Business context and reporting period
Evolution Petroleum Corporation’s Form 10-K covers the fiscal year ended June 30, 2013, not calendar 2012 Q4. The company acquires and develops U.S. oil and gas properties, with its Delhi Field CO₂ enhanced-oil-recovery (EOR) royalty interest in Louisiana as its principal asset. Delhi supplied over 90% of revenue and approximately 98% of proved reserves.
Financial and operating highlights
| Metric | FY2013 | FY2012 |
|---|---|---|
| Revenue | $21.35 million | $17.96 million |
| Operating income | $10.70 million | $8.83 million |
| Net income attributable to company | $6.63 million | $5.13 million |
| Net income attributable to common shareholders | $5.95 million; diluted EPS $0.19 | $4.50 million; diluted EPS $0.14 |
| Cash provided by operations | $11.93 million | $10.38 million |
| Cash capital expenditures | $4.92 million | $7.06 million |
| Cash and cash equivalents at year-end | $24.93 million | $14.43 million |
| Working capital at year-end | $24.8 million | $11.7 million |
| Total liabilities | $11.72 million | $12.33 million |
Revenue grew 18.9%, reflecting 9% higher sales volume (226,819 BOE) and a 9% increase in average realized price per BOE to $94.13. Operating margin was approximately 50.1%, versus 49.2% in FY2012. General and administrative expense rose 22% to $7.50 million, partly due to higher legal, compensation, compliance, and asset-sale costs. Stock-based compensation was $1.53 million.
The company reported no funded debt and had an undrawn $5 million initial borrowing base under its unsecured credit facility. Total assets were $66.56 million and stockholders’ equity was $54.84 million. The 8.5% Series A preferred stock had a $7.93 million liquidation preference; $674,302 of preferred dividends were paid during FY2013. The filing reports no impairment under the full-cost ceiling test.
Proved reserves were 13.77 million BOE at June 30, 2013, up from 13.44 million BOE. Proved-reserve PV-10 was $459.0 million, versus $445.5 million; the GAAP standardized measure was $307.2 million. These reserve valuation measures are not market value. Proved reserves increased mainly from a 2.81 million BOE upward revision at Delhi, partly offset by production and the sale of 2.25 million BOE of Giddings reserves. Proved developed reserves rose to 73% of proved reserves from 60%.
Material changes and unusual items
- Delhi annual sales increased 33% to 180,658 barrels net to the company, although the average Delhi price declined 4.4% to $106.38 per barrel. Delhi’s higher sales offset divestitures and declining volumes from other properties.
- The company sold most non-GARP Giddings assets, receiving approximately $3.5 million in proceeds and retaining certain royalty and back-in interests. It also began a process to monetize its Lopez Field asset.
- In the Mississippian Lime joint venture, the first two horizontal wells produced substantially less oil and gas than expected. The company reduced its interest in undeveloped leases from 45% to approximately 33.9%, extinguishing a $1.2 million remaining leasehold obligation. Assigned probable reserves fell to 3.3 million BOE from 6.4 million BOE.
- Fiscal Q4 revenue was $5.40 million and net income available to common shareholders was $944,012, compared with $6.01 million and $2.23 million, respectively, in Q3. The filing attributes the lower Q4 result partly to lower Delhi revenue, asset-sale tax effects, and higher G&A.
- Delhi proved reserves were estimated at 13.55 million BOE with PV-10 of $455.3 million. The report assumes the company’s 23.9% reversionary working interest becomes effective around January 1, 2014; after reversion, its net revenue interest is expected to increase from 7.4% to 26.5%, alongside responsibility for its share of costs.
Outlook, risks, and contingencies
Management expected FY2014 capital expenditures of at least $18 million, including approximately $17 million for Delhi, subject to the working-interest reversion and development timing. The company expected to fund its base plan from working capital and operating cash flow. GARP-related spending was expected to be $1–3 million; Mississippian Lime spending depended on recompletion results, a possible third evaluation well, and partner participation.
A June 2013 environmental release at Delhi led the operator to suspend CO₂ injection in part of the field. Gross production fell from roughly 7,500 barrels per day to approximately 5,500–6,000 barrels per day; the operator expected injection to resume in the affected area in calendar Q4 2013, followed by a gradual production recovery. The operator estimated remediation costs of at least $70 million. Evolution stated it was not then a working-interest owner and was not bearing those costs, but its royalty revenue was affected and the reversion date could be delayed. Management did not expect a material impact on ultimate field recoveries, but timing and costs remained uncertain.
Key risks include dependence on Delhi and on operators the company does not control; volatile oil and gas prices; reserve-estimation uncertainty; operational, environmental, regulatory, and financing risks; and the uncertain commercial adoption of GARP. Plains Marketing accounted for 90% of FY2013 revenue. The company disclosed pending Delhi-related litigation: the Jones lawsuit, for which counsel assessed loss risk as remote, and an amended McCarthy claim. A separate Texas lease dispute had a $67,000 settlement, with execution pending. Management reported effective disclosure controls and internal control over financial reporting; the auditor issued unqualified opinions on the financial statements and internal controls.
Investor facts to verify
- Whether Delhi CO₂ injection resumed as anticipated, the production recovery achieved, final remediation costs, and any effect on Evolution’s revenue or working-interest reversion date.
- Whether the Delhi deemed payout and reversion occurred, and the resulting net cash flow after Evolution began bearing working and capital costs.
- Updated independent reserve estimates, development assumptions, and the sensitivity of PV-10 and the standardized measure to prices, costs, and timing.
- Results of the Mississippian Lime recompletion and any subsequent well, plus the joint venture’s remaining obligations and partner funding.
- Progress and economics of GARP commercialization and the Lopez asset monetization.
- Developments in the Jones and McCarthy lawsuits, preferred dividend payments, and any use of the company’s credit facility or shelf registration.