Published on Monday, March 9 2026
Authors : Sandeep Sayal, Vice President, Industry & Market Analytics

A disruption in the Strait of Hormuz is testing the resilience of global oil and LNG logistics, with implications for supply flows, refining systems, and energy prices.

Modern energy shocks rarely begin at the wellhead—they begin in logistics. In the current Middle East conflict, the primary constraint has not been damaged reservoirs but disrupted trade. When tankers cannot, or will not, move through the Strait of Hormuz, export terminals cannot clear barrels, storage fills rapidly, and producers may be forced into shut-ins even when upstream infrastructure remains intact.

Markets have therefore repriced quickly. The emerging “Hormuz risk premium” reflects uncertainty over whether the physical trading system—shipping, insurance, port access, and naval escorts—can continue functioning.

Why the Strait of Hormuz Matters

The Strait of Hormuz is the world’s most critical energy chokepoint. Roughly 20 million barrels per day of crude oil and petroleum products transit the Strait in a typical year, representing about a third of global seaborne oil trade. Around one-fifth of global LNG trade also moves through the corridor, largely from Qatar.

This concentration of flows makes the global energy system highly sensitive to disruptions in the Strait. A relatively small number of export hubs handle most Gulf shipments, including Saudi Arabia’s Ras Tanura and Ju’aymah terminals, Iraq’s Basra offshore facilities, Iran’s Kharg Island export hub, Qatar’s Ras Laffan LNG complex, and the UAE’s Fujairah hub (which sits outside the Strait). When tanker traffic slows, disruptions ripple quickly across multiple national export systems.

Over 80% of oil passing through Hormuz is destined for Asian markets, meaning the earliest impacts often appear in Asian refinery procurement and trading activity before spreading into global pricing.

Crude Pipelines Help—but Cannot Replace Hormuz

Some Gulf crude producers have pipelines that bypass the Strait, but available bypass capacity is limited relative to the roughly 20 million b/d that normally transits Hormuz.

Saudi Arabia’s East–West Pipeline (Petroline) moves crude from the eastern oil fields to the Red Sea port of Yanbu. The line has nameplate capacity of roughly 5 million b/d, with potential surge capacity near 7 million b/d, though typical operating flows are closer to 2–3 million b/d. This suggests several million barrels per day of incremental capacity could be utilized in a disruption, although export capacity and tanker availability at Yanbu would also influence how much additional crude could realistically be redirected.

The UAE operates the Habshan–Fujairah pipeline, which transports Abu Dhabi crude from inland fields to the Fujairah export terminal on the Gulf of Oman, outside the Strait. This system can move roughly 2.1 million b/d.

Even combined, these routes could offset only a portion of the roughly 20 million b/d that normally moves through the Strait.

Shipping, Insurance, and the Logistics Constraint

The current disruption is less about a formal blockade and more about commercial hesitation under extreme uncertainty.

Shipping markets depend heavily on insurance, and war-risk coverage can be withdrawn or repriced quickly during geopolitical crises. Reports suggest a significant portion of insurers offering war-risk coverage have suspended or restricted policies for voyages through the Strait, sharply limiting the ability of many vessels to operate. Premiums that are normally modest can escalate dramatically, adding hundreds of thousands of dollars, or more, to a single voyage. When coverage becomes uncertain, ships often remain idle.

Governments are exploring measures to stabilize trade flows, including naval escorts and political-risk insurance support. These steps can help restore confidence, but practical constraints remain, particularly given the scale of shipping activity through the narrow Strait.

Tanker tracking shows vessels waiting both inside the Gulf and outside the Strait as operators reassess security risks, insurance coverage, and port access. Much of the limited traffic attempting to transit the Strait appears to involve tankers owned or chartered by oil companies that may be able to self-insure or assume greater risk.

Oil and Gas Markets React

Energy markets have responded in ways typical of sudden supply risk. Brent crude rose sharply, while WTI also increased but to a lesser degree, widening the Brent–WTI spread. Brent tends to respond more directly to disruptions affecting seaborne trade, while WTI remains more closely linked to North American supply balances.

Natural gas markets in Europe have reacted differently. European benchmark gas prices have risen significantly because LNG supply disruptions directly affect Europe’s procurement options. This sensitivity is because only 50% of Europe’s LNG supply is covered by long-term contracts. Thus, the upward pressure on spot LNG prices stemming from the force majeure declared by QatarEnergy at its Ras Laffan LNG complex is expected to disproportionately impact Europe during its upcoming stock-rebuilding season. By contrast, U.S. natural gas prices have remained relatively stable because the U.S. market is largely domestic. Unfortunately for the Europeans U.S. LNG export terminals are already operating near capacity.

Israel has also temporarily shut down several offshore gas fields in the Eastern Mediterranean following security concerns. These fields normally supply gas to Israel and export markets such as Egypt, thereby tightening regional gas balances and reinforcing upward pressure in international gas markets.

