form10qa.htm
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
FORM 10-Q/A
(Mark One)
|
x
|
QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
For the quarterly period ended June 30, 2012
OR
|
£
|
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 1-32955
HOUSTON AMERICAN ENERGY CORP.
(Exact name of registrant as specified in its charter)
|
Delaware
|
|
76-0675953
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|
(State or other jurisdiction of incorporation or organization)
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|
(IRS Employer Identification No.)
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| |
801 Travis Street, Suite 1425, Houston, Texas 77002
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|
| |
(Address of principal executive offices)(Zip Code)
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|
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(713) 222-6966
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| |
(Registrant's telephone number, including area code)
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|
| |
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|
| |
(Former name, former address and former fiscal year, if changed since last report)
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|
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):
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Large accelerated filer ¨
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Accelerated filer x
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Non-accelerated filer ¨
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Smaller reporting company ¨
|
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, 2012, we had 37,365,230 shares of $0.001 par value Common Stock outstanding.
Explanatory Note
The sole purpose of this Amendment No. 1 to the Registrant’s Quarterly Report on Form 10–Q for the quarterly period ended June 30, 2012, originally filed with the Securities and Exchange Commission on August 9, 2012 (the “Form 10–Q”), is to furnish Exhibit 101 to the Form 10–Q in accordance with Rule 405 of Regulation S-T. Exhibit 101 to this report provides the consolidated financial statements and related notes from the Form 10-Q formatted in XBRL (eXtensible Business Reporting Language).
Under Rule 405(a)(2)(ii) of Regulation S-T, this Exhibit 101 is permitted to be furnished by amendment within 30 days of the original filing date of the Form 10-Q.
No other changes have been made to the Form 10–Q. This Amendment No. 1 to the Form 10-Q speaks as of the original filing date of the Form 10–Q, does not reflect events that may have occurred subsequent to the original filing date and does not modify or update in any way, disclosures made in the original Form 10–Q. Pursuant to Rule 406T of Regulation S–T, the interactive data files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities Act of 1934, as amended, and otherwise are not subject to liability under those sections.
FORM 10-Q
INDEX
PART I – FINANCIAL INFORMATION
|
Item 1.
|
Financial Statements
|
HOUSTON AMERICAN ENERGY CORP.
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| |
June 30,
2012
|
|
|
|
|
ASSETS
|
|
|
CURRENT ASSETS
|
|
|
|
|
|
Cash
|
|
$ |
6,392,057 |
|
|
$ |
9,930,284 |
|
|
Restricted cash – letter of credit
|
|
|
3,056,250 |
|
|
|
3,056,250 |
|
|
Accounts receivable – oil and gas sales
|
|
|
— |
|
|
|
40,502 |
|
|
Accounts receivable – other
|
|
|
4,322,074 |
|
|
|
4,322,063 |
|
|
Escrow receivable – current
|
|
|
2,030,328 |
|
|
|
1,863,332 |
|
|
Marketable securities – available for sale
|
|
|
470,957 |
|
|
|
707,445 |
|
|
Prepaid expenses and other current assets
|
|
|
143,285 |
|
|
|
13,635 |
|
|
TOTAL CURRENT ASSETS
|
|
|
16,414,951 |
|
|
|
19,933,511 |
|
| |
|
|
|
|
|
|
|
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PROPERTY, PLANT AND EQUIPMENT
|
|
|
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|
|
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|
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Oil and gas properties – full cost method
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|
|
|
|
|
|
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Costs subject to amortization
|
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37,486,672 |
|
|
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2,490,164 |
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Costs not being amortized
|
|
|
4,759,057 |
|
|
|
22,890,944 |
|
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Office equipment
|
|
|
90,004 |
|
|
|
90,004 |
|
|
Total property, plant and equipment
|
|
|
42,335,733 |
|
|
|
25,471,112 |
|
|
Accumulated depreciation, depletion and impairment
|
|
|
(37,487,592 |
) |
|
|
(1,675,232 |
) |
|
TOTAL PROPERTY, PLANT, AND EQUIPMENT, NET
|
|
|
4,848,141 |
|
|
|
23,795,880 |
|
| |
|
|
|
|
|
|
|
|
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OTHER ASSETS
|
|
|
|
|
|
|
|
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|
Deferred tax asset
|
|
|
— |
|
|
|
3,195,583 |
|
|
Escrow receivable
|
|
|
1,664,581 |
|
|
|
1,664,581 |
|
|
Other assets
|
|
|
3,166 |
|
|
|
68,381 |
|
|
TOTAL ASSETS
|
|
$ |
22,930,839 |
|
|
$ |
48,657,936 |
|
| |
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS’ EQUITY
|
|
|
CURRENT LIABILITIES
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$ |
68,811 |
|
|
$ |
84,300 |
|
|
Accrued cash call to operator
|
|
|
3,728,695 |
|
|
|
— |
|
|
Accrued expenses
|
|
|
190,288 |
|
|
|
185,597 |
|
|
Income taxes payable
|
|
|
21,139 |
|
|
|
27,074 |
|
|
TOTAL CURRENT LIABILITIES
|
|
|
4,008,933 |
|
|
|
296,971 |
|
| |
|
|
|
|
|
|
|
|
|
LONG-TERM LIABILITIES
|
|
|
|
|
|
|
|
|
|
Reserve for plugging and abandonment costs
|
|
|
7,596 |
|
|
|
41,419 |
|
|
Deferred rent obligation
|
|
|
— |
|
|
|
3,620 |
|
|
TOTAL LONG-TERM LIABILITIES
|
|
|
7,596 |
|
|
|
45,039 |
|
| |
|
|
|
|
|
|
|
|
|
COMMITMENTS AND CONTINGENCIES
|
|
|
— |
|
|
|
— |
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| |
|
|
|
|
|
|
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SHAREHOLDERS’ EQUITY
|
|
|
|
|
|
|
|
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Common stock, $0.001 par value; 100,000,000 shares authorized; 37,365,230 and 31,165,230 shares issued and outstanding, respectively
|
|
|
37,365 |
|
|
|
31,165 |
|
|
Additional paid-in capital
|
|
|
54,278,307 |
|
|
|
40,602,643 |
|
|
Retained earnings (accumulated deficit)
|
|
|
(35,114,427 |
) |
|
|
7,575,747 |
|
|
Accumulated other comprehensive income (loss)
|
|
|
(286,935 |
) |
|
|
106,371 |
|
|
TOTAL SHAREHOLDERS’ EQUITY
|
|
|
18,914,310 |
|
|
|
48,315,926 |
|
|
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY
|
|
$ |
22,930,839 |
|
|
$ |
48,657,936 |
|
The accompanying notes are an integral part of these unaudited consolidated financial statements.
