Forward-Looking Information

This Form 10-Q quarterly report of Houston American Energy Corp. (the "Company") for the six months ended June 30, 2012, 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, 2011.

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 fiscal year ended December 31, 2011.

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, 2011. As of, and for the quarter ended, June 30, 2012, there have been no material changes or updates to our critical accounting policies other than the following updated information relating to Unevaluated Oil and Gas Properties:

Unevaluated Oil and Gas Properties

Unevaluated oil and gas properties not subject to amortization, net of
impairment, include the following at June 30, 2012:

                                    June 30, 2012
Acquisition costs                  $       925,423
Development and evaluation costs         3,833,514
Total                              $     4,759,057

Included in the carrying value of unevaluated oil and gas prospects above was $3,832,634 for properties in the South American country of Colombia. We are maintaining our interest in these properties and development has or is anticipated to commence within the next twelve months.

Current Year Developments

Drilling Activity

During the six months ended June 30, 2012, we drilled 4 international wells in Colombia, as follows:

? 2 wells were drilled on the La Cuerva concession in which we hold a 1.6% working interest, of which 2 were completed and brought onto production (both wells were sold in connection with the sale of our interest in HC, LLC described below).

? 2 wells were drilled on the CPO 4 block in Colombia, of which one was determined to be non-commercial and the second was being tested at June 30, 2012.

Subsequent to June 30, 2012, the second well drilled on the CPO 4 block was determined to be non-commercial and drilling efforts on a third well commenced (see "CPO 4 and Serrania Development" below).

During the six months ended June 30, 2012, no domestic wells were drilled.

Sale of La Cuerva and LLA 62 Blocks

During the first quarter of 2012, we sold all of our interest in Hupecol Cuerva, LLC ("HC, LLC"), which holds interests in the La Cuerva block and, pending approval of the Colombian authorities, the LLA 62 block, together covering approximately 90,000 acres in the Llanos Basin in Colombia.

HC, LLC sold for $75 million, adjusted for working capital. 13.3% of the sales price of HC, LLC will be held in escrow to fund potential claims arising from the sale. Pursuant to our 1.6% ownership interest in HC, LLC, we received 1.6% in the net sale proceeds after deduction of commissions, overriding royalty interest, and transaction expenses; subject to the escrow holdback and a further contingency holdback by Hupecol of 1.3% of the sales price. Following completion of the sale of HC, LLC, we have no continuing interest in the La Cuerva and LLA 62 blocks.

CPO 4 and Serrania Development

During the six months ended June 30, 2012, the Company invested $18,595,206 (of which $3,728,695 was accrued as of June 30, 2012) for the development of oil and gas properties, consisting of (1) drilling and drilling preparation costs on 3 wells in Colombia of $18,277,606, (2) seismic cost in Colombia of $139,400, (3) evaluation cost in Colombia of $107,430 and (4) leasehold costs on U.S. properties of $70,770. Of the amount invested, we capitalized $18,530,832 to oil and gas properties subject to amortization, primarily attributable to developmental activity related to the Company's first two wells on CPO 4 block (the Tamandua #1 and Cachirre #1), as well as the preparation for drilling the Company's third well (the Zorro Gris) on CPO 4, seismic expenses on CPO 4 and other expenses on unevaluated concessions in Colombia.

In April 2012, we, together with the operator, determined to cease efforts to test and complete the Tamandua #1 sidetrack well on the CPO 4 prospect in Colombia. As a result of the determination to cease efforts to complete the Tamandua #1 well, we included the costs related to the Tamandua #1 well in the full cost pool for inclusion in the ceiling test. We recorded an impairment charge of $26,527,300 during the six months ended June 30, 2012 to write off costs not being amortized that were attributable to the drilling of the Tamandua #1 well on the CPO 4 block as well as to write off seismic exploration and evaluation cost, general and administrative cost and environmental and governmental cost that were attributable to the CPO 4 block through June 30, 2012.

