~due ~~unitizing~~to the ~~Coke~~June ~~Field Assets~~1, ~~including~~2015 ~~the~~ purchase of ~~adjacent~~the ~~leases~~Bonnie toView beField. ~~included~~A inmajority of the ~~unit,~~remainder asof wethe ~~prepared~~capital toexpenditures ~~deploy~~were ~~phase~~efforts Iassociated ofwith implementing our AERO System technology. ~~Phase~~at Ithe ~~commenced~~Coke ~~during~~Field, ~~the~~including ~~third~~unitization, ~~quarter~~drilling of ~~2015~~a ~~with~~water ~~the~~source ~~injection~~well ofand ~~nutrients~~an ~~into~~injection ~~one~~ well. Additional expenditures were made for other unproved property leasing efforts in East Texas.

Financing Activities

During the ~~three~~six months ended ~~March~~June 3130, 2016, cash used by financing activities was $~~321~~584 thousand consisting of $~~196~~316 thousand in principal payments on long-term debt, $85228 thousand in deferred charges related to our loan guarantee application to the United States Department of Energy’s LPO, and $40 thousand in annual administrative fees related to our senior secured term loan.

During the ~~three~~six months ended ~~March~~June 3130, 2015, cash used by financing activities was $12.91 million consisting of $2.12 million in payments on long-term debt and $40 thousand in payments for deferred loan costs. ~~This~~These cash ~~outflow~~outflows ~~was~~were partially offset by proceeds of $130 thousand from stock option exercises. Payments on long-term debt included $888 thousand for the prepayment of the remaining principal balance on an $8.0 million secured term promissory note originated in 2012.

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Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements, except for operating lease obligations presented in the table below.

Contractual Obligations and Commercial Commitments

At ~~March~~June 3130, 2016, we had contractual obligations and commercial commitments as follows (in thousands):

	Payments Due By Period
ContractualObligations	Total		LessThan 1Year		1-3 Years		3-5 Years		More Than5 Years
Operating lease obligations(1)	$	~~261~~165	$	~~240~~165	$	21—	$	—	$	—
Asset retirement obligation(2)	1,~~565~~618		67215		~~242~~113		~~672~~685		~~584~~605
Long-term debt(3)	11,~~702~~066		11,~~657~~025		20		20		51
Total	$	1312,~~528~~849	$	11,~~964~~405	$	~~283~~133	$	~~692~~705	$	~~589~~606


(1)	Our commitments for operating leases primarily relate to the leases of office and warehouse facilities in Houston, Texas and warehouse facilities in Gull Lake, Saskatchewan.

(2) Relates to our oil properties, net of accretion. Current asset retirement obligations included in Accrued expenses on the June 30, 2016 condensed consolidated balance sheet.


(3)	Includes expected future interest payments.

Recently Issued 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 two 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 conditions 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. 28

