This paper presents a new numerical model for analyzing transient pressure test data taken from naturally-fractured reservoirs. The model computes well pressures for a single well completed in a naturally-fractured reservoir. It models characteristic properties of naturally-fractured reservoirs including fracture orientation, fracture length, fracture density and fracture distribution. A single-phase, slightly compressible fluid flow is assumed. Fluid flow is modelled based on a hybrid approach which combines single continuum (block-based permeability tensor for small to medium fractures) and flow in discrete fractures (long fractures). A sensitivity analysis is presented to examine the effects of fracture density, fractal dimension and percolation probability. Then the model is validated against two worked examples reported in the literature. Results reveal that new model can predict transient pressure response of complex naturally-fractured reservoirs. Hence, it can be used to match pressure test data and diagnose characteristic properties of naturally-fractured reservoirs.