LNG Trade
Global LNG trade reached 400 million tonnes in 2023 — quadruple the 2000 level. The US became the world's largest LNG exporter in 2023, exceeding Qatar and Australia. Europe replaced 80% of lost Russian pipeline gas with LNG imports in 2022–23. The post-2022 European market reshape is one of the largest energy trade-flow shifts in history.
Key insights
US LNG export industry built in a decade
The US was a net LNG importer until 2015. The first export terminal (Cheniere Sabine Pass) commissioned in February 2016. By 2024 the US operates 7 export terminals with 7 more under construction. The shale revolution generated stranded cheap gas; LNG provided the export outlet. Without the 2008-2015 shale boom, the European response to 2022 would have been very different.
Qatar's North Field expansion
Qatar's North Field is the world's largest single gas reservoir. QatarEnergy is doubling its LNG export capacity from 77 Mtpa to 142 Mtpa by 2030 — adding capacity equivalent to half of the entire US LNG industry. Long-term contracts (20+ years) with European utilities, Chinese state companies, Japanese trading houses and US oil majors have locked in much of the new supply. Qatar will remain a top-3 LNG exporter for decades.
Spot vs long-term contract markets diverged
Most LNG historically traded under 15-25 year contracts indexed to oil prices. The 2022 European demand surge pulled spot prices well above contract prices for ~18 months. Asian buyers (Japan, Korea, China, India) saw US and Australian cargoes diverted to Europe at higher prices. The diversion exposed Asian buyer dependence on a 'flexible' market that ran out of flexibility in stress. New contracts since 2022 have been signed with destination flexibility but mostly long-term fixed-price.
Top LNG exporters 2023
Million tonnes per annum
Key Finding: USA passed Qatar and Australia in 2023. Russia (pre-2022) had been a major LNG exporter; sanctions have suppressed its share.
EU gas import mix 2019–2024
% of EU gas imports
Key Finding: Russian pipeline gas collapsed from 41% (2021) to under 8% (2024). LNG share more than doubled.
Methodology & caveats
LNG basics
Natural gas is cooled to -162°C for transport. Liquefaction reduces volume by ~600× and enables ocean transport. Receiving terminals regasify and inject into pipeline grids. Capital cost: $5-10B per train (~7 Mtpa). Operating margins depend on the spread between source-region gas price plus liquefaction cost and destination gas price. The combined cost is ~$5-7/MMBtu — the structural floor on intercontinental gas arbitrage.
Three main pricing regions
Henry Hub (US, ~$2-4/MMBtu) is the cheap producer market. TTF (NW Europe, ~$10-12/MMBtu) is the deep liquid European hub. JKM (Asia LNG spot) tracks Japan/Korea/China deliveries. The TTF-Henry Hub spread minus liquefaction-plus-shipping costs (~$5/MMBtu) is the rough margin available to US LNG exporters.
Climate impact
Natural gas combustion produces about half the CO₂ per unit energy of coal. But methane leakage from production, processing, transport and LNG liquefaction can offset some of the advantage. Leakage rates vary widely — US Permian basin estimates run 2-4% of production; Norwegian operations under 0.5%. LNG climate footprint is roughly comparable to coal on a 20-year basis if leakage exceeds 3%; far better at 1%.