Dynamic variation of porosity, permeability, and elastic modulus was considered in order to investigate the single-phase fluid flow in a fractured porous media using fully coupled hydro and geomechanical models. The development of streamlines, pressure distribution, effective stress and strain generations have been extensively studied. However, from the present model results, it can be critically noted that the development of streamlines and pressure are highly dependent on (a) fracture orientation; (b) the distance from injection/production well; and (c) the fracture density. The results have been analyzed both in the presence and absence of geomechanics. It was observed from the model results that there was no fluid flow within the fracture when the fracture aperture varied between 10−6 and 10−9 m; and the respective streamlines were very smooth at the fracture-matrix interface, whereas, a significant fluid flow was observed within the fracture when the aperture sizes exceeded 10−6 m; and in this case, streamlines and pressure variations were very sensitive at the fracture-matrix interface. The model results clearly projected that this sensitivity primarily resulted from the lateral stresses arising from the generation of effective-stress and its associated strains. It was further observed from the numerical results that the effective stress, strain, and pressure in the fractured porous media were extremely sensitive to the Biot-Willis coefficient; and thereby clearly projecting the significance of the considered lateral stresses (which are generally absent, while characterizing a typical conventional reservoir). In addition, it was also observed that the lowest effective stress occurred in the vicinity of the injection well, while the highest value was found nearer to the production well for Biot-Willis coefficients with values less than 0.6. Thus, it can be critically concluded that the compressive strains were dominating over the highest sweep volume of the fractured porous media that starts a little bit away from the injection well, and that gradually increases to the maximum at the production well, when the Biot-Willis coefficient falls below 0.6. Finally, the model has been upscaled by increasing the scale of the porous medium with complex embedded fracture along with the dynamic variation of permeability, porosity, and elastic modulus so that the developed numerical model will better replicate the complex reality associated with the field scale. © 2020