One Shock, Many Desks: From LNG Tankers to Interest Rates
In the three months before the current Middle East conflict began on 28 February 2026, Qatar exported an average of around 6.51 million tonnes of liquefied natural gas each month through the Strait of Hormuz. By August, only around 70,000 tonnes, roughly one cargo, had managed to leave through the Strait. The scale of that collapse matters because the Strait of Hormuz had previously carried almost 20 per cent of global LNG supply, according to the International Energy Agency.
At first, this looks like a straightforward commodity story. Remove a major source of supply and the price rises. Yet the global LNG market has made the consequences much more interesting. A missing cargo from Qatar can change what an Asian utility is willing to pay, redirect another tanker towards Europe, alter European gas prices, affect household energy bills and eventually influence what financial markets expect the European Central Bank to do with interest rates.
That is the journey from cargo to curve.
LNG, or liquefied natural gas, is ordinary natural gas that has been cooled to around minus 162 degrees Celsius until it becomes a liquid. In liquid form, natural gas occupies around 600 times less space than it does as a gas, which allows it to be transported in specialised tankers between regions that cannot easily be connected by pipeline. At an import terminal, the LNG is converted back into gas before entering pipelines and reaching power stations, industrial facilities and consumers.
This ability to transport natural gas across oceans has linked regional gas markets much more closely. Europe and Asia can now compete for the same flexible cargo even though they are thousands of miles apart. That also means that a disruption in one exporting region can quickly affect prices somewhere else.
Qatar is particularly important within this system. Before the war, it supplied nearly one fifth of global LNG and competed with Australia as the second largest exporter behind the United States. The problem is no longer purely about ships struggling to pass through Hormuz. QatarEnergy said in September that attacks on its Ras Laffan export complex had disabled around 17 per cent of Qatar’s LNG capacity and damaged two LNG trains, which are processing units that turn natural gas into LNG. Repairs to those units could take as long as three years.
However, the disappearance of Gulf exports did not translate into an equally large fall in global LNG supply. Other producers responded.
Between March and June, LNG loadings from Qatar and the United Arab Emirates fell by around 35 billion cubic metres compared with the same period a year earlier. During those same months, LNG production outside the Gulf increased by around 27 billion cubic metres as new projects in North America and Africa came online and existing producers increased output. This replaced around three quarters of the lost Gulf deliveries, leaving global LNG production around 4 per cent lower over the period rather than collapsing by anything close to 20 per cent.
This is the first important market insight. The size of the original disruption is only one part of the story. What matters next is the elasticity of supply, meaning how easily other producers can respond when prices rise.
The International Energy Agency expects new LNG projects in North America, Africa and Australia to add close to 50 billion cubic metres of supply to the global market during 2026, while existing projects could contribute more than another 10 billion cubic metres. As a result, the IEA expects global LNG supply for the full year to remain broadly unchanged from 2025, despite the enormous reduction in Gulf exports.
But replacing lost supply is not the same as replacing it at the same price.
In March, immediately after the disruption, natural gas prices in both Europe and Asia reached their highest monthly averages since January 2023. European TTF prices averaged around 18 dollars per MMBtu, while Asian JKM traded close to 21 dollars per MMBtu. Price volatility also surged sharply.
TTF, or the Title Transfer Facility, is the main reference price for European natural gas and has grown from a Dutch trading hub into one of the world’s most important gas benchmarks. JKM, or the Japan Korea Marker, is the main benchmark for spot LNG cargoes delivered into Japan, South Korea, China and Taiwan. MMBtu means one million British thermal units and is a common unit for measuring the amount of energy contained in natural gas.
The relationship between those two prices helps determine where flexible LNG moves.
During January and February, European gas carried an average premium of around 0.90 dollars per MMBtu over Asian LNG. Between March and June, that relationship reversed. JKM traded at an average premium of around 2.10 dollars per MMBtu over TTF, and the International Energy Agency says this encouraged flexible LNG cargoes to move away from Europe and towards Asian markets.
This is where commodity markets behave differently from many financial markets. Price is not merely recording the fact that gas is scarce. It is helping decide where physical energy goes.