In July 2012, we determined to plug and abandon the Cachirre #1 well on the CPO 4 prospect in Colombia. As a result of such determination, we recorded an impairment charge of $10,101,619 during the quarter and six months ended June 30, 2012 to write off costs not being amortized that were attributable to the drilling of the Cachirre #1 well as well as to write off seismic exploration and evaluation cost, general and administrative cost and environmental and governmental cost that were attributable to the CPO 4 block through June 30, 2012. The Company estimates that an additional impairment charge of approximately $1.2 million will be recorded in the third quarter on the Cachirre well for cost incurred on the well by the Company after the six months ended June 30, 2012.

With respect to development of our Serrania Block, the National Hydrocarbon Agency of Colombia (the "ANH") has granted extensions of required development commitments, including drilling of a first test well, until September 2013 based on conditions on the ground. Based on those conditions, we anticipate that drilling of a first test well on the Serrania Block will not occur until 2013.

Financing Activities

On May 3, 2012, we entered into definitive agreements with certain institutional investors to sell, and on May 8, 2012 we sold, 6,200,000 units, with each unit consisting of one of our common shares and one warrant to purchase one common share, for gross proceeds of approximately $13.14 million, before deducting placement agent fees and estimated offering expenses, in a "registered direct" offering. The investors purchased the units at a purchase price of $2.12 per unit. The warrants, which represent the right to acquire an aggregate of up to 6,200,000 common shares, are exercisable at any time on or after November 9, 2012 and prior to November 9, 2015 at an exercise price of $2.68 per share, which was 120% of the closing price of our common shares on the NYSE Amex on May 2, 2012.

Legal Proceedings

On April 27, 2012, a purported class action lawsuit was filed in the U.S. District Court for the Southern District of Texas against us and certain of our executive officers: Steve Silverman v. Houston American Energy Corp. et al., Case No. 4:12-CV-1332. The complaint generally alleges that, between March 29, 2010 and April 18, 2012, all of the defendants violated Sections 10(b) of the Securities Exchange Act of 1934 and SEC Rule 10b-5 and the individual defendants violated Section 20(a) of the Exchange Act in making materially false and misleading statements including certain statements related to the status and viability of the Tamandua #1 well. Additional class action suits have since been filed against us, and may in the future be filed against us, based on the same factual allegations set forth in the Silverman case. The Complaint in the Silverman case seeks unspecified damages, interest, attorneys' fees, and other costs. We believe all of the claims in the Silverman case are without merit and intend to vigorously defend against these claims. It is not possible at this time to predict the timing or outcome of the Silverman case or any other class action lawsuits that have or may be filed. We expect to incur costs and to devote management time and resources to defending such lawsuits.

On July 19, 2012, a purported derivative cause of action was filed in the U.S. District Court for the Southern District of Texas against certain directors and officers of the Company and the Company, as nominal defendant: E. Howard King, Jr., derivatively, on behalf of Houston American Energy Corp., v. John F. Terwilliger, John P. Boylan, Orrie Lee Tawes III, Stephen Hartzell, James J. Jacobs, Kenneth A. Jeffers, defendants, and Houston American Energy Corp., as nominal defendant, Case No. 4:12-CV-02182. The complaint asserts a cause of action by a shareholder on behalf of Houston American against certain of our directors and senior executive officers in connection with the June 11, 2012 approval of payment of certain bonuses, increases in salary, grant of certain stock options and entry into certain Change in Control Agreements. The complaint alleges that the approval of such matters constituted breach of fiduciary duty and corporate waste and seeks injunctive relief to bar each of the actions in question and seeks restitution. No damages have been or, by the nature of the derivative cause of action, are expected to be alleged against Houston American. We may, however, incur certain costs and demands on management time and resources in connection with the lawsuit.

In connection with the ongoing non-public formal investigation being conducted by the SEC and indemnification provisions contained in an engagement agreement with Global Hunter Securities, LLC relating to the Company's 2009 equity offering, in July 2012, the Company and Global Hunter entered into an agreement whereby the Company agreed to pay $271,580 on or before July 27, 2012 to settle any and all claims by Global Hunter related to reimbursement of attorney's fees under the indemnity provision. In exchange for the payment, the Company was granted a full release by Global Hunter Securities of any future claims or liabilities asserted by Global Hunter in connection with the offering. The Company paid the amount on July 27, 2012.