Qatar and LNG Supply

The global gas response centers on Ras Laffan Industrial City in Qatar, the world’s largest LNG export hub. Qatar supplies roughly 20% of global LNG, and all those cargoes must transit the Strait of Hormuz.

Unlike crude oil, LNG shipments cannot easily be rerouted. Liquefaction plants also require time to restart after shutdowns, meaning even short interruptions in shipping could translate into weeks of reduced supply reaching global markets. Storage capacity at Ras Laffan is limited relative to production, which means loadings could be slowed even after the plant returns to operations.

Refined Product Markets

Disruptions in the Gulf are also affecting refined product markets. Reports indicate operational disruptions at facilities such as Saudi Arabia’s Ras Tanura refining and export complex. while Israel has temporarily shut offshore gas fields that supply regional markets.

Diesel markets have tightened quickly. U.S. diesel futures have moved above $3 per gallon, and European prices have also risen sharply as traders anticipate tighter supplies of middle distillates.

Heavy crude availability is another factor. If Middle Eastern heavy exports are constrained, refiners that rely on heavier grades may turn to alternatives such as Canadian heavy crude or Latin American supplies. Higher heavy crude prices could also encourage incremental production responses from light oil producers, particularly in the U.S. Permian Basin. But such reactions will take months, not weeks.

Jet fuel markets face competing forces. Airspace closures and reduced travel may lower demand, but longer flight paths and rerouting increase fuel consumption. For now, supply concerns appear to dominate.

Further, higher crude prices would eventually filter through to retail fuel markets, with a common industry rule of thumb suggesting that a $10 move in crude can translate into roughly 20–30 cents per gallon at the pump.

Who Is Most Exposed

China enters the disruption with significant buffers. Combined commercial and strategic inventories are estimated to be between 900 million and 1.4 billion barrels, providing several months of import coverage. These inventories allow refiners to delay purchases and diversify supply sources, reducing the risk of immediate market panic. China’s initial reaction has been to halt exports of petroleum products.

India faces greater exposure. A large share of its crude imports transits Hormuz, and its LNG supply chain operates with smaller buffers. India processes roughly 5.6 million b/d of crude and holds around 25 days of crude inventories, which may help manage a short disruption but leave the country more sensitive to prolonged shipping constraints.

Europe’s direct crude exposure is smaller, but the region relies heavily on Middle Eastern supplies of diesel, jet fuel, and LNG-linked gas pricing, meaning refined product markets may react quickly to disruptions.

Timelines That Drive Shut-Ins

Three timelines help explain how disruptions could evolve: storage constraints, restart dynamics, and market expectations.

First, producers typically shut in output only when export disruptions prevent barrels from clearing the system. Export terminals in the Gulf have limited storage buffers—often only several days to a few weeks, meaning sustained shipping disruptions can force production curtailments relatively quickly. In fact, Kuwait announced on March 6 that it will begin curtailing production due to storage limits.

Second, restarting facilities takes time. LNG plants typically restart in stages following shutdowns, meaning even a short interruption in exports can take time to normalize once shipping resumes. Upstream oil wells are generally more flexible, but longer disruptions can still complicate restart schedules.

Third, markets reflect expectations about the duration of disruption. Near-term crude prices have strengthened while prices further out on the forward curve remain lower, suggesting traders expect some eventual normalization of shipping activity.

Three Possible Scenarios

Partial stabilization. Shipping resumes gradually under higher insurance costs and selective naval escorts. In practice, U.S. naval vessels typically escort only U.S.-flagged, U.S.-owned, or U.S.-crewed ships, which may limit how much of the global tanker fleet can directly benefit from such protection. Oil prices stabilize as exports resume, though refined product markets remain tight as inventories rebuild.

Limited bypass and rising curtailments. Pipeline routes operate at full capacity but cannot replace tanker exports. Storage fills and additional producers reduce output, tightening global supply and raising crude procurement costs and margin pressure for Asian refiners.

Extended disruption. If shipping constraints persist or infrastructure is damaged, the market could shift from a price shock toward a genuine supply shortfall, forcing refinery run cuts in import-dependent regions and intensifying competition for LNG cargoes.

What to Watch

Key indicators for the coming weeks include:

	•	tanker queues and transit activity near Hormuz
	•	establishment of convoys escorted by U.S. (and potential other) naval warships
	•	availability and pricing of war-risk insurance
	•	LNG loading activity at Ras Laffan
	•	diesel and jet fuel margins relative to crude
	•	policy responses such as escorts or strategic inventory releases
	•	refinery run adjustments and crude procurement in Asia

The coming weeks will determine whether the current disruption remains a temporary logistics shock or evolves into a more persistent supply constraint. The Strait of Hormuz has long been recognized as the world’s most important energy chokepoint; episodes like this illustrate how quickly disruptions to logistics—not geology—can ripple through global oil and gas markets.

If you have any questions, please email Sandeep Sayal at sandeepsayal@turnermason.com  about ways we can assist you.