In Australia’s shale patch, Americans bring money, tech and lessons learned

In Australia’s Beetaloo Basin, project developers are importing U.S. equipment, capital, technical know-how and—potentially—the scale and productivity gains typical of American shale operations, aiming to cut costs and prove the viability of the nation’s inaugural shale gas venture, according to reporting from Darwin on September 8.

The Beetaloo shale, which produced its first gas earlier this month, is frequently likened to the U.S. Marcellus shale. However, its isolation in the Northern Territory will require multibillion-dollar investments in pipeline infrastructure.

If successful, the project could create a fresh source of LNG exports for Asia. Yet well costs need to fall by up to 60% in a region without the established infrastructure and vendor ecosystems found in mature U.S. basins.

The venture also operates against new gas-use policies from Canberra, although the Northern Territory government is fully committed to a development projected to generate 1,000 terajoules daily—enough to supply two LNG trains.

During the inauguration ceremony last week, when the first 40 terajoules of gas were sent to Darwin, Tamboran Resources CEO Todd Abbott—a Texan with extensive U.S. shale experience—said: “This is the most supportive regime I’ve ever worked under, the most supportive government I’ve worked under, and that includes Texas.”

That optimism stands in sharp contrast to industry caution following a decade of tightening energy regulation in Australia, which ranks as the world’s second-largest LNG exporter.

Tamboran, based in Australia, counts Liberty Energy—the fracking-services company created by U.S. Energy Secretary Chris Wright—and American oilfield services major Baker Hughes among its backers.

The company has also deployed high-capability drilling rigs manufactured by U.S.-based Helmerich & Payne.

Beetaloo developers are seeking to sidestep the missteps of certain U.S. shale operators, who concentrated on drilling at the expense of marketing.

Tamboran’s early gas marketing effort is designed to assess well decline curves and reservoir behavior before it greenlights a larger buildout. Together with partners, the company has invested roughly A$1 billion ($722 million) in exploration and appraisal drilling to date.

At a recent industry conference in the Northern Territory capital, Stephanie Reed, COO of Texas-based Formentera Partners, said: “We’ve already avoided a lot of what we did in the U.S. just by focusing on the right things, focusing on cash flow, focusing on EBITDA (earnings before interest, taxes, depreciation and amortisation).”

Formentera, which holds an interest in Tamboran’s Beetaloo project, plans to drill on its own acreage in the basin next year.

Drilling and completion expenses in the Beetaloo still significantly exceed those in established U.S. shale plays. Rami Yassine, Halliburton’s Eastern Hemisphere president, noted that U.S. rig activity has dropped 30% thanks to efficiency gains.

Executives in the sector estimate well costs will need to decline by 40-60% for the basin to achieve its full potential. As part of that drive, companies are looking to develop local sources of sand used in hydraulic fracturing.

Operators have seen completion efficiency improve by about 25% between Beetaloo drilling campaigns. A service provider estimates that continuous drilling practices alone could lower rig costs by around 30%.

Industry players said that a broader local supplier base and workforce would improve project economics by cutting the need to move equipment and materials across vast distances.

Halliburton’s Yassine emphasized that the Beetaloo is at a stage requiring industry-wide collaboration, saying: “Today, we are at a phase in the Beetaloo Basin, where we need to collaborate as an industry.”