NewMed Energy - Limited Partnership (DKDRF) Q4 2025 Earnings Call Transcript

NewMed reported Q4 production just under 1.1 Bcf/d (2.8 Bcm) and averaged ~1.06 Bcf/d (10.9 Bcm) in 2025. Operations are currently closed due to the regional war, though management expects to resume activity soon. The company completed the third Leviathan gathering line on time and under budget, raising potential capacity to ~1.4–1.45 Bcf/d (≈14–15 Bcm/yr).

Analysis

The recent regional disruption creates a multi-horizon supply shock where near-term price signaling and contract behavior will diverge sharply from longer-term capacity dynamics. In the first 30–90 days expect buyers to draw on short-term LNG and pipeline swaps, pushing spot spreads and freight rates higher while fixed offtake nominations and tolling mechanics compress realized margins for those with limited destination flexibility.

Medium-term (3–12 months) the incremental deliverability from completed upstream/infrastructure work materially increases optionality on exports, but that optionality is subject to operational gating (insurance, port acceptances, vessel availability) that typically lags mechanical completion by weeks to months. This creates a window where incremental throughput exists on paper but is monetizable only at a premium — an attractive environment for counterparties who can offer quick logistics or flexible cargo nominations.

Key catalysts to watch that will flip the trade: government clearances and cargo insurance reinstatements are binary and can restore full revenue run-rates rapidly, while renewed regional hostilities or protracted insurance disputes would elongate the premium regime. Counterparty and lender behavior is the overlooked vector — covenant waivers or force majeure claims could shift cash flow timing and create asymmetric payout profiles for equity vs. debt holders, making capital structure plays particularly actionable.

Key Decisions for Investors

• Long CHeniere Energy (LNG) — 6–12 month horizon. Buy outright or buy-call spread to limit premium. Rationale: captures higher global LNG spreads and destination-flex optionality. Position sizing: 2–4% portfolio; stop-loss 20%. Target: 25–40% upside if premium persists; downside: 30%+ if regional flows normalize quickly.
• Pair trade: Long ENI (E) / Short ENGIE (ENGI.PA) — 3–9 month horizon. Rationale: integrated E&P benefit from margin capture and rerouted volumes; utilities with regulated/short exposures suffer margin squeeze. Size: 1.5:1 long/short exposure; stop-loss 15% on pair marked-to-market. Expected asymmetry: 20–35% net upside if spreads remain elevated.
• Long LNG shipping exposure via Frontline (FRO) — 3–6 months. Rationale: higher demand for prompt tonnage and longer voyage distances lifts charter rates before onshore throughput normalizes. Keep small tactical allocation (1–2%); use 10–20% trailing stop. Reward: charter-rate-driven equity uplift of 30%+ in tight market; risk: rapid destocking reduces voyages and rates.
• Event hedge: Buy short-dated out-of-the-money puts on regional midstream credits or senior bonds (select names) — 1–3 month horizon. Rationale: asymmetric protection against enforcement/waiver risk and cash-flow delays; low cost if purchased ahead of catalyst windows. Target protection equal to 50–75% of exposure; cost budget 0.5–1% of portfolio.