A Study on the Production Performance of a Horizontal Shale Gas Well Using a Fully Coupled Flow and Geomechanics Modeling

Conventional petroleum reservoir simulators use constant rock compressibility to denote deformation. However, due the stress-sensitive nature of shale formations, using in does not accurately capture pressure diffusion reservoir, leading a higher error margin flow rate estimation. Fluid coupling with geomechanics is used account for such phenomenon numerically. Such an approach important numerical studies and any energy underground storage modeling (i.e., CO2 storage). Usually, when fluid studied fluid, stimulated petrophysical properties are overlooked. This paper aims present study on effect performance gas-producing well. In addition, results from cases coupled decoupled simulations compared. The governing equations were discretized Finite Element Method. First, model was validated against Terzaghi's consolidation theory analytical solution. After that, history matching production performed field data Barnett Shale. Then sensitivity analysis carried out gas viscosity, Stimulated Reservoir Volume (SRV) porosity, fracture conductivity. Next, conducted cases. Finally, compared between show that lower SRV conductivity improved horizontal well performance. geomechanical effects decoupled, simulator overestimated cumulative production.