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By G. Jones, Q. J. Fisher, R. J. Knipe
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Additional info for Faulting, fault sealing and fluid flow in hydrocarbon reservoirs
Fault 2 has a N - S trend (Fig. 8), it forms a linear high dip feature on the dip map and a low correlation zone on the correlation map; its length on both these maps is c. 700 m. It is also represented as a low value anomaly on the amplitude map, but this is not easily distinguished from the background amplitude variations. The maximum throw on the fault lies close to its centre and is c. 15 m; this decreases towards the visible displacement tips in both directions. In the seismic sections, an amplitude anomaly can be observed at the location of Fault 2 (Fig.
Yielding et al. Knipe 1996; Knott et al. 1996). g. Cowie et al. 1996 and references therein). Also, the spatial distribution of faults will be controlled by factors, such as structural history, lithology and fluid-rock interactions (Peacock 1996; Sverdrup & Bjorlykke 1997). Alternative ways to predict fault patterns in subsurface reservoirs which may provide new information and understanding of the deformation below seismic resolution are therefore needed (see Townsend et al. this volume). 3D seismic data have been increasingly used by oil companies for defining horizons as well as for describing reservoir architecture.
2 • ..... ~_ 90 180 270 Strike azimuth (degrees) 360 90 180 270 Strike azimuth (degrees) 360 50 0 35 0 Fig. 7. (a) Strike of interpreted faults plotted against fault throw. The lowest resolvable limit is marked by the stippled line at 15 m throw. (b) Histogram of fault strikes. Histogram interval is 10. of fault blocks, which were formed in the Late Jurassic to Early Cretaceous as a complex footwall uplift between the Viking Graben and More Basin (Badley et al. 1988). The study area displayed on Fig.
Faulting, fault sealing and fluid flow in hydrocarbon reservoirs by G. Jones, Q. J. Fisher, R. J. Knipe