Abstract - Two discrete pressure cells with a 128 bar pressure difference within a 130m thick Tarbert reservoir interval are separated by a fault with a throw of ca. 50m. Given that high permeability reservoir rocks are juxtaposed across the fault, the observed across fault pressure gradient cannot be maintained statically for reasonable fault rock permeabilities and over geologically significant periods (>10,000years). Single phase hydrodynamic flow modelling of the boundary between the pressure cells indicates that both low fault transmissibilities and relatively high hydrodynamic flow rates (10m3/day) are required to explain the observed pressure distribution. The most significant contributor to the high flow rates is gas generation and migration into the high pressure cell. Low fault transmissibilities may be due either to the occurrence of shale smearing or extensive quartz cementation of the fault rock.
In: Hydrocarbon Seal Quantification, (edited by Koestler, A.G. & Hunsdale, R.). Norwegian Petroleum Society (NPF), Special Publication, 11, 127-139, 2002.