Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations

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Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations. / Sedaghat, Mohammadhossein; Matthäi, Stephan K.; Azizmohammadi, Siroos.
2018. Poster session presented at Third EAGE Workshop on Naturally Fractured Reservoirs, Muscat, Oman.

Research output: Contribution to conferencePosterResearchpeer-review

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Sedaghat M, Matthäi SK, Azizmohammadi S. Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations. 2018. Poster session presented at Third EAGE Workshop on Naturally Fractured Reservoirs, Muscat, Oman.

Author

Sedaghat, Mohammadhossein ; Matthäi, Stephan K. ; Azizmohammadi, Siroos. / Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations. Poster session presented at Third EAGE Workshop on Naturally Fractured Reservoirs, Muscat, Oman.

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@conference{733193c751d949679c9316abd0594b30,
title = "Tensorial Fracture-Matrix Ensemble Relative Permeabilities in Naturally Fractured Reservoirs: Evidence from Discrete Fracture and Matrix Simulations",
abstract = "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.",
author = "Mohammadhossein Sedaghat and Matth{\"a}i, {Stephan K.} and Siroos Azizmohammadi",
year = "2018",
month = feb,
day = "5",
language = "English",
note = "Third EAGE Workshop on Naturally Fractured Reservoirs ; Conference date: 05-02-2018 Through 07-02-2018",
url = "https://events.eage.org/en/2018/third-eage-workshop-on-naturally-fractured-reservoirs",

}

RIS (suitable for import to EndNote) - Download

TY - CONF

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 -