Mimetic Finite Differences for Flow in Fractures from Microseismic Data

Omar Al-Hinai; Sanjay Srinivasan; Mary F. Wheeler

doi:10.2118/173319-ms

Mimetic Finite Differences for Flow in Fractures from Microseismic Data

Omar Al-Hinai, Sanjay Srinivasan, Mary F. Wheeler

Research output: Chapter in Book/Report/Conference proceeding › Conference contribution

19 Scopus citations

Abstract

We present a method for porous media flow in the presence of complex fracture networks. The approach uses the Mimetic Finite Difference method (MFD) and takes advantage of MFD's ability to solve over a general set of polyhedral cells. This flexibility is used to mesh fracture intersections in two and three-dimensional settings without creating small cells at the intersection point. We also demonstrate how to use general polyhedra for embedding fracture boundaries in the reservoir domain. The target application is representing fracture networks inferred from microseismic analysis.

Original language	English (US)
Title of host publication	SPE Reservoir Simulation Symposium
Publisher	Society of Petroleum Engineers (SPE)
DOIs	https://doi.org/10.2118/173319-ms
State	Published - Feb 23 2015
Externally published	Yes

Bibliographical note

KAUST Repository Item: Exported on 2020-10-01
Acknowledgements: The code used to generate the results was written in Python and used the SciPy and NumPy libraries[Jones et al. (2001)]. The Python package Shapely was used for two-dimensional polygon calculations.Visualization was done using Paraview [Henderson (2007)]. For cell volume and centroid computations,the code uses the algorithm defined in Mirtich (1996). The Authors would like to acknowledge help fromDr. Ivan Yotov, Dr. Mark Mear, and Dr. Xin Yang. A portion of this research was supported by the KingAbdullah University of Science and Technology Academic Excellence Alliance and Saudi Aramco.
This publication acknowledges KAUST support, but has no KAUST affiliated authors.

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10.2118/173319-ms

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title = "Mimetic Finite Differences for Flow in Fractures from Microseismic Data",

abstract = "We present a method for porous media flow in the presence of complex fracture networks. The approach uses the Mimetic Finite Difference method (MFD) and takes advantage of MFD's ability to solve over a general set of polyhedral cells. This flexibility is used to mesh fracture intersections in two and three-dimensional settings without creating small cells at the intersection point. We also demonstrate how to use general polyhedra for embedding fracture boundaries in the reservoir domain. The target application is representing fracture networks inferred from microseismic analysis.",

author = "Omar Al-Hinai and Sanjay Srinivasan and Wheeler, {Mary F.}",

note = "KAUST Repository Item: Exported on 2020-10-01 Acknowledgements: The code used to generate the results was written in Python and used the SciPy and NumPy libraries[Jones et al. (2001)]. The Python package Shapely was used for two-dimensional polygon calculations.Visualization was done using Paraview [Henderson (2007)]. For cell volume and centroid computations,the code uses the algorithm defined in Mirtich (1996). The Authors would like to acknowledge help fromDr. Ivan Yotov, Dr. Mark Mear, and Dr. Xin Yang. A portion of this research was supported by the KingAbdullah University of Science and Technology Academic Excellence Alliance and Saudi Aramco. This publication acknowledges KAUST support, but has no KAUST affiliated authors.",

year = "2015",

month = feb,

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doi = "10.2118/173319-ms",

language = "English (US)",

booktitle = "SPE Reservoir Simulation Symposium",

publisher = "Society of Petroleum Engineers (SPE)",

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T1 - Mimetic Finite Differences for Flow in Fractures from Microseismic Data

AU - Al-Hinai, Omar

AU - Srinivasan, Sanjay

AU - Wheeler, Mary F.

N1 - KAUST Repository Item: Exported on 2020-10-01 Acknowledgements: The code used to generate the results was written in Python and used the SciPy and NumPy libraries[Jones et al. (2001)]. The Python package Shapely was used for two-dimensional polygon calculations.Visualization was done using Paraview [Henderson (2007)]. For cell volume and centroid computations,the code uses the algorithm defined in Mirtich (1996). The Authors would like to acknowledge help fromDr. Ivan Yotov, Dr. Mark Mear, and Dr. Xin Yang. A portion of this research was supported by the KingAbdullah University of Science and Technology Academic Excellence Alliance and Saudi Aramco. This publication acknowledges KAUST support, but has no KAUST affiliated authors.

PY - 2015/2/23

Y1 - 2015/2/23

N2 - We present a method for porous media flow in the presence of complex fracture networks. The approach uses the Mimetic Finite Difference method (MFD) and takes advantage of MFD's ability to solve over a general set of polyhedral cells. This flexibility is used to mesh fracture intersections in two and three-dimensional settings without creating small cells at the intersection point. We also demonstrate how to use general polyhedra for embedding fracture boundaries in the reservoir domain. The target application is representing fracture networks inferred from microseismic analysis.

AB - We present a method for porous media flow in the presence of complex fracture networks. The approach uses the Mimetic Finite Difference method (MFD) and takes advantage of MFD's ability to solve over a general set of polyhedral cells. This flexibility is used to mesh fracture intersections in two and three-dimensional settings without creating small cells at the intersection point. We also demonstrate how to use general polyhedra for embedding fracture boundaries in the reservoir domain. The target application is representing fracture networks inferred from microseismic analysis.

UR - http://hdl.handle.net/10754/598837

UR - http://www.onepetro.org/doi/10.2118/173319-MS

U2 - 10.2118/173319-ms

DO - 10.2118/173319-ms

M3 - Conference contribution

BT - SPE Reservoir Simulation Symposium

PB - Society of Petroleum Engineers (SPE)

ER -

Mimetic Finite Differences for Flow in Fractures from Microseismic Data

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