HOUSTON AMERICAN ENERGY CORP - Quarter Report: 2016 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark One)

For the quarterly period ended June 30, 2016

OR

For the transition period from ___________ to ______________.

Commission File Number 1-32955

HOUSTON AMERICAN ENERGY CORP.

(Exact name of registrant as specified in its charter)

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. Yes [X] 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). Yes [X] 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 definition 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 12b-2 of the Exchange Act). Yes [  ] No [X]

As of August 9, 2016, we had 51,499,336 shares of $0.001 par value Common Stock outstanding.

HOUSTON AMERICAN ENERGY CORP.

FORM 10-Q

INDEX

PART I - FINANCIAL INFORMATION

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

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

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2016 AND 2015

(Unaudited)

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

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE SIX MONTHS ENDED JUNE 30, 2016 AND 2015

(Unaudited)

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

HOUSTON AMERICAN ENERGY CORP.

Notes to Consolidated Financial Statements

(Unaudited)

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

The accompanying unaudited consolidated financial statements of Houston American Energy Corp., a Delaware corporation (the “Company”), have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q. They do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America for a complete financial presentation. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair presentation, have been included in the accompanying unaudited consolidated financial statements. Operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year.

These unaudited consolidated financial statements should be read in conjunction with the Company’s audited consolidated financial statements and footnotes, which are included as part of the Company’s Form 10-K for the year ended December 31, 2015.

Going Concern

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business for the twelve-month period following the date of these consolidated financial statements. The Company has incurred continuing losses, negative operating cash flow and declining cash balances since 2011, including negative operating cash flow of $713,669 for the six months ended June 30, 2016. These conditions, together with continued low oil and natural gas prices and financial commitments the Company has made relative to its Colombian properties, raise substantial doubt as to the Company’s ability to continue as a going concern. These financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

To address these concerns, the Company may seek additional financing or may consider divestiture of certain assets. There can be no assurance that the Company will be successful in its efforts.

Consolidation

The accompanying consolidated financial statements include all accounts of the Company and its subsidiaries (HAEC Louisiana E&P, Inc., HAEC Oklahoma E&P, Inc. and HAEC Caddo Lake E&P, Inc.). All significant inter-company balances and transactions have been eliminated in consolidation.

Accounting Principles and Use of Estimates

The consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews its estimates, including those related to such potential matters as litigation, environmental liabilities, income taxes and the related valuation allowance, determination of proved reserves of oil and gas and asset retirement obligations. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.

Concentration of Credit Risk

Financial instruments that potentially subject the Company to a concentration of credit risk include cash, cash equivalents and any marketable securities. The Company had cash deposits of $944,001 in excess of the FDIC’s current insured limit on interest bearing accounts of $250,000 as of June 30, 2016. The Company has not experienced any losses on its deposits of cash and cash equivalents.

Loss per Share

Basic loss per share is computed by dividing net loss available to common shareholders by the weighted average common shares outstanding for the period. Diluted earnings per share reflects the potential dilution that could occur if securities or other contracts to issue common shares were exercised or converted into common shares that then shared in the earnings of the Company. The Company’s only outstanding potentially dilutive securities are options and warrants. Using the treasury stock method, outstanding ‘in-the-money’ options would have increased our diluted weighted average shares outstanding by approximately 55,600 and 55,600 shares, respectively, for the three and six months ended June 30, 2016 and by approximately 55,600 and 55,600 shares, respectively, for the three and six months ended June 30, 2015; however, due to losses during these periods, these options were excluded from the diluted earnings per share calculation because their effect would have been anti-dilutive.

Subsequent Events

The Company has evaluated all transactions from June 30, 2016 through the financial statement issuance date for subsequent event disclosure consideration.

Recent Accounting Pronouncements

No accounting standards or interpretations issued recently are expected to a have a material impact on our consolidated financial position, operations or cash flows.

