Houston American Energy Corp. — FY 2011 Form 10-K
Filing identity: The request metadata names Abundia Global Impact Group, Inc., but the supplied filing is for Houston American Energy Corp. (NYSE Amex: HUSA). This summary reflects the filing text, which reports the fiscal year ended December 31, 2011, and includes fourth-quarter results.
Business context and reporting period
Houston American is a non-operating oil and gas exploration and production company with interests mainly in Colombia and the U.S. Gulf Coast. Its strategy is to acquire early-stage prospects, partner with larger operators, and periodically sell assets to redeploy capital. The December 2010 sale of interests in four Colombian concessions removed most of the company’s prior production base; 2011 spending focused principally on exploration, especially Colombia’s CPO 4 block.
Key financial and operating metrics
| Metric | FY 2011 | FY 2010 |
|---|---|---|
| Oil and gas revenue | $1.16 million | $19.51 million |
| Operating income (loss) | $(5.88) million | $30.31 million |
| Net income (loss) | $(4.34) million | $21.03 million |
| Basic loss / earnings per share | $(0.14) | $0.68 |
| Cash from operating activities | $(4.63) million | $8.29 million |
| Cash from investing activities | $(11.93) million | $12.66 million provided |
| Cash at year-end | $9.93 million | $26.66 million |
| Working capital | $19.64 million | $34.26 million |
| Total assets | $48.66 million | $55.48 million |
| Long-term liabilities | $45,039 | $26,761 |
Current liabilities were $297,000 at year-end 2011. The company reported no material funded debt; long-term liabilities mainly comprised plugging costs and deferred rent. The filing does not provide a meaningful operating margin comparison given the large 2010 asset-sale gain and the sharp change in the business following the divestiture.
Oil and gas production fell to 11,016 barrels of oil and 10,838 Mcf of gas in 2011, from 261,779 barrels and 17,798 Mcf in 2010. Average oil price increased to $101.12 per barrel from $74.18, while average U.S. gas price declined to $3.90 per Mcf from $5.01. Average production cost rose to $65.65 per BOE from $30.70, principally because lower Colombian volumes left fixed costs spread over less production.
At December 31, 2011, proved reserves were approximately 115,627 BOE, including 63,774 BOE of proved undeveloped reserves. The filing reports PV-10 of $3.89 million and a standardized measure of $3.05 million; these are reserve valuation measures, not balance-sheet cash or market value.
Material changes versus the prior comparable period
- Revenue dropped 94% year over year, primarily because the 2010 sale of Colombian properties removed assets that had generated most of the company’s production and revenue. The 2010 results included a $27.16 million gain on property sales; 2011 included a $1.03 million loss from post-closing adjustments.
- Net results changed from $21.03 million profit in 2010 to a $4.34 million loss in 2011. Operating cash flow also shifted from $8.29 million provided to $4.63 million used.
- Investments in oil and gas properties and assets totaled $13.28 million in 2011. Cash declined by $16.73 million during the year, while working capital fell by $14.62 million.
- Fourth-quarter 2011 revenue was $359,109 and net loss was $312,079, compared with fourth-quarter 2010 revenue of $2.28 million and net income of $18.06 million. The 2010 quarter included the property-sale gain.
Outlook, risks, contingencies, and unusual items
- Management’s 2012 acquisition and drilling budget was approximately $40.8 million, including approximately $40 million for CPO 4 activity. Management stated that available cash and anticipated 2012 operating cash flow were insufficient to fund the full budget; no financing commitments were in place. Failure to raise funds could require cuts to drilling plans and could risk penalties or loss of property interests.
- The Tamandua #1 sidetrack on CPO 4 encountered high-pressure drilling problems, tool failures, and stuck pipe. As of March 1, 2012, it had reached 15,562 feet and shown oil indications and resistive sands, but the lower zones could not be adequately tested. The operator planned further evaluation and a possible completion; commercial production was not established.
- For 2012, operators advised plans for additional drilling on CPO 4 and Hupecol properties, plus seismic work. Timing, selection, and costs are substantially controlled by third-party operators and may change.
- Gulf United owed approximately $3.95 million for CPO 4 past and seismic costs, contingent on Colombian agency approval of its assignment; approval and reimbursement remained pending at filing. The balance was recorded as a receivable.
- Approximately $3.53 million of sale-related escrow receivables remained at year-end, subject to post-closing claims and releases. The company recorded sale-related losses in 2011, including charges against escrow balances.
- Colombia is the principal operating exposure. Risks include political and security conditions, foreign regulation and tax, anti-corruption compliance, commodity-price volatility, environmental obligations, and dependence on non-operating partners. The company had no production hedges and sold production on spot markets.
- The company reported no material pending litigation and no off-balance-sheet arrangements. Its independent auditor issued an unqualified opinion on the financial statements and internal control over financial reporting; management also concluded disclosure controls were effective.
Important facts for investors to verify
- Confirm the issuer: the supplied 10-K is for Houston American Energy Corp., not the company named in the request metadata.
- Review the latest status and test results of Tamandua #1, and whether it achieved commercial production or required additional spending.
- Determine whether Houston American obtained financing for the 2012 budget, and how actual spending and drilling commitments compared with the plan.
- Verify collection of the Gulf United receivable and release or reduction of remaining transaction escrow balances.
- Assess reserve estimates, the proportion of proved undeveloped reserves, and the assumptions underlying PV-10 and standardized measure.
- Evaluate the continuing decline in production, operating cash flow, and liquidity following the asset sale, along with the company’s reliance on third-party operators and Colombia.