Business Context and Reporting Period
Company: GeoPark Limited (Bermuda-incorporated, NYSE-listed)
Reporting Period: Fiscal year ended December 31, 2016
Operations: Independent oil and natural gas exploration and production (E&P) company operating in Colombia, Chile, Brazil, Peru, and Argentina.
Accounting Basis: International Financial Reporting Standards (IFRS).
Key Context: The company operated in a low oil price environment following the 2014 price crash. Management implemented significant cost reduction initiatives and reduced capital expenditures to preserve cash. The company recorded a net loss for the year, though significantly improved compared to the prior year due to the reversal of a large impairment charge.
Key Financial Metrics
| Metric (in thousands USD) | 2016 | 2015 |
|---|---|---|
| Net Revenue | 192,670 | 209,690 |
| Operating Loss | (28,613) | (232,491) |
| Net Loss | (60,646) | (284,566) |
| Net Loss Attributable to Owners | (49,092) | (234,031) |
| Adjusted EBITDA | 78,321 | 73,787 |
| Adjusted EBITDA Margin | 40.6% | 35.2% |
| Cash Flow from Operations | 82,884 | 25,895 |
| Cash and Cash Equivalents (Year End) | 73,563 | 82,730 |
| Total Debt Outstanding | 358,672 | 378,673 |
| Proved Reserves (mmboe) | 73.6 | 62.6 |
| Average Net Production (boepd) | 22,394 | 20,367 |
Material Changes vs. Prior Period
- Revenue: Decreased 8% to $192.7 million, driven primarily by lower realized oil prices (average $25.6/bbl in 2016 vs. $32.1/bbl in 2015), partially offset by a 10% increase in production volumes.
- Profitability: Net loss attributable to owners improved significantly by 79% to $49.1 million. This improvement was largely due to a $5.7 million reversal of impairment losses in 2016, compared to a $149.6 million impairment charge in 2015.
- Costs: Production and operating costs decreased 22% to $67.2 million due to cost reduction initiatives. Administrative expenses fell 9% to $34.2 million.
- Foreign Exchange: Recorded a foreign exchange gain of $13.9 million in 2016, a reversal from a $33.5 million loss in 2015, primarily due to the appreciation of the Brazilian Real against the US dollar on net debt.
- Capital Expenditures: Reduced to $39.3 million in 2016 from $48.8 million in 2015, reflecting a disciplined approach to capital allocation in a low-price environment.
Guidance, Outlook, and Risks
2017 Strategy and Outlook
- Capital Program: Preliminary base capital program for 2017 is estimated at $80–$90 million, assuming oil prices of $45–$50 per barrel.
- Colombia: $60–$65 million (Focus: Llanos 34 Block development).
- Chile: $10–$12 million (Focus: Gas growth and optimization).
- Brazil: $5–$7 million (Focus: Exploration drilling).
- Argentina: $5–$7 million (Focus: Exploration drilling).
- Scenarios: Management has developed downside scenarios ($50–$60 million capex) for oil prices below $40/bbl and upside scenarios ($110–$120 million capex) for prices above $50/bbl.
- Hedging: Entered into zero-premium collar derivatives in late 2016 to manage oil price exposure.
Key Risks and Contingencies
- Commodity Prices: Significant exposure to oil and natural gas price volatility; 75% of revenue is derived from oil.
- Customer Concentration: High reliance on key customers: Trafigura (59% of revenue), ENAP (10%), and Methanex (9%).
- Debt Covenants: The company did not meet the incurrence test covenants (Debt/EBITDA and EBITDA/Interest ratios) in its Notes due 2020 indenture due to low oil prices. While this does not trigger a default, it restricts the ability to incur additional indebtedness or pay dividends.
- Operational Risks: Infrastructure constraints (pipelines in Peru and Colombia), political risks in operating countries (Brazil, Colombia, Argentina), and the need to replace depleting reserves.
- Legal Proceedings: Ongoing litigation regarding the PN-T-597 Concession Agreement in Brazil, which is subject to an injunction.
Investor Verification Checklist
- Debt Covenant Compliance: Verify the current status of the Debt/EBITDA and Interest Coverage ratios relative to the Notes due 2020 indenture restrictions.
- Customer Contract Renewals: Confirm the status of negotiations with ENAP (Chile oil) and Methanex (Chile gas), as contracts were expiring or being renegotiated in early 2017.
- Capital Expenditure Execution: Monitor actual 2017 capital spending against the $80–$90 million base scenario to ensure alignment with cash flow generation.
- Reserve Replacement: Review the success rate of exploration drilling in Colombia (Llanos 34) and new blocks in Argentina and Brazil to ensure reserve life is maintained.
- Brazilian Operations: Assess the impact of the Brazilian economic slowdown and the "Lava Jato" corruption investigations on the Manati Field operations and Petrobras relationship.