The Strait of Hormuz logged its best month for liquefied natural gas traffic since the US-Iran war began in February, with 19 to 21 cargoes exiting the waterway in September according to analytics firms S&P Global Energy and Kpler. That number represents the highest monthly total since hostilities began on February 28 — and it still represents roughly one-fifth of the approximately 86 LNG vessels that crossed the strait every month before the war.

The gap matters most to the hundreds of millions of European households and businesses now heading into a heating season with underground gas storage at its lowest level in at least 15 years. European gas storage transparency data has tracked the shortfall week by week as the injection season ends without the cushion that would normally exist.

Nineteen Cargoes or Twenty-One? Why the Count Itself Is Uncertain

S&P Global Energy’s senior principal analyst Eric Yep put the September figure at 19 cargoes — 13 from Qatar and six from the United Arab Emirates — up from 15 in June, when a US-Iran memorandum of understanding had briefly eased tensions, according to Reuters reporting via Baird Maritime. Kpler’s independent tracking put the figure slightly higher, at 21 cargoes for the month.

The discrepancy reflects a specific technical reality of the September recovery: most vessels that successfully transited the strait did so by deactivating their Automatic Identification System (AIS) transponders, a practice known as a dark transit. Under international maritime law, AIS transmission is mandatory under the Safety of Life at Sea Convention, making these deactivations technically unlawful — but in a waterway contested by Iranian mines, drone strikes, and speedboat patrols, the risk calculation runs the other way. Ship operators disable the transponders to reduce the chance of detection.

In the final week of September alone, three QatarEnergy-linked or QatarEnergy-chartered LNG vessels — the Al Kharaitiyat, the Al Gharrafa, and the Milaha Qatar — disappeared from public tracking data inside the strait for six to seven days before reappearing off the western coast of India. The Milaha Qatar was offloading its cargo at India’s Hazira port by September 30. Whether those three vessels are counted as September transits depends on when a given tracking firm considers the crossing complete — a methodological difference that explains why S&P and Kpler arrive at different totals.

The technical upshot is that the “19 to 21” range is itself a floor, not a ceiling. Vessels that conducted dark transits without any external confirmation may simply not be counted at all.

What September’s Milestone Actually Means for European Heating Bills

Yep’s own projection offered a cautiously worded benchmark: if October’s pace holds, the Strait could handle roughly 25% of pre-war LNG volume for the full month. That projection implies approximately 21 to 22 cargoes per month — against a pre-war baseline of around 86 monthly crossings. In other words, even under the most optimistic near-term trajectory, Europe and Asia would be receiving roughly a quarter of the Gulf LNG volumes that normally flow through the strait.

The structural implications for European consumers are direct. Gas storage across European Union member states stood at approximately 71% of capacity as of early October, compared to a five-year seasonal average of 87%. The European Commission has already lowered the mandatory winter storage target from 90% to 80% in recognition that 90% is unreachable under wartime supply constraints. Wood Mackenzie has estimated that European storage will reach only about 76% by the end of the restocking season. HSBC analysts, in turn, projected storage of only around 72% by November.

The implication for household energy bills is not abstract: storage at 71–76% entering a heating season is the tightest position European consumers have faced since the acute phase of the 2022 Russian gas supply crisis, and it arrives with no guarantee of rapid Hormuz normalization to soften it.

European TTF natural gas benchmark prices were trading at approximately €73–75/MWh ($82–$84/MWh) as of October 2, up from approximately €41/MWh ($46/MWh) at the start of the year — a rise of roughly 78–83% year-to-date. Goldman Sachs has warned that December 2026 TTF could exceed €100/MWh ($112/MWh) if Gulf energy exports normalize only gradually through 2027. Oxford Economics has modeled a more contained scenario, projecting prices closer to €60/MWh ($67/MWh) for the fourth quarter and first quarter of 2027.