HOUSTON AMERICAN ENERGY CORP.
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS
(Unaudited)
| |
|
Six Months Ended
June 30,
|
|
|
Three Months Ended
June 30,
|
|
| |
|
2012
|
|
|
2011
|
|
|
2012
|
|
|
2011
|
|
| |
|
|
|
|
|
|
|
|
|
|
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|
OIL AND GAS REVENUE
|
|
$ |
356,857 |
|
|
$ |
477,808 |
|
|
$ |
36,347 |
|
|
$ |
353,505 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
EXPENSES OF OPERATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expense and severance tax
|
|
|
158,648 |
|
|
|
321,464 |
|
|
|
19,047 |
|
|
|
193,562 |
|
|
Joint venture expenses
|
|
|
3,244 |
|
|
|
5,924 |
|
|
|
— |
|
|
|
3,164 |
|
|
General and administrative expense
|
|
|
3,113,187 |
|
|
|
2,747,468 |
|
|
|
2,032,339 |
|
|
|
1,572,374 |
|
|
Impairment of oil and gas properties
|
|
|
36,628,919 |
|
|
|
— |
|
|
|
16,633,074 |
|
|
|
— |
|
|
Loss (gain) on sale of oil and gas properties
|
|
|
(315,119 |
) |
|
|
179,595 |
|
|
|
— |
|
|
|
179,595 |
|
|
Depreciation and depletion
|
|
|
55,467 |
|
|
|
70,344 |
|
|
|
6,185 |
|
|
|
42,347 |
|
|
Total operating expenses
|
|
|
39,644,346 |
|
|
|
3,324,795 |
|
|
|
18,690,645 |
|
|
|
1,991,042 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
(39,287,489 |
) |
|
|
(2,846,987 |
) |
|
|
(18,654,298 |
) |
|
|
(1,637,537 |
) |
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER INCOME (EXPENSE)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
6,692 |
|
|
|
43,405 |
|
|
|
2,242 |
|
|
|
20,324 |
|
|
Other expense
|
|
|
(44,012 |
) |
|
|
(42,761 |
) |
|
|
(13,869 |
) |
|
|
(10 |
) |
|
Total other income (expense)
|
|
|
(37,320 |
) |
|
|
644 |
|
|
|
(11,627 |
) |
|
|
20,314 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss before taxes
|
|
|
(39,324,809 |
) |
|
|
(2,846,343 |
) |
|
|
(18,665,925 |
) |
|
|
(1,617,223 |
) |
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense
|
|
|
3,365,365 |
|
|
|
88,377 |
|
|
|
3,356,154 |
|
|
|
85,583 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss
|
|
$ |
(42,690,174 |
) |
|
$ |
(2,934,720 |
) |
|
$ |
(22,022,079 |
) |
|
$ |
(1,702,806 |
) |
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted loss per common share
|
|
$ |
(1.29 |
) |
|
$ |
(0.09 |
) |
|
$ |
(0.63 |
) |
|
$ |
(0.05 |
) |
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Based and diluted weighted average common shares outstanding
|
|
|
33,004,790 |
|
|
|
31,111,267 |
|
|
|
34,844,351 |
|
|
|
31,128,142 |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COMPREHENSIVE LOSS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss
|
|
$ |
(42,690,174 |
) |
|
$ |
(2,934,720 |
) |
|
$ |
(22,022,079 |
) |
|
$ |
(1,702,806 |
) |
|
Unrealized loss on marketable securities
|
|
|
(393,306 |
) |
|
|
— |
|
|
|
(159,548 |
) |
|
|
— |
|
|
Net comprehensive loss
|
|
$ |
(43,083,480 |
) |
|
$ |
(2,934,720 |
) |
|
$ |
(22,181,627 |
) |
|
$ |
(1,702,806 |
) |
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, 2012 AND 2011
(Unaudited)
| |
|
For the Six Months Ended June 30,
|
|
| |
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
Net loss
|
|
$
|
(42,690,174
|
)
|
|
$
|
(2,934,720
|
)
|
|
Adjustments to reconcile net loss to net cash used in operations:
|
|
|
|
|
|
|
|
|
|
Depreciation and depletion
|
|
|
55,467
|
|
|
|
70,344
|
|
|
Stock-based compensation
|
|
|
1,284,165
|
|
|
|
1,159,911
|
|
|
Impairment of oil and gas properties
|
|
|
36,628,919
|
|
|
|
—
|
|
|
Accretion of asset retirement obligation
|
|
|
648
|
|
|
|
5,664
|
|
|
Amortization of deferred rent
|
|
|
(3,620
|
)
|
|
|
(3,159
|
)
|
|
(Gain) loss on sale of oil and gas properties – Colombia
|
|
|
(315,119
|
)
|
|
|
179,595
|
|
|
Deferred tax asset
|
|
|
3,195,583
|
|
|
|
—
|
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
Decrease in accounts receivable
|
|
|
40,491
|
|
|
|
1,124,448
|
|
|
Increase in prepaid expense
|
|
|
(119,293
|
)
|
|
|
(78,003
|
)
|
|
Decrease in accounts payable and accrued liabilities
|
|
|
|
)
|
|
|
|
)
|
| |
|
|
|
|
|
|
|
|
|
Net cash used in operating activities
|
|
|
|
)
|
|
|
|
)
|
| |
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Payments for the acquisition and development of oil and gas properties
|
|
|
(14,866,511
|
)
|
|
|
(4,072,201
|
)
|
|
Proceeds from sale of Colombian oil and gas properties, net of expenses
