The study including field and artificial data was performed to analyze the production performance of shale gas and coalbed methane reservoirs with the different well trajectories and completion techniques and also to investigate the handicaps of the available commercial numerical simulator methodology. Each unconventional gas reservoir is unique and needs special interests to be characterized accurately. Ordinarily, it is very difficult to characterize that and choose the right recovery techniques. Furthermore, the accurate stimulation strategy plays an important role to produce natural gas commercially and optimize the recovery efficiently. With the help of the numerical simulation applications like this project, the comparison of the each system and identifying the best case scenario allow us to validate and predict the performance of the unconventional reservoir systems properly. A series of reservoir simulation were conducted with dual porosity model for coal bed methane and shale gas reservoirs. In some reservoir systems, hydraulic fractures were represented and included into the model by local grid refinement and well multiplier facilities of the simulator for vertical, horizontal, and multilateral well types. The purpose of the project is to integrate and analyze the effect of the different well trajectories and completions, and the number of hydraulic fracture stages on the future production performance of shale gas and coal bed methane reservoirs. The efficient and correct use of the numerical simulation become more significant in the unconventional gas system since it is absolutely challenging process due to the several reasons such as ultra-low permeability, desorption effect, and complex geological characteristics. In this regard, the study provides the different systematic approach to take into account the aforementioned circumstances. As a result, the work leads to development of the numerical simulation methodology by permitting to better understand these types of reservoirs.
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