Basin Modeling Approach to the Prediction of Fault Rock Properties in High Net-to-Gross Reservoirs

Prediction of fault rock properties is critical where exploration prospects involve reservoir-reservoir juxtaposition (static seals) and during field production when faults may baffle or enhance (dynamic response) the flow of hydrocarbons. Traditional approaches to the estimation of fault rock properties (e.g., gouge porosity, permeability, etc.) have concentrated upon the present day reservoir conditions (depth, juxtaposition, core observations, and permeability contrasts) and do not typically take into account the evolution of these properties. This contribution describes a basin modeling approach for predicting the paleo and present day properties of fault rocks formed at different depths and temperatures in clean (clay content < 20%), high net-to-gross sandstones.