|
|
|
1,027,068
|
|
|
|
—
|
|
|
Proceeds from escrow receivable
|
|
|
—
|
|
|
|
516,392
|
|
|
Purchase of marketable securities
|
|
|
|
)
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
|
)
|
|
|
|
)
|
| |
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Proceeds from sale of common stock, net of expenses of $746,300
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
Decrease in cash
|
|
|
(3,538,227
|
)
|
|
|
(7,858,895
|
)
|
|
Cash, beginning of period
|
|
|
|
|
|
|
|
|
|
Cash, end of period
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
|
SUPPLEMENTAL CASH FLOW INFORMATION
|
|
|
|
|
|
|
|
|
|
Interest paid
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Income taxes paid
|
|
$
|
172,246
|
|
|
$
|
3,893,126
|
|
| |
|
|
|
|
|
|
|
|
|
NON-CASH INVESTING AND FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Change in escrow receivable funds utilized to pay accrued taxes
|
|
$
|
—
|
|
|
$
|
1,144,285
|
|
|
Change in reserve for plugging and abandonment costs
|
|
$
|
—
|
|
|
$
|
9,532
|
|
|
Accrued oil and gas development cost
|
|
$
|
3,728,695
|
|
|
$
|
—
|
|
|
Sales price of oil and gas properties placed in escrow
|
|
$
|
166,995
|
|
|
$
|
—
|
|
|
Unrealized loss on available for sale securities
|
|
$
|
393,306
|
|
|
$
|
—
|
|
|
Cashless exercise of stock options
|
|
$
|
—
|
|
|
$
|
39
|
|
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, 2011.
Consolidation
The accompanying consolidated financial statements include all accounts of the Company and its subsidiaries (HAEC Louisiana 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 $9,103,398 in excess of the FDIC’s current insured limit on interest bearing accounts of $250,000 as of June 30, 2012. 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. Using the treasury stock method, outstanding ‘in-the-money’ options would have increased our diluted weighted average shares outstanding by approximately 92,551 and 351,691 shares, respectively, for the three and six months ended June 30, 2012 and by approximately 859,400 and 838,000 shares, respectively, for the three and six months ended June 30, 2011; 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, 2012 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 – ACCOUNTS RECEIVABLE – OTHER
Gulf United Energy, Inc.
In connection with the Company’s acquisition in July 2010 of an additional 12.5% interest in the approximately 345,452 acre CPO 4 Block in the Llanos Basin of Colombia and which is operated by SK Energy Co. LTD (“SK Energy”), the Company entered into a separate agreement with Gulf United Energy, Inc. (“Gulf United”) whereby the Company waived its right of first refusal under the CPO 4 Block Joint Operating Agreement for the specific purpose of permitting Gulf United to acquire from SK Energy a 12.5% interest in the CPO 4 Block. Under the agreement with Gulf United, as a condition of the Company’s agreement to waive its preferential rights, Gulf United agreed to pay to the Company, not later than 30 days following National Hydrocarbon Agency of Colombia (the “ANH”) approval, which is still pending and is expected to occur in 2012, (i) the Company’s 12.5% share of past costs (as defined in the Farmout Agreement with SK Energy) incurred through July 31, 2010, and (ii) the Company’s 25% share of seismic acquisition costs incurred through July 31, 2010, or a total of $3,951,423. The amount due from Gulf United is classified as accounts receivable – other in the accompanying balance sheet.
Hupecol Operating, LLC
During 2011, Hupecol Operating, LLC (“Hupecol”) disbursed funds from a 5% contingency escrow established with a portion of the proceeds from the sale of Hupecol Dorotea & Cabiona Holdings, LLC (“HDC, LLC”), to pay certain operating expenses incurred on behalf of the purchaser of these entities. Hupecol is currently seeking reimbursement from the purchaser for these expenses as part of the post-closing process and expects to collect within the next twelve months. As a result of this activity, the Company has established a receivable from Hupecol for the Company’s proportionate share of the escrow funds disbursed for these expenses of $370,639. The amount due from Hupecol is classified as accounts receivable – other in the accompanying balance sheet.
