Merging outcrop data and geomechanical information in stochastic models of fractured reservoirs

According to recent estimates, the potential for oil production from fractured reservoirs in North America is of the order of tens of billion of barrels. With domestic production depending more and more on mature fields, better technology for characterizing fracture flow paths, especially in deep, nonconventional plays and in carbonate rocks is key to producing hydrocarbons economically. Fracture transmissivity (or permeability) can enhance oil production, or on the other hand, result in early water breakthrough and consequently early well abandonment. However, spatial characteristics of the fracture system cannot be known deterministically in the subsurface reservoir. Instead, stochastic characterisation of fracture systems is usually attempted. The development of a stochastic modeling approach that yields realistic field-scale model of fracture networks consistent with patterns observed on an outcrop and adhere to a mechanical basis for fracture propagation is presented in this paper.