This website summarizes the results from the FAULTPROP (Petrophysical properties of fault rocks) project, which was a joint industry project (JIP) undertaken by the University of Leeds, and sponsored by BHP, ConocoPhilips, Shell, Statoil and Wintershall.
The key aim of the FAULTPROP project is to develop An Atlas of the Petrophysical Properties of Fault Rocks. This will contain high quality measurements of the single and multiphase (relative permeability and capillary pressure) of fault rocks to enhance the ability of industry to predict fault-related fluid flow in petroleum systems. Key work elements include.
Each sponsor provides up to 20 fault rock samples and we have also collected samples from outcrop. The microstructure, absolute permeability at in situ stress as well as the Hg-injection pressures of all samples will be analyzed. The relative permeability and capillary pressure of around 50% of these will be measured.
The FAULTPROP sponsors have so far provided ~30 fault rock samples from core. Around 10 samples have also been collected from oultcrop. It is expected that the number will double by the end of the project. Each sample will be subject to routine core analysis (RCA) and around 50% of these were then subject to special core analysis (SCAL). RCA analysis involves:
- X-ray CT tomography;
- Microstructural analysis using secondary electron microscopy (SEM),
- Quantitative X-ray diffraction analysis (QXRD),
- He porosity;
- Hg-injection porosimetry;
- Gas permeability vs confining pressure
- Brine permeability vs confining pressure;
SCAL analysis involves:
- Gas relative permeability measurement
- Oil-water relative permeability measurement
- Capillary pressure measurement.
- Hg-injection analysis at stress
In addition, numerous experiments are being conducted to:
- Assess the impact of capillary end effects on across fault flow.
- Assess whether it is safe to use standard laboratory techniques for such highly heterogeneous samples.