NOTE 3 – MARKETABLE SECURITIES – AVAILABLE FOR SALE
At June 30, 2012, the Company held common stock in a publicly traded company valued at $470,957, based on the closing market price per share. This investment is classified as marketable securities - available for sale and, accordingly, any unrealized changes in market values are recognized as other comprehensive income (loss) in the consolidated statements of operations. During the six months ended June 30, 2012, the Company purchased additional common shares in the same publicly traded company at a cost of $156,818 and recognized other comprehensive losses during the three and six months ended June 30, 2012 of $159,548 and $393,306, respectively, reflecting the unrealized decline in fair market value of this investment as of June 30, 2012.
NOTE 4 – OIL AND GAS PROPERTIES
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 on CPO 4 (the Zorro Gris), seismic expenses on CPO 4 and other expenses on unevaluated concessions in Colombia.
Our estimated drilling budget during the second half of 2012 is approximately $20.0 million, principally relating to the drilling of a third well (Zorro Gris) on the CPO 4 prospect, a future seismic acquisition program on CPO 4, a new Standby Letter of Credit on CPO 4 for our Phase II election which was made in July of 2012, as well as general and administrative and social and environmental costs associated with CPO 4.
Impairments
In April 2012, the Company, 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, the Company included the costs related to the Tamandua #1 well in the full cost pool for inclusion in the ceiling test. The Company recorded impairment charges of $6,531,455 and $26,527,300 during the three and six months ended June 30, 2012, respectively, to write off costs not being amortized that were attributable to the drilling of the Tamandua #1 well on the Company’s 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, the Company determined to plug and abandon the Cachirre #1 well on the CPO 4 prospect in Colombia. As a result of such determination, the Company included the costs related to the Cachirre #1 well in the full cost pool for inclusion in the ceiling test at June 30, 2012. The Company recorded an impairment charge of $10,101,619 during the three 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.
Sale of Oil and Gas Properties
During the first quarter of 2012, the Company sold all of its 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 its 1.6% ownership interest in HC, LLC, the Company 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, the Company had no continuing interest in the La Cuerva and LLA 62 blocks.
At December 31, 2011, the Company’s estimated proved reserves associated with the La Cuerva and LLA 62 blocks totaled 94,619 barrels of oil, which represented 82% of the Company’s estimated proved oil and natural gas reserves. Sales of oil and gas properties under the full cost method of accounting are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless the adjustment significantly alters the relationship between capitalized costs and reserves. Since the sale of these oil and gas properties would significantly alter the relationship, the Company recognized a gain on the sale of $315,119 during the six months ended June 30, 2012, computed as follows:
|
Sales price
|
|
$
|
1,224,393
|
|
|
Add: Transfer of asset retirement and other obligations
|
|
|
34,471
|
|
|
Less: Transaction costs
|
|
|
(30,330
|
)
|
|
Less: Prepaid deposits
|
|
|
(54,857
|
)
|
|
Less: Carrying value of oil and gas properties, net
|
|
|
|
)
|
|
Net gain on sale
|
|
$
|
315,119
|
|
The following table presents pro forma data that reflects revenue, income from continuing operations, net loss and loss per common share for the three and six months ended June 30, 2012 as if the HC, LLC sale had occurred at the beginning of each period and excludes the gain on sale.
|
Pro-Forma Information:
|
|
Three Months Ended
June 30, 2012
|
|
|
Six Months Ended
June 30, 2012
|
|
| |
|
|
|
|
|
|
|
Oil and gas revenue
|
|
$ |
36,347 |
|
|
$ |
93,672 |
|
|
Loss from operations
|
|
$ |
(18,654,298 |
) |
|
$ |
(39,701,581 |
) |
|
Net loss
|
|
$ |
(18,826,496 |
) |
|
$ |
(39,899,473 |
) |
| |
|
|
|
|
|
|
|
|
|
Basic and diluted loss per common share
|
|
$ |
(0.63 |
) |
|
$ |
(1.20 |
) |
The following table presents pro forma data that reflects revenue, income from continuing operations, net loss and loss per common share for the three and six months ended June 30, 2011 as if the HC, LLC sale had occurred at the beginning of each period and excludes the gain on sale.
