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Petroleum Geoscience

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Faults in conventional flow simulation models: a consideration of representational assumptions and geological uncertainties

¹ Fault Analysis Group, UCD School of Geological Sciences, University College Dublin, Dublin 4, Ireland(tom{at}fag.ucd.ie)
² Fault Analysis Group, Department of Earth and Ocean Science, University of Liverpool, Liverpool L69 3GP, UK

Even when geologically based methods are used to determine fault rock permeabilities and thicknesses for input into flow simulators, a wide range of simplifying assumptions regarding fault structure and content are still present. Many of these assumptions are addressed by defining quantitative and flexible methods for realistic parameterization of fault-related uncertainties, and by defining automated methods for including these effects routinely in full-field flow simulation modelling. The fault effects considered include: the two-phase properties of fault rocks; the spatial distributions of naturally variable or uncertain single-phase fault rock properties and fault throws; and the frequencies and properties of sub-resolution fault system or fault zone complexities, including sub-seismic faults, normal drag and damage zones, paired slip surfaces and fault relay zones. Innovative two-phase or geometrical upscaling approaches implemented in a reservoir simulator pre-processor provide transmissibility solutions incorporating the effect, but represented within the geometrical framework of the full-field flow simulation model. The solutions and flexible workflows are applied and discussed within the context of a sensitivity study carried out on two faulted versions of the same full-field flow simulation model. Significant influence of some of these generally neglected fault-related assumptions and uncertainties is revealed.

KEYWORDS: fault permeability, fault transmissibility, uncertainty, variability, oil production, fault rock, fault zone, fault throw, relay zones, two-phase flow

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