The basic aim of this paper is to increase the understanding of the fluid flow properties of faults and hence increases our ability to model fluid flow in fault-compartmentalised reservoirs. The paper will assess the importance of accounting for the multiphase fluid flow properties of fault rocks in simulation models. We are then present some new experimental results on the relative permeability and capillary pressure measurements for fault rocks (cataclastic and faults in impure sandstone). Finally, the incorporation of these results into production simulation models suggest that it is vital in some cases to account for the multi-phase fluid flow properties to better achieve history matching and will for future field development plans.


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