An LNG trader deciding whether a flexible cargo should sail towards Europe or Asia cannot simply compare the two headline prices. The trader also has to account for freight, fuel, journey time, available ships, terminal capacity and contractual restrictions. The relevant number is therefore closer to the netback, which is the value left after the costs of delivering the cargo have been deducted.
If Asia offers a higher headline price but is much more expensive to reach, Europe may still offer the better return. When the difference between regional prices becomes wide enough to overcome those delivery costs, a tanker can physically change destination. This gives LNG an important role in connecting previously separate regional gas markets. ICE describes Europe as an important balancing market for global LNG because its liquid gas market and extensive infrastructure allow it to absorb cargoes that are not sold in Asia.
The other way a commodity market can rebalance is less comfortable. Consumers can simply stop buying.
By the week ending 11 September, LNG cargoes for delivery into North Asia were being assessed at around 26 dollars per MMBtu, compared with around 10.40 dollars immediately before the conflict. That represented an increase of approximately 150 per cent.
At those prices, demand in more price sensitive Asian markets began to weaken. Asia was expected to import around 20.09 million tonnes of LNG in September, its weakest September in eight years. China’s imports were estimated at 4.32 million tonnes, compared with 5.32 million tonnes a year earlier, while Pakistan’s imports were expected to fall from 490,000 tonnes in September 2025 to only 120,000 tonnes in September 2026.
Some countries have also responded by switching from expensive gas towards coal and oil. The International Energy Agency expects Asian natural gas demand to decline during 2026 as high LNG prices encourage fuel switching in power generation and lower activity in energy intensive industries.
This is demand destruction. Prices rise far enough that some consumers reduce how much they buy, switch fuels or cut production altogether.
For a commodity trader, that creates an important question. It is not enough to know where demand is strongest. The trader also needs to understand which demand will survive if prices rise further.
This process has produced a counterintuitive result for Europe. High LNG prices have made life more difficult for Asian buyers, but the reduction in Asian purchases has freed some cargoes for Europe.
European LNG imports were expected to rise to around 7.98 million tonnes in September from 7.55 million tonnes in August, while Asian imports were falling. Europe therefore benefits from additional physical supply when some Asian demand disappears, even though it still has to pay much higher prices to attract those cargoes.
That distinction between physical availability and affordability is central to the current European gas market.
By mid-September, European Union gas storage was only around 68 to 69 per cent full, compared with a five year seasonal average of roughly 85 per cent. Storage gives Europe a buffer because gas accumulated before winter can be withdrawn when heating demand increases. Lower inventories therefore leave the region more exposed if the winter is cold or if further supply is disrupted.
Europe is nevertheless in a stronger structural position than it was during the 2021 and 2022 energy crisis. The European Commission said this month that increased supply diversification, greater LNG import capacity and lower overall gas demand mean there is currently no immediate risk to security of supply, despite below normal storage levels.
The market’s challenge is therefore less about whether Europe can obtain gas at all and more about the price required to secure enough of it.
This has also changed how LNG buyers think about security. Companies and importing countries are increasingly looking for supply from a wider range of regions, including North America, West Africa, Indonesia and Australia. Reuters reported in September that LNG buyers and sellers are deliberately broadening both their sources and delivery routes following the disruption in the Gulf.
For a commodity trading business, diversification creates optionality. A portfolio that can source cargoes from several countries and redirect them across multiple markets is more valuable when one supply route suddenly becomes unavailable. The current crisis has therefore highlighted that flexibility itself can have economic value.
Up to this point, the story remains largely one of physical energy markets. The connection to Global Markets begins when high wholesale gas prices start passing through the wider European economy.
The European Central Bank published research in September showing that changes in wholesale gas prices are now transmitted into household gas inflation more quickly than they were during the previous energy crisis. In more than half of the euro area, changes in wholesale gas prices are now expected to feed into HICP gas inflation, the euro area’s measure of consumer gas price inflation, within just one to three months. In 2022, around 40 per cent of countries experienced a much longer transmission lag of 13 to 24 months, whereas today that figure has fallen to roughly 5 per cent.
