Economics-And-Milestones-For-Validation
Sources: 1 • Confidence: Medium • Updated: 2026-03-08 21:17
Key takeaways
- A key proof milestone for superhot EGS is a durable flow test demonstrating two wells connected by a fracture network that can produce high-temperature steam at sufficient pressure and flow without rapid decline.
- No field project has yet demonstrated the proposed deep-hot permeability activation effect, and the closest evidence cited is from laboratory experiments.
- Traditional hydrothermal geothermal wells are typically drilled to about one mile depth and target mostly sub-boiling reservoir temperatures around 200°F or lower.
- Development is expected to proceed sequentially by proving shallower superhot systems first and then progressing to deeper systems rather than attempting the deepest systems first.
- A key open question is how much standard oil-and-gas downhole equipment and materials must be replaced to tolerate superhot geothermal temperatures.
Sections
Economics-And-Milestones-For-Validation
- A key proof milestone for superhot EGS is a durable flow test demonstrating two wells connected by a fracture network that can produce high-temperature steam at sufficient pressure and flow without rapid decline.
- Quaise asserts that in superhot geothermal, drilling cost becomes about 20–30% of LCOE because higher power output improves the revenue side of the LCOE equation.
- Quaise projects superhot geothermal LCOE of roughly $50–$100/MWh, with shallow tier-one systems potentially below $50/MWh and global-at-the-meter costs around $100/MWh.
- Quaise prioritizes reducing drilling nonproductive time over maximizing instantaneous rate of penetration, targeting an all-in average drilling rate of roughly 3–5 meters per hour to reach 10 km in about 100 days.
- Quaise expects the Oregon project to achieve a superhot flow test by the end of the year.
- Quaise expects to reach a commercial-grade injector-producer EGS flow test outputting about 25–30 MWe by the end of 2026 at roughly three-mile depth in Oregon.
Technical-Gates-Drilling-Vs-Permeability-And-Evidence-Gaps
- No field project has yet demonstrated the proposed deep-hot permeability activation effect, and the closest evidence cited is from laboratory experiments.
- Two technical gates for superhot geothermal at scale are drilling systems that can operate at the required temperatures and creating reservoir permeability at those depths and temperatures with acceptable performance decline.
- Drilling is described as the dominant technical challenge relative to fracturing for superhot geothermal systems.
- Oil and gas drilling is primarily constrained by temperature rather than depth, and typical mechanical systems do not reach the superhot temperatures targeted for superhot geothermal.
- High-temperature rock fracturing is claimed to have natural analogues in processes that form hydrothermal vents and mines, implying a geological precedent for the stimulation mechanism.
- There is claimed to be no geological precedent for mechanically drilling superhot geothermal wells from the surface.
Baseline-Vs-Superhot-Physics-And-Site-Constraints
- Traditional hydrothermal geothermal wells are typically drilled to about one mile depth and target mostly sub-boiling reservoir temperatures around 200°F or lower.
- Quaise targets approximately 800°F as a thermodynamically optimal temperature for extracting heat with water, with diminishing returns above and substantial opportunity cost below.
- Reaching approximately 800°F requires drilling roughly 3 to 12 miles deep depending on location.
- Pacific Ring of Fire and mid-ocean ridge-related regions (e.g., Iceland and parts of Kenya) are more likely to reach approximately 800°F at around three miles depth.
- An approximately 800°F well can yield about ten times the electric power output of an approximately 200°F well for a similar wellbore size.
Project-De-Risking-And-Commercialization-Structure
- Development is expected to proceed sequentially by proving shallower superhot systems first and then progressing to deeper systems rather than attempting the deepest systems first.
- The Oregon site’s prior wells were drilled during earlier hydrothermal exploration that was abandoned due to insufficient permeability, and Quaise plans to proceed by shifting to EGS to create permeability.
- Quaise plans to spin successful commercial plants into separately financed project companies while the parent company focuses on repeatable playbooks and scaling.
- Quaise selected a first Oregon site with existing wells already drilled to the needed temperature-depth regime to reduce iteration risk and support signing a take-or-pay PPA.
Downhole-Tooling-Reuse-And-Materials-Bottlenecks
- A key open question is how much standard oil-and-gas downhole equipment and materials must be replaced to tolerate superhot geothermal temperatures.
- For shallow superhot systems of roughly 3–5 miles, the required downhole materials and tools are described as incremental evolutions leveraging oil-and-gas precedents such as SAGD operations up to about 600°F, with electronics described as the main temperature bottleneck.
Watchlist
- A key open question is how much standard oil-and-gas downhole equipment and materials must be replaced to tolerate superhot geothermal temperatures.
- A key proof milestone for superhot EGS is a durable flow test demonstrating two wells connected by a fracture network that can produce high-temperature steam at sufficient pressure and flow without rapid decline.
Unknowns
- Will a field-scale superhot EGS system demonstrate a durable two-well connection with stable pressure/flow/temperature and without rapid decline over weeks-to-months?
- What downhole equipment (casing, seals, electronics, wireline/logging) can survive and operate at the target temperature regimes, and what must be redesigned or replaced?
- What are the achieved drilling performance metrics at high temperature (tool survival hours, nonproductive time sources, and repeatability across wells) versus the stated operational targets?
- How accurate is the claimed relationship between superhot temperature operation and per-well electric output (including net power after parasitics and conversion) across real projects?
- To what extent do previously drilled hot wells represent a practical pipeline for redevelopment via EGS, versus being constrained by site-specific issues (well integrity, geology, or stimulation limits)?