The results show that porous kerogen, Knudsen diffusion and the effects of slippage during viscous flow in the inorganic matrix significantly influence production and should not be neglected in models. The MPM model solutions are in good agreement with those from the classic dual-porosity trilinear flow model. Solutions for the MPM model were derived in the Laplace transform domain and were validated by actual production data. Given that MFHWs are reservoir stimulated in shale gas reservoirs, we present an analytic multiple porosity media model (MPM model) to describe gas flow from kerogen to MFHWs. Continuity equations for porous kerogen, the inorganic matrix and natural fractures are given to describe the mechanism of flow through multiple pore sizes in shale gas reservoirs using apparent permeability.
Because shale gas reservoirs are composed of media with multiple pore sizes (including porous kerogen, the inorganic matrix, and natural fractures), it is necessary to consider the effects of slippage during viscous flow, Knudsen diffusion, surface diffusion and gas adsorption and desorption. Shale reservoirs have abundant kerogen and nanoscale pores, making it crucial to consider the influence of gas flow on these reservoirs the Darcy formula cannot accurately describe the gas flow in shale reservoirs. Shale reservoirs are becoming more important in worldwide oil and gas production because of the use of multi-fractured horizontal wells (MFHWs).
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