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Fault seal modelling workflows have been used unchanged for a long time for determining number of wells and well placements in field development or predicting remaining reserves in late life field production. We are however still struggling with trusting the predictions, and lately the old methods are being questioned and new methods have been suggested. In this presentation experiences from >25 years of fault seal work will be presented and try to demonstrate why simple solutions trying to calibrate against single parameters for calibration (like depth or SGR) is not logical. There is a general depth trend where shallow reservoirs have the smallest reduction in permeability when faulted. However, there is about 2 orders of magnitude variation of reduction of fault permeability vs undeformed reservoir rock permeability for reservoirs at similar depths. What can we learn from practical use of manually defined SGR/Fault permeability relationships which are based on core measurements, and how does it link to fault deformation processes, depth and rock composition?