Due to the complexity in reservoir development of a Naturally Fractured Carbonate, a static model, combining matrix and natural fractures properties was carried out and then dynamically simulated in order to evaluate different scenarios both for vertical and horizontal wells. DFN model included in the static model was constrained by Drill core description, Borehole image analysis and 3D Seismic structural interpretation. From this data a Geomecanically based Tectonic evolution model was carried out in order generate Natural Fractures Orientation and Intensity drivers which were used to guide DFN population. All properties were then upscaled for dynamic modeling. During this modeling, several parameters where evaluated with the aim of reduce reservoir uncertainty. This process allows recognizing the relative importance of parameters as quantity of perforation meters, fracture porosity, fracture permeability and Oil-water contact. At the end of this simulation it was recognized that a horizontal well could produce 2.5 times more than a vertical well.

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