NOTE 2 – ESCROW RECEIVABLE

At June 30, 2016 and December 31, 2015, the Company’s balance sheets reflected the following current escrow receivables relating to various oil and gas properties previously held by the Company:

NOTE 3 – OIL AND GAS PROPERTIES

During the six months ended June 30, 2016, the Company invested $71,010 for the development of oil and gas properties, consisting of: (1) preparation and evaluation costs in Colombia of $67,966, and (2) costs on U.S. properties of $3,044. Of the amount invested, the Company capitalized $3,044 to oil and gas properties subject to amortization, and $67,966 to oil and gas properties not subject to amortization.

During the six months ended June 30, 2015, the Company disposed of a portion of its interest in three non-producing domestic prospects for proceeds of $56,705. Proceeds received from disposal of such interests were accounted for as a reduction in capitalized cost of oil and gas properties.

Geographical Information

The Company currently has operations in two geographical areas, the United States and Colombia. Revenues for the six months ended June 30, 2016 and long lived assets (net of depletion, amortization, and impairments) as of June 30, 2016 attributable to each geographical area are presented below:

NOTE 4 – STOCK-BASED COMPENSATION EXPENSE

The Company periodically grants options to employees, directors and consultants under the Company’s 2005 Stock Option Plan and the Company’s 2008 Equity Incentive Plan (together, the “Plans”). The Company is required to make estimates of the fair value of the related instruments and recognize expense over the period benefited, usually the vesting period.

Stock Option Activity

In March 2016, options to purchase an aggregate of 20,000 shares were granted to non-employee directors. The options were granted in connection with service on an ad hoc board committee and vest on the earlier of August 15, 2016, the termination of the committee or termination of service on the committee due to death or disability. The options have a five-year life and an exercise price of $0.1982 per share. The options were valued on the date of grant at $2,896 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 1.49%; (2) expected life in years of 4.99; (3) expected stock volatility of 106.95%; (4) expected dividend yield of 0%; and (5) forfeiture rate of 15.22%. The Company determined the options qualify as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

In June 2016, options to purchase an aggregate of 800,000 shares were granted to non-employee directors. The options, which included a one-time supplemental grant to purchase an aggregate of 600,000 shares, were granted in connection with service on the board of directors. 200,000 of the options granted to non-employee directors vested 20% on the grant date and vest as to the remaining 80% nine months from the grant date, have a ten-year life and have an exercise price of $0.2201 per share. Those option grants were valued on the date of grant at $32,640 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 1.26%; (2) expected life in years of 5.28; (3) expected stock volatility of 108.5%; (4) expected dividend yield of 0%; and (5) forfeiture rate of 15.01%. 600,000 of the options granted to non-employee directors vest (i) 50% on the earlier of June 7, 2017 or the day preceding the next annual shareholders meeting at which directors are elected, (ii) 50% on the earlier of June 7, 2018 or the day preceding the second annual shareholders meeting (after the grant date) at which directors are to be elected, and (iii) in the event that the Company consummates a transaction(s) (after the option grant date) in the nature of a sale of shares of equity securities for cash or assets resulting in a net addition(s) to the Company’s stockholders’ equity of not less than $2 million, all unvested options vest in full. Those options have a ten-year life and have an exercise price of $0.2201 per share. Those option grants were valued on the date of grant at $83,421 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 1.26% (2) expected life in years of 5.28, and (3) expected stock volatility of 108.5%. The Company determined the option qualifies as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

A summary of stock option activity and related information for the six months ended June 30, 2016 is presented below:

Shares available for issuance under the Plans as of June 30, 2016 totaled 767,835 shares.

Share-Based Compensation Expense

During the three and six months ended June 30, 2016, the Company recognized $38,334 and $61,201, respectively, of stock compensation expense attributable to the amortization of unrecognized stock-based compensation.

As of June 30, 2016, total unrecognized stock-based compensation expense related to non-vested stock options was $190,656. The unrecognized expense is expected to be recognized over a weighted average period of 1.55 years and the weighted average remaining contractual term of the outstanding options and exercisable options at June 30, 2016 is 6.85 years and 5.72 years, respectively.

