Exclusive: Saudi Aramco reducing output at two oilfields, two sources say

Brent crude has jumped to nearly $120/bbl (highest since mid‑2022) as regional disruptions choke the Strait of Hormuz; Aramco has begun cutting output at two undisclosed fields and is rerouting volumes to Yanbu. Iraq's main southern fields are down ~70% due to storage constraints, while Kuwait, Qatar, UAE and Bahrain have cut output or declared force majeure, leaving 'millions of barrels' sidelined. Redirected flows via the East‑West pipeline are insufficient to replace lost Gulf exports, implying months of elevated fuel prices and a sustained supply shock that favors risk‑off positioning.

Analysis

The market move is as much a logistics shock as a production shock — longer voyage legs, higher tanker time-on-hire and elevated war-risk premiums are creating a multi-dollar per-barrel wedge between posted crude prices and delivered barrels in Asia/Europe. That wedge compresses refinery crack spreads unevenly: coastal refiners with VLCC/FSO access capture higher margins while inland/short-haul refineries and product arbitrageurs see margin erosion; expect regional product spreads to reprice over weeks as cargoes reallocate.

Second-order winners are owners of seaborne transport and LNG lifting flexibility (time-charter upside and spot cargo arbitrage), and Atlantic-basin producers able to redirect supply into short-haul trades; losers include regional traders carrying hedged crude exposure, refiners without access to sour/heavy grades, and insurers underwriting Gulf transits. Over months, U.S. shale provides a cap on price upside but not immediately — production response lags by 2-6 months, so a supply gap can persist and keep backwardation and contango dynamics elevated for the near term.

Key catalysts and time horizons: immediate (days–weeks) — tanker rates, war-risk insurance and force-majeure roll-offs; medium (1–3 months) — inventory draws and rerouting cadence; long (3–12 months) — production ramp from non-Gulf sources and political/diplomatic resolution. Reversal triggers include rapid re-opening of Hormuz, coordinated SPR releases or a decisive diplomatic deal; downside would be swift and violent for freight-exposed equities if shipping corridors normalize quickly.

Key Decisions for Investors

• Long Cheniere Energy (LNG) — buy shares size 2-4% NAV or buy 6-month call spread (long 6-month $240 / short $300) to cap cost; R/R: asymmetric if Asian gas tightness continues (30-50% upside vs 7-10% premium paid); stop-loss at -18% on shares or if JKM/HH spread narrows below historical floor.
• Long tanker owners (Frontline FRO or Euronav EURN) — tactical 4-8 week trade to capture spiking time-charter rates; buy FRO shares or 3-month call options sized 1-2% NAV; target 40-80% upside if rates remain elevated, cut to flat if rates revert to pre-crisis levels (stop -25%).
• Pair trade — long US Gulf export-capable refiners (MPLX/MPC) + short European coastal refiners (VOW3 or IPGP proxy via RDS.B/BP) — 3-month horizon to capture arbitrage re-routing and freight-penalty; size neutral, target 8-15% relative performance, stop if Brent basis tightens >$15/bbl.
• Volatility hedge / asymmetric oil exposure — buy 3-month Brent call spread via BNO (long 3-month $115 / short $145) for directional upside with defined max loss; allocate <=1.5% NAV, payoff 3x+ if Brent sustains above $120, loss limited to premium paid.