Simulation of Matrix/Fracture Interaction in Low-Permeability Fractured Unconventional Reservoirs
- Didier Y. Ding (IFP Energies Nouvelles) | Nicolas Farah (IFP Energies Nouvelles) | Bernard Bourbiaux (IFP Energies Nouvelles) | Yu-Shu Wu (Colorado School of Mines) | Imen Mestiri (IFP Energies Nouvelles)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- August 2018
- Document Type
- Journal Paper
- 1,389 - 1,411
- 2018.Society of Petroleum Engineers
- Fractured reservoir, MINC (multiple interacting continua), Discrete fracture model, Shale-gas, Tight-oil
- 10 in the last 30 days
- 383 since 2007
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Unconventional reservoirs, such as shale-gas or tight oil reservoirs, are generally highly fractured (including hydraulic fractures and stimulated and nonstimulated natural fractures of various sizes) and embedded in low-permeability formations. One of the main production mechanisms in unconventional reservoirs is the flow exchange between matrix and fracture media. However, because of extremely low matrix permeability, the matrix/fracture exchange is very slow and the transient flow may last several years to tens of years, or almost the entire production life. The commonly used dual-porosity (DP) modeling approach involves a computation of pseudosteady-state matrix/fracture transfers with homogenized fluid and flow properties within the matrix medium. This kind of model clearly fails to handle the long-lasting matrix/fracture interaction in very-low-permeability reservoirs, especially for multiphase flow with phase-change problems. Moreover, a DP model is not adapted for the simulation of matrix/fracture exchange when fractures are described by a discrete-fracture network (DFN). This paper presents an embedded discrete-fracture model (EDFM) dependent on the multiple-interacting-continua (MINC) proximity function to overcome this insufficiency of the conventional DP model.
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