The following table reflects share-based compensation recorded by the Company for the three months ended June 30, 2016 and 2015:

The following table reflects share-based compensation recorded by the Company for the six months ended June 30, 2016 and 2015:

NOTE 5 - COMMITMENTS AND CONTINGENCIES

Lease Commitment

The Company leases office facilities under an operating lease agreement that expires on May 31, 2017. As of June 30, 2016, the lease agreement requires future payments as follows:

For the three and six months ended June 30, 2016, the total base rental expense was $25,627 and $51,056, respectively. The Company does not have any capital leases or other operating lease commitments.

NOTE 6 – TAXES

The Company has estimated that its effective tax rate for U.S. purposes will be zero for 2016, and consequently, recorded no U.S. income tax liability or tax expense for the three and six months ended June 30, 2016.

During the three and six months ended June 30, 2016, significant temporary differences between financial statement net loss and estimated taxable income related primarily to the stock compensation expense recognized for book purposes during the period.

Forward-Looking Information

This Form 10-Q quarterly report of Houston American Energy Corp. (the “Company”) for the six months ended June 30, 2016, contains certain 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, which are intended to be covered by the safe harbors created thereby. To the extent that there are statements that are not recitations of historical fact, such statements constitute forward-looking statements that, by definition, involve risks and uncertainties. In any forward-looking statement, where we express an expectation or belief as to future results or events, such expectation or belief is expressed in good faith and believed to have a reasonable basis, but there can be no assurance that the statement of expectation or belief will be achieved or accomplished.

The actual results or events may differ materially from those anticipated and as reflected in forward-looking statements included herein. Factors that may cause actual results or events to differ from those anticipated in the forward-looking statements included herein include the Risk Factors described in Item 1A herein and in our Form 10-K for the year ended December 31, 2015.

Readers are cautioned not to place undue reliance on the forward-looking statements contained herein, which speak only as of the date hereof. We believe the information contained in this Form 10-Q to be accurate as of the date hereof. Changes may occur after that date, and we will not update that information except as required by law in the normal course of our public disclosure practices.

Additionally, the following discussion regarding our financial condition and results of operations should be read in conjunction with the financial statements and related notes contained in Item 1 of Part 1 of this Form 10-Q, as well as the Risk Factors in Item 1A and the financial statements in Item 7 of Part II of our Form 10-K for the year ended December 31, 2015.

Critical Accounting Policies

The discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. We believe certain critical accounting policies affect the more significant judgments and estimates used in the preparation of our financial statements. A description of our critical accounting policies is set forth in our Form 10-K for the year ended December 31, 2015. As of, and for the six months ended, June 30, 2016, there have been no material changes or updates to our critical accounting policies.

Unevaluated Oil and Gas Properties

Unevaluated oil and gas properties not subject to amortization, include the following at June 30, 2016:

Of the carrying value of unevaluated oil and gas prospects above, $2,181.340 was attributable to properties in the South American country of Colombia and $765,689 was attributable to properties in the United States. We are maintaining our interest in these properties and development has or is anticipated to commence within the next twelve months.

Recent Developments

Drilling and Related Activity

During the six months ended June 30, 2016, we drilled no wells and, at June 30, 2016, no drilling operations were ongoing.

During the six months ended June 30, 2016, our capital investment expenditures totaled $71,010 principally relating to the preparation and evaluation of our three concessions in Colombia.

Hupecol, the operator of our Colombian concessions, has advised us that they are continuing to experience opposition, at the local level, to their efforts to secure necessary permits to commence drilling operations on our Serrania concession. Commencement of drilling operations remains contingent upon receipt of final permits in Colombia. Notwithstanding the federal government’s grant of the concession, local opposition to drilling in the vicinity of the Serrania concession has resulted in repeated delays in issuance of, including the issuance and subsequent rescission of, necessary permits and there is no assurance as to if, and when, necessary permits will be issued or the concession will be drilled and/or developed. Given the continuing permitting issues, we, through Hupecol, are evaluating our rights and options with respect to Serrania and, unless a satisfactory resolution is reached in the near term, have shelved plans to drill the concession in 2016.

Hupecol is also expected to defer commencement of work on the Los Picachos and Macaya concessions until satisfactory resolution of the permitting issues on the Serrania concession.

