Petroleum reservoirs of the Brazilian pre-salt are found in carbonate rocks located offshore at the edge of the continental shelf. To optimize the exploitation of these reservoirs, it is of paramount importance to properly represent them in the flow simulation models. Nevertheless, this is not a straightforward task. Carbonate rocks usually present fractures and karsts, where flow differs from what is traditionally represented by single porosity reservoir simulators. With the purpose of better modelling the fluid flow behavior through multiple media, alternative techniques exist. However, these alternatives require additional complexities and variables for the adequate characterization of the geologic formations and production forecast. In this work, the impact that some of the fracture and matrix characteristics and the well positioning have on the results of dual-porosity and dual-permeability simulations is addressed.