Fluid flow modelling in fractured reservoir is one of the most challenging problem in the oil business; discontinuities are present in the reservoir at various scales (from big faults to microfractures) and play a very different role during production. This problem has been frequently approached in a too simplistic way, also because the software traditionally adopted does not allow an accurate characterisation of the complex faulted-fractured reservoirs. The present paper is relevant to a new workflow allowing the transfer of much more knowledge into the fluid flow model, when a "dual porosity" model is required. The reservoir architecture and shape, even with very complex fault system, is reconstructed merging structural models, reservoir layering and 3D seismic interpretation. It is, then, possible for different reservoir sub-volumes, such as fold and/or fault and/or well zones, create the relevant 3D discrete fracture network utilising the information from different data source, including cores, logs and outcrops. Each fracture network is then dynamically validated with the available tests (MDT, PLT, Interference) and used to calculate fracture intensity, fracture porosity, equivalent fracture permeability and sigma factor for a reservoir simulator grid block. These petrophysical properties for each sub-volume are then used to populate the fluid flow model.

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