A prolonged closure or severe restriction of the Strait of Hormuz would do more than produce another oil-price spike. It could change what governments, refiners, utilities and shipping companies are willing to pay for reliable energy.

The strait, a narrow waterway between Iran and Oman, carries a concentration of energy trade that is hard to replace. About 20 million barrels a day of crude oil and oil products moved through it in 2025, roughly a quarter of world seaborne oil trade, according to the International Energy Agency (IEA). Nearly a fifth of global liquefied natural gas trade also depends on the route, mainly from Qatar and the United Arab Emirates.

That makes Hormuz a global economic risk, not just a regional security problem. If confidence in the route is damaged for months rather than days, the shock can spread beyond immediate shortages into higher insurance and freight costs, larger inventories, more expensive backup supply and renewed pressure on governments to cushion consumers from fuel and power prices.

The scale of the disruption has already tested old assumptions. The IEA's April oil market report said restrictions on tanker movements through Hormuz and attacks on Middle East energy infrastructure contributed to a 10.1 million-barrel-a-day fall in global oil supply in March. Early-April loadings through the strait averaged about 3.8 million barrels a day, down from more than 20 million barrels a day in February before the crisis. The U.S. Energy Information Administration (EIA) built that shock into its latest forecast, estimating that Iraq, Saudi Arabia, Kuwait, the UAE, Qatar and Bahrain collectively shut in 7.5 million barrels a day of crude production in March and would shut in 9.1 million barrels a day in April. Even assuming the conflict did not persist beyond the month and traffic gradually resumed, the EIA still expected production to return close to pre-crisis levels only late in 2026.

That is the heart of the long-term risk. The question is not whether Hormuz will stay closed indefinitely. It is whether reopening the strait would quickly restore the old cost of doing business. The EIA forecast Brent crude would average $96 a barrel in 2026, up from a 2025 average of $69, and projected $76 in 2027, citing uncertainty over future supply disruptions as a reason for a continuing risk premium.

The physical limits are stark. Saudi Arabia and the UAE have some ability to bypass Hormuz, with an estimated 3.5 million to 5.5 million barrels a day of available crude export capacity through alternative routes. That helps, but it is far below the normal volume of oil and products moving through the strait. Those routes also depend on logistics and supply chains that have not been fully tested at crisis scale.

LNG is even less flexible. Around 93% of Qatar's LNG exports and 96% of the UAE's LNG exports transit Hormuz, representing about 19% of global LNG trade. Unlike crude, LNG cannot be redirected through spare pipelines. Export terminals, buyers and shipping schedules are locked into a narrower system.

Asia would feel that pressure first. The EIA estimated that 83% of LNG moving through Hormuz in 2024 went to Asian markets, with China, India and South Korea the top destinations. Bangladesh, India and Pakistan imported almost two-thirds of their LNG supplies through the strait in 2025, leaving them exposed to both price spikes and physical shortages if disruptions persist.

The effects could reach beyond energy bills. Natural gas is a power fuel and a feedstock for fertilizer, so a sustained LNG shortfall can hit factories, electricity systems and food costs at the same time. The World Bank warned in 2024 that a Middle East escalation could lift natural gas, fertilizer and food prices, a risk channel that becomes more serious when a major LNG route is under strain.

For policymakers, the crisis turns redundancy from an abstract goal into a budget question. Strategic petroleum reserves can soften a short disruption, but they cannot replace months of interrupted crude, refined products and LNG flows. More storage, more flexible import contracts and more diversified supply would improve security, but consumers or taxpayers eventually pay for them.

Companies face the same trade-off. Refiners may look harder for crude outside the Gulf. Utilities may reduce dependence on spot LNG cargoes tied to one route. Airlines, shippers and petrochemical producers may hedge more aggressively against fuel and feedstock shocks. Those choices can make supply chains more resilient, but they also raise the cost of operating them.

Over time, a persistent Hormuz risk premium could influence investment in non-Gulf oil and gas projects, storage, alternative export infrastructure and shipping security. It could also strengthen the case for renewable power, nuclear energy, batteries and efficiency in countries that see lower fuel imports as an energy-security objective as well as a climate goal.

There are reasons a worst-case disruption may not last. Gulf producers have a strong economic interest in keeping exports moving. The IEA's February factsheet said lasting disruptions were unlikely, while warning that even short interruptions would have major market effects. Importing countries also have emergency stocks, demand-reduction tools and some ability to switch fuels. But the market does not easily forget a chokepoint that can interrupt oil, LNG, refining and product markets at once. Even after traffic resumes, buyers may demand more protection, governments may hold larger buffers and companies may pay more for supply that avoids a single exposed route.

The cost of Hormuz risk may no longer be measured only in barrels delayed today. Increasingly, it may be measured in the price of making tomorrow's energy system less fragile.