|
Pro-Forma Information:
|
|
Three Months Ended
June 30, 2011
|
|
Six Months Ended
June 30, 2011
|
| |
|
|
|
|
|
|
|
|
|
Oil and gas revenue
|
|
$
|
97,132
|
|
|
$
|
160,693
|
|
|
Loss from operations
|
|
$
|
(2,588,583
|
)
|
|
$
|
(3,340,939
|
)
|
|
Net loss
|
|
$
|
(2,181,712
|
)
|
|
$
|
(2,913,337
|
)
|
| |
|
|
|
|
|
|
|
|
|
Basic and diluted loss per common share
|
|
$
|
(0.07
|
)
|
|
$
|
(0.09
|
)
|
The Company currently has operations in two geographical areas, the United States and Colombia. Revenues for the three and six months ended June 30, 2012 and 2011 and Long Lived Assets (net of depletion, amortization, and impairments) as of June 30, 2012 and December 31, 2011 attributable to each geographical area are presented below:
| |
|
Three Months Ended
June 30, 2012
Revenues
|
|
|
Six Months Ended
June 30, 2012
Revenues
|
|
|
As of June 30, 2012
Long Lived Assets
Net
|
|
| |
|
|
|
|
|
|
|
|
|
|
United States
|
|
$ |
36,347 |
|
|
$ |
93,671 |
|
|
$ |
1,015,506 |
|
|
Colombia
|
|
|
- |
|
|
|
263,186 |
|
|
|
3,832,635 |
|
|
Total
|
|
$ |
36,347 |
|
|
$ |
356,857 |
|
|
$ |
4,848,141 |
|
| |
|
Three Months Ended
June 30, 2011
Revenues
|
|
|
Six Months Ended
June 30, 2011
Revenues
|
|
|
As of Dec. 31, 2011
Long Lived Assets
Net
|
| |
|
|
|
|
|
|
|
|
|
United States
|
|
$ |
40,043 |
|
|
$ |
84,527 |
|
|
$ |
603,135 |
|
|
Colombia
|
|
|
313,462 |
|
|
|
393,281 |
|
|
|
23,192,745 |
|
|
Total
|
|
$ |
353,505 |
|
|
$ |
477,808 |
|
|
$ |
23,795,880 |
|
NOTE 5 – ESCROW RECEIVABLE
At June 30, 2012 and December 31, 2011, the Company’s balance sheet reflected the following escrow receivables relating to amounts held in escrow to fund post-closing adjustments with respect to the sale of various oil and gas properties previously held by the Company:
| |
|
Balance as of June 30, 2012
|
|
|
Description
|
|
Current
|
|
|
Noncurrent
|
|
|
Total
|
|
| |
|
|
|
|
|
|
|
|
|
|
Caracara Escrow
|
|
$
|
131,021
|
|
|
$
|
—
|
|
|
$
|
131,021
|
|
|
Tambaqui Escrow
|
|
|
31,500
|
|
|
|
—
|
|
|
|
31,500
|
|
|
HDC LLC & HL LLC 15% Escrow
|
|
|
1,664,581
|
|
|
|
1,664,581
|
|
|
|
3,329,162
|
|
|
HDC LLC & HL LLC 5% Contingency
|
|
|
36,231
|
|
|
|
—
|
|
|
|
36,231
|
|
|
HC LLC 5% Contingency
|
|
|
15,947
|
|
|
|
—
|
|
|
|
15,947
|
|
|
HC LLC 14.66% Escrow
|
|
|
151,048
|
|
|
|
—
|
|
|
|
151,048
|
|
|
TOTAL
|
|
$
|
2,030,328
|
|
|
$
|
1,664,581
|
|
|
$
|
3,694,909
|
|
| |
|
Balance as of December 31, 2011
|
|
|
Description
|
|
Current
|
|
|
Noncurrent
|
|
|
Total
|
|
| |
|
|
|
|
|
|
|
|
|
|
Caracara Escrow
|
|
$
|
131,021
|
|
|
$
|
—
|
|
|
$
|
131,021
|
|
|
Tambaqui Escrow
|
|
|
31,500
|
|
|
|
—
|
|
|
|
31,500
|
|
|
HDC LLC and HL LLC 15% Escrow
|
|
|
1,664,581
|
|
|
|
1,664,581
|
|
|
|
3,329,162
|
|
|
HDC LLC and HL LLC 5% Contingency
|
|
|
36,230
|
|
|
|
—
|
|
|
|
36,230
|
|
|
TOTAL
|
|
$
|
1,863,332
|
|
|
$
|
1,664,581
|
|
|
$
|
3,527,913
|
|
Changes in escrow receivables from December 31, 2011 to June 30, 2012 reflect the establishment of the HC LLC escrow receivable totaling $166,995. There were no settlements and releases relating to the escrow receivables during the six months ended June 30, 2012. As of June 30, 2012, the Company is not aware of any other claims by the purchasers of the Caracara assets or HDC, LLC, HL, LLC and HC, LLC that would further reduce the escrow receivables.
NOTE 6 – STOCK-BASED COMPENSATION EXPENSE
The Company periodically grants options to employees, directors and consultants under the Company’s 2005 Stock Option Plan (the “2005 Plan”) and the Company’s 2008 Equity Incentive Plan (the “2008 Equity Incentive Plan” and, together with the 2005 Plan, 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
A summary of stock option activity and related information for the six months ended June 30, 2012 is presented below:
| |
|
Options
|
|
|
Weighted Average Exercise Price
|
|
|
Aggregate Intrinsic Value
|
|
| |
|
|
|
|
|
|
|
|
|
|
Outstanding at January 1, 2012
|
|
|
1,833,582
|
|
|
$
|
7.02
|
|
|
|
|
|
|
Granted (1)
|
|
|
584,475
|
|
|
|
1.65
|
|
|
|
|
|
|
Exercised
|
|
|
—
|
|
|
|
—
|
|
|
|
|
|
|
Forfeited
|
|
|
—
|
|
|
|
—
|
|
|
|
|
|
|
Outstanding at June 30, 2012 (1)
|
|
|
2,418,057
|
|
|
$
|
5.72
|
|
|
$
|
—
|
|
|
Exercisable at June 30, 2012
|
|
|
1,893,677
|
|
|
$
|
5.59
|
|
|
$
|
—
|
|
|
(1)
|
Does not include 915,525 options subject to shareholder approval, which were granted on June 11, 2012 and which are described in more detail below.
|
On June 11, 2012, options to purchase an aggregate of 300,000 shares were granted to non-employee directors and options to purchase an aggregate of 1,200,000 shares were granted to employees.
