The War in Iran and Closure of the Strait of Hormuz Could Focus Greater Attention on Latin America’s Energy Prospects

3% — Only about 3% of Spain's LNG imports come from Qatar, and while a disruption to Qatar's Ras Laffan facilities is unlikely to cause global shortages, it will raise LNG and oil prices and increase import bills. Latin America (3% of global LNG exports) stands to gain: Argentina has record gas production and two FLNG projects (6 MTPA in H2 2027 and a 12 MTPA project targeting FID mid-2026), Mexico’s 3.2 MTPA Sempra ECA re-export terminal is due summer 2026, and the region could add ~700–800kb/d of oil supply in 2026. Elevated fuel and fertilizer costs will pressure importers, likely accelerating renewables, storage, and EV adoption (regional EV sales +~40% last year; 22% global passenger car share in 2024).

Analysis

The immediate market response will be driven by a marginal-cost shock to the LNG curve rather than physical scarcity: with liquefaction utilization already tight, any drop in Middle East flows raises the price of the marginal cargo and widens spot vs. contract spreads. That widens the revenue pool for traders and tolling/LNG marketing desks while increasing volatility in regas and power-supply hedges for utilities, creating short-term cashflow winners and balance-sheet pain for importers.

Second-order winners include owners of flexible liquefaction and re‑export capacity and LNG carriers — they capture both higher tolling fees and elevated charter rates; incumbents with deep trading desks and integrated downstream positions (large supermajors and Cheniere-style tollers) gain optionality. Losers are firms with fixed-price fuel costs, fertilizer producers with thin pass-through, and countries/companies reliant on inland pipeline arbitrage — they will see margin compression and politically driven subsidy risk.

Key catalysts and timelines: shipping and spot-price dislocations play out in days–months via charter rates and destination swaps; capacity relief from new FLNG/Latin American ramps is a months–years story and likely already priced only partially. Tail risks that could reverse the rally include rapid diplomatic de‑escalation, coordinated SPR releases or accelerated commissioning of non-Middle East liquefaction; regulatory/permit delays remain the main downside to the supply-relief narrative. The market currently underweights the speed of charter-rate feedback into upstream P&L (trading desks can monetize weeks, producers take months), so near-term volatility will favor market-makers and flexible capacity owners.

Key Decisions for Investors

• Long SHEL (Shell) equity, 6–12 month horizon: allocate 2–4% portfolio, target +20–30% upside if LNG spreads remain elevated and trading P&L beats; set a hard stop at -15% given cyclicality and refinery exposure.
• Buy Cheniere Energy (LNG) 6–9 month call spread (buy 1x 6–9 month ATM calls, sell nearer OTM) to express tolling optionality with defined downside — asymmetric payoff if spot-TOO (tolling) and Henry Hub–TTF spreads widen; R/R ~3:1 if spreads sustain.
• Accumulate Sempra (SRE) on pullbacks, 12–24 months: 3–5% position to capture terminal ramp and Californian regulatory optionality; upside +30–40% if export volumes materialize, downside -20% if FID/timing slips.
• Tactical long in LNG shipping (GLNG), 3–9 months to capture higher charter rates: small position size (1–2%) as a volatility play — expected alpha via spot TC increases, but high operational and maturity risk so use two-way hedges or calls.