One of the top concerns for numerical simulation of naturally fractured reservoirs is fractures’ distribution and properties throughout the reservoir; However, most of the times this kind of information is absent between reservoir data. Due to this lack of data, the production rate and pressure in numerical simulation of fractured reservoirs usually could not consistently and accurately match with the reservoir’s actual observed data. In this study it’s tried to find some specific patterns for fractures’ network in a real Case study of an Iranian oil field. Although the fractures may have considerable porosity and permeability, the network of fractures may not continued in the reservoir layers but are concentrated in some specific area such as beside major faults. By this assumption, fractures which are created by faults, the fracture properties have been defined by considering the orientation of faults and getting a decreasing trend from faults toward the reservoir flanks. For this purpose some correlations are developed for fracture porosity, permeability and shape factor, whether the grid block is modeled as single porosity or dual porosity. The application of this method could improve the numerical simulation history matching of reservoir clearly in a famous Iranian fractured reservoir.


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