In June 2016, a peace accord was announced between the Colombian government and the Revolutionary Armed Forces of Colombia, also known as FARC. While the peace accord remains in its early days, is subject to execution of a final comprehensive peace agreement and there is no assurance as to how that accord will, or will not, impact our assets, we are reevaluating our plans regarding our Colombian assets in light of the peace accord and the potential of the accord to enhance our prospects of arriving at a favorable resolution to the impasse that has prevented the commencement of drilling operations on our Colombian properties.

Termination of Planned Tamboran Investment

In February 2016, we agreed to acquire a 12.5% equity ownership interest in Tamboran Resources Limited for $1,000,000. Closing of the planned acquisition of the interest in Tamboran was subject to satisfaction of certain conditions by Tamboran, including the receipt by Tamboran of funding from investors other than Houston American Energy in an amount not less than $705,000. Tamboran failed to satisfy one of the conditions of closing the investment and, effective June 30, 2016, our agreement to purchase an equity ownership interest in Tamboran was terminated.

Strategic Alternatives

In May 2016, our board approved the exploration of strategic alternatives, including, among other options, seeking merger and acquisition candidates, asset acquisitions or sales. To facilitate our exploration of strategic alternatives, in June 2016, we engaged Drexel Hamilton, an investment banking firm, to assist in making merger and acquisition introductions, negotiating deals, capital sourcing and other supporting services.

Supplemental Director Option Grants

In light of the limited cash compensation paid to non-employee directors and the anticipated increased demands on non-employee directors associated with the search for and consideration of strategic alternatives, in June 2016, in addition to ordinary annual option grants to non-employee directors, we granted supplemental stock options pursuant to which each of the non-employee directors may acquire up to 150,000 shares of common stock (or an aggregate of 600,000 shares) for a term of ten years at an exercise price of $0.2201 per share. The supplement options vest: (i) 50% on the earlier of June 7, 2017 or the day preceding the next annual shareholders meeting at which directors are elected, (ii) 50% on the earlier of June 7, 2018 or the day preceding the second annual shareholders meeting (after the grant date) at which directors are to be elected, and (iii) in the event that the Company consummates a transaction(s) (after the option grant date) in the nature of a sale of shares of equity securities for cash or assets resulting in a net addition(s) to the Company’s stockholders’ equity of not less than $2 million, all unvested options vest in full.

Results of Operations

Oil and Gas Revenues. Total oil and gas revenues decreased by 70.3% to $33,887 in the three months ended June 30, 2016 compared to $114,122 in the three months ended June 30, 2015. Oil and gas revenues decreased 62% to $82,147 in the six months ended June 30, 2016 compared to $216,093 in the six months ended June 30, 2015. The decrease in revenue was due to a steep decline in oil (down 33%) and natural gas (down 35%) prices and a 64% decline in crude oil production and a 22% decline in natural gas production.

The following table sets forth the gross and net producing wells, net oil and gas production volumes and average hydrocarbon sales prices for the quarter and six months ended June 30, 2016 and 2015:

The change in average sales prices realized reflects a steep decline in global commodity prices from 2015 and continuing into 2016. The decline in crude oil production reflects natural decline rates and termination, during 2015, of production on two wells that were no longer economical to produce at current commodity prices.

Oil and gas sales revenues by region were as follows:

Lease Operating Expenses. Lease operating expenses decreased by 12% to $26,973 during the three months ended June 30, 2016 from $30,376 during the three months ended June 30, 2015. During the six months ended June 30, 2016, lease operating expenses decreased by 37% to $37,361 from $59,648 during the six months ended June 30, 2015. The decrease in lease operating expenses was attributable to operation of fewer wells during the 2016 periods and receipt of a severance tax abatement on one well during 2016.

Following is a summary comparison of lease operating expenses, by region, for the periods.

Consistent with our business model and operating history, we experience steep declines in lease operating expenses following strategic divestitures and anticipate lease operating expenses to ramp up to levels consistent with regional costs as new wells are brought on line.

