For years, Gulf energy giants treated US gas projects as smart diversification. Now, those bets look like insurance.

The closure of the Strait of Hormuz has shaken one of the world’s most important energy routes. It has squeezed nearly a fifth of global liquefied natural gas trade and forced buyers to hunt for supply elsewhere.

That is why US LNG has suddenly moved from useful option to strategic hedge.

Abu Dhabi’s Mubadala Energy and XRG, QatarEnergy, Saudi-linked buyers, sovereign investors and regional funds have all built exposure to American gas infrastructure. These moves did not begin with the current crisis. But the crisis has made the logic painfully clear.

If a single waterway can interrupt so much gas, producers and buyers need backup routes.

LNG is natural gas chilled into liquid form so ships can carry it across oceans. Unlike pipeline gas, it depends heavily on ports, tankers and safe sea lanes. When shipping routes close, the shock travels quickly from the Gulf to power plants, factories and household bills in Asia and Europe.

The Strait of Hormuz is not just another stretch of water. It is the narrow exit route for much of the Gulf’s energy trade. When it shuts, the impact reaches far beyond the region.

More than 10 billion cubic feet per day of LNG supply, roughly 20 per cent of global trade, has been affected. That is a large hole in a market where buyers often plan cargoes months ahead.

The squeeze has been made worse by damage at Qatar’s Ras Laffan LNG export facility. The site accounts for 17 per cent of Qatar’s LNG capacity. QatarEnergy has warned repairs could take up to five years, and force majeure on shipments has been extended through mid-June.

Force majeure means a company says extraordinary events prevent it from meeting contract obligations. In plain terms, some buyers cannot get the gas they expected, when they expected it.

No loaded LNG vessel was known to have crossed the Strait between March 1 and April 24, according to US energy data citing ship-tracking information. For Asian importers, that is a major disruption.

The reason is simple. Most LNG from Qatar and the UAE goes east.

In 2025, about 90 per cent of LNG volumes exported through the Strait of Hormuz were headed to Asia. Those flows made up more than a quarter of Asia’s total LNG imports. Europe received just over 10 per cent.

Japan, South Korea and China are especially exposed because they depend on seaborne gas to keep homes warm, industries running and electricity systems stable. When Gulf cargoes disappear, these buyers must compete harder in the spot market.

Prices reacted quickly.

The Japan Korea Marker, the key benchmark for spot LNG deliveries into north-east Asia, rose 51 per cent in the two months after the Hormuz closure. It reached $16.02 per million British thermal units for the week ending April 24.

Europe’s TTF gas benchmark rose 35 per cent during the same period. But US Henry Hub prices fell 9 per cent, helped by strong domestic supply.

That price gap explains why American LNG now looks so attractive. US gas may be far away, but it comes from a market with deep supply and growing export capacity. It also often comes with more flexible destination terms, which means cargoes can be redirected more easily than some traditional contracts allow.

This is where Gulf investments matter.

Mubadala Energy said this month it was moving ahead with a $13 billion LNG project in Louisiana. The project targets 9.5 million tonnes a year by 2030.

In Texas, QatarEnergy began exports in March from its Golden Pass LNG project, marking a major step in its largest US investment. XRG, also from Abu Dhabi, expanded its position in the Rio Grande project by buying an additional 7.6 per cent equity stake in Trains 4 and 5 at the Port of Brownsville.

Saudi Arabia has a long-term agreement with Houston-based Caturus Energy. It has also secured offtake from Rio Grande LNG and Commonwealth LNG.

The Abu Dhabi Investment Authority holds positions in Sempra Infrastructure and Cheniere Energy. The Arab Energy Fund has taken a $120 million stake in MidOcean Energy.

Taken together, this is not a scattered set of deals. It is a pattern.

Gulf producers are putting money into supply chains outside their own geography. That gives them commercial exposure to the gas buyers still need when Gulf routes are blocked. It also gives them influence in the next phase of LNG growth.

But the strategy comes with a twist.

If Asian buyers sign more long-term US LNG contracts during this crisis, some of that demand may not return fully to Gulf suppliers later. Energy contracts often run for years. Once utilities lock in dependable alternatives, they do not easily unwind them.

So Gulf companies may end up funding infrastructure that competes with their own regional exports.

That sounds odd, but it is not irrational. In a disrupted world, owning part of the alternative can be better than losing the customer entirely.

The US is also expanding fast. Its LNG exports rose 28 per cent year-on-year to a record 32.15 million tonnes between January and April, based on ship-tracking data. The country is on course to double export capacity by 2030.

Still, US LNG cannot replace the lost Gulf volumes overnight.

The Strait of Hormuz handles about 86 million tonnes of LNG a year. New US trains are starting up, including at Corpus Christi and Golden Pass, but the additional volume is not enough to fully cover the losses from Qatar and Abu Dhabi.

That means the market faces two problems at once.

The first is immediate supply. Asian buyers need cargoes now, and spot prices can stay sensitive while Hormuz remains disrupted.

The second is long-term trust. Buyers will ask whether relying heavily on one export corridor still makes sense. Producers will ask how much capital should remain concentrated in the Gulf.

For Indian readers, the story matters even if India is not the central player in these flows.

India imports LNG, watches global energy prices closely and competes with other Asian buyers when cargoes are tight. Higher LNG prices can raise fuel costs for industry, city gas distributors and fertiliser-linked supply chains. They can also complicate inflation management if energy costs stay elevated.

The UAE angle is equally important. Abu Dhabi is not just a producer. It is an investor, trader and financial player in global energy. Its move into US LNG shows how Gulf economies are using capital to reduce exposure to regional choke points.

This is the new energy map. Security is no longer only about who owns the gas field. It is also about who owns the port, the liquefaction plant, the contract and the optional route.

The Hormuz disruption has turned that lesson into a live market event.

Gulf capital will still flow into regional energy. Qatar and the UAE remain central LNG players. But the crisis has changed the question investors ask.

It is no longer enough to ask where the gas is cheapest or most abundant. The harder question is whether it can reach the buyer when politics, war and shipping risk collide.

For now, US LNG is not a complete substitute for Gulf supply. But it has become the backup plan everyone can see.