Carbonate reservoirs represent more than 60 per cent of oil production in Brazil. These reservoirs have gained such importance in the Brazilian energy matrix owing to Pre-Salt layer discovery, responsible for over the half PETROBRAS oil production. Among the principal challenges to development the Brazilian Pre-Salt is included the characterization of fractured and karstified systems. The estimating of parameters required by reservoir simulators, such as porosity, permeability and compressibility of karst to generate curves that represent the variation of these parameters over time, representing geomechanical effects in a combined way, is still configured in the state of the art of oil industry research. This work aims to present a methodology for estimating karst features compressibility. The proposed numerical geological model was generated from an outcrop, Lajedo Arapuá, located in Potiguar Basin. This outcrop has dimensions compatible with a typical simulation model cell (200 x 200 x 3). The simulation model was built using a structured mesh using finite difference approximations to solve the flow equations.Márc The geomechanical effects will be coupled in a commercial simulator, IMEX (BlackOil fluid) from CMG, through the inclusion of porosity and permeability modifiers tables as a function of pore pressure variations (reservoir pressure). Thus, the impact of these parameters on the production forecast curves could be evaluated considering a field under the depletion production mechanism.