A history match for gas and water production from Travis Peak Formation in the Eastern Texas Basin using our numerical simulator was performed. In our simulator, unlike dual porosity models, we used one general equation for both fracture and matrix, and variable computational cells. This enabled us to reduce the size of the computational cell close to fracture size which is closer to real situations in the gas reservoirs, and in turn, we believe our prediction is more accurate and reliable. Other advantages of our approach are: a) the flow equations in the fracture are not oversimplified, and b) the fracture system is not restricted to network of fractures.

Gas and water production predicted using our modified program agreed well with 30 days of production data from SFE No. 1 in Travis Peak formation. The effect of permeability, porosity, capillary pressure, viscosity of fracturing fluid, the level of invasion of formation by fracturing fluid and presence of single and multiple fractures on production were studied. Our calculation showed that interfacial forces between gas, water and porous medium are the most sensitive parameter effecting the enhancement of the gas production. Furthermore, the increase in overall mobility of the porous medium of reservoir due to presence of the fractures does not have significant effect on production in comparison with the location and distribution of the fractures.

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