How the Strait Got This Far: Mines, Drones, and the Technology of Closure

The September recovery did not happen through diplomacy alone. It happened, in significant part, because of a shift in the physical conditions inside the strait — and because shippers were willing to accept the remaining risks.

The Hormuz Traffic Separation Scheme (TSS) — the engineered pair of unidirectional sea lanes that channel all commercial shipping through the 34-kilometer (21-mile) strait — had been mined by Iranian forces beginning in March 2026, according to 2026 Strait of Hormuz crisis documentation. US Navy officials confirmed on August 25 that American naval forces, using underwater drone systems and private contractors, had cleared more than 100 suspected mines from the TSS over recent months. A secondary complication: Iran was also reported to have deployed GPS spoofing and GNSS jamming technologies in the strait, degrading navigational accuracy and contributing to the environment in which vessels prefer to go dark rather than broadcast their position.

With mine clearance partially completed and US naval escorts operating through the corridor, the risk calculus for individual voyages shifted enough that some operators were willing to attempt crossings. The dark transit approach — cutting AIS transponders to reduce detectability — allowed vessels to move without providing Iran’s navy with an easily tracked, publicly broadcast target.

Iran has simultaneously been operating what it established in May 2026 as the Persian Gulf Strait Authority, a body that has claimed the right to regulate and authorize maritime transit and to charge tolls — a practice the United States has rejected as incompatible with international maritime law. Iran also redefined the “Strait of Hormuz” as a broader operational zone extending from the port of Jask to Sirik Island — well beyond the traditional straits definition — in a legal and strategic maneuver that remains unrecognized by Western governments.

QatarEnergy’s Enduring Constraint: No Exit Route, No Quick Fix

Qatar is in a structurally unique position among Gulf LNG exporters: every tanker carrying its gas must pass through Hormuz. The UAE has built pipeline alternatives for crude oil — the 380-kilometer (236-mile) Habshan-Fujairah pipeline moves Abu Dhabi oil to an east coast port outside the strait — but Qatar has no equivalent for LNG. Gas must be cooled to cryogenic temperatures and loaded onto specialized tankers at Ras Laffan, and those tankers have no route to open ocean except through the contested strait.

Qatar’s energy minister Saad Sherida Al-Kaabi addressed this directly in late September, ruling out any pipeline bypass as economically unviable — it would require building an entirely new LNG liquefaction plant at the end of the pipeline, outside the strait, before cargoes could reach overseas buyers. He added that Qatar’s 12 undamaged LNG production trains at Ras Laffan could return to normal operations “within weeks” once the strait is genuinely safe — but that conditional “within weeks” has been on the table since April, and the strait has not yet stayed safe long enough to test it.

Iranian missile strikes in March destroyed or heavily damaged two of the facility’s 14 production trains, reducing annual export capacity by approximately 17%. Al-Kaabi confirmed that repairs to the damaged trains would take approximately three years. In practical terms, even a full diplomatic resolution of the Hormuz dispute would leave global LNG markets structurally tighter than they were before February 28, for years.

QatarEnergy has extended its force majeure declaration — the legal mechanism that suspends a seller’s contractual obligations when circumstances beyond its control prevent delivery — on a rolling monthly basis throughout the crisis. In Italy alone, Edison, a unit of EDF, confirmed on September 29 that it had received a new force majeure notice extending QatarEnergy’s non-delivery through early December — bringing the total number of missed Edison cargoes to 35 since April. Edison’s official force majeure press release put the cumulative undelivered volume at approximately 3.8 billion cubic meters of gas. Edison’s 25-year contract with QatarEnergy supplies approximately 10% of Italy’s total gas consumption annually.

Buyers in Pakistan and Bangladesh were similarly notified that delivery suspensions will continue through November. Qatar had exported only 18 LNG cargoes in the first six months of the war, compared with 509 in the prior year, according to data provider ICIS.

