CO2 Injection Flow Properties in Two Carbonate Rocks with Dissolution Stages

Eight alternating sequences of mineral dissolution and flow measurement were performed on Ketton and Estaillades limestone cores to study CO2 storage. Observations of nitrogen-water relative permeability and residual trapping were made at 100 bars pressure and 22°C using X-ray tomography. The dataset was created by the British Geological Survey and last updated in April 2026.

Use Cases

• Model changes in relative permeability based on pore structure evolution from dissolution.
• Predict residual trapping of CO2 in saline aquifers based on rock type.
• Calibrate pore-scale simulations using experimental data from X-ray tomography and mercury injection.
• Analyze the impact of bimodal versus wide pore size distributions on drainage characteristics.

Strengths

• Experimental data includes eight alternating sequences of dissolution and flow measurement.
• Measurements were conducted under controlled conditions of 100 bars pressure and 22°C.
• Analysis covers two distinct carbonate rock types with different pore structures.

Limitations

• Column-level documentation is absent; field semantics must be inferred after download.
• Row count is unknown, which may limit suitability assessment.

Provenance

Source

British Geological Survey (BGS)

Collection Method

Laboratory experiments using X-ray tomography and mercury injection capillary pressure on rock cores.

Time Range

Experimental timeframe not specified.

Freshness

Last updated 2026-04-09 08:40:38.202165; freshness should be verified

Geography

Rock samples are from specific limestone formations (Ketton and Estaillades).