With Bass Strait production declining faster than projected and southern states facing potential supply shortfalls from 2028, inland gas projects like the Beetaloo Basin could become meaningful contributors to energy security Australia depends on, provided operators can overcome significant capital, regulatory, and execution challenges.
Eastern Australia’s gas market faces a complicated period of structural change. For decades, the Bass Strait has supplied roughly two-thirds of the gas used in the East Coast Gas Market, according to AEMO. Production from that legacy infrastructure is now declining faster than demand is falling, a trajectory that creates projected supply gaps no single solution can easily fill. Inland developments offer a potential path forward, though their contribution will depend heavily on commercial, environmental, and logistical conditions that remain unresolved.
The Drive Behind the Beetaloo Basin Development
Against that backdrop, the Beetaloo Basin in the Northern Territory has drawn considerable operator attention. Under a Gas Sales Agreement with the Northern Territory Government, Tamboran Resources is drilling horizontal wells reaching approximately 10,000 feet at its Shenandoah South project. They’re targeting first gas sales in mid-2026
Across at the Sturt Plateau Compression Facility, crews have passed the 78% completion mark, which the company reports as on schedule and within budget in its SEC filings. It’s a meaningful milestone for a project operating under tight timelines.
Reaching that mid-2026 target depends on stimulating four remaining wells, securing joint venture partner commitment, and clearing customary regulatory approvals. None of those are guaranteed. With a cash balance of US45.2 million as of June 30, 2025, per Tamboran’s SEC filings, and a broader pro forma liquidity figure of US71.1 million when including receivables, Tamboran’s financial headroom is fairly limited for a project of this ambition. A $28.5 million farm-in deal with Formentera and INPEX helps extend the runway, though the company has been frank with investors: meaningful revenue won’t arrive before 2026 at the earliest. Wet season drilling windows, permitting processes, and commodity price swings could each, independently, push that date further out.
Bridging the Gap for Energy Security Australia
Look past the headlines and the supply picture for energy security Australia gets considerably more complicated. According to the ACCC March 2025 Gas Inquiry Interim Report, the east coast market could face a shortfall of up to 9 petajoules across the July-to-September 2025 quarter if LNG producers export all uncontracted gas.
In the southern states specifically, ACCC modelling projects a potential 40-petajoule gap in the same period (a projected historic high for that quarter), driven primarily by declining production from the Gippsland, Otway, and Cooper basins.
ACCC Commissioner Anna Brakey stated that gas prices eased over the preceding six months, “reflecting movements in international prices and an increase in market activity following implementation of the Gas Code.” Contracted prices fell approximately 10 percent to $13.58 per gigajoule in the second half of 2024, offering some short-term relief for heavy industrial users.
Looking further ahead, AEMO’s 2025 Gas Statement of Opportunities puts peak-day shortfall risks on the clock from 2028, with structural supply gaps in southern states projected from 2029, and only under the assumption that every committed and anticipated project hits its milestones. For any Northern Territory gas to address southern demand, significant natural gas infrastructure linking the region to eastern grid connection points would need to be in place, a requirement that involves substantial lead times, capital expenditure, and regulatory coordination not yet fully secured.
Expanding LNG Asia Pacific Export Capabilities
Satisfying domestic contracts first is a stated priority for Beetaloo Basin operators, with surplus volumes potentially directed toward the LNG Asia-Pacific market. Maintaining consistent volumes for LNG Asia-Pacific buyers matters beyond pure revenue. Steady supply helps stabilise regional energy relationships and supports the trade alliances that underpin Australia’s international standing.
Delivering on export commitments while protecting domestic supply offers three potential economic benefits:
- Attracting foreign capital for large-scale natural gas infrastructure investment
- Offsetting development costs for domestic energy transition gas projects
- Strengthening trade alliances across the Asia-Pacific region
Balancing domestic obligations with export volumes requires precise logistical planning (export terminals typically lock in schedules months in advance), and commodity price swings in global LNG markets can affect project economics considerably. Stable domestic supply agreements, if achieved, could help underpin the investment case for expanded export facilities while also reducing the risk of domestic consumers bearing disproportionate cost increases.
Why the Energy Crisis Accelerates Infrastructure Growth
Could the current tightness in Australia’s energy market be what finally unlocks the investment needed to address longer-term shortfalls? Winter peak demand has a way of revealing what grid reliability actually means in practice. When wind generation drops and solar output fades, gas-fired power generation steps in to hold the system together, and that role becomes harder to fill as offshore reserves thin out.
According to AEMO CEO Daniel Westerman, “flexible gas-powered generation will remain the ultimate backstop in a high-renewable power system.” Gas, alongside batteries and pumped hydro, may support higher renewable penetration as coal-fired stations progressively retire, a position AEMO has consistently expressed in its annual planning reports. AEMO’s 2025 Gas Statement of Opportunities also notes that the phased exit of coal creates a generation gap at a time when overall consumption is rising due to electrification, making dispatchable gas-fired power generation a potential stabilising resource if sufficient fuel supply can be secured at competitive prices.
Securing Long-Term Power Supply Stability
Routing Northern Territory gas to major southern grids would likely involve significant new pipeline capacity and careful coordination of storage infrastructure. Yet, the buildout that remains unsecured and contingent on future investment decisions, approvals, and commercial agreements that are not yet in place. According to the Australian Department of Industry, Science and Resources, the government is working with LNG producers under the Heads of Agreement framework to ensure uncontracted gas is offered to the domestic market ahead of export during periods of potential shortfall.
Iona Underground Gas Storage sits at the centre of near-term winter planning, with the ACCC identifying it as essential to managing demand across the coming quarters. Any Beetaloo Basin contribution to power supply stability in the south remains some years away, and its scale will depend on commercial outcomes that are still uncertain. Planners may incorporate Northern Territory gas into long-term grid adequacy models, but those projections assume on-schedule delivery across a chain of interlinked natural gas infrastructure milestones.
Engineering the Next Phase of Grid Resilience
Tapping unconventional gas Australia-wide requires considerably more than a strong drilling result. Environmental monitoring is a legal requirement for hydraulic fracturing operations in the Northern Territory, and methane management is coming under increasing regulatory scrutiny. Tamboran has disclosed a Scope 1 net-zero obligation upon commencing commercial production, adding both complexity and cost to what is already a capital-intensive operation.
What does long-term grid reliability actually require? Probably a combination of new supply, storage upgrades, natural gas infrastructure investment, and sustained demand-reduction policies, rather than any single intervention. According to AEMO, all scenarios in its 2025 modelling identify the need for new supply investments to support energy transition gas objectives, though the optimal mix continues to be assessed. Developing the unconventional gas Australia holds, including Beetaloo Basin resources, remains part of a wider energy security Australia effort, provided regulators, investors, and communities can align on the terms.
Disclaimer: Forecasts and project timelines cited are based on publicly available data from AEMO, the ACCC, and company disclosures as of publication. Actual outcomes may differ materially. Nothing in this article constitutes financial or investment advice.