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- W4386495641 abstract "ABSTRACT Natural fractures play a significant role in oil and gas production by serving as the primary fluid pathways in reservoirs with low matrix permeability. However, their behavior is sensitive to stress change. The depletion of reservoir pressure will increase the effective stress and may cause natural fractures to close. Closure of opened fractures may create pressure barriers and impede further depletion. Numerical simulation of a naturally fractured reservoir remains challenging. A fully coupled finite element model is developed in this study using commercial finite element method (FEM) software. The interaction between total stress and reservoir pressure is computed using a Biot-Gassmann poroelastic model, and the depletion is modeled as pressure diffusion using Darcy's law. The closure of natural fractures is modeled by associating the permeability to stress using a subroutine that reads the stress at each time iteration to compute the corresponding permeability and update the material property at each material point. A scenario study successfully demonstrates the modification of the depletion pattern because of the closure of natural fractures. INTRODUCTION When natural fractures develop within a reservoir, geomechanical and hydraulic properties interact with one another (Davies & Davies, 2001). The initial spatial distribution of opened fractures has a significant impact on fluid flow and pressure depletion (Heffer et al., 1994). The in-situ stress field responds to reservoir pressure changes according to porous media constituting material laws. On the other hand, hydraulic properties of natural fractures are sensitive to stress conditions. Closure of opened fractures creates a pressure barrier and can impede further depletion. Such interactive behaviors are highly dynamic and should be modeled in a coupled manner (Jin et al., 2000). Most current modeling approaches involve two separate simulation platforms: (1) fluid flow and reservoir pressure modeled with reservoir simulators and (2) stress evolutions modeled using FEM simulators (Myers et al., 2017). Such approaches depend on a large amount of data repeatedly transferred between the two platforms. Recently lots of efforts of coupled modeling have been reported or implemented into commercial software. Generally, the reservoir simulator is the master or host in the coupled process, therefore the focus is on fluid simulation, but the stress is typically handled oversimplified. Furthermore, properly modeling the modification of fracture transport properties attributed to stress variations remains challenging (Gao & Gray, 2022)." @default.
- W4386495641 created "2023-09-07" @default.
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- W4386495641 date "2023-06-25" @default.
- W4386495641 modified "2023-10-16" @default.
- W4386495641 title "Coupled Pore Pressure and Geomechanical Modeling of a Naturally Fractured Reservoir" @default.
- W4386495641 doi "https://doi.org/10.56952/arma-2023-0748" @default.
- W4386495641 hasPublicationYear "2023" @default.
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