There are several reasons for this faster transmission. The ECB points to greater liberalisation of retail gas markets, shorter fixed contracts and more flexible tariffs that are more closely linked to wholesale prices. At the same time, the effect of gas prices on electricity bills has weakened somewhat because Europe now generates more electricity from renewable sources.
This creates the bridge from energy trading into interest rate markets.
The ECB raised its three main policy rates by 25 basis points in June, explicitly stating that the Middle East war was generating inflation pressures and that higher energy prices were expected to feed into food, goods and services inflation. It raised them by another 25 basis points in September, taking the deposit facility rate to 2.50 per cent. Its latest projections put headline inflation at 3.0 per cent in 2026, 2.5 per cent in 2027 and 2.1 per cent in 2028.
This does not mean that every rise in LNG prices automatically leads to an ECB rate increase. What matters is persistence.
A rates trader watching European gas markets would therefore care about whether the shock is temporary, whether companies are passing higher energy costs into other prices, whether workers respond by demanding higher wages and whether inflation expectations remain anchored around the ECB’s 2 per cent target. The ECB itself has said it is monitoring the size and persistence of the energy price shock and how it feeds into wages, prices, inflation expectations and the wider economy.
If markets conclude that energy inflation will remain stronger for longer, expectations for the future path of ECB interest rates can change before the central bank actually makes another decision. That can alter European government bond yields and move the entire interest rate curve.
The same shock can create a more ambiguous signal for currencies. Higher expected European rates can support the euro because euro denominated assets become relatively more attractive, but expensive imported energy can simultaneously weaken European growth and reduce household purchasing power. An FX trader therefore has to decide which of those competing forces the market is placing more weight on.
Equity investors face another version of the same problem. Energy intensive manufacturers may suffer if they cannot pass higher gas costs to customers, while LNG producers can benefit from higher realised prices. Companies that hedged their future energy costs may be less exposed than competitors buying energy at current market prices.
The interesting part of the story is not that every trading desk reacts in the same direction. It is that the same physical shock generates different questions depending on which part of the market absorbs it.
For the commodity trader, the story begins with supply, regional price differences, freight costs and the flexibility to move cargoes. For the macro trader, the important question comes later: whether the price needed to bring those cargoes into Europe is high enough and persistent enough to alter inflation and monetary policy.
A disruption in one narrow waterway can therefore travel surprisingly far. It can reduce Qatari LNG exports, encourage new production elsewhere, increase Asian and European prices, change the destination of physical tankers, destroy demand among price sensitive consumers, expose weaknesses in European storage and eventually change expectations for ECB policy.
The original shock occurs in the physical commodity market. The consequences do not stay there.
For traders, understanding what has already moved is useful. Understanding where the shock travels next may be much more valuable.
References
Reuters, 17 September 2026. LNG spot price surge deters Asian buyers, but saves Europe.
https://www.reuters.com/commentary/reuters-open-interest/lng-spot-price-surge-deters-asian-buyers-saves-europe-2026-09-17/
International Energy Agency, July 2026. Gas Market Report, Q3 2026.
https://www.iea.org/reports/gas-market-report-q3-2026/executive-summary
Reuters, 21 September 2026. QatarEnergy says Hormuz crisis may delay LNG expansion projects.
https://www.reuters.com/business/energy/qatarenergy-says-hormuz-crisis-may-delay-lng-expansion-projects-2026-09-21/
Reuters, 21 September 2026. LNG buyers and sellers seek greater supply diversity amid Iran war.
https://www.reuters.com/business/energy/lng-buyers-sellers-seek-greater-supply-diversity-amid-iran-war-2026-09-21/
European Central Bank, 21 September 2026. The uneven journey of wholesale gas and electricity prices to consumer bills.
https://www.ecb.europa.eu/press/economic-bulletin/focus/2026/html/ecb.ebbox202606_04~5f026ee8e2.en.html
European Central Bank, 10 September 2026. Monetary policy decisions.
https://www.ecb.europa.eu/press/pr/date/2026/html/ecb.mp260910~314e508016.en.html