Australia’s proposed Narrabri Gas Project is drawing increasing scrutiny from energy analysts who argue that the development may do little to ease domestic gas prices despite its significant investment requirements. A report released in February 2026 by the Institute for Energy Economics and Financial Analysis (IEEFA) suggests the coal seam gas development could produce gas at costs significantly higher than existing supply sources, limiting its ability to provide meaningful price relief for households and industrial consumers.
High Production Costs Could Set a New Price Floor
According to the IEEFA assessment, gas from the Narrabri development may rank among the most expensive sources in the Australian market. The report estimates the project’s break-even price could exceed $10 per gigajoule, substantially above the historical average for conventional gas fields.
These higher costs are largely linked to the technical complexity of coal seam gas extraction. Production requires large-scale dewatering of underground coal seams and significant new pipeline infrastructure to connect the fields in regional New South Wales to demand centers along Australia’s east coast. Analysts caution that introducing higher-cost gas into the supply mix could effectively create a new pricing floor, potentially pushing wholesale gas prices higher rather than lowering them.
This could have significant implications for gas-dependent sectors such as chemicals, fertilizers, and manufacturing, which rely on competitively priced energy to remain globally competitive.
Limited Impact on East Coast Gas Supply
Despite its scale, the project is expected to supply only around 5 percent of total east coast gas demand at peak output. Because of this relatively modest contribution, analysts argue that the project alone cannot resolve the region’s structural gas supply challenges.
The report highlights demand-side strategies as potentially more effective solutions. Improvements in energy efficiency and broader electrification – including replacing gas heating with electric heat pumps – could significantly reduce long-term gas demand. Each petajoule of gas saved through efficiency measures effectively creates new supply without requiring additional drilling, infrastructure investment, or emissions.
Environmental Risks and Water Management Concerns
Coal seam gas extraction also raises environmental concerns, particularly around groundwater management. The process requires pumping large volumes of underground water to the surface to release trapped gas. This produces substantial quantities of saline water that must be treated or disposed of safely.
IEEFA warns that long-term management of salt waste could pose environmental challenges and increase project costs. There are also concerns about protecting groundwater systems that support agriculture and local communities in regional New South Wales.
In addition, tightening global climate policies increase the risk that large fossil fuel developments could become stranded assets before the end of their intended operating life. If that occurs, investors or taxpayers could face significant decommissioning costs.
Alternative Approaches to Energy Security
Rather than relying primarily on new greenfield gas developments, the report recommends strengthening existing infrastructure and reducing structural demand. Expanding storage capacity at facilities such as the Iona Gas Plant could help manage seasonal supply fluctuations more efficiently.
The analysts also advocate an electrification-first approach that prioritizes renewable power integration and electrified heating systems. Such measures could stabilize long-term energy costs while supporting Australia’s climate commitments.
Major Gas Companies Advance Parallel Projects
While debate continues over Narrabri, several major companies are expanding production and infrastructure across Australia’s gas sector.
Santos Limited, the lead developer of the Narrabri project, has committed all production from the field to the domestic market. In early 2026, the company raised its annual production guidance to between 101 million and 111 million barrels of oil equivalent, supported by the ramp-up of the Barossa LNG Project and the start of production at the Pikka Oil Project in Alaska.
Origin Energy continues to strengthen its retail and supply portfolio. In February 2026, the company reported statutory profit of $557 million and announced an additional $25 million investment in the Golden Beach Gas Storage Project to enhance supply flexibility along the east coast.
Woodside Energy reported a net profit of $2.7 billion in its 2025 full-year results and recently marked a key milestone with the arrival of a floating production unit at the Scarborough Gas Field. On March 16, 2026, the company also held a sustainability briefing outlining how environmental priorities are being integrated into long-term business strategy.
Meanwhile, Senex Energy is expanding production in Queensland’s Surat Basin. The company announced a 50 percent increase in output from its Project Atlas operation following a $40 million investment aimed at delivering 18 petajoules of gas annually to Australian manufacturers.
Market Outlook Remains Tight
Market outlook reports highlight continuing supply uncertainty across Australia. The Australian Energy Market Operator recently released its 2025 WA Gas Statement of Opportunities, projecting a strengthened gas surplus for Western Australia through 2026 to 2030.
However, the situation on the east coast remains tighter. In its December 2025 interim report, the Australian Competition and Consumer Commission noted that while supply conditions may improve slightly in early 2026, producer offers for that year averaged $13.12 per gigajoule, reflecting persistent price pressure in southern states.
Overall, analysts suggest that while the Narrabri project could add new supply to the market, its high production costs and limited scale may restrict its effectiveness in delivering long-term relief for Australia’s domestic gas prices.
FASNA SHABEER