Refrac Revival: Nine and NewGen Raise the Pressure

A new 15,000-psi liner hanger highlights how refrac technology is evolving as operators chase more value from mature shale assets

16 May 2025

The best rock in America’s shale basins has mostly been drilled. That simple fact is pushing oil and gas firms to look again at wells they once considered finished. Refracturing, pumping new fractures into old ones, is no longer a niche experiment. It is becoming a cautious strategy for wringing more oil and gas from tired assets.

Interest is growing fastest in mature basins, where pipelines, pads and permits are already in place and investors are wary of fresh drilling binges. Refracs promise lower capital costs and quicker payback, but they bring technical risks. Old wells are depleted. Pressures behave oddly. Equipment fails.

That is where service firms see an opening. Nine Energy Service, a completion specialist, has been promoting refracturing as a response to shrinking top-tier inventory. Its collaboration with NewGen Systems focuses on mechanically isolated refracs, which aim to control pressure more precisely in ageing wellbores.

In May Nine announced a new 15,000-psi liner hanger developed with NewGen. The target is a weak point in many refracs, namely conventional hydraulic hangers that rely on O-ring-sealed pistons. In depleted wells, Nine said, those pistons can burst under high pressure, forcing operators to back off or abandon candidates altogether. The new design removes potential leak paths and is meant to tolerate higher frac pressures with less risk of failure.

NewGen markets its REGEN™ liner hanger as a slim, high-pressure, high-temperature tool for recompletions. It is designed to allow refracturing with only one reduction in liner size, while limiting vibration and erosion that can damage cement and casing, common enemies in older wells.

Refracturing still accounts for only 1–2% of completion activity, according to industry estimates. Yet analysts at ADI Analytics argue that better tools are changing the economics. As Tier-1 locations run out, incremental recovery from existing wells looks more attractive.

For operators, the appeal is pragmatic rather than bold. Partnerships such as Nine’s with NewGen are less about reviving shale’s boom years than about making ageing assets last a little longer. In a basin of diminishing options, even modest gains matter.