Highlights

  • Omega Oil and Gas (ASX:OMA) has started drilling Canyon-4 as part of its broader Taroom Trough appraisal program.
  • The well follows Canyon-3, which intersected a substantial oil- and gas-bearing Permian interval with 170 metres of aggregate net pay.
  • Two further vertical wells and potential horizontal wells are planned as Omega works to test reservoir quality and commercial flow potential.
  • Resource updates, drilling results and Horizontal Well performance remain the key milestones ahead.

Omega Oil and Gas (ASX:OMA) has moved into the next stage of its Taroom Trough appraisal campaign, with drilling now underway at Canyon-4. The well follows recent work at Canyon-3 and forms part of a broader multi-well program designed to improve understanding of the eastern Taroom Trough’s stacked Permian tight-sand reservoirs.

What Omega is drilling, and where

Omega Oil and Gas (ASX:OMA) is appraising the eastern Taroom Trough within Queensland’s Bowen Basin, around 400 kilometres north-west of Brisbane.

The company is targeting stacked Permian tight-sand reservoirs, which generally require stimulation and horizontal development to establish commercial hydrocarbon flow rates.

Canyon-4 is located approximately eight kilometres south of Canyon-3 within Potential Commercial Areas 342 and 343, where Omega holds a 100% operated interest.

The well is planned to reach around 3,900 metres measured depth and is designed with a deviation of approximately 24 degrees. The top of the Permian section is expected at around 3,200 metres.

Drilling commenced in early September 2026, with results expected later in the month.

The program is using Helmerich and Payne’s FlexRig AE 648, which was mobilised for Omega’s broader 2026 appraisal campaign.

Two additional vertical wells, Canyon North-1 and Canyon North-2, are planned in ATP 2081. Omega holds a 45% operated interest in that permit, alongside Tri-Star with 30% and Beach Energy with 25%.

Subject to results and land access, the company also plans one or two horizontal wells with laterals of up to 2,000 metres.

What Canyon-3 actually delivered

Canyon-3 provided the most recent technical reference point for the campaign.

The well reached a total depth of 3,792.6 metres and intersected a 526-metre oil- and gas-bearing Permian interval containing around 170 metres of aggregate net pay.

Within the primary Canyon Sandstone, the well returned 18 metres of net oil-bearing sand at average porosity of 11.5%.

That compared with 12 metres at 7.4% average porosity in Canyon-1.

The result is significant from a reservoir-quality perspective, but it remains a wireline interpretation rather than a production result.

Canyon-3 has not yet been flow tested.

Omega also identified a prospective interval in the Lower Kianga Sandstone, although that remains an exploration lead rather than a booked resource.

The flow test that still matters most

The most relevant production test across the acreage remains Canyon-1H.

That horizontal well underwent a nine-day flow test across a 650-metre lateral with nine stimulation stages.

The test recorded a peak rate of 452 barrels of oil per day and 0.60 million standard cubic feet per day of gas.

The best 24-hour sustained rate was 321 barrels of oil per day and 0.472 mmscf/d of gas.

Omega has also modelled how a longer 2,000-metre lateral might perform, with company estimates implying higher potential flow rates.

Those figures remain projections rather than measured production data.

This distinction matters because the commercial case for the Taroom Trough ultimately depends on how longer horizontal wells perform after stimulation.

Why it matters, and what could go wrong

Omega Oil and Gas (ASX:OMA) has previously reported 1.73 trillion cubic feet of gross 2C contingent gas resources and 68.6 million barrels of net contingent liquids across ATP 2037 and ATP 2038.

Contingent resources are not reserves, and commercial recovery has not yet been demonstrated.

That is why the current appraisal campaign is important.

Vertical wells can improve geological understanding and help define reservoir quality, but horizontal wells and stimulation performance will provide the more meaningful test of commercial potential.

The risks remain substantial.

Tight-sand reservoirs can appear encouraging on logs while producing weaker-than-expected flow rates.

Drilling and stimulation costs can also materially affect project economics, while land access and approvals remain important operational dependencies.

Omega raised A$60 million in April 2026 and has stated that it is fully funded for its 2026/27 campaign.

The broader gas backdrop

The commercial case for new gas Supply remains linked to Australia’s longer-term energy balance.

Recent market outlooks have indicated improved near-term supply adequacy, while still pointing to declining legacy production and the need for new Investment later in the decade.

For Omega Oil and Gas (ASX:OMA), that backdrop creates strategic relevance, but it does not remove the need to prove that the Taroom Trough reservoirs can be developed economically.

Resource size, well productivity, stimulation effectiveness and development cost will ultimately determine whether the project can move beyond appraisal.

What to watch

The first milestone is the Canyon-4 result later in September 2026.

The next phase will include two further vertical wells, which should provide additional data on reservoir continuity and quality across the broader acreage.

An updated resource assessment is also expected later in 2026.

The most important technical test, however, will come from future horizontal wells with longer laterals.

For Omega Oil and Gas (ASX:OMA), the central question is whether the reservoir quality observed in vertical appraisal drilling can translate into sustained commercial flow rates from larger stimulated horizontal wells.