Goldman raises Brent forecasts again, sees higher oil prices for longer

Goldman now expects Brent to average $110/bbl in March–April (up from a prior $98 forecast) after assuming Strait of Hormuz flows at ~5% of normal for six weeks followed by a one-month recovery. The bank raised 2026 Brent to $85/bbl (from $77) and WTI to $79/bbl, and sees Brent averaging $80 in 2027 while flagging significant upside risks — in extreme scenarios daily Brent could exceed the 2008 record and a severely adverse case could see Brent around $115 by late‑2026. Goldman cites deeper commercial inventory drawdowns and a repricing of effective spare capacity, implying a lasting risk premium and upward pressure on oil prices.

Analysis

Concentration of spare capacity and a persistent shipping chokepoint will shift the oil market from transient technical squeezes to structurally higher precautionary demand — not just for crude but for product inventories and insurance capacity. Expect a marked steepening in short-term physical premia (basis/backwardation) alongside higher long-dated risk premia as sovereigns and refiners rebuild buffers; that combination amplifies volatility in roll yields and makes calendar spreads a primary source of tradeable alpha over the next 1–3 months.

Second-order supply-chain impacts will propagate into freight, marine insurance, and refining-grade economics. Longer voyage times and insurance premiums will favor nearby producers with pipeline access, widen heavy/light differentials for refiners able to process heavier barrels, and increase FCF dispersion across E&P capital structures — advantaging low-decline, high-margin shale and integrated players with refining optionality.

Timing and reversal mechanics are asymmetric: price spikes can occur within days on a new disruption, but normalisation (diplomatic resolution, rerouting, SPR or OPEC+ releases) typically takes weeks-to-months to feed through inventories and futures curves. A sustained regime change that tightens capex and reduces effective spare capacity would push structural price expectations higher for years, whereas coordinated releases or rapid restoration of Hormuz throughput would collapse the near-term risk premium and steepen the curve in the opposite direction.

Key Decisions for Investors

• Long select US E&P (PXD, FANG, DVN) — buy 9–12 month OTM call spreads (e.g., 60–90 delta buy / 30–45 delta sell) sized 3–5% NAV. Rationale: captures margin kicker from higher realized prices with defined downside; target 2:1 upside/downside if front-month crude stays > current risk-premium levels for 3–9 months.
• Relative-value pair: long XLE / short XLI for 3 months — size 2–4% NAV. Rationale: energy cash margins reroute profits to producers while industrials face input-cost squeeze; historic post-shock outperformance is ~300–500bps over a 1–3 month window. Close on evidence of diplomatic de-escalation.
• Near-term calendar steepener via Brent/WTI futures (buy front 1–2 month, sell 6–12 month) or buy 1–3 month call spreads on WTI — horizon 1–3 months. Rationale: monetizes expected front-month premium and inventory draws; stop-loss if front-month futures compress by >50% vs 6-month to avoid contango losses.
• Hedge consumer/cyclical exposure: buy 3–6 month put spreads on airlines (AAL, UAL) sized to offset fuel-cost sensitivity in portfolio companies. Rationale: limits downside from sudden jet-fuel-driven margin hits; aim for 2:1 hedged payoff (cost vs protection) and unwind on sustained crack-strength weakness.