Business Context and Reporting Period
Company: GeoPark Limited (Bermuda-incorporated independent oil and natural gas E&P company).
Reporting Period: Fiscal year ended December 31, 2015.
Operations: Primary operations in Colombia (65% of production), Chile (19%), Brazil (16%), and Argentina (<1%). The company operates 33 hydrocarbon blocks, with 8 in production as of year-end. A pending acquisition of the Morona Block in Peru (75% working interest) is subject to regulatory approval.
Accounting Basis: International Financial Reporting Standards (IFRS).
Key Financial Metrics (Year Ended Dec 31, 2015)
| Metric | 2015 (US$ Thousands) | 2014 (US$ Thousands) |
|---|---|---|
| Net Revenue | 209,690 | 428,734 |
| Operating Loss | (232,491) | 71,844 |
| Net Loss | (284,566) | 15,930 |
| Net Loss Attributable to Owners | (234,031) | 8,085 |
| Adjusted EBITDA | 73,787 | 220,077 |
| Adjusted EBITDA Margin | 35.2% | 51.3% |
| Cash from Operating Activities | 25,895 | 230,746 |
| Cash and Cash Equivalents (Year-End) | 82,730 | 127,672 |
| Total Debt | 378,673 | 369,593 |
| Proved Reserves (Net) | 48.6 mmboe | 45.2 mmboe (implied) |
Note: Total debt includes US$343.2 million non-current and US$35.4 million current borrowings.
Material Changes vs. Prior Period
- Revenue Decline: Net revenue dropped 51% to US$209.7 million, driven by a 56% decrease in net oil sales (from US$367.1M to US$162.6M) due to the global oil price crisis (WTI/Brent fell >60% from Aug 2014 to Mar 2016).
- Impairment Charges: Recorded a significant impairment loss of US$149.6 million on non-financial assets in Chile and Colombia due to lower commodity prices affecting asset recoverability.
- Foreign Exchange Loss: Incurred a US$33.5 million foreign exchange loss, primarily US$35.6 million in the Brazilian subsidiary due to the devaluation of the Brazilian Real against the US Dollar on a US$70.5 million credit facility.
- Cost Reductions: Successfully reduced capital expenditures by 79% year-over-year. Production and operating costs fell 34%, and administrative/selling expenses dropped 39%.
- Production: Maintained average net production of 20,367 boepd despite the price environment, with Colombia contributing 65% of total production.
Guidance, Outlook, and Risks
2016 Capital Expenditure Scenarios
Management has developed three scenarios for 2016 CAPEX based on oil price assumptions:
- Base Case (US$35-40/bbl): US$45-55 million.
- Downside Case (US$25-30/bbl): US$20-25 million (focused on low-risk, quick cash flow projects).
- Upside Case (US$50+/bbl): US$75-90 million.
The company intends to fund these programs through cash flows from operations and cash on hand.
Key Risks and Contingencies
- Commodity Price Volatility: 77% of 2015 revenue was derived from oil. Sustained low prices threaten debt capacity and covenant compliance.
- Customer Concentration: In Chile, 100% of oil sales go to ENAP and nearly all gas sales to Methanex. In Colombia, sales are concentrated among Gunvor, Trafigura, and Petrominerales.
- Regulatory Approvals: The Morona Block acquisition in Peru (18.8 mmboe reserves) is subject to Peruvian government approval, with a deadline of June 30, 2016 (subject to extension).
- Legal Proceedings: The PN-T-597 Concession in Brazil is subject to an injunction and may not close due to legal challenges regarding unconventional resource exploration.
- Debt Covenants: The Notes due 2020 contain restrictive covenants. At current prices, the company does not anticipate achieving Adjusted EBITDA sufficient to incur additional financial indebtedness beyond permitted baskets.
Investor Verification Checklist
- Impairment Methodology: Verify the specific oil price scenarios and discount rates used to calculate the US$149.6 million impairment charge.
- Brazilian FX Exposure: Confirm the status of the US$70.5 million Itaú BBA credit facility and the impact of Real volatility on future debt service.
- Morona Block Timeline: Monitor the status of Peruvian regulatory approvals for the Morona Block acquisition, noting the June 2016 deadline and potential impact of Peruvian elections.
- Customer Contract Renewals: Track the renewal status of the ENAP oil sales agreement (effective June 2016) and the Methanex gas supply agreement (expires April 2017).
- Debt Covenant Compliance: Review the specific Adjusted EBITDA thresholds in the Notes due 2020 indenture to assess the risk of default or inability to borrow.
- Reserve Reclassification: Assess the risk of further reclassification of proved undeveloped reserves to non-proved status if development costs exceed economic viability under low price scenarios.