The 300,000 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 $1.65 per share. Of those options, 155,475 are exercisable commencing 6 months from the date of grant and 144,525 are exercisable on and after shareholder approval of an amendment to the Company’s 2008 Equity Incentive Plan to increase the shares reserved under the plan to facilitate exercise. The option grants to non-employee directors, excluding grants that are subject to shareholder approval of amendment to the 2008 Equity Incentive Plan, were valued on the date of grant at $128,328 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 0.353%, (2) expected life in years of 2.83, (3) expected stock volatility of 84.6%, and (4) expected dividend yield of 1.21%. 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.
The 1,200,000 options granted to employees 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 the Company’s 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 with the following parameters: (1) risk-free interest rate of 0.353%, (2) expected life in years of 2.83, (3) expected stock volatility of 84.6%, and (4) expected dividend yield of 1.21%. 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.
During the three and six months ended June 30, 2012, the Company recognized $686,767 and $1,161,284, respectively, of stock compensation expense attributable to outstanding stock option grants, including current period grants and unamortized expense associated with prior period grants but excluding grants that remain subject to shareholder approval of amendment to the 2008 Equity Incentive Plan. As of June 30, 2012, total unrecognized stock-based compensation expense related to non-vested stock options, excluding grants that remain subject to shareholder approval of amendment to the 2008 Equity Incentive Plan, was $1,895,845. The unrecognized expense is expected to be recognized over a weighted average period of 1.76 years and the weighted average remaining contractual term of the outstanding options and exercisable options at June 30, 2012 is 7.06 years and 6.98 years, respectively.
Shares available for issuance under the Plans as of June 30, 2012 totaled 150,277. The Company’s board of directors adopted an amendment to the Company’s 2008 Equity Incentive Plan to increase the shares reserved thereunder by 1,800,000 shares. The amendment to the 2008 Equity Incentive Plan is subject to approval by the Company’s shareholders. 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.
Restricted Stock Activity
During 2011, the Company granted to officers an aggregate of 45,000 shares of restricted stock, which shares vest over a period of three years. The fair value of $743,400 was determined based on the fair market value of the shares on the date of grant. This value is being amortized over the vesting period and, during the three and six months ended June 30, 2012, $61,457 and $122,881, respectively, was amortized to expense. As of June 30, 2012, there was $484,844 of unrecognized compensation cost related to unvested restricted stock. The cost is expected to be recognized over a weighted average period of approximately 1.95 years.
Share-Based Compensation Expense
The following table reflects share-based compensation recorded by the Company for the three months ended June 30, 2012 and 2011:
| |
|
Three Months Ended
June 30,
|
|
| |
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
Share-based compensation expense included in general and administrative expense
|
|
$
|
748,224
|
|
|
$
|
567,421
|
|
|
Earnings per common share effect of share-based compensation expense – basic and diluted
|
|
$
|
(0.02)
|
|
|
$
|
(0.02)
|
|
The following table reflects share-based compensation recorded by the Company for the six months ended June 30, 2012 and 2011:
| |
|
Six Months Ended
June 30,
|
|
| |
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
Share-based compensation expense included in general and administrative expense
|
|
$
|
1,284,165
|
|
|
$
|
1,159,911
|
|
|
Earnings per common share effect of share-based compensation expense – basic and diluted
|
|
$
|
(0.04)
|
|
|
$
|
(0.04)
|
|
NOTE 7 – COMMON STOCK AND WARRANTS
On May 3, 2012, the Company entered into definitive agreements with certain institutional investors to sell, and on May 8, 2012 the Company sold, 6,200,000 units, with each unit consisting of one of the Company’s 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, had an estimated relative fair value of $3.76 million of the $13.14 million in total proceeds from the offering. The estimated warrants value was calculated using Black-Scholes pricing model with the following parameters; (1) risk-free interest rate of 0.252%, (2) expected life in years of 1.80, (3) expected stock volatility of 85.0%, and (4) expected divided yeild of 0.0. The warrants 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 the Company’s common shares on the NYSE Amex on May 2, 2012. As of June 30, 2012, the warrants had an intriasic value of $0.
NOTE 8 – COMMITMENTS AND CONTINGENCIES
Lease Commitment
The Company leases office facilities under an operating lease agreement that expires May 31, 2017. As of June 30, 2012, the lease agreement requires future payments as follows:
|
Year
|
|
Amount
|
|
|
2012
|
|
|
43,947 |
|
|
2013
|
|
|
89,054 |
|
|
2014
|
|
|
91,432 |
|
|
2015
|
|
|
93,793 |
|
|
2016
|
|
|
96,162 |
|
|
2017
|
|
|
40,479 |
|
|
Total
|
|
$ |
454,867 |
|
For the three and six months ended June 30, 2012, the total base rental expense was $21,751 and $43,725, respectively. The Company does not have any capital leases or other operating lease commitments.
