The Strait of Hormuz Crisis: What the Loss of Qatari LNG Capacity Means for Global Buyers

The effective closure of the Strait of Hormuz since early March 2026 has triggered what the International Energy Agency has called the greatest global energy security challenge in history. While much of the public conversation has focused on crude oil — with Brent surging past $120 per barrel — the more structurally consequential story is playing out in the liquefied natural gas market. The damage to Qatar's export infrastructure, combined with the physical blockade of the world's most critical LNG transit corridor, will alter the global gas supply picture for years.

The Scale of the Disruption

Approximately 20% of the world's LNG trade transits the Strait of Hormuz under normal conditions, the vast majority of it originating from Qatar — the world's second-largest LNG exporter. When Iran's Islamic Revolutionary Guard Corps declared the strait closed on March 4 in retaliation for the U.S.–Israeli strikes that began on February 28, LNG tanker traffic through the passage collapsed almost immediately. Over 150 vessels anchored outside the strait. Major shipping firms — including Maersk, MSC, and Hapag-Lloyd — suspended all transits. War risk insurance premiums spiked from negligible levels to above 20% of vessel value, making commercial passage economically unviable even where physically possible.

QatarEnergy, the world's largest LNG producer, initially halted all production at its Ras Laffan Industrial City and Mesaieed Industrial City facilities on March 2 following Iranian drone strikes. It subsequently declared force majeure on long-term supply contracts with buyers in South Korea, China, Italy, and Belgium, among others.

The situation escalated further on March 18, when an Iranian missile strike on the Ras Laffan complex knocked out two of Qatar's 14 LNG trains and one of two gas-to-liquids facilities. QatarEnergy CEO Saad al-Kaabi confirmed the attack eliminated approximately 12.8 million tonnes per year of LNG production capacity — roughly 17% of the country's total — and estimated that full repair will require three to five years. The company has also announced delays to its North Field East expansion project, which had been expected to come online by mid-2026.

The combined effect — a physical blockade of the transit route and lasting damage to production infrastructure — represents a structural supply loss without modern precedent in the LNG market.

Why LNG Is Not Oil

This crisis is more acute for natural gas than for crude oil. Oil markets, while severely stressed, benefit from greater flexibility: Saudi Arabia has rerouted some crude exports through the East–West Pipeline to Yanbu on the Red Sea; the UAE has diverted volumes through its pipeline to Fujairah on the Arabian Sea; and global strategic petroleum reserves provide a limited buffer.

LNG has none of these relief valves. There is no pipeline bypass for Qatari gas. LNG is not fungible in the way crude oil is — it requires specialized liquefaction at the source and regasification at the destination, and the global fleet of LNG carriers is already stretched thin. Rerouting LNG tankers around the Cape of Good Hope adds 45 to 55 days to a voyage that normally takes 21 days via Suez and Hormuz, effectively tripling transit time and adding upwards of $13.5 million per cargo at current charter rates. Unlike oil, there are no internationally coordinated strategic LNG reserves.

Asian spot LNG prices have surged more than 140% since the onset of the crisis. European TTF benchmarks have nearly doubled. U.S. Henry Hub prices, by contrast, have remained largely flat — a gap that reflects the fragmented nature of global gas markets and how concentrated this supply shock really is.

Differentiated Impact on Key Buyers

The crisis is hitting buyers unevenly. The determining factors are Gulf LNG dependency, storage depth, procurement flexibility, and access to domestic energy alternatives.

Japan

Japan faces the most direct disruption among developed economies. Roughly 93% of its crude oil imports transit the Strait of Hormuz, and approximately 6% of its LNG imports come directly from Qatar and the UAE. While that LNG share appears modest, Japan's broader exposure is significant: the country holds only about 4.4 million tons of LNG in reserve — roughly two to four weeks of stable demand. Japanese refiners have requested government release of stockpiled oil. The knock-on effects extend beyond fuel: about 42% of Japan's naphtha supply originates from the Middle East, and LNG-dependent electricity generation is critical to the semiconductor and petrochemical industries. The crisis has also injected urgency into Japan's competition with China for U.S. LNG supplies, with Chinese state media publicly framing Beijing's recent resumption of U.S. energy purchases as a strategic win over Tokyo.

Taiwan

Taiwan sources approximately 30% of its LNG through the Strait of Hormuz. The exposure is not just residential. Taiwan's semiconductor industry, led by TSMC — which produces nearly 90% of the world's most advanced chips and consumes roughly 9% of the island's electricity — depends on stable LNG-powered generation. A prolonged LNG disruption puts Taiwan's grid and, by extension, a global technology supply chain worth trillions of dollars annually at direct risk. Taiwan has activated emergency energy security protocols and is competing aggressively for Atlantic basin spot cargoes.

India

India faces the largest combined exposure in Asia. More than half of its LNG imports are Gulf-linked, and Qatar and the UAE account for approximately 53% of total LNG supply. India also sources roughly 40–47% of its LNG imports and about 53% of its crude oil from the Middle East. The crisis has already produced acute shortages of cooking gas — a commodity affecting over 300 million Indian households. India has deployed naval escorts under Operation Sankalp to evacuate Indian-flagged carriers from the strait, and Iran has granted rare transit exceptions for select Indian vessels. However, because a significant share of India's LNG contracts are Brent-indexed, the simultaneous surge in crude oil prices is lifting both oil import costs and LNG contract prices in a compounding effect. India's partial ability to substitute coal for gas in power generation provides some cushion that its South Asian neighbors lack.