Europe’s US LNG Dependency and the Catch-Up Race

With Gulf LNG flows severely constrained since March, European buyers have restructured their supply chains around US exports with speed that few anticipated. American LNG exports in September totaled approximately 10.9 million tonnes, with roughly 5.91 million tonnes — approximately 54% — directed to European buyers. Some estimates now put US LNG at roughly two-thirds of total EU LNG imports and approximately 30% of overall EU gas supply.

Cheniere Energy’s Chief Commercial Officer Anatol Feygin put the challenge plainly at September’s Gastech industry conference in Bangkok, telling Reuters at Gastech: “Europe is in a very difficult position going into this winter.” Equinor’s Senior Vice President for Marketing and Supply, Helle Ostergaard Kristiansen, made the competitive dynamic explicit — a cold winter in both Europe and Asia would put European and Asian buyers in direct bidding competition for US LNG cargoes, with the Atlantic Basin market as the swing supply.

Asian benchmark prices told the same story of tightness. The Japan-Korea Marker (JKM) briefly reached the high-$28 per million British thermal units range during the second week of September — its highest level in approximately two and a half years — before easing to the low-$25 range by month’s end as geopolitical risk premiums partially unwound. Henry Hub futures in the US moved in the opposite direction, edging higher through September as US LNG export demand remained structurally elevated.

Shell, which has estimated the war removed 36 million metric tons of LNG from global markets in 2026, said at Gastech that it sees global LNG supply returning to growth in 2027 — but remained cautious about the near term.

G7 Oil Release Signals Wider Energy Crisis Response

The scale of the energy disruption extended well beyond the LNG market to produce a broader policy response from major Western governments. On October 2, G7 nations led by French President Emmanuel Macron agreed to release 100 million barrels over four months, coordinated through the International Energy Agency and focused particularly on diesel supplies. The announcement followed pressure from Washington, including a threat from President Trump to restrict diesel exports.

The G7 statement said the nations would “implement our commitments with a coordinated release through the IEA of 100 million barrels to begin immediately over four months.” The 100 million barrel release equates to roughly 830,000 barrels per day if released evenly — a meaningful addition to refined product supplies, though analysts cautioned that strategic crude releases do not translate into diesel immediately, as refinery processing time and logistics intervene.

The combined picture emerging on October 2 — a wartime LNG high alongside a major G7 strategic reserve action — illustrates both the partial progress made in restoring Gulf energy flows and the degree to which the world’s richest nations remain on a wartime energy footing seven months into the conflict.

What Would Make the October Outlook?

Whether the September recovery holds into October depends on factors that the LNG market cannot control. Yep of S&P Global flagged two central uncertainties: first, whether Iran would resort to more serious military escalation if higher export volumes through Hormuz are perceived as eroding its leverage; second, whether naval escort costs remain sustainable at current intensity.

Iran’s position as of early October remained unchanged: its Foreign Minister and its Parliament Speaker had both issued warnings against regional infrastructure attacks, stating that no infrastructure in the region would be safe unless Iran’s security and sanctions relief were addressed. A seven-day reopening proposal that Iran’s foreign minister transmitted to Washington through Qatari mediators in late September — contingent on the US lifting its blockade, providing sanctions relief, and releasing frozen assets — was rejected by Trump on September 27.

Without a durable ceasefire, the “19 to 21 cargoes” figure that the market celebrated this week could be the ceiling of September’s wartime performance rather than the floor of a new trajectory.

Is Europe’s Winter Actually at Risk?

The short answer is: more than the September headline number suggests.

Reaching even 80% storage — the revised European Commission target — by November 1 would require attracting substantially more LNG cargoes per month through October than EPRINC and Wood Mackenzie considered achievable absent a full Hormuz resolution. European storage was approximately 71% full as of early October, compared with roughly 87% in a typical year. The gap is 16 percentage points, and the injection season is effectively over.

Anne-Sophie Corbeau, a gas expert at Columbia University’s Center on Global Energy Policy, noted months ago that the market’s failure to respond urgently to the storage gap would produce exactly this situation: “I have been saying for six months that we need to be more careful about storage or we will have high prices going into winter.”

