Carbonate reservoirs are responsible for over 50 per cent of world hydrocarbon production. In Brazil, they started to gain more importance after the Pre-Salt discovery, in 2006. The main method to predict and manage reservoirs is numerical simulation in which, traditionally, the only geomechanical parameter is the rock compressibility. Usually it is adopted one single value for the whole model, which is kept constant. During exploitation, though, the reservoir-rock deforms, causing porosity and permeability reduction. While the first effect is not well predicted by rock compressibility, the second is simply kept constant. Besides that, each facies has its own stress-strain behavior. That is why it is so important to model the reservoir flow coupled to geomechanics representing each rock type in a single layer. With the aim of obtaining these integrated analyses, but without additional computational cost, the pseudo-coupling is used, which lets such models to be ran on day-by-day basis by reservoir engineers. This kind of coupling updates both porosity and permeability based on tables that correlate porepressure and porosity and permeability multipliers. In order to have the mechanical behavior of the reservoir-rock well represented, the pseudo-coupling tables are elaborated based on laboratory mechanical tests with samples from the same field to be modeled. In this way, each facies represented on the model has its own table that takes to reservoir simulation the geomechanical effects through porosity and permeability variation. Comparative analyses are done using homogeneous and heterogeneous models, varying the type of geomechanical representation, through rock compressibility or pseudo-coupling. Once known the compaction geomechanical effects, it is simulated a model that tries to attenuate them.