Bangladesh

Bangladesh is among the most vulnerable nations globally. Qatar and the UAE account for approximately 72% of the country's LNG imports. Bangladesh took delivery of its first cargo under a new 15-year QatarEnergy supply agreement just seven weeks before force majeure was declared at Ras Laffan — transforming what was intended as an anchor of long-term energy security into an immediate liability. The country was already running a structural gas deficit exceeding 1,300 million cubic feet per day before the crisis. With limited storage infrastructure, minimal procurement flexibility, and no meaningful domestic coal or gas reserves to fall back on, Bangladesh faces the prospect of power-sector demand destruction rather than the ability to bid for expensive spot replacements. The country is now part of a small group of nations — alongside Pakistan, Zimbabwe, Nigeria, and Vietnam — facing severe fuel shortages.

Pakistan

Pakistan's position is arguably the most precarious. Qatar and the UAE account for 99% of the country's LNG imports, and more than 90% of its crude oil comes from the Persian Gulf. Pakistan had an LNG surplus as recently as January 2026; by March, it was in emergency management mode. The government has officially requested that Saudi Arabia reroute oil supplies through the Red Sea port of Yanbu, and has received at least one crude shipment via that alternative corridor. Authorities are reportedly considering a mandatory four-day workweek as an emergency conservation measure. Pakistan's reserves are estimated at roughly 20 days of supply. Gas dominates the domestic energy mix, and the country has neither indigenous alternatives nor the fiscal capacity to compete for high-priced spot cargoes against European or East Asian buyers.

Other Exposed Markets

South Korea sources roughly 14% of its LNG from Qatar and the UAE, with reserves covering two to four weeks. Singapore, where Qatar accounts for approximately 90% of LNG imports, is bidding aggressively for replacement cargoes. Vietnam holds oil reserves estimated at less than 20 days — among the thinnest buffers in Asia. Across Southeast Asia, the first-order impact is cost inflation: fuel rationing, school closures, and export restrictions have already been implemented in Thailand, Laos, Cambodia, and the Philippines. China, though the world's largest LNG buyer, is better positioned than most — it holds approximately 7.6 million tons of LNG inventory, benefits from pipeline gas from Russia and Central Asia, and has re-exported a record eight to ten LNG cargoes in March, capitalizing on high spot prices and cementing its position as Asia-Pacific's de facto swing supplier.

Strategic Implications

The immediate supply shock will eventually ease. The structural shifts it has set in motion will not.

The security premium on non-Hormuz LNG supply is now permanently repriced. Buyers that previously evaluated LNG primarily on cost are now weighting physical supply security as a co-equal factor. U.S. Gulf Coast LNG — which does not transit any contested chokepoint — is the most obvious beneficiary. While existing U.S. terminals are operating at capacity and cannot immediately increase exports, the crisis is expected to accelerate final investment decisions on proposed U.S. projects and other non-Gulf developments. North American projects in particular have received a meaningful boost from the turmoil, though current U.S. export capacity of approximately 14.6 Bcf/d cannot offset the roughly 20% shortfall in global supply created by the Hormuz closure.

Long-term contracting dynamics are shifting. Asian buyers, particularly in South Asia and Southeast Asia, now have urgent incentives to diversify their supply portfolios and lock in long-term agreements with non-Gulf producers. QatarEnergy's own investments in U.S.-based LNG capacity — including Golden Pass — and ADNOC's RioGrande project may paradoxically benefit from the damage to Gulf facilities, as buyers seek affiliated molecules that do not require Hormuz transit.

Renewables are now a national security argument, not just a climate one. Solar and wind capacity, once built, does not require ships to transit a strait. India's relatively stronger position compared to Bangladesh tracks directly to its more aggressive investment in domestic renewable capacity over the past five years.

The fertilizer and petrochemical supply chains are under concurrent stress. The Gulf region produces nearly half the world's urea and 30% of its ammonia. Urea prices have surged 50% since the war began. This is a second-order but potentially devastating effect for agricultural economies across South Asia, Sub-Saharan Africa, and Southeast Asia, where fertilizer shortages directly threaten food production during the spring planting season.

Outlook

Even under an optimistic scenario in which the Strait of Hormuz is fully reopened in the near term, the damage to Qatar's Ras Laffan infrastructure means that approximately 12.8 million tonnes per year of LNG capacity will remain offline for three to five years. Port congestion, logistics bottlenecks, insurance repricing, and the slow process of restarting idled liquefaction trains will keep supply tight well into 2027. Analysts see sustained elevated pricing across both European and Asian LNG benchmarks for the foreseeable future.

The takeaway for buyers is simple: concentration risk in energy supply — whether by geography, chokepoint, or counterparty — carries consequences that no force majeure clause can mitigate. The structural reordering of global LNG trade that many expected to unfold over the next decade is now being compressed into months.

Abbert Capital provides strategic advisory services across energy, cross-border M&A, and infrastructure. For further discussion of these developments and their implications, contact us at info@abbertcapital.com.

The views expressed in this article are for informational purposes only and do not constitute investment advice. This material may contain forward-looking statements based on current expectations that involve risks and uncertainties.