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Inthose ~~April~~goods ~~2015,~~or ~~the FASB issued ASU No~~services. ~~2015-03, "Interest—Imputation~~ ofThe ~~Interest:~~standard ~~Simplifying~~creates ~~the~~a ~~Presentation of Debt Issuance Costs" (ASU 2015~~five-~~03).~~step ~~ASU~~model ~~2015-03~~that isrequires ~~effective for~~companies ~~fiscal~~to ~~years,~~exercise ~~and~~judgment ~~for~~when ~~interim~~considering ~~periods~~the ~~within~~terms ~~those~~of ~~fiscal~~a ~~years,~~contract ~~beginning~~and ~~after~~all ~~December~~relevant ~~15,~~facts ~~2015~~ and ~~early adoption is permitted~~circumstances. ~~Prior~~The ~~GAAP~~standard ~~guidance~~allows ~~mandates~~for ~~recognizing~~two ~~debt~~transition ~~issuance~~methods: ~~costs~~(a) as a ~~deferred~~full ~~charge.~~retrospective ~~Such~~adoption ~~treatment is different from the guidance~~ in ~~International Financial Reporting Standards (IFRS),~~ which ~~requires~~the ~~that~~standard ~~transaction~~is ~~costs~~applied beto ~~deducted~~all ~~from the carrying value~~ of the ~~financial~~periods ~~liability and not recorded as separate assets. Additionally~~presented, ~~the~~or ~~requirement~~(b) toa ~~recognize~~modified ~~debt~~retrospective ~~issuance~~adoption ~~costs as deferred charges conflicts with the guidance~~ in ~~FASB Concepts Statement No. 6, Elements of Financial Statements,~~ which ~~states~~the ~~that~~standard ~~debt~~is ~~issuance~~applied ~~costs~~only ~~are~~to ~~similar~~the tomost ~~debt~~current ~~discounts~~period ~~and~~presented in ~~effect reduce~~ the ~~proceeds~~financial ~~of borrowing~~statements, ~~thereby~~including ~~increasing~~additional ~~the~~disclosures ~~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~~standard’s inapplication ~~this~~impact ~~Update~~to ~~require~~individual ~~that~~financial ~~debt~~statement ~~issuance~~line ~~costs~~items. This ~~related~~standard tois aeffective ~~recognized~~for ~~debt~~annual ~~liability~~reporting beperiods ~~presented~~beginning inafter ~~the~~December ~~balance~~15, ~~sheet~~2017, asincluding ainterim ~~direct~~periods ~~deduction~~within ~~from the carrying amount of~~ that ~~debt~~reporting ~~liability, consistent with debt discounts~~period. ~~The~~We ~~recognition and measurement guidance for debt issuance costs~~ are ~~not~~currently ~~affected~~evaluating ~~by the amendments in~~ this ~~Update. Glori adopted this~~ standard ~~during~~and the ~~first~~impact ~~quarter~~it ofwill ~~2016.~~have ~~See~~on ~~Part~~our I,future ~~Item 1.~~revenue ~~Note~~recognition ~~2 of this report for a discussion of the impact of ASU No~~policies. ~~2015-03.~~

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 conditions 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. Glori adopted this standard during the second quarter of 2016. See Part I, Item 1. Note 3 of this report for a discussion about liquidity considerations and Glori's ability to continue as a going concern.

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. Glori adopted this standard during the first quarter of 2016. See Part I, Item 1. Note 2 of this report for a discussion of the impact of ASU No. 2015-03.

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. During the first quarter of 2016 Glori chose to adopt the standard. Because the Company has applied a 100% valuation allowance to its net deferred tax asset, there are no deferred tax accounts reported in the consolidated balance sheet as of March 31, 2016. This Standard would have otherwise been effective for the Company’s fiscal year beginning January 1, 2017, but Management believes that the revised presentation more realistically reflects the Company’s financial position related to deferred income taxes. As allowed by the Standard, the company has elected to apply the provisions prospectively, and accordingly, has not adjusted deferred tax accounts retrospectively for any earlier periods.

In February 2016, the FASB issued Accounting Standards Update No. 2016-02: Leases (Topic 842). The main objective of ASU 2016-02 is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The main difference between previous GAAP and Topic 842 is the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. ASU 2016-02 requires lessees to recognize assets and liabilities arising from leases on the balance sheet. ASU 2016-02 requires disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. For public entities, ASU 2016-02 is effective for financial statements issued for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years; early application is permitted. We are currently evaluating this standard and the impact it will have on our consolidated financial statements.

In March 2016, the FASB issued Accounting Standards Update (ASU) 2016-09, which seeks to simplify accounting for share-based payment transactions including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The new standard requires the Company to recognize the income tax effects of awards in the income statement when the awards vest or are settled. The guidance is effective for fiscal years beginning after December 15, 2016. Early adoption is permitted and if an entity early adopts the guidance in an interim period, any adjustments must be reflected as of the beginning of the fiscal year that includes that interim period. The Company is currently evaluating the impact of adopting this standard on its consolidated financial statements.29

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approach. For public entities, ASU 2016-02 is effective for financial statements issued for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years; early application is permitted. We are currently evaluating this standard and the impact it will have on our consolidated financial statements.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodities Risk

Our major commodity price risk exposure is to the prices received for our oil production. Our results of operations and operating cash flows are affected by changes in market prices. Realized commodity prices received for our production are the spot prices applicable to oil in the region produced. Prices received for oil, condensate, and natural gas, none of which are for trading purposes, are volatile and unpredictable and are beyond our control, none of which are for trading purposes. To mitigate a portion of the exposure to adverse market changes, we have entered into derivative instruments. For the three months ended ~~March~~June 3130, 2016, a 10% change in the prices received for oil, condensate, and natural gas production would have had an approximate $~~102~~116 thousand impact on our revenues prior to commodity derivatives which partially mitigate our commodity pricing risk. See NOTE 56 in the Notes to the Condensed Consolidated Financial Statements in Part I, Item 1 of this report for additional information regarding our commodity derivative activities.

