Australia is one of the three largest LNG exporters in the world, alongside the United States and Qatar, with nameplate liquefaction capacity of roughly 88 million tonnes per annum (MTPA) spread across ten projects on the country's west, north, and east coasts. Built out in a remarkable decade-long, multi-hundred-billion-dollar investment wave, the industry now faces a different challenge: ageing upstream gas fields, a politically charged domestic shortage on the East Coast, and pressure to decarbonise some of the most emissions-intensive plants in the global fleet.
How Australia became an LNG superpower
Australia's LNG story runs in two chapters. The first began in 1989, when the North West Shelf project off Western Australia shipped its first cargo to Japan, anchoring decades of Asian demand. The second was the 2010s construction boom: seven major projects reached final investment decision in quick succession, and total capacity quadrupled. By the late 2010s Australia had briefly become the world's largest LNG exporter before the United States and Qatar's expansions reordered the table.
What makes Australia distinctive is the diversity of its gas sources. The country liquefies conventional offshore gas (the West Coast and Northern Territory projects), unconventional coal seam gas (the Queensland projects — the first plants in the world to liquefy CSG at scale), and even offshore gas via the world's largest floating facility, Prelude FLNG.
The major projects
Australian LNG clusters into three regions. The West Coast (Western Australia) and the Northern Territory process conventional offshore gas; Queensland's East Coast projects are fed by coal seam gas.
| Project | Location | Capacity (MTPA) | Lead operator | Gas source |
|---|---|---|---|---|
| Gorgon | Western Australia | ~15.6 | Chevron | Offshore conventional |
| North West Shelf | Western Australia | ~16.9 | Woodside | Offshore conventional |
| Wheatstone | Western Australia | ~8.9 | Chevron | Offshore conventional |
| Ichthys | Northern Territory | ~8.9 | INPEX | Offshore conventional |
| Pluto | Western Australia | ~4.9 | Woodside | Offshore conventional |
| Prelude FLNG | Offshore WA | ~3.6 | Shell | Offshore (floating) |
| Queensland Curtis (QCLNG) | Queensland | ~8.5 | Shell | Coal seam gas |
| Australia Pacific (APLNG) | Queensland | ~9.0 | ConocoPhillips / Origin | Coal seam gas |
| Gladstone (GLNG) | Queensland | ~7.8 | Santos | Coal seam gas |
| Darwin LNG | Northern Territory | ~3.7 | Santos | Offshore conventional |
A coal-seam-gas first: The three Queensland plants (QCLNG, APLNG, GLNG), all near Gladstone, were the first in the world to liquefy coal seam gas — methane extracted from coal beds — at export scale. This required drilling thousands of wells across the inland Surat and Bowen basins and piping the gas hundreds of kilometres to the coast.
Export markets
Australia's LNG flows almost entirely into North Asia, reflecting both geography and the long-term contracts that underwrote the projects' construction:
- Japan — the foundation customer since 1989 and still the largest single destination.
- China — a major and growing buyer, taking a large share under long-term deals.
- South Korea — a long-standing North Asian customer.
- Taiwan and Southeast Asia — smaller but steady volumes.
Proximity is Australia's enduring advantage: a cargo from Western Australia reaches Japan in roughly half the sailing time of one from the U.S. Gulf Coast, lowering shipping cost and emissions per delivered tonne. The trade-off is concentration — Australia's fortunes are tightly tied to North Asian demand and to the JKM spot benchmark. See LNG pricing for how JKM, TTF, and Henry Hub interact.
The East Coast domestic supply squeeze
One of the defining policy issues in Australian energy is a paradox: a top-three LNG exporter faces forecasts of domestic gas shortages in its populous southern states.
When the Queensland CSG-to-LNG plants were built, they linked the previously isolated East Coast gas market to global prices for the first time. Gas that once stayed onshore could now be exported, and domestic prices rose toward export parity. With southern conventional fields (notably in Bass Strait) in decline, market operators have repeatedly warned of potential winter shortfalls in the south later this decade.
Government responses have included a mandatory code of conduct for gas producers, an "Australian Domestic Gas Security Mechanism" allowing export limits in a shortfall, and proposals for southern LNG import terminals — the unusual prospect of an export superpower importing LNG into its own southern cities because moving gas from the north is harder than shipping it overseas.
Emissions and the Scarborough/Browse question
Australian LNG sits under growing climate scrutiny on two fronts. First, several fields contain high levels of reservoir CO₂ that must be stripped out before liquefaction; Gorgon hosts one of the world's largest carbon capture and storage projects, injecting CO₂ underground beneath Barrow Island — though it has run below its design capture target. Second, the federal Safeguard Mechanism now caps and ratchets down emissions from large industrial facilities, directly affecting LNG plants.
Future growth hinges on developing new gas to backfill ageing fields — Woodside's Scarborough project (feeding an expanded Pluto) is the largest near-term addition, while the Browse Basin remains a long-debated, environmentally contested prospect. The central tension is whether Australia can sustain export volumes without breaching tightening domestic emissions limits. See carbon capture in LNG and methane emissions for the underlying technology and measurement issues.
Outlook
- Plateau, not expansion. Unlike the U.S. and Qatar, Australia has few new greenfield trains under construction. The near-term story is sustaining existing capacity by developing backfill gas, not adding nameplate.
- Upstream depletion is the binding constraint. Several plants face declining feed gas and need new fields tied in to stay full.
- Domestic politics will shape exports. The East Coast shortfall debate could constrain how freely gas is exported from Queensland.
- Decarbonisation pressure is structural. The Safeguard Mechanism and investor scrutiny make emissions performance a competitive factor, not an afterthought.
Frequently asked questions
Is Australia the biggest LNG exporter?
Australia is consistently among the top three LNG exporters in the world, trading places with the United States and Qatar depending on the year. It was briefly the single largest exporter in the late 2010s before the U.S. and Qatari expansions moved ahead.
How much LNG does Australia produce?
Australia has roughly 88 MTPA of nameplate liquefaction capacity across ten projects, though actual output varies with field performance and demand.
Why does an LNG exporter like Australia worry about gas shortages?
The export plants are on the coast and linked to global prices, while the populous southern states rely on separate, depleting conventional fields. Moving northern gas south is costly, so southern Australia faces potential winter shortfalls — and has even considered building LNG import terminals.
What is special about Australia's Queensland LNG plants?
The three plants near Gladstone were the first in the world to liquefy coal seam gas (methane from coal beds) at export scale, fed by thousands of inland wells.
Key takeaways
- Australia is a top-three global LNG exporter with ~88 MTPA across ten projects
- Gas sources are unusually diverse: offshore conventional, coal seam gas, and floating LNG
- Queensland's Gladstone plants were the world's first CSG-to-LNG facilities
- Exports flow overwhelmingly to Japan, China, South Korea, and Taiwan
- The East Coast faces a domestic supply squeeze despite the export boom
- Growth depends on backfill gas (Scarborough, Browse) under tightening emissions caps