Middle East energy: a transition under fire

Oil and gas still dominate power capacity at roughly 20% (oil) and 64% (gas) in 2025, with gas producing ~71% of electricity and oil ~23%; oil-fired capacity is forecast to fall to ~10% by 2035 while gas remains ~65% of generation. Renewables are growing from a 6% generation base in 2025 to ~21% by 2035 (38% of capacity), with solar expected to reach ~33% of installed capacity and ~18% of generation; 2026–2030 shows ~86GW of thermal build versus 10.8GW decommissioned. Geopolitical disruption (Iran conflict) has caused acute emissions shocks (>5m tonnes CO2) and supply outages, raising near-term commodity value and delivery risk for storage (Saudi ~48GWh by 2030 target), CCUS (4.8mtpa today to ~30mtpa by 2030) and rapidly expanding hydrogen projects (c.48% annual capacity growth to 2030).

Analysis

The region is evolving into a bifurcated market where episodic shocks raise the price of reliability services faster than headline renewable capacity expands; that increases the value of assets and contractors that deliver dispatchable power, grid firming and extreme-environment engineering rather than pure generation nameplates. Financing and insurance will re-price projects with higher perceived delivery risk, shifting capital toward projects with contracted cashflows or sovereign/backstop guarantees — expect credit spreads on merchant projects and project bonds to widen ahead of construction milestones. Contractors and technology providers that can demonstrate performance under high heat, dust and long-duration duty cycles will capture outsized margins as developers pay premiums to de-risk integration.

Second-order supply-chain winners are likely to be power-electronics, thermal-management and HVDC/inverter specialists, plus upstream miners of copper and nickel used in robust chemistries and cooling infrastructure; conversely, pure-play OEMs built for temperate climates and oil-export logistics providers face retrofit costs and demand volatility. Concentration risk in nascent CCUS and hydrogen projects creates a binary financing outcome: a few large winners if permitting and incentives materialize, or large write-offs if delivery stalls — underwriters will price that binary accordingly, amplifying equity volatility. Geopolitical tail events will intermittently revalue export-focused players versus those pivoting to domestic contracted-offtake, altering free cash flow trajectories on multi-year timelines.

Key catalysts and reversal paths are political: rapid de-escalation or targeted sanctions relief could compress risk premia and re-open export markets within weeks, while protracted instability will lift demand for resilient infrastructure and defense spending over years. Technological/market catalysts that would reverse the need for gas-anchored systems include a step-change in low-cost, long-duration storage or scalable CCUS commercialisation; absent that, expect structural allocation shifts toward grid firming and project-backed capacity. Monitor project-level permits, sovereign guarantee announcements, and insurance rate moves as high-frequency indicators of investment momentum and delivery risk.

Key Decisions for Investors

• Long ABB (ABB) — buy equity or 9–12 month call spread (buy 1x 12m $30 call, sell 1x 12m $40 call). Rationale: exposure to power-electronics, inverters and thermal-management systems needed for harsh environments; target 30–50% upside if regional grid builds accelerate. Risk: order deferrals and currency/sovereign payment delays; stop-loss at -18% from entry.
• Long AES (AES) — enter 18–36 month position via buy-and-hold or 2y call calendar to capture storage growth. Rationale: merchant/contracted storage operator with optionality on long-duration projects; asymmetric payoff if financing tightens for new entrants. Risk/reward: 2:1 upside vs downside where project underperformance or rate rises compress valuations.
• Pair trade: Long Siemens/ABB-like grid exposure (SIEGY/ABB) vs Short XOM — 6–18 month horizon, 1:1 notional. Rationale: relative performance trade betting integration and grid spend re-rate vs integrated oil sensitivity to episodic price swings; expected positive carry if renewables integration drives durable capex. Tail risk: sustained oil rally benefits XOM and blows out pair — hedge with short-dated calls on the short leg.
• Tactical hedge: Long RTX (RTX) 3–6 month OTM calls (small sizing). Rationale: insurance against escalation-driven infrastructure and defense spend spikes that also disrupt energy flows. Keep position size <2% portfolio; premium lost is the primary downside if no escalation occurs.