Long-term effects of fluid injection and production on the thermo-hydro-mechanical behavior of a fractured reservoir
Deep geological media will be intensively utilized for achieving carbon neutrality within the next few decades (Friedmann et al., 2020). Widespread deployment of geothermal energy production, geologic carbon storage, and subsurface energy storage will require massive injection and production of fluids in porous reservoir rock and fractured low permeable formations. Fluid injection and production causes pore pressure and temperature perturbations that induce deformation and stress changes (Tsang, 1991). These pressure, temperature, and stress changes affect fracture and fault stability, leading to aseismic and/or seismic slip if failure conditions are reached (Cornet et al., 1997). Understanding how coupled processes control fluid flow and fracture stability is crucial for the success of geo-energy projects. While small shear slip, in the order of mm to cm, can be beneficial to enhance the permeability of the rock mass (Rutqvist and Stephansson, 2003), larger slip, in the order of tens of cm over rupture areas on the scale of hundred meters in diameter, may induce earthquakes that could be felt on the surface, causing nuisance to the local populations and eventually damaging structures and infrastructures (Kanamori and Brodsky, 2004). Numerical simulations of coupled processes are a useful tool to understand the interactions between pore pressure, temperatures, and stress in fractured rock as a result of fluid injection and/or extraction. In this study, we aim at identifying the long-term thermo-hydro-mechanical (THM) response of a fractured reservoir to water injection and production.
| Main Authors: | , , , |
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| Other Authors: | |
| Format: | comunicación de congreso biblioteca |
| Language: | English |
| Published: |
2020-11-11
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| Subjects: | Deep geological media, Fractured reservoirs, |
| Online Access: | http://hdl.handle.net/10261/224452 http://dx.doi.org/10.13039/501100000781 |
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| Summary: | Deep geological media will be intensively utilized for achieving carbon neutrality within the next few decades (Friedmann et al., 2020). Widespread deployment of geothermal energy production, geologic carbon storage, and subsurface energy storage will require massive injection and production of fluids in porous reservoir rock and fractured low permeable formations. Fluid injection and production causes pore pressure and temperature perturbations that induce deformation and stress changes (Tsang, 1991). These pressure, temperature, and stress changes affect fracture and fault stability, leading to aseismic and/or seismic slip if failure conditions are reached (Cornet et al., 1997).
Understanding how coupled processes control fluid flow and fracture stability is crucial for the success of geo-energy projects. While small shear slip, in the order of mm to cm, can be beneficial to enhance the permeability of the rock mass (Rutqvist and Stephansson, 2003), larger slip, in the order of tens of cm over rupture areas on the scale of hundred meters in diameter, may induce earthquakes that could be felt on the surface, causing nuisance to the local populations and eventually damaging structures and infrastructures (Kanamori and Brodsky, 2004). Numerical simulations of coupled processes are a useful tool to understand the interactions between pore pressure, temperatures, and stress in fractured rock as a result of fluid injection and/or extraction. In this study, we aim at identifying the long-term thermo-hydro-mechanical (THM) response of a fractured reservoir to water injection and production. |
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