Whether that winter will be severe or merely expensive depends on the weather — the same variable that saved Europe in the winters of 2022 and 2023. A mild autumn can ease demand enough to make 71% workable. A cold snap, concurrent with Asian buyers competing for the same US LNG cargoes, could produce the kind of price spike that forces industrial demand curtailment and presses household heating budgets across the continent.

None of that uncertainty cancels the fact that September marked a genuine wartime milestone in Hormuz LNG transit. What it means for European consumers is that the milestone needs to sustain itself through October, November, and the full heating season — in a strait where the last “sustained recovery” lasted just six weeks before Iran struck again in July.

Exchange rate as of October 2, 2026; conversions are approximate.

Frequently Asked Questions

What is the Strait of Hormuz and why does it matter for natural gas prices?

The Strait of Hormuz is a 34-kilometer (21-mile) wide chokepoint at the mouth of the Persian Gulf — the only sea passage through which oil and liquefied natural gas from Qatar, the UAE, Iraq, Kuwait, and Saudi Arabia can reach the open ocean. Before the US-Iran war began on February 28, 2026, approximately 20% of the world’s LNG trade passed through the strait each month. Qatar alone shipped around 509 LNG cargoes through it in the first six months of 2025; in the same period of 2026, only 18 made it through. When the strait is contested, global gas supply tightens sharply — and European household energy bills rise with it.

What are “dark transits” and why do they make the September cargo count uncertain?

A dark transit occurs when a ship deactivates its Automatic Identification System (AIS) transponder — the mandatory tracking beacon required under international maritime law. In the Strait of Hormuz, vessel operators have been turning off AIS to avoid being tracked and potentially targeted by Iranian naval forces. The practical result is that ship-tracking firms like Kpler and S&P Global can only confirm transits they have data for; vessels that go dark and stay dark are not reliably counted. That is why competing September cargo counts exist — Kpler’s figure of 21 cargoes differs from S&P Global’s count of 19, and from an earlier Kpler count of approximately 17 “confirmed” exits reported by some outlets. The dark-transit gap between those numbers represents real cargoes moving through the strait without public verification.

Why can’t Qatar simply route its LNG around the Strait of Hormuz?

Qatar has no alternative export route for its liquefied natural gas. Every LNG tanker departs from the Ras Laffan industrial complex on Qatar’s northeastern coast and must transit the Strait of Hormuz to reach the open ocean. Unlike the UAE, which has the Habshan-Fujairah oil pipeline running 380 kilometers (236 miles) to its eastern coast to bypass the strait for crude oil, Qatar has no equivalent infrastructure for gas. Building a bypass would require constructing an entirely new liquefaction facility outside the strait — a multi-year, multi-billion-dollar project. Qatar’s energy minister explicitly ruled this out as economically unviable in September 2026. That structural constraint means every barrel of Qatari LNG that reaches Europe or Asia depends on the safety and accessibility of a 34-kilometer (21-mile) channel currently contested by Iranian naval forces, underwater mines, and the threat of drone attack.

What does European gas storage at 71% mean for household energy bills this winter?

At 71% of storage capacity at the start of October — compared to a five-year seasonal average of 87% — Europe is entering its heating season with roughly 16 percentage points less gas cushion than a typical year. That shortfall translates into greater price sensitivity to any supply disruption, any cold snap, or any surge in Asian competition for available LNG cargoes. European TTF gas prices rose approximately 78–83% year-to-date as of October 2 to approximately €73–75/MWh ($82–$84/MWh), compared with roughly €41/MWh ($46/MWh) in early January. Goldman Sachs has warned that December 2026 TTF could exceed €100/MWh ($112/MWh) if Gulf supply normalization remains gradual. For consumers across the EU, that scenario would mean heating bills substantially higher than the war-elevated prices they have already paid for months — though a warm autumn could significantly moderate the outcome.