Tamboran Resources operates in a capital-intensive and technically challenging upstream shale gas sector with a focus on the Beetaloo Basin. The company’s current business model relies on successful pilot project execution and subsequent scaling via farmouts and infrastructure development. While ge…
Tamboran Resources (TBN) Q3 2025: $96M Capital Raise Fuels 3-Well Drilling Push Toward Mid-2026 First Gas
Tamboran Resources secured a $70 million capital raise, boosting pro forma cash to $96 million, fully funding its Shenandoah South pilot drilling and completion activities. The company targets mid-2026 for first gas from its ~40 MMcf/d pilot project, underpinned by a 62-day soak and ongoing flow testing of the SS-2H ST1 well. A formal farmout process for 400,000 acres in the Phase 2 Development Area has commenced, positioning Tamboran for scale-up into Australia's East Coast gas market by decade-end.
Summary
- Funding Milestone Achieved: Pro forma cash of $96 million enables full funding of pilot project drilling and completions.
- Operational Efficiency Gains: Targeted sub-25 day spud-to-total-depth drilling with local sand use aims to reduce well costs materially.
- Strategic Expansion Set: Farmout process underway for 400,000 acres targeting East Coast gas market supply by 2029-30.
Business Overview
Tamboran Resources is an upstream natural gas exploration and development company focused on the Beetaloo Basin in Australia’s Northern Territory. The company operates and holds interests in multiple shale gas acreage blocks, generating value through drilling, hydraulic fracturing, and gas production. Its business model centers on advancing pilot projects toward commercial production and monetizing resources via domestic gas sales and potential exports. Key segments include the Shenandoah South pilot project and the Phase 2 Development Area, aimed at supplying local and East Coast Australian gas markets.
Performance Analysis
Tamboran successfully completed 35 stimulation stages in the SS-2H ST1 well, followed by a 62-day soaking period designed to enhance well productivity by dehydrating fractures in the highly desiccated Mid Velkerri B Shale. Flow testing commenced in mid-May 2025, with an initial 30-day flow test (IP30) expected in June and a full 90-day test (IP90) by August. This extended soak period is a strategic shift from prior shorter soak times, supported by CoreLab modeling predicting production uplift from soaking in this unique geological setting.
The company raised $70.4 million in May 2025, including a $55.4 million private investment in public equity (PIPE) and a $15 million acreage sale to Daly Waters Energy (DWE), boosting pro forma cash to $96 million. This funding fully supports drilling and completion of three additional wells (SS-4H, 5H, and 6H) planned for the second half of 2025, targeting sub-25 day drilling cycles and leveraging batch drilling and optimized technologies to improve cost efficiency.
- Cost Efficiency Drive: Local sand sourcing is expected to cut sand costs by approximately $3.5 million per well, a major contributor to reducing well costs from $28 million toward a $16 million target.
- Scale and Timing: The company plans to pump 240 completion stages across four wells, including the SS-3H well, with first gas from the pilot project on track for mid-2026.
- Strategic Acreage Management: The Phase 2 Development Area farmout process has begun, focusing on ~400,000 gross acres with 58% operated interest, aimed at supplying the East Coast gas market facing a forecasted ~1 Bcf/d shortfall by 2029-30.
These developments demonstrate Tamboran’s progress in de-risking its assets, optimizing operations, and positioning for commercial gas production and expansion.
Executive Commentary
"Having successfully raised funding to progress drilling activity in the Beetaloo Basin, we are focused on delivering the largest single drilling campaign in the region to date. The program includes three wells drilled from the SS2 pad, commencing in mid-2025, and stimulation of up to 240 stages across four 10,000-foot horizontal wells. These wells are going to be critical for meeting the binding Gas Sales Agreement with the Northern Territory Government that will supply much needed gas to Darwin to keep the lights on."
Joel Riddle, Chief Executive Officer
"We believe there's material cost efficiencies that we'll see with multiple wells going down. We long-term believe that we can get well costs down, both drilling and completing, down to about $15 million. One of the biggest opportunities to reduce well cost over the 240 stages that we're going to be pumping is really sourcing local sand. We've confirmed that we have sand, crack quality sand that we've identified very close to the pilot pad, which can drop sand costs from $4 million to about half a million."
Joel Riddle, Chief Executive Officer
Strategic Positioning
1. Fully Funded Path to Pilot Production
Tamboran’s recent $70 million capital raise and acreage sale have increased liquidity to $96 million, fully funding the drilling and completion of three critical wells in the Shenandoah South pilot project. This financial footing reduces execution risk and enables the company to maintain its mid-2026 first gas target, a pivotal milestone for transitioning from exploration to commercial production.
2. Operational Efficiency and Well Cost Reduction
The company is aggressively targeting a sub-25 day spud-to-total-depth (TD) drilling timeline for the SS-4H, 5H, and 6H wells, leveraging batch drilling of top-hole sections, optimized bit and directional tool designs, and improved mud systems. These advances, combined with local sand sourcing that dramatically lowers completion costs, position Tamboran to materially reduce well costs from $28 million to a long-term target near $16 million, enhancing project economics.