Compensation Expense

In June 2012, our board of directors approved, and we paid, cash bonuses to our senior management team totaling $403,199 and grants of stock options to acquire an aggregate of 1,200,000 shares of common stock and, effective July 1, 2012, we increased the base salary of members of our senior management team by amounts ranging from 5% to 15%.

The options granted vested on the grant date, have a ten year life and have an exercise price of $1.65 per share. Of those options, 429,000 are exercisable commencing 6 months from the date of grant and 771,000 are exercisable on and after shareholder approval of an amendment to our 2008 Equity Incentive Plan to increase the shares reserved under the plan to facilitate exercise. The option grants to employees, excluding grants that are subject to shareholder approval of amendment to the 2008 Equity Incentive Plan, were valued on the date of grant at $354,098 using the Black-Scholes option-pricing model. Of that value, all were recognized as compensation expense at the date of grant. Option grants that remain subject to shareholder approval of amendment to the 2008 Equity Incentive Plan will be valued and accounted for at the time of shareholder approval of the amendment.

In June 2012, our board of directors approved grants of stock options to purchase 25,000 shares of common stock, consistent with our existing director compensation program, to each of our non-employee directors and one-time extraordinary grants of stock options to purchase 75,000 shares of common stock to each of our non-employee directors. Each of the options vest 20% on the grant date and 80% nine months from the grant date and is exercisable for a term of 10 years at an exercise price of $1.65 per share; provided, however, that 48,175 of the options granted to each of the directors shall not be exercisable, in part or in whole, until such time as our shareholders shall have approved an amendment to our 2008 Equity Incentive Plan increasing the shares reserved for issuance under the plan to an amount sufficient to permit issuance of such shares.

In June 2012, our board of directors amended our cash compensation arrangements for non-employee directors, effective June 30, 2012, to increase all amounts payable thereunder by 50% to: annual retainer of $9,000, payable in quarterly installments of $2,250; annual retainer for service on each committee of $3,000, payable in quarterly installments of $750; annual retainer for service as chairman of the audit committee of $3,750, payable in quarterly installments of $937.50; and annual retainer for service as chairman of the compensation committee of $2,250, payable in quarterly installments of $562.50.

In June 2012, our board of directors approved the entry into Change in Control Agreements (the "Change in Control Agreements") with our President and Chief Executive Officer, John Terwilliger, Chief Financial Officer, James J. Jacobs, and Senior Vice President - Exploration, Kenneth Jeffers. Pursuant to the Change in Control Agreements, if we undergo a change in control and a covered officer is terminated without cause or resigns for good reason within 90 days prior to or within 12 months following a change in control, the subject officer is entitled to (i) a lump sum cash severance payment equal to 250% of his average annual cash compensation (including salary and bonuses) during the three years ending on the termination date, and (ii) acceleration of vesting of all unvested time-based stock options.

During the three and six months ended June 30, 2012, we recognized non-cash compensation expense associated with grants of restricted stock and stock options totaling $61,457 and $122,881, respectively.

As of June 30, 2012, excluding grants that remain subject to shareholder approval of amendment to the 2008 Equity Incentive Plan, there was $484,844 of total unrecognized compensation cost related to unvested restricted stock and $1,895,845 of total unrecognized compensation cost related to unvested, or un-exercisable, stock options. The cost is expected to be recognized over a weighted average period of approximately 1.95 years for restricted stock and 1.73 years for stock options. Option grants that remain subject to shareholder approval of amendment to the 2008 Equity Incentive Plan will be valued and accounted for at the time of shareholder approval of the amendment.

Strategic Alternative Review

In July 2012, our board authorized the engagement of an investment banking firm, and we engaged Canaccord Genuity, Inc., to assist in the evaluation of a broad range of financial and strategic alternatives, including, but not limited to, seeking additional financing to support the long-term development of our oil and gas properties, seeking financial and/or industry partners to participate in the development of our properties, selling some of or all of our assets or interests in those assets, and the possible sale of our company, among other alternatives.

