Several wells have been drilled and stimulated in a tight gas field in Middle East, however, very few have been economic. Many wells encountered difficulties pumping the required treatment and a number of horizontal wells did not produce as expected. A fit-for-purpose integrated subsurface model coupling geophysical, petrophysical, and geomechanical models with fully 3D hydraulic fracture simulation modeling was carried out to provide the operational path forward to overcome these challenges. This study is a showcase of the applicability of our integrated approach to simulate fluid flow and proppant placement within complex, naturally fractured reservoirs where the interaction between induced fractures and natural fractures dominates hydraulic fracture propagation [Izadi et al. 2015; Cruz et al. 2016; Izadi et al. 2017; Izadi et al. 2018; Cruz et al. 2018]. Seismic data calibrated with rock physics analyses were used to delineate structural components and incorporate rock properties into the high-fidelity 3D subsurface model. High porosity zones and areas of high natural fracture intensity were identified with seismic acoustic impedance and geometric attributes. Reservoir properties of porosity, permeability and gas saturations vary across this field. Variations in geomechanical parameters correlate spatially with variations in porosity and permeability. This paper demonstrates a methodology to evaluate reservoir heterogeneities on hydraulic fractures propagation through fully 3D simulations at a planned well's location.

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