Australia's New Domestic Gas Reservation Policy: Key Concerns and Uncertainties

The Australian federal government has rejected calls for a 25% tax on liquefied natural gas (LNG) exports, instead announcing a 20% domestic gas reservation policy effective from July 1 next year. This decision, outlined in the recent federal budget, has raised significant concerns among critics and producers, who argue it creates more questions than answers regarding its implementation and long-term market impact.

Policy Implementation and State-Level Coordination

While the concept of gas reservation is not new—Western Australia has had a similar policy for nearly two decades—the national scheme introduces uncertainty about how it will align with existing state-level policies. Key unresolved issues include whether volumes reserved under the Western Australian policy (which mandates 15% over a project's life, not annually) will count toward the national requirement. Commercial law firm Allens suggests it "seems likely" that the state's 15% will be considered, but industry consultations are ongoing. Critics also note that Western Australia's limited pipeline infrastructure connecting it to the Northern Territory and East Coast poses practical obstacles, potentially necessitating exceptions for transportation limitations.

Impact on Producers and Export Contracts

Analysts at Wood Mackenzie warn that the policy could affect future export contract negotiations and raise feasibility questions for projects lacking domestic pipeline infrastructure. The policy excludes gas already allocated under long-term contracts signed before December 22, 2025, meaning immediate relief for domestic supply shortages is unlikely. Current export contracts are not expected to expire until the 2030s, delaying the policy's impact. Some operators have expressed support for a "credit system" allowing flexibility, such as selling to domestic customers, arranging swaps, or trading obligations with other export projects, as noted by S&P Global's Logan Reese.

Market Uncertainty and Long-Term Risks

The policy introduces potential market distortions, uneven impacts across producers, and higher long-term upstream investment risk. Questions remain about how increased domestic gas volumes will affect the market when export contracts expire, particularly for operators with planned domestic-only projects. Until specific mechanisms are released, uncertainty is likely to persist for both gas buyers and sellers, potentially destabilizing rather than stabilizing the domestic market.

Fiscal Context and Existing Tax Regime

The Petroleum Resource Rent Tax (PRRT) remains the primary levy on oil and gas producers, a relief for major producers who defended the status quo in a recent senate inquiry. Despite the rejection of a 25% export tax, the federal exchequer is expected to benefit from higher oil prices due to Middle East conflicts and increased domestic production. Budget papers project PRRT revenues will rise by A$400 million (US$286 million) in 2026-2027, a 27% increase from 2023-2024, totaling A$1.6 billion over five years through 2030.