Results of Operations

Oil and Gas Revenues. Total oil and gas revenues decreased 89.7% to $36,347 in the three months ended June 30, 2012 compared to $353,505 in the three months ended June 30, 2011. For the six month period, oil and gas revenues decreased 25.3% to $356,857 in the six months ended June 30, 2012 compared to $477,808 in the six months ended June 30, 2011.

The decrease in revenue was due to the sale of the La Cuerva concession during the first quarter of 2012.

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, 2012 and 2011:

                                                 Three Months Ended           Six Months Ended
                                                      June 30,                    June 30,
                                                 2012          2011          2012          2011
Gross producing wells                                  6            22            22            22
Net producing wells                                 0.18          0.44          0.44          0.44
Net oil production (bbl)                             249         3,270         2,384         4,465
Net gas production (mcf)                           2,951         2,817         7,251         6,020
Average sales price - oil (per barrel)        $   113.42     $  105.66     $  110.13     $  101.80
Average sales price - natural gas (per Mcf)   $     2.76     $    2.83     $    3.42     $    3.87

The number of gross wells shown above for the six month period ended 2012 includes the 16 gross (0.256 net) wells attributable to the La Cuerva concession that were sold during the first quarter of 2012. At June 30, 2012, the Company had 6 gross (0.18 net) wells.

The change in average sales prices realized reflects fluctuations in global commodity prices.

Oil and gas sales revenues by region were as follows:

                        Colombia        U.S.         Total
2012 First Six Months
Oil sales               $ 263,182 *   $ 68,878     $ 332,060
Gas sales                       -       24,797        24,797
2011 First Six Months
Oil sales               $ 393,281     $ 61,259     $ 454,540
Gas sales                       -       23,268        23,268

* Includes a $69,186 payment from Hupecol for oil produced in 2011 which is considered immaterial to the 2011 financial statements.

Lease Operating Expenses. Lease operating expenses, excluding joint venture expenses relating to our Colombian operations discussed below, decreased 90.2% to $19,047 in the 2012 quarter from $193,562 in the 2011 quarter. For the six month period, lease operating expenses decreased 50.7% to $158,648 from $321,464 in the 2011 period. The decrease in lease operating expenses was attributable to the sale of our interest in the La Cuerva concession during the first quarter of 2012.

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

                                     Colombia        U.S.         Total
                  Quarter   - 2012   $       -     $ 19,047     $  19,047
                            - 2011   $ 176,574     $ 16,988     $ 193,562

                 Six Months - 2012   $ 118,734     $ 39,914     $ 158,648
                            - 2011   $ 288,218     $ 33,246     $ 321,464

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.

Joint Venture Expenses. Our allocable share of joint venture expenses attributable to the Colombian Joint Venture with Hupecol totaled $0 and $3,164 during three months ended June 30, 2012 and 2011, respectively, and $3,244 and $5,924 during the six months ended June 30, 2012 and 2011, respectively. The change in joint venture expenses was attributable to reduced allocated administrative cost following the sale of our interest in the La Cuerva concession during the first quarter of 2012.

Depreciation and Depletion Expense. Depreciation and depletion expense was $6,185 and $42,347 for the quarter ended June 30, 2012 and 2011, respectively, and $55,467 and $70,344 for the six months ended June 30, 2012 and 2011, respectively. The decrease in depreciation and depletion was due to the sale of our interest in the La Cuerva concession.

Gain on Sale of Oil and Gas Properties. The sale of our indirect interests in Hupecol Cuerva, LLC resulted in a gain of $315,119 during the 2012 first quarter and six month period. During the six months ended June 30, 2011, post closing adjustments related from the sale of our indirect interests in Hupecol Dorotea and Cabiona, LLC, Hupecol Llanos, LLC and Caracara resulted in a loss of $179,595.

