Australia occupies a paradoxical position in the global energy landscape. It is the world’s largest exporter of liquefied natural gas (LNG), shipping vast volumes to Japan, China, South Korea, and other Asian buyers. Yet Australians themselves face some of the highest gas and electricity prices in the developed world, a situation that has generated intense political controversy and prompted government intervention. The story of Australian energy in 2026 is one of extraordinary export wealth alongside domestic affordability challenges — and a renewable energy transition that is accelerating but unevenly paced.
LNG Export Giant
Australia’s LNG export sector has grown from almost nothing in the early 2010s to world-leading scale within a decade. The country’s three main LNG export hubs — North West Shelf and Gorgon/Wheatstone in Western Australia, and the Queensland Curtis, Gladstone, and Australia Pacific LNG projects on the east coast — have a combined capacity of approximately 88 million tonnes per annum (mtpa). In 2025, Australia exported approximately 81 million tonnes of LNG, making it the world’s top LNG exporter alongside Qatar.
The primary buyers are in Asia. Japan, which has been dependent on LNG for baseload power since the 2011 Fukushima disaster triggered a nuclear shutdown, is Australia’s largest customer. South Korea’s KOGAS and major power utilities are significant long-term contract holders. China has been both a large buyer under long-term contracts and an active participant in spot markets, though the relationship between Australia and China has been commercially significant but diplomatically complicated.
LNG export revenues represent a substantial contribution to Australia’s national income. The sector has invested hundreds of billions of dollars in upstream gas development, liquefaction infrastructure, and marine terminals, supporting significant employment particularly in Western Australia and Queensland.
The Domestic Price Problem
Despite sitting atop world-class gas reserves, Australian households and businesses have faced sharply elevated gas and electricity prices over recent years. The mechanism is straightforward: because Australian LNG is sold into global export markets at international prices, domestic gas must compete economically with export parity pricing. When global LNG prices spiked in 2021–2022 following the Ukraine crisis and Asian demand surges, domestic Australian gas prices rose in tandem, triggering industry outrage and policy responses.
The Australian government introduced domestic gas reservation mechanisms — price caps and mandatory domestic supply obligations for east coast gas producers — as emergency measures in 2022–2023. These have been extended and modified but remain politically contentious, with the LNG industry arguing that they undermine investment incentives and the broader principle of market-based pricing, while consumer groups and manufacturers argue that resource-rich Australians should not pay export-linked prices for their own gas.
East Coast vs West Coast: A Tale of Two Markets
Australia’s gas market has a geographic split that complicates policy. Western Australia has long maintained a domestic gas reservation policy, requiring LNG exporters to reserve 15% of their production for the domestic market at regulated prices. This policy has kept domestic gas prices in WA considerably lower than on the east coast and is widely credited with protecting WA’s manufacturing sector and households. The IEA has pointed to the WA model as an example of how resource-rich jurisdictions can balance export ambitions with domestic affordability.
The east coast, by contrast, has a more fragmented and price-exposed market. The Queensland LNG projects draw on the same gas basins that supply Sydney, Melbourne, and Brisbane consumers, creating direct competition for supply. Infrastructure constraints — particularly limited pipeline capacity from the northern gas basins to southern demand centres — exacerbate the price volatility problem.
The Renewable Transition
Australia’s electricity grid is undergoing a rapid and at times turbulent transition to renewable energy. South Australia — which has some of the best wind resources in the world — has been a pioneer, with wind and solar regularly covering over 100% of state electricity demand at favourable times. The state’s investment in grid-scale battery storage, particularly the Tesla Hornsdale Power Reserve (the “big battery”), demonstrated that large-scale storage could provide fast-frequency response more cost-effectively than conventional thermal plant.
Nationally, Australia’s Renewable Energy Zone (REZ) programme is developing designated areas with strong resources, transmission access, and coordinated development frameworks. Major projects in New South Wales, Victoria, and Queensland are under development, with offshore wind a significant future growth area given Australia’s long coastline. The government has set a target of 82% renewables in the national electricity market by 2030 — ambitious given that renewables currently provide around 38%.
The pace of transition has created its own challenges. The retirement of coal-fired power stations — several of which have closed earlier than anticipated — has reduced dispatchable capacity and contributed to reliability concerns in some periods. The construction of replacement capacity has not always kept pace with retirement, and grid-scale storage and transmission investment are seen as critical to managing the transition safely.
Gas as Transition Fuel
Gas-fired generation plays an important role in Australia’s electricity transition, providing peaking capacity and backup during periods of low renewable output. Gas peakers can ramp quickly, providing the flexibility needed in a high-renewable grid. However, gas generation becomes increasingly costly as carbon pricing mechanisms are developed and as renewable and storage costs continue to fall.
The long-term future of gas in Australia’s domestic market is genuinely uncertain. On the one hand, LNG exports are likely to continue well into the 2030s as Asian buyers — particularly Japan and South Korea — have not yet found affordable substitutes for gas in power and industrial applications. On the other hand, domestic gas demand for heating and hot water is being gradually displaced by electrification, and the economics of gas peaking plant are challenged by falling battery storage costs. Follow developments in global gas markets and Australian renewables across our site.
