Cladtek Whitepaper · Case Study
Proven in the Harshest Wells on Earth.
See how mechanically lined tubulars performed after 18 months in one of the most corrosive geothermal environments in operation today.
High-salinity brine, low pH, temperatures above 680°F, and heavy CO₂ and H₂S exposure make the Salton Sea geothermal field one of the toughest tests for tubular materials in the energy sector.
What's inside the case study
A technical and commercial review of mechanically lined tubulars (MLT) performance, covering real field data from deep geothermal pilot wells and a full cost comparison against carbon steel and solid CRA.
Extreme conditions, real results
How CRA-lined tubing held up after 18 months of exposure to 680°F brine, high H₂S and CO₂ — with zero measurable wall loss, cracking, or pitting.
Scale formation & operational impact
What the calcium carbonate deposits found on the liner mean for long-term flow assurance, and how they were managed without affecting material performance.
Total cost of ownership
A full CAPEX/OPEX comparison across carbon steel, MLT, and solid CRA tubing — and why mechanically lined tubing consistently wins on lifecycle cost in aggressive wells.
Get the full case study
Download the complete whitepaper, including material specifications, performance data, and the full cost-of-ownership model.
No spam — just the case study, straight to your inbox.