Abstract
In this paper we only consider fractured reservoirs where fractures are inter-connected in a continuous network (at least in some part of the field) and where mobile hydrocarbons are initially in place in the matrix.
The description of naturally fractured reservoirs for simulation studies aims to define the parameters which have to be input in the simulator. Thus this paper first presents the different types of reservoir schematisations and the types of simulators which are presently available and discusses how to choose the most appropriate one according to the reservoir characteristics. Characterization of the fracture and matrix media (porosity, permeability, relative permeabilities, capillary pressures) are furtherly considered. The definition of the geometry of the matrix blocks is analyzed with a brief review of the presently available tools. The importance of an even partial vertical continuity is emphasized.
Possible influence of the gas-oil interfacial tension, diffusion, and thermal convection is also presented. Some considerations are also given on the use of reservoir simulators in connection with reservoir description.