Interest Rate Risk

Our floating rate loan ~~facilities~~facility ~~expose~~exposes us to interest rate risk. Our ~~two major~~ credit ~~facilities~~facility ~~outstanding~~is ~~are~~ based on interest at a floating ~~rates~~rate that ~~are~~is subject to increase based upon certain increases in the prime rate or LIBOR. Therefore upward fluctuations in interest rates expose us to additional interest payments. As of ~~March~~June 3130, 2016, our ~~total~~credit ~~long-term~~facility ~~debt~~is ~~was~~a $10.32 million current liability which matures in March 2017. An increase of 100 basis points in both the prime and LIBOR interest rate will expose us to a $26,000 quarterly increase in interest.

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Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (“Exchange Act”), as of ~~March~~June 3130, 2016. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that, as of ~~March~~June 3130, 2016, our disclosure controls and procedures were effective in providing reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended ~~March~~June 3130, 2016 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II: OTHER INFORMATION

Item 1. Legal Proceedings

From time to time, we may be subject to legal proceedings and claims that arise in the ordinary course of business. We are not a party to any material litigation or proceedings and not aware of any material litigation or proceedings, pending or threatened against us.

Item 1A. Risk Factors

In addition to the disclosures in this report, see the risk factors discussed in the section "Risk Factors", beginning on page 14, of Item 1A. to our Annual Report on Form 10-K filed March 23, 2016 for discussion of other risk factors. Those risk and uncertainties are not the only ones facing us, and there may be additional matters of which we are unaware or that we currently consider immaterial. All of those risks and uncertainties could adversely affect our business, financial condition, and/or results of operations

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None

Item 3. Defaults Upon Senior Securities

None

Item 4. Mine Safety Disclosures

Not applicable

Item 5. Other Information

None

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ITEM 6. EXHIBITS

EXHIBIT INDEX

Exhibit	Description
3.1	Amended and Restated Certificate of Incorporation of Glori Energy Inc. (incorporated by reference to Exhibit 3.3 of the Company's Form 8-K/A, filed May 2, 2014)
10.1	Separation Agreement by and between Glori Energy Inc. and Stuart Page (incorporated by reference to Exhibit 10.1 of the Company's Form 8-K, filed June 8, 2016)
3.2	Amended and Restated Bylaws of Glori Energy, Inc. (incorporated by reference to Exhibit 3.4 of the Company's Form 8-K, filed April 18, 2014)
10.2	Advisor Agreement by and between Glori Energy Inc. and Stuart Page (incorporated by reference to Exhibit 10.2 of the Company's Form 8-K, filed June 8, 2016)
3.3	Amended and Restated Bylaws of Glori Energy, Inc. (incorporated by reference to Exhibit 3.3 of the Company's Form 10-K, filed March 23, 2016)
10.3	Amendment to Incentive Option Agreement by and between Glori Energy Inc. and Stuart Page (incorporated by reference to Exhibit 10.3 of the Company's Form 8-K, filed June 8, 2016)
10.1	Fourth Amendment to the Note Purchase Agreement made and entered into as of March 18, 2016, between Glori Energy Production Inc., Stellus Capital Investment Corporation and each of the holders signatory thereto (incorporated by reference to Exhibit 10.16 of the Company's Form 10-K, filed March 23, 2016.
31.1*	Certification by Kevin P. Guilbeau, Interim Chief Executive Officer and Executive Co-Chairman of the Board, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.1*	Certification by Stuart Page, Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2*	Certification by Victor M. Perez, Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2*	Certification by Victor Perez, Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1*	Certification by Kevin P. Guilbeau, Interim Chief Executive Officer and Co-Chairman of the Board, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.1*	Certification by Stuart Page, Chief Executive Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2*	Certification by Victor M. Perez, Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2*	Certification by Victor Perez, Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*	XBRL Instance Document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Label Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document



*	Filed herewith

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SIGNATURE

Pursuant to the requirements of the Securities and Exchange Act of 1934, I have duly caused this report to be signed on our behalf by the undersigned thereunto duly authorized.

~~May~~August 1311, 2016 Date



		Glori Energy Inc.
		Registrant

By:		/s/ Victor M. Perez
		Victor M. Perez Chief Financial Officer (Principal Financial Officer)

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