Formentera Partners and Daly Waters Energy Achieve First Natural Gas Sales from the Beetaloo Basin

Formentera Partners, Daly Waters Energy and Tamboran Resources achieved first commercial natural-gas sales from the Shenandoah South Pilot Project in Australia’s Beetaloo Basin. The first gas ever sold from the basin will be delivered through the Sturt Plateau pipeline system to help power Darwin, marking an operational milestone for Tamboran and the Northern Territory’s domestic gas supply.

Analysis

For TBN, initial monetization matters less for near-term EBITDA than as a financing and execution proof point: it demonstrates a route from wellhead to a paying customer, reducing the perceived risk premium on future development capital. The next valuation inflection is whether pilot flow rates, decline curves, and delivered-gas pricing support scalable development rather than merely technical production; without those disclosures, the market cannot credibly underwrite reserve value or a full-field multiple. Over the next 1-3 months, TBN could outperform other pre-cash-flow Australian gas explorers as investors reassess infrastructure access and strategic value to Northern Territory gas security.

The second-order effect is potentially negative for incumbent eastern-Australia gas suppliers only if Beetaloo volumes become large enough to alter domestic supply expectations, which remains a multi-year outcome rather than an immediate threat to Santos (STO.AX) or Beach Energy (BPT.AX). Consensus may overvalue the symbolism of first sales: remote-basin projects often fail at the capital-intensity stage, where gathering systems, compression, water handling, and pipeline capacity can absorb most upstream margin. The principal reversal risks are weak sustained flow data, cost escalation, equity financing at a discount, or regulatory/approvals friction; any of these would re-rate TBN back toward an option on undeveloped acreage rather than a developing gas supplier.

Key Decisions for Investors

• Initiate only a small, catalyst-driven long TBN position over the next 1-3 months; add only after independently disclosed sustained flow rates, delivered gas pricing, and development-capex guidance support commercial returns. Size as venture-style exposure given likely future funding needs.
• Use a defined-risk structure where liquid options are available, or cap cash-equity exposure at a pre-set loss budget: the upside is a material resource/midstream de-risking re-rating, while the downside is severe if pilot data do not translate into repeatable commercial wells.
• Set alerts for three thesis validators: a long-term gas sales agreement, final investment decision or committed midstream financing, and reserve/resource certification. Absence of progress on at least one within 6-12 months would weaken the commercialization thesis.
• Do not short STO.AX or BPT.AX on this development alone. Reassess only if TBN discloses contracted volumes sufficient to affect Northern Territory or broader Australian gas-balance expectations; until then, incumbent cash-flow and LNG-linked exposures remain driven by commodity prices and their own operating performance.