Hydraulic fractures play a paramount role in the economical production of gas from shale gas formations. In the context of representing these formations as either single-porosity (SP) or dual-porosity (DP) media, different approaches have been used to represent the fractures in reservoir simulation models; for example, bi-wing planar planes, planar fracture networks, local grid refinements (LGR), discrete facture networks, hydraulic propped zones, and mircoseismic-based fracture networks. With their relatively short production histories, and because of the single-phase (gas) or two-phase (gas and water) nature of their production, most simulation models can reasonably history match the performance of any shale gas production well.

This paper reviews the evolution of different reservoir simulation models (SP-planar fracture, SP-planar fracture network, DP, DP-LGR, and DP-microseismic-based fracture network). Differences in SP and DP models are discussed, and examples demonstrate a match of the actual production from a shale gas well with the long-term prediction of each model.

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