Evolution Petroleum Corporation — FY2018 Form 10-K Summary
Reporting period: Fiscal year ended June 30, 2018 (with selected fourth-quarter results for the three months ended June 30, 2018). This is not a calendar-year 2017 filing. The company is an oil and gas producer pursuing a sustainable dividend and growth primarily through acquisitions and selective development. Its sole producing asset is its interest in the Delhi CO₂ enhanced-oil-recovery field in Louisiana.
Financial and operating performance
| Metric | FY2018 | FY2017 |
|---|---|---|
| Revenue | $41.3 million | $34.5 million |
| Operating income | $16.2 million | $12.9 million |
| Net income attributable to company | $19.6 million | $8.0 million |
| Net income attributable to common shareholders | $19.6 million; $0.59 per diluted share | $6.8 million; $0.21 per diluted share |
| Cash provided by operating activities | $20.5 million | $16.5 million |
| Capital expenditures incurred | $5.4 million | $7.6 million |
| Common dividends paid | $11.6 million | $8.4 million |
- Revenue rose 20%, mainly because average realized price increased 23% to $55.39 per BOE; sales volumes fell 3% to 745,297 BOE. Oil averaged $58.52 per barrel and NGLs $33.50 per barrel.
- Operating margin was approximately 39% of revenue, versus 37% in FY2017. FY2018 net income included a one-time, non-cash tax benefit of about $6.1 million from federal tax-rate changes; reported income tax benefit was $3.4 million. The effective tax rate excluding the discrete deferred-tax adjustment was approximately 16%.
- Production costs increased 13% to $12.2 million, or $16.36 per BOE versus $14.10. Higher CO₂ and NGL-plant operating costs contributed.
- At June 30, cash and cash equivalents were $24.9 million, plus $2.8 million of restricted cash; working capital was $27.7 million. Total liabilities were $16.4 million and stockholders’ equity was $77.3 million.
- The company had no borrowings under its credit facility, with a $40 million borrowing base available at year-end. The facility was extended to April 2021; the company reported covenant compliance.
- Proved reserves were 9.4 million BOE, down 7%; probable reserves were 4.5 million BOE, down 15%; possible reserves were 4.6 million BOE, up 42%. Proved-reserve standardized measure increased to $119 million from $83 million, while PV-10 was $146 million. These reserve-value measures are not estimates of market value.
Changes, outlook, and notable items
- Higher commodity prices lifted revenue despite lower total volumes. Proved reserve value increased primarily with higher pricing; lower-than-expected NGL plant performance reduced estimated NGL reserves.
- The twelve-well infill program, comprising eight producer wells and four CO₂ injection wells, began in March 2018. Three producers and one injector were online by year-end. The company expected the remaining wells to be completed by October 2018 and anticipated an oil-volume uplift over subsequent quarters. Estimated total company cost was about $4.7 million, with approximately $1.9 million remaining after year-end.
- Management expected Phase V development in Delhi’s eastern area to proceed, subject to oil prices and the operator’s capital allocation. Approximately $10.9 million of future development costs were associated with Phase V proved undeveloped reserves; the company expected the project within the next two fiscal years.
- Management said FY2019 capital needs were expected to be funded from working capital and operating cash flow. It stated a preference to remain debt-free, while retaining borrowing capacity. No derivative positions were outstanding at June 30, 2018.
- The quarterly common dividend was increased to $0.10 per share in March 2018, equivalent to $0.40 annually at that rate. A further $0.10 dividend was declared in August for payment in September. Future dividends remain discretionary and subject to financial condition, capital needs, and debt covenants.
- CEO Randy Keys retired on May 31, 2018. Chairman Robert Herlin became interim CEO while the board searched for a permanent successor.
- The company’s May 2018 stalking-horse agreement to acquire certain Enduro assets for $27.5 million did not close after a higher bidder emerged. The $2.75 million deposit was returned, and the company received a $1.1 million break-up fee in August 2018; $0.4 million of related due-diligence expense had been recorded in FY2018.
- Key risks include dependence on Delhi for substantially all revenue, lack of operational control, reliance on Denbury as operator, oil-price volatility, and customer concentration: Plains Marketing accounted for 92% of FY2018 oil and NGL revenue. The filing also describes CO₂ supply, operating and environmental risks and uncertainty in reserve estimates.
Important facts for investors to verify
- Whether the infill wells delivered the forecast production and recovery uplift, and whether Phase V proceeds on the expected timetable and budget.
- Delhi operating performance, CO₂ injection volumes, NGL plant output and costs, and the operator’s financial and capital-spending capacity.
- How much of FY2018 earnings and the increase over FY2017 reflects the one-time tax benefit rather than recurring operations.
- Whether commodity prices and realized differentials support operating cash flow, planned capital investment, and the dividend.
- Availability and terms of the $40 million borrowing base after redetermination, covenant headroom, and any material change in customer or pipeline arrangements.
- Reserve revisions and the assumptions underlying proved reserves, standardized measure, and PV-10; the filing cautions that these are estimates and not market-value measures.