Standby Letter of Credit – CPO 4 Block
On November 5, 2009, JP Morgan Chase issued a Letter of Credit to Banco de Bogota S.A. for $2,037,500. Banco de Bogota then in turn issued a Stand by Letter of Credit to the Agency De National Hydrocarbons to guarantee the Company’s compliance and proper execution of the work obligations relating to the phase one (1) work program of the CPO-4 block for the Company’s 25% interest in the block. Per the Standby Letter of Credit issued between JP Morgan Chase and Banco de Bogota, the Company was required to keep on deposit with JP Morgan Chase $2,037,500.
On December 2, 2010, JP Morgan Chase amended the Letter of Credit to Banco de Bogota S.A. to increase the total amount of the Letter of Credit to $3,056,250. Banco de Bogota then in turn issued an amended Stand by Letter of Credit to the Agency de National Hydrocarbons to guarantee the Company’s compliance and proper execution of the work obligations relating to the phase one (1) work program for the CPO-4 block for the Company’s 37.5% interest in the block. Per the amended Standby Letter of Credit issued between JP Morgan Chase and Banco de Bogota, the date of expiration was extended until January 18, 2013 and the Company is required to keep on deposit with JP Morgan Chase $3,056,250. This increase in deposits was related to the Company increasing its interest in the CPO-4 block from 25.0% to 37.5%.
On July 17, 2012, JP Morgan Chase amended the Letter of Credit to Banco de Bogota S.A. to extend the date of expiration to April 1, 2013. Banco de Bogota then in turn issued an amended Stand by Letter of Credit to the Agency de National Hydrocarbons to extend its existing Stand by Letter of Credit to April 1, 2013. The deposit with JP Morgan Chase is classified as restricted cash – letter of credit in the accompanying balance sheet. The Company paid Banco de Bogota and JP Morgan Chase $13,869 and $30,144 in fees, respectively, during the six months ended June 30, 2012 related to the Letter of Credit and recorded the fees as other expense. All other terms and conditions of the Letter of Credit remained unchanged.
Legal Contingencies
At June 30, 2012, the Company was the subject of a non-public formal investigation being conducted by the Securities and Exchange Commission (the “SEC”). Pursuant to the investigation, the Company received subpoenas issued by the SEC. The subpoenas called for the testimony of certain of the Company’s officers and the delivery of certain documents. The subpoenas were issued pursuant to a nonpublic formal order of private investigation issued by the SEC on March 1, 2011, which followed a nonpublic informal inquiry commenced by the SEC in October 2010. The Company received a copy of the nonpublic formal order of private investigation on February 10, 2012 in connection with a subpoena issued by the SEC. Although the Company cannot be certain of the scope of the investigation, the SEC is trying to determine whether there have been any violations of the federal securities laws. The investigation does not represent a conclusion by the staff that there have been any violations of the federal securities laws nor whether the staff would conclude that any enforcement action is appropriate. At this time, the Company has not been made aware of a finding by the SEC of any securities violations. Also, as stated in the subpoenas issued by the SEC, the investigation does not mean that the SEC has a negative opinion of any person, entity or security. The Company has cooperated fully, and is committed to continuing to cooperate fully, with the SEC in this matter. It is not possible at this time to predict the scope, timing or outcome of the SEC investigation, including whether or when any proceedings might be initiated, when these matters may be resolved or what, if any, penalties or other remedies may be imposed, and whether any such penalties or remedies would have a material adverse effect on the Company’s consolidated financial position, results of operations, or cash flows.
On April 27, 2012, a purported class action lawsuit was filed in the U.S. District Court for the Southern District of Texas against the Company and certain of its 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 suits have been filed, and may in the future be filed against the Company, 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. The Company believes all of the claims in the Silverman case are without merit and intends 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.
The Company is subject to legal proceedings, claims and liabilities that arise in the ordinary course of its business. The Company accrues for losses associated with legal claims when such losses are probable and can be reasonably estimated. These accruals are adjusted as further information develops or circumstances change. Except as noted above and in Note 10 - Subsequent Events, the Company is currently not a party to any known material litigation.
Tax Contingency
At June 30, 2012, the Company had engaged its tax advisors in Colombia to evaluate certain tax and other filings made in Colombia by other advisors for 2010 and 2011. The Company’s advisors identified inconsistencies between tax and non-tax filings with respect to equity investments made by the Company in Colombia during 2010. Based on guidance from the Company’s advisors, no liability or expense has been accrued with respect to the tax on equity investments. In the event that it is determined that a Colombian equity tax is due, the full amount of the Colombian tax is estimated at approximately $1.2 million.
Deferred income taxes are provided on a liability method whereby deferred tax assets and liabilities are established for the difference between the financial reporting and income tax basis of assets and liabilities as well as operating loss and tax credit carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized.
The Company has estimated that its effective tax rate for US purposes is (8.44)% for 2012. The Company reported income tax expense of $3,365,365 for the period ending June 30, 2012 of which $3,195,583 is attributable to the increase in the Company’s valuation allowance due to the uncertainty of realizing the benefit of all the Company’s deferred tax assets. The difference relates to cash taxes paid in Colombia. Income tax expense for 2011 was entirely attributable to the Company’s Colombian operations and represents the actual taxes paid or accrued in both Colombia and the United States.
