Ecopetrol (EC) Q1 2025 Earnings Call Transcript

Ecopetrol reported Q1 EBITDA of COP 13.3 trillion and net income of COP 3.1 trillion, while producing 745,000 boe/d (highest Colombian crude output in five years) and holding COP 17 trillion in cash with COP 1.4 trillion free cash flow. Downstream was weak: refining throughput fell ~7% and downstream EBITDA dropped 67%; group lifting cost averaged $11.25/bbl and management targets < $12 for 2025. Material risks include a DIAN VAT retroactive claim of COP 9.4 trillion (administrative/legal review) and a COP 3.6 trillion prospective VAT payment in 2025 that is ~93% expected to be recoverable; management has $500m of CapEx flexibility and diesel/FX hedges to mitigate lower Brent scenarios.

Analysis

VAT reclassification and the government receivable dynamics are not just a one-off cash item — they create a durable working-capital profile change: Ecopetrol will sit on larger tax-credit receivables that amplify short-term liquidity sensitivity to government timing and repo markets. Management’s use of TES repo to monetize receipts is an explicit signal they will continue to trade receivables into short-term funding when necessary, raising rollover risk if repo markets tighten or if political timing delays tranche receipts.

ISA’s contribution is a double-edged structural hedge: it materially lowers earnings volatility but also produces a consolidated leverage metric that looks worse to rating agencies than Ecopetrol’s underlying cash generation justifies. Expect episodic negative rating action driven by methodology rather than economics — that makes credit instruments asymmetric (higher spread moves than fundamentals warrant) on bad news.

Operationally, the company’s expansion in offshore pre-salt and the Permian raises medium-term reserve quality but materially increases contractor and FPSO execution risk and capital intensity into 2027–2030; any delay or cost inflation will disproportionately hit free cash flow in the years before new volumes come online. Conversely, the combination of regulated midstream/transmission cash flow and contracted regasification exposure creates a natural hedge to oil-price declines, compressing downside for equity but capping upside vs pure-play explorers.

Market consensus is fixated on headline VAT and short-term refining weakness; it's underestimating the optionality embedded in partner divestitures (Shell) and ISA-driven diversification. That optionality — asset swaps, bolt-on M&A funded at attractive rates if the market over-reacts — is the contrarian engine that makes selective, hedged long exposure attractive through the next 12–24 months.

Key Decisions for Investors

• Long EC equity with a funded hedge (12–18 month horizon): Buy EC on a disciplined pullback (target: allocate 3–6% of long book). Hedge with a 9–12 month 10–15% OTM put or put-spread financed by selling 3–6 month covered calls; objective R/R ~2:1 (capped short-term upside in exchange for low-cost downside protection). Rationale: secures upside from reserve/M&A optionality while limiting near-term VAT/legal downside.
• Credit trade — buy senior Ecopetrol bonds vs CDS protection (6–24 months): add selective IG/BB bonds showing >150bp spread widening vs pre-claim levels and hedge 20–30% notional with CDS or short sovereign bonds. Reward: carry + tightening if legal risk resolves favorably; Tail risk: adverse DIAN ruling or rating action could widen spreads 200–400bp.
• Relative-value pair: long EC equity / short a pure international integrated (e.g., SHEL) (3–12 months): target a reversion of 5–15% in relative performance if local diversification and FEPC/tariff mechanics outperform. This isolates upside from domestic regulated cash flows and potential asset reallocation following partner exits while short consolidator caps crude upside exposure.
• Event-driven option: buy 12–24 month call spreads on EC ahead of key milestones (partner divestiture resolution, regasification commercial launch, reserve booking). Structure as debit call spread to cap premium; if milestones occur, expect outsized equity re-rating; if not, loss limited to premium paid.
• Liquidity-fragility hedge: reduce unhedged long-cycle upstream exposure elsewhere and rotate into midstream/transmission-like cash generators (instrument selection: regulated utilities/transmission peers or ISA exposure if available) for 6–18 months to protect portfolio cash flow against areal VAT/refund timing shocks.