Eni S.p.A.

Strong Q3 performance + cash generation; upstream growth raised - E&P production +4.2% in the quarter; pro forma EBIT EUR 4.6bn for E&P. - Cash flow momentum: CFFO before working capital EUR 4.3bn (broadly in line with Q2; ~+30% YoY). - Balance sheet improvement: gearing 10% reported / 9% pro forma, at the bottom end of 10–15% and record low. - Full-year 2026 outlook (upstream): raised underlying production guidance to +6–7% (growth sources highlighted: Congo, Libya, Côte d’Ivoire, Mexico, Ghana, plus Searah in Indonesia/Malaysia), despite Middle East operating complexity and Kazakh export constraints.

Exploration & development “step change” in resource additions (value-led, not just volume) - Exploration success: resources >1.2 billion barrels, technical success rate 80%, commercial success rate 70%, with discovery cost < $1/bbl (notable/rare). - Value acceleration: through dual exploration valorization (Côte d’Ivoire + Indonesia), Eni cited ~$2bn accelerated value. - Project pipeline & FIDs locking growth (key examples): Baleine Phase 3 (Côte d’Ivoire), Kutai North & Gendalo (Indonesia), Cronos (Cyprus), Greater PAJ (Angola). - Governed by “hubs” approach: management emphasized multiple growth engines globally; ~4.6bn BOE of additional equity resource from new access/opportunities in 2026 (with Venezuela/Argentina major contributors).

Venezuela (Junín 5) + Perla LNG: upside potential, but still timing/capital-light at first - Junín 5 phased ramp (questioned but clarified): - ~200,000 bpd: expected in 18–24 months after the new contractual regime and development approvals; possibility of FID-driven acceleration mentioned (potentially even before year-end). - ~400,000 bpd by end-2029. - Potential ~1 million bpd mid/2032–2033 (big upside, but requires logistics and major build-out over time). - Technical reality (heavy oil + diluents): Eni cited use of Perla condensate synergies and other Venezuela liquids (Corocoro) to support extraction. - Perla export facility: submitted development plan with domestic debottlenecking (+90 MMscfd) then floating LNG ~3.4–3.5 mtpa; post-FID lead time ~3.5 years; FID depends on government plan approvals. - Investor takeaway: very large long-term optionality; near-term capex expected to be “low intensity” by using spare capacity before scaling (but Eni did not give hard total capex numbers yet).