Depreciation and Depletion Expense.  Depreciation and depletion expense was $24,251 and $146,172 for the three months ended June 30, 2016 and 2015, respectively, and $49,264 and $278,075 for the six months ended June 30, 2016 and 2015, respectively.  The decrease was due to impairment charges during 2015 and lower production rates.

Impairment of Oil and Gas Properties. During the three months and six months ended June 30, 2015, we recorded an impairment expense of $0 and $677,051, respectively, associated with the decline in energy prices.

General and Administrative Expenses. General and administrative expense increased by 72% to $474,865 during the three months ended June 30, 2016 from $276,703 during the three months ended June 30, 2015, and increased by 13.4% to $831,135 during the six months ended June 30, 2016 from $732,576 during the six months ended June 30, 2015. The increases in general and administrative expense was primarily attributable to an increase in consulting fees and the reversal, during 2015, of an over accrual of legal fees that resulted in lower legal fees in 2015.

Other Income. Other income consisted of interest earned on cash balances, net of interest expense. Other income totaled $1,796 and $5,756 of net other income during the three and six-month periods ended June 30, 2016, respectively, as compared to $4,989 and $10,445 of other income during the three and six-month periods ended June 30, 2015, respectively. The changes were attributable to lower cash balances.

Income Tax Expense/Benefit. We reported no income tax expense during the three months ended June 30, 2016 compared to income tax expense of $17,309 during the three months ended June 30, 2015. For the six months ended June 30, 2016, we reported no income tax expense compared to income tax expense of $18,060 during the six months ended June 30, 2015.

Financial Condition

Liquidity and Capital Resources. At June 30, 2016, we had a cash balance of $1,248,762 and working capital of $1,504,078, compared to a cash balance of $2,123,520 and working capital of $2,384,283 at December 31, 2015. The change in cash and working capital during the period was primarily attributable to the operating loss for the first six months of 2016.

Operating activities used cash of $713,669 during the six months ended June 30, 2016 as compared to $1,199,917 of cash used during the six months ended June 30, 2015. The change in operating cash flow used was primarily attributable to (1) changes in operating assets and liabilities (reflecting settlement of litigation and insurance claims and associated legal fees, an increase in prepaid expenses and a decrease in payables and accrued expenses) which accounted for a reduction in cash of $656,982 in 2015 versus changes in operating assets and liabilities which accounted for an increase in cash of $5,438 in 2016, partially offset by (2) an increase in cash loss, after elimination of non-cash items, of $176,181, attributable to increased general and administrative expenses.

Investing activities used $71,010 during the six months ended June 30, 2016 compared to $76,739 of cash used during the six months ended June 30, 2015. The funds used by investing activities during the 2016 six-month period reflect the investments in oil and gas properties, totaling $71,010. The funds used by investing activities during the six months ended June 30, 2015 reflect the investments in oil and gas properties, totaling $192,856, partially offset by proceeds of $56,705 from the sale of the Company’s interest in several oil and gas wells and the release of $59,412 of funds held in escrow from the prior sale of our interests in HDC LLC, HL, LLC and the Tambaqui prospect.

Financing activities used $90,079 for the acquisition of treasury shares during the six-months ended June 30, 2016 compared to $0 used during the 2016 period.

Long-Term Liabilities. At June 30, 2016, we had long-term liabilities of $25,538 as compared to $25,262 at December 31, 2015. Long-term liabilities at June 30, 2016 and December 31, 2015 consisted of a reserve for plugging costs.

Capital and Exploration Expenditures and Commitments. Our principal capital and exploration expenditures relate to ongoing efforts to acquire, drill and complete prospects. We expect that future capital and exploration expenditures will be funded principally through funds on hand and funds generated from operations of wells being brought on line during 2014.

During the six months ended June 30, 2016, the Company invested $71,010 for the development of oil and gas properties, consisting of: (1) preparation and evaluation costs in Colombia of $67,966, and (2) costs on U.S. properties of $3,044. Of the amount invested, the Company capitalized $3,044 to oil and gas properties subject to amortization, and $67,966 to oil and gas properties not subject to amortization

With the termination of our agreement to purchase an equity interest in Tamboran Resources, we presently have no budgeted capital expenditures for the balance of 2016. Capital expenditure plans for 2016 may change should the permitting issues at Serrania be satisfactorily resolved in order to permit drilling during 2016 and based on field conditions and other factors beyond our control or the control of the operators of our prospects and, as such, there can be no assurance as to the timing of these operations or the amount actually spent on such operations.

