ABSTRACT
Oil and gas fractured reservoirs generally have a non-uniform distribution of filtration and storage capacity properties.
Research results by the authors of this work show that the filtration characteristics distribution of fractured reservoirs is affected by geological factors connected with the genesis of the part of the rock mass and the geomechanical parameters connected with the stress state and its change during the production process.
Because of that the problem of locating the high permeability zones in the reservoir should be considered using the geomechanical, hydrodynamic and geological modeling methods together. The main focus of this work is on the methods of the oil and gas field geological geomechanical models development. The main aim of geological geomechanical modeling is to get the stress tensor components for the reservoir and the host rock. The components are then correlated with the well performance parameters which are based on the specimen permeability change and mechanical tests results, geophysical well logs and 3D seismic data. 3D geomechanical model geometry is based on the geological model. The coupled structural-pore-fluid-diffusion solution is performed using the finite element method. The faults are represented by mesh refining or by using the contact elements. The calibration of the boundary conditions is performed using both the well data (breakouts, tensile cracks, LOTs, minifracs etc.) and permeability profile along the wellbore. The initial permeability in the wells is determined using the well tests data and the history data considering the law of permeability change found through specimen tests.
Subsequently it becomes possible to predict the permeability based on found correlations.