At December 31, 2011, the Company had deferred tax assets of $4,310,769, of which $1,115,186 related to net operating losses. At March 31, 2012, management determined that a full valuation allowance should be placed against the deferred tax asset related to the net operating loss only, resulting in the reporting of a deferred tax asset of $3,195,583 at March 31, 2012. Due to unsuccessful drilling efforts in Colombia, management has re-evaluated the Company’s ability to fully utilize these deferred tax assets. As a result, management has determined that a full valuation allowance is required resulting in an estimated valuation allowance at June 30, 2012 of $17,450,000.
NOTE 10 – SUBSEQUENT EVENTS
In July 2012, the Company appointed a new non-employee director following the resignation of a non-employee director. In connection with the appointment, the Company granted stock options to purchase 25,000 shares of common stock at $1.18 per share with a fair value of 19,375.
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 the Company against certain of the 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 the Company.
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 26, 2012.
In July 2012, the Company determined to plug and abandon the Cachirre #1 well on the CPO 4 prospect in Colombia. As a result of such determination, the Company included the costs related to the Cachirre #1 well in the full cost pool for inclusion in the ceiling test at June 30, 2012. The Company recorded an impairment charge of $10,101,619 during the three 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 costs incurred on the well by the Company after the six months ended June 30, 2012.
In July 2012, the Company’s board authorized the engagement of an investment banking firm, and the Company 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 its oil and gas properties, seeking financial and/or industry partners to participate in the development of its properties, selling some of or all of the Company’s assets or interests in those assets, and the possible sale of the Company, among other alternatives.
|
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
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
|
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
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:
| |
|
|
|
|
|
|
|
|
|
|
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. 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 our first two wells on CPO 4 block (the Tamandua #1 and Cachirre #1), as well as the preparation for drilling our third well (the Zorro Gris) on CPO 4, seismic expenses on CPO 4 and other expenses on unevaluated concessions in Colombia.
Following delays and cost overruns in drilling our Tamandua #1 well, and the ultimate failure to complete Tamandua #1 as a commercial well, we lacked the necessary financial resources to fully fund our 2012 drilling budget. In May 2012, we completed the sale of shares of common stock and warrants that resulted in our receipt of approximately $12.5 million (net of placement fees and offering costs of $0.64 million) of additional cash. Notwithstanding the receipt of such funding, given the costs of drilling and testing and the subsequent failure to complete our Cachirre #1 well, we do not believe that we presently have adequate capital to fully fund the balance of our 2012 drilling budget. Our estimated drilling budget during the second half of 2012 is approximately $20.0 million, principally relating to the drilling of a third well (Zorro Gris) on the CPO 4 prospect, a future seismic acquisition program on CPO 4, a new Standby Letter of Credit on CPO 4 for our Phase II election which was made in July of 2012, as well as general and administrative and social and environmental cost associated with CPO 4. If, for any reason, we are unable to fully fund our drilling budget and fail to satisfy commitments reflected therein, including funding of our share of drilling and related cost on the third well of the CPO 4 prospect as well as our future seismic and other obligations, 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 and there is no guarantee that we will be able to secure additional financing on acceptable terms, or at all, to fully fund our 2012 drilling budget and to support future acquisitions and development activities.
Off-Balance Sheet Arrangements
We had no off-balance sheet arrangements or guarantees of third party obligations at June 30, 2012.
Inflation
We believe that inflation has not had a significant impact on operations since inception.
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Quantitative and Qualitative Disclosures About Market Risk
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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, 2012 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 effective as of June 30, 2012.
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, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
PART II – OTHER INFORMATION
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.
We expect to need additional financing to fund our drilling budget for the balance of 2012 and may need additional financing to support operations and future capital commitments.
At June 30, 2012, our estimated drilling budget for the balance of 2012 was approximately $20.0 million, principally relating to the drilling of a third well on the CPO 4 prospect, a future seismic acquisition program on CPO 4, a new Standby Letter of Credit for our Phase II election on CPO 4, as well as general and administrative and social and environmental cost associated with CPO 4. We do not believe that we presently have adequate capital to fully fund the balance of our 2012 drilling budget. If, for any reason, we are unable to fully fund our drilling budget and fail to satisfy commitments reflected therein, including funding of our share of drilling and related cost on the third well of the CPO 4 prospect as well as our future seismic and other obligations, 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 and there is no guarantee that we will be able to secure additional financing on acceptable terms, or at all, to fully fund our 2012 drilling budget and to support future acquisitions and development activities.
In July 2012, the Company’s board authorized the engagement of an investment banking firm, and the Company 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 its oil and gas properties, seeking financial and/or industry partners to participate in the development of its properties, selling some of or all of the Company’s assets or interests in those assets, and the possible sale of the Company, among other alternatives.
Exhibit
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Certification of CEO pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
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Certification of CFO pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
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Certification of CEO Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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Certification of CFO Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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101.INS
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XBRL Instance Document
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101.SCH
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XBRL Taxonomy Extension Schema Document
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101.CAL
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XBRL Taxonomy Extension Calculation Linkbase Document
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101.DEF
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XBRL Taxonomy Extension Definition Linkbase Document
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101.LAB
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XBRL Taxonomy Extension Label Linkbase Document
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101.PRE
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XBRL Taxonomy Extension Presentation Linkbase Document
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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.
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HOUSTON AMERICAN ENERGY CORP.
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Date: August 23, 2012
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By:
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/s/ John F. Terwilliger
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John Terwilliger
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CEO and President
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By:
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/s/ James J. Jacobs
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James J. Jacobs
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Chief Financial Officer
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