Depending on the timing and ultimate outcome of our strategic alternatives initiative and potential expenditures relating to the Serrania concession, our cash on hand may not be adequate to fully fund our operations during 2016, including our capital expenditure budget. Accordingly, we may require additional capital to fully fund our future drilling budget and operations. If, for any reason, we are unable to fully fund our drilling budget and fail to satisfy commitments reflected therein, we may be subject to penalties or to the possible loss of some of our rights and interests in prospects with respect to which we fail to satisfy funding commitments. We have no commitments to provide any additional financing should we require and seek such financing and there is no guarantee that we will be able to secure additional financing on acceptable terms, or at all, to fully fund our drilling budget and to support future acquisitions and development activities.

Outlook; Strategic Alternatives

Continued low oil and natural gas prices during 2015 and into 2016 and lagging production in light of recurring delays in drilling of our Serrania prospect in Colombia have had a significant adverse impact on our business. Our financial statements include a “going concern” qualification reflecting substantial doubt as to our ability to continue as a going concern. While we have no debt and have taken steps to reduce our overhead, we continue to operate at a loss and expect to continue to do so until such time as we can increase production levels and realize substantial improvement in commodity prices. With the continuing permitting issues at Serrania and the lack of clarity as to the ultimate development of the concession, our near term efforts to bolster production and profitability are focused on opportunistic acquisitions of assets or companies in the current depressed market.

Given the uncertainty as to timing and ultimate outcome of our current initiatives in Colombia, management has determined that we should consider strategic alternatives, including seeking a merger partner or acquisition of significant oil and gas assets with a view to maximizing long-term value to our shareholders. To that end, we have retained a business development advisor and an energy investment bank to assist in identifying and financing strategic transactions. While we believe that there are attractive opportunities that will be available to execute one or more strategic transactions that will position us to take advantage of an anticipated future recovery in energy markets, such transactions may be highly dilutive and there can be no assurance that any such strategic transaction can be executed on acceptable terms or at all.

Absent a timely and favorable resolution of permitting issues in Colombia and resulting successful drilling operations or consummation of a strategic transaction, given our limited resources, financial commitments and continuing negative cash flow from operations, we may be required to seek additional financing or may be required to divest certain assets in order to support operations until such point, if ever, as our revenues increase sufficiently, either through price increases or the addition of production, to cover our operating costs and overhead. We can provide no assurance that our efforts will be sufficient to reverse the trend of operating losses, to provide adequate financial resources to sustain operations and retention of our assets pending attainment of profitable operations or consummate of a strategic transaction.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements or guarantees of third party obligations at June 30, 2016.

Inflation

We believe that inflation has not had a significant impact on operations since inception.

Commodity Price Risk

The price we receive for our oil and gas production heavily influences our revenue, profitability, access to capital and future rate of growth. Crude oil and natural gas are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for oil and gas have been volatile, and these markets will likely continue to be volatile in the future. The prices we receive for production depends on numerous factors beyond our control.

We have not historically entered into any hedges or other transactions designed to manage, or limit, exposure to oil and gas price volatility.

Evaluation of Disclosure Controls and Procedures

Under the supervision and the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation as of June 30, 2016 of the effectiveness of the design and operation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended. Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective as of June 30, 2016. Such conclusion reflects the 2013 departure of our chief financial officer and assumption of duties of principal financial officer by our chief executive officer and the resulting lack of segregation of duties. Until we are able to remedy these material weaknesses, we are relying on third party consultants and our accounting firm to assist with financial reporting.

Changes in Internal Control over Financial Reporting

No change in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) occurred during the quarter ended June 30, 2016 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II

Exhibit

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on behalf by the undersigned thereunto duly authorized.