A new method is proposed to estimate the matrix and fracture’s effective compressibilities by using the material balance equation (MBE) and production data. Assuming the behavior of naturally fractured reservoir (NFR), accordingly to the pressure tests analysis, it is then possible to replace the effective compressibilities into a MBE of double porosity to determine original oil from both systems. Due to the lack of information from cores and the problem that implies acquiring it, this method represents a useful alternative for analytical models. Generally, it is complicated to determine representative values of fracture compressibilities for the entire reservoir; especially when this is very heterogeneous. The calculated compressibility of the matrix and fractures can be compared with formation compressibility correlations when there are no core analysis or pressure tests available. This is an innovative method to obtain reliable compressibilities for the analysis of material balance of double porosity (MBDP). In addition, with this method it is also possible to obtain the original ratio of the volume stored in the fractures to the total volume in the reservoir; which is a crucial factor in the determination of the final oil recovery.

Production records provide important information about volumes and contribution areas in oil wells. Over time, the records are also a great contribution to monitoring of oil water contacts. In adition, with these records it is possible to test production pressure without surface wellhead’s measurements. This new approach to obtain such information results from the need to determine the source of water in sime carbonate fields with channeling and / or coning problems, as well as to decide an optimum choke in the operation of the well. For this reason we have implemented a new way of obtaining production records that allows us to maximize the use of data by analysis of applied engineering.

Most of the Cretaceous fractured reservoirs in Mexico are producing from reservoirs with very poor matrix quality and therefore matrix, for the most part, cannot support the fluid flow into fracture and further on towards the wellbore. Considering other important factors like reservoir rock wettability, which is supposed to be oil wet for this type of rock, small matrix block height, and possible capillary continuity between blocks, the effective production mechanism from these reservoirs (fluid transfer from matrix to fracture) changes from capillary imbibition dominated to gravity drainage and viscos dominated.Based on the interpretation of field production data as well as discrete fracture network modeling results, most of the movable oil is considered to be stored in the fractured system, and little participation from matrix to the produced fluid is expected. Also considering the very heterogeneous nature of these reservoirs caused by extended systems of faults and fractured, it is very common that this kind of reservoirs can be divided into different compartments with completely different dynamic behavior.In this work, we try to present a dynamic workflow to compartmentalize the reservoir into isolated or partially isolated blocks, which is the first step in reservoir history-matching process. Later, and through considering the reservoir effective production mechanisms that are discussed in the bulk of the study, a layered history matching process will be presented. In developing this workflow, the raw and interpreted data as well as the final reservoir history-matched models of several fields located in the area have been taken into account to be able to calibrate the workflow and propose a comprehensive procedure that can be of use in similar cases.