Impairment Expense. Termination of our testing and completion efforts on our Tamandua #1 sidetrack well and Cachirre #1 well resulted in impairment expense of $16,633,074 and $36,628,919, respectively, during the quarter and six months ended June 30, 2012.

General and Administrative Expenses. General and administrative expense increased by 29.0% to $2,032,339 during the 2012 quarter from $1,572,374 during the 2011 quarter and by 13.2% to $3,113,187 during the 2012 six month period from $2,747,468 during the 2011 six month period.

The increase in general and administrative expense was primarily attributable to an increase in stock compensation of $180,803 and $124,254, respectively, during the quarter and six month periods, partially offset by a decrease in cash compensation paid of $109,320 and $98,490, respectively, during the quarter and six month periods. The increase in stock compensation expense reflect one-time special grants of stock options to non-employee directors and immediately vested stock option grants to each of our officers. The decrease in cash compensation paid reflected lower bonus payment during the 2012 periods.

Other Income (Expense). Other income (expense) consists of interest earned on cash balances, net of other bank fees. Other income (expense), net totaled $(11,627) of net expense and $(37,320) of net expense during the three months and six month periods ending June 30, 2012, respectively, as compared to $20,314 of net income and $644 of net income during the 2011 three months and six month periods. The change was attributable to reduced interest income on lower cash balances.

Income Tax Expense/Benefit. We reported income tax expense of $3,356,154 during the 2012 second quarter compared to income tax expense of $85,583 during the 2011 second quarter. For the six months ended June 30, 2012 we reported income tax expense of $3,365,365 as compared to $88,377 during the 2011 six month period. The change in income tax expense during the 2012 quarter was attributable to the increase in our valuation allowance which resulted in the write off of our deferred tax asset of $3,195,583. The increase in valuation allowance was due to an uncertainty about the utilization of the deferred tax asset. The difference between the deferred tax asset and our income tax expense related to cash taxes paid in Colombia. The Company recorded no U.S. income tax liability in the 2012 or 2011 quarters.

Financial Condition

Liquidity and Capital Resources. At June 30, 2012, we had a cash balance of $6,392,057 and working capital of $12,406,018, compared to a cash balance of $9,930,284 and working capital of $19,636,540 at December 31, 2011. The change in working capital during the period was primarily attributable to the payment of costs associated with drilling of our Tamandua #1 sidetrack well and Cachirre #1 well, offset by our capital raise in May of 2011.

Operating activities used cash of $1,939,666 during the six months ended June 30, 2012 quarter as compared to $4,303,086 of cash used during the 2011 six-month period. The change in operating cash flow was primarily attributable substantial reductions in payables during the 2011 period partially offset by an increase in accounts receivable during the 2011 period as well as increased general and administrative expense.

Investing activities used $13,996,261 during the 2012 six month period compared to $3,555,809 used during the 2011 period. The funds used in investing activities principally reflect investments in oil and gas properties and assets of $14,866,511 and the purchase of marketable securities of $156,818, partially offset by proceeds from sale of our interest in Hupecol Cuerva, LLC of $1,027,068 during 2012. The change in investing cash flows was attributable to our investments in drilling wells on our CPO 4 prospect which wells were more expensive than wells drilled during 2011 and reflect our substantially larger ownership interest in the CPO 4 prospect that in prospects drilled during 2011.

Financing activities during 2012 provided $12,397,700 of net proceeds from the sale of units of common stock and warrants in May 2012.

Long-Term Liabilities. At June 30, 2012, we had long-term liabilities of $7,596 as compared to $45,039 at December 31, 2011. Long-term liabilities at June 30, 2012 and December 31, 2011 consisted of a reserve for plugging costs and a deferred rent obligation.

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 by proceeds from anticipated financing transactions or other transactions.

During the six months ended June 30, 2012, we invested $18,595,206 (of which $3,728,695 was accrued as of June 30, 2012) for the development of oil and gas properties, consisting of (1) drilling and drilling preparation costs on 3 wells in Colombia of $18,277,606, (2) seismic cost in Colombia of $139,400, (3) evaluation cost in Colombia of $107,430 and (4) leasehold costs on U.S. . . .