All the alternative routes for Middle East oil and gas to bypass the Strait of Hormuz

Shipping through the Strait of Hormuz has been sharply disrupted, with only three vessels passing in one 24-hour period and the route previously handling about one-fifth of global oil and LNG supply. The article highlights multiple bypass options, including Saudi Arabia’s 1,200-km East-West pipeline (up to 7 million bpd, with effective exports around 4.5 million bpd) and the UAE’s 1.5-1.8 million bpd Habshan-Fujairah line, but most alternatives are constrained by capacity, security, or project risk. The situation raises significant supply-risk premiums for oil and gas markets.

Analysis

The market is underestimating how much of the Gulf’s export system is structurally redundant on paper but fragile in practice. The true bottleneck is not crude-in-the-ground; it is export sequencing, berth availability, insurance, and the ability to move barrels without clustering them into a few vulnerable nodes. That means the first-order shortage may remain contained, while the second-order winners are logistics assets and non-Hormuz routes with spare capacity and physical flexibility.

Saudi and UAE bypasses create asymmetric optionality for regional flows, but the benefits are uneven: countries with pipeline-to-Red-Sea or Gulf-of-Oman access can keep monetizing barrels, while Iraq and Iran remain most exposed to any escalation because their evacuation routes are either incomplete, politically constrained, or vulnerable to sabotage. The more important knock-on is that every incremental barrel pushed onto non-Hormuz routes raises congestion and security premia elsewhere, especially the Red Sea and Mediterranean legs. In other words, rerouting does not eliminate risk; it redistributes it to chokepoints with thinner naval coverage and more fragmented jurisdiction.

Near term, the key catalyst is not a permanent closure but intermittent disruption that forces charterers and refiners to pay up for optionality. That is bullish for tanker dayrates, marine insurance, and port/terminal throughput outside the Gulf, while being mildly bearish for refiners that depend on Gulf sour crude continuity. Over months, a sustained disruption would likely flatten Brent prompt backwardation into a more extreme structure, favoring storage and shipping over outright commodity exposure.

Contrarian view: the headline risk premium may be larger than the physical loss of barrels, because spare capacity outside Hormuz is enough to keep a significant share of exports moving. If diplomacy de-escalates, risk premium can compress faster than inventories can rebuild, so outright long oil is less attractive than expressions tied to logistics dislocation and volatility. The better trade is to own the bottlenecks, not the molecule.

Key Decisions for Investors

• Go long tanker equities/options basket (FRO, TNK, INSW) for 1-3 months: rerouting and insurance uncertainty should support spot rates and time-charter equivalents; prefer call spreads to cap theta if the ceasefire holds.
• Pair trade long XLE vs short transportation-heavy European refiners for 4-8 weeks: Gulf disruption supports upstream cash flows and pressures crude-dependent refiners through feedstock volatility and freight costs.
• Buy upside in marine insurance/volatility proxy via Lloyd’s-linked names or broader shipping vol if available; if not, use short-dated Brent strangles to monetize realized volatility rather than direction.
• Long ADX/ADNOC-adjacent infrastructure beneficiaries or regional logistics proxies where accessible, with a 3-6 month horizon: non-Hormuz export terminals gain strategic value as rerouting demand persists.
• Avoid aggressive outright long crude here; instead, if Brent spikes on headlines, fade into strength with tight stops unless physical outages exceed 1-1.5 mbpd for more than several sessions.