After several years of scarcity pricing — driven by the post-2022 scramble to replace Russian pipeline gas — the global LNG market is entering a very different phase. A large cohort of new liquefaction plants, sanctioned years ago, is now starting up more or less together. If the bulk of this capacity ramps on schedule, the second half of the 2020s should bring a markedly better-supplied market than the one buyers have grown used to.
Where the new supply is coming from
The current wave is concentrated in a handful of countries, led by the United States and Qatar, with a notable new entrant in Canada. Together, projects under construction worldwide add up to well over 100 million tonnes per annum (MTPA) of new capacity relative to a market that has recently traded around 420 MTPA.
| Country | Driver of new supply | Notes |
|---|---|---|
| United States | New Gulf Coast trains ramping up | Flexible, destination-free cargoes; see USA profile |
| Qatar | North Field expansion toward 142 MTPA | Low-cost, large-scale; see Qatar profile |
| Canada | First West-Coast exports | Short sailing distance to Asia |
| Others | Africa, Russia (sanction-constrained), small-scale | Adds incremental volume |
What makes this wave distinctive is not just its size but its timing: a lot of capacity arrives in a compressed window, which tends to move a market more sharply than the same volume spread over a decade.
Why a looser market is expected
The basic logic is supply-and-demand arithmetic. Demand for LNG is growing — particularly in price-sensitive Asian markets — but recent forecasts generally have new supply growing faster over 2026–2028 than demand can absorb at current prices. When that happens, several things tend to follow:
- Softer spot prices. Benchmarks like JKM (Asia) and TTF (Europe) ease as cargoes compete for buyers. See Pricing Mechanisms.
- More spot and flexible trade. A larger share of volume — much of it U.S. cargoes with no fixed destination — trades short-term rather than under rigid long-term contracts.
- Demand response. Lower prices pull in price-sensitive buyers, especially in China and India, who throttle imports up and down with the spot price.
- New demand unlocked. Cheaper LNG supports coal-to-gas switching and the slow build-out of LNG as a marine bunker fuel.
The caveats
A looser market is the central expectation, not a certainty. Several factors could delay or offset it:
- Construction and ramp-up delays. Large LNG projects routinely slip; a few quarters' delay across several plants can keep the market tight for longer.
- Unplanned outages. As the March 2026 episode showed, a single large disruption can erase a comfortable balance within days. (See our coverage of the Qatari production halt.)
- Cold winters or low wind. Weather still drives short-term demand and can drain storage faster than new supply refills it.
- Faster-than-expected demand. Strong Asian economic growth or aggressive coal-switching could soak up the extra cargoes.
What it means for buyers and sellers
For importers, a better-supplied market improves negotiating leverage and lowers the premium on long-term security — though prudent buyers remember how quickly tight conditions can return. For exporters, especially higher-cost ones, a softer market sharpens competition on price and reliability; low-cost producers such as Qatar are best placed to weather it. For the energy transition, cheaper gas is double-edged: it accelerates coal displacement but can also slow investment in alternatives.
Outlook
The signposts to watch are concrete: the actual ramp-up schedules of the new trains, European storage trajectories through each summer-and-winter cycle, the JKM–TTF spread that steers cargoes between basins, and Chinese spot buying. If the new capacity arrives broadly on time and winters are unremarkable, the late-2020s LNG market should feel materially more comfortable than the white-knuckle years that followed 2022.