3. Extended Soaking Strategy to Enhance Well Productivity
Tamboran’s 62-day soak of the SS-2H ST1 well is a deliberate technical innovation based on CoreLab modeling and prior well data indicating significant productivity uplift from longer soak periods in the highly desiccated Mid Velkerri B Shale. This strategy aims to optimize gas flow and well longevity, providing a critical data point for refining flowback and stimulation techniques in this unique geological setting.
4. Phase 2 Development Area Farmout and Market Expansion
The company has finalized a checkerboard acreage arrangement with partner Daly Waters Energy and engaged RBC Capital Markets to initiate a formal farmout of approximately 400,000 gross acres in the Phase 2 Development Area. This area, with 58% operated interest, is strategically positioned to supply the East Coast gas market, which faces a forecasted shortfall of approximately 1 Bcf/d by 2029-30, offering a pathway for Tamboran to scale production significantly.
5. Infrastructure and Market Development
Progress continues on midstream infrastructure, including the Sturt Plateau Pipeline and Compression Facility, with pipe and equipment delivered and construction scheduled to commence in the second half of 2025. The company is also advancing discussions to expand Phase 1 capacity, supported by a non-binding Letter of Intent with Arafura Rare Earths for up to 26 MMcf/d over ten years, signaling potential for incremental local demand growth.
Key Considerations
Tamboran’s Q3 2025 results reflect a critical juncture where funding, operational execution, and strategic positioning converge to enable commercial development of its Beetaloo Basin assets.
- Capital Adequacy: The $96 million pro forma cash position reduces near-term financing risk and underpins the pilot project’s next phases.
- Cost Optimization Trajectory: Well cost reduction efforts targeting a 40%+ decrease are vital for project viability amid commodity price volatility.
- Technical Innovation: The extended soak strategy exemplifies tailored reservoir management in an ultra-dry shale, potentially enhancing long-term well performance.
- Strategic Acreage Management: The Phase 2 farmout process is a critical lever to bring in capital and expertise for scale-up beyond pilot production.
- Regulatory and Political Environment: Stable government support and the appointment of a territory coordinator to accelerate approvals mitigate regulatory risk.
Risks
Tamboran’s early-stage development profile entails execution risks including drilling and completion performance, reservoir uncertainty, and timing of infrastructure build-out. The reliance on extended soak periods to boost productivity introduces technical risk. Market risks include commodity price fluctuations and potential delays in securing farmout partners or regulatory approvals, which could impact project timelines and capital access.
Forward Outlook
For Q4 2025, Tamboran plans to:
- Report IP30 flow test results for the SS-2H ST1 well in June 2025.
- Commence drilling of SS-4H, 5H, and 6H wells starting in July 2025.
For full-year 2026, management maintains guidance to:
- Complete stimulation and flow testing of four wells, including SS-3H, with a 30-day flow test on one well.
- Achieve first gas production from the Shenandoah South pilot project by mid-2026.
Management highlights continued focus on operational execution, cost control, and advancing the Phase 2 farmout process to support growth beyond the pilot stage.
Takeaways
Tamboran Resources is executing a well-funded, technically nuanced pilot program designed to validate and optimize shale gas production in a challenging geological setting. The company’s emphasis on operational efficiencies and cost reduction is critical to underpinning the economics of commercial development. The initiation of a farmout process for a large, development-ready acreage block signals strategic intent to scale production in response to Australia’s looming gas supply shortfall. Investors should monitor flow test outcomes, drilling efficiency gains, and farmout progress as key indicators of the company’s trajectory.
- Funding and Execution: With $96 million pro forma cash, Tamboran is positioned to deliver its largest drilling campaign and maintain its mid-2026 first gas target.
- Technical Differentiation: The extended soak period and local sand integration reflect tailored approaches to reservoir and completion challenges unique to the Beetaloo Basin.
- Growth Pathway: The Phase 2 farmout targeting 400,000 acres aims to leverage market demand dynamics and infrastructure proximity for East Coast gas supply by decade-end.
Conclusion
Tamboran’s Q3 2025 results demonstrate meaningful progress toward commercializing its Beetaloo Basin shale gas resources. The company’s strategic capital raise, operational improvements, and acreage farmout efforts collectively reduce execution risk and position Tamboran to capitalize on Australia’s tightening gas market. Upcoming flow test results and drilling execution will be critical near-term milestones for validating this trajectory.
Industry Read-Through
Tamboran’s advances underscore the growing viability of unconventional shale gas development outside North America, particularly in geologically unique and underexplored basins like Australia’s Beetaloo. The company’s focus on cost reduction through local sourcing and operational efficiencies reflects broader industry imperatives to improve project economics amid fluctuating commodity prices. The farmout process and strategic partnerships highlight the importance of capital and expertise sharing in scaling resource plays. Other operators and investors in emerging shale basins should watch Tamboran’s flow test outcomes and farmout progress as benchmarks for de-risking and commercializing unconventional gas assets in frontier regions.