Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations
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2018. Postersitzung präsentiert bei Third EAGE Workshop on Naturally Fractured Reservoirs, Muscat, Oman.
Publikationen: Konferenzbeitrag › Poster › Forschung › (peer-reviewed)
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T1 - Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations
AU - Sedaghat, Mohammadhossein
AU - Matthäi, Stephan K.
AU - Azizmohammadi, Siroos
PY - 2018/2/5
Y1 - 2018/2/5
N2 - The prediction of water breakthrough and oil recovery for naturally fractured reservoirs (NFRs) cannot be performed accurately without dynamic upscaled relative permeability functions. Relative permeability is commonly assumed to be a scalar quantity, although a justification for NFRs has yet to be presented. In this study, we show how accurate this assumption is for fracture-matrix ensemble relative permeabilities determined by numeric simulations of unsteady-state core flooding.Numerical determination of relative permeability requires a realistic flow model, a spatially adaptive simulation approach and a sophisticated analysis procedure. To fulfil these requirements, we apply discrete fracture and matrix (DFM) modelling to well characterized hm-km outcrop analogues. These are parametrized with aperture, permeability, and capillary pressure data. Fracture attributes are allowed to vary from segment to segment, trying to emulate in situ conditions.
AB - The prediction of water breakthrough and oil recovery for naturally fractured reservoirs (NFRs) cannot be performed accurately without dynamic upscaled relative permeability functions. Relative permeability is commonly assumed to be a scalar quantity, although a justification for NFRs has yet to be presented. In this study, we show how accurate this assumption is for fracture-matrix ensemble relative permeabilities determined by numeric simulations of unsteady-state core flooding.Numerical determination of relative permeability requires a realistic flow model, a spatially adaptive simulation approach and a sophisticated analysis procedure. To fulfil these requirements, we apply discrete fracture and matrix (DFM) modelling to well characterized hm-km outcrop analogues. These are parametrized with aperture, permeability, and capillary pressure data. Fracture attributes are allowed to vary from segment to segment, trying to emulate in situ conditions.
UR - https://events.eage.org/en/2018/third-eage-workshop-on-naturally-fractured-reservoirs/technical-programme/proceedings
M3 - Poster
T2 - Third EAGE Workshop on Naturally Fractured Reservoirs
Y2 - 5 February 2018 through 7 February 2018
ER -
