Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches

Walid Mohamed Mahmud

doi:doi:10.11648/j.ogce.20170505.14

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Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches

Walid Mohamed Mahmud

Received: 1 January 2017 Accepted: 31 January 2017 Published: 24 October 2017

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Abstract

The effect of topological properties on imbibition relative permeabilities and residual saturations was previously studied by utilizing quasi-static network model topologies extracted from actual sandstones 3D micro-tomographic images. Non-wetting fluid in imbibition displacements can be disconnected by snap-off as a result of swelling of wetting films in the corners of pores and throats. The findings showed that the effect of topology on imbibition relative permeabilities depends on the level of snap-off. For strongly wetting conditions where snap-off dominates the displacement the effect of network topology is significantly smaller than for weakly wet conditions where snap-off is suppressed. The findings were valid for random networks and for networks displaying short-range pore-throat and longer-range spatial correlations. The aim of this study is to validate network model findings by comparing them with laboratory measurements of relative permeabilities. Laboratory measured data include imbibition relative permeability for sandstones of similar petrophysical properties to Fontainebleau sandstone used to extract 3D micro-tomographic images. Laboratory measurements were made at ambient conditions on core samples of different diameters and different porosities and permeabilities. Experimental measurements were in good qualitative agreement with stochastic networks that match the full coordination number distribution and geometric properties of networks obtained from 3D micro-CT images. Experimental measurements were also in good agreement with networks displaying both short-range pore-throat correlations and longer-range spatial correlations.

DOI	10.11648/j.ogce.20170505.14
Published in	International Journal of Oil, Gas and Coal Engineering (Volume 5, Issue 5, September 2017)
Page(s)	90-96
Creative Commons	This is an Open Access article, distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution and reproduction in any medium or format, provided the original work is properly cited.
Copyright	Copyright © The Author(s), 2024. Published by Science Publishing Group

Keywords

Two-Phase Flow, Relative Permeability, Network Models, Imbibition, Topology, Experimental Measurements

References

[1]	Olalekan, A. O., Sheppard, A. P., Arns, C. H., Sok, R. M., Cinar, Y., Knackstedt, M. A., Pinczewski, W. V.: “Experimental Investigation of Drainage Capillary Pressure Computed From Digitized Tomographic Images” SPE 99897 in proceedings of the SPE/DOE Symposium on Improved Oil Recovery. Tulsa, 22-26 April (2006).
[2]	Mahmud, W. M., Arwini, S., Lalah, M.: “Experimental and Network Model Study on the Effect of Network Topology on Two-Phase Imbibition Relative Permeability”, The Thirteenth Mediterranean Petroleum Conference and Exhibition, Istanbul, Turkey, 14-16 November (2014).
[3]	Mahmud, W. M, Arns, J. Y., Sheppard, A., Knackstedt, M. A., Pinczewski, W. V.: “Effect of Network Topology on Two-Phase Imbibition Relative Permeability”, Transport in Porous Media, 66 (3), 481-493 (2007).
[4]	Arns, J. Y., Robins, V., Sheppard, A. P., Sok, R. M., Pinczewski, W. V., Knackstedt, M. A.: ''Effect of Network Topology on Relative Permeability,'' Transport in Porous Media {1804}, 1-25, (2003).
[5]	Lindquist, W. B., Venkatarangan, A., Dunsmuir, J., and Wong, T. F.: ''Pore and Throat Size Distributions Measured from Synchrotron X-ray Tomographic Images of Fontainebleau Sandstones,'' Journal Geophysical Research 105B, 21508 (2000).
[6]	Ioannidis, M. A., and Chatzis, I.: ''A Mixed-Percolation Model of Capillary Hysteresis and Entrapment in Mercury Porosimetry,'' Journal of Colloid and Interface Science 161, 278-291 (1993).
[7]	Knackstedt, M. A., Sheppard, A. P., and Pinczewski, W. V.: ''Simulation of Mercury Porosimetry on Correlated Grids,'' Physical Review E. American Institute of Physics (1999), USA, R6923-R6926, No. 58.
[8]	Hewett, T. A.: ''Fractal Distributions of Reservoir Heterogeneity and Their Influence on Fluid Transport,'' paper SPE 15386 presented at the 1986 SPE Annual Technical Conference and Exhibition, New Orleans, 5-8 October.
[9]	Knackstedt, M. A., Sheppard, A. P., and Sahimi, M.: ''Pore Network Modelling of Two-Phase Flow in Porous Rock: the Effect of Correlated heterogeneity,'' Advances in Water Resources 21, 257-277 (2001).
[10]	Knackstedt, M. A., Sahimi, M., and Sheppard, A. P.: ''Invasion Percolation with Long-Range Correlations: First-Order Phase Transition and Nonuniversal Scaling Properties,'' Physical Review E 61 (5), 4920-4934 (2000).
[11]	Sok, R. M., Knackstedt, M. A., Sheppard, A. P., Pinczewski, W. V., Lindquist W. B., Venkatarangan, A., and Paterson, L.: ''Direct and Stochastic Generation of Network Models from Tomographic Images; Effect of Topology on Two Phase Flow Properties,'' Transport in Porous Media 46, 345-371 (2002).
[12]	Paterson, L., Painter, S., Zhang, X., and Pinczewski, W. V.: ''Simulating Residual Saturation and Relative Permeability in Heterogeneous Formations,'' SPE Journal 211-218 (1998).
[13]	Paterson, L., Scott Painer, Knackstedt, M., and Pincewski, W. V.: ''Patterns of Fluid Flow in Naturally Heterogeneous Rocks,'' Physica A 223, 619-628 (1996).
[14]	Sheng, Q., K. E. Thompson, K. E., Fredrich, J. T. and Salino, P. A.: ''Numerical Prediction of Relative Permeability from MicroCT Images: Comparison of Steady-State versus Displacement Methods,’’ SPE 147431 presented at the SPE Annual Technical Conference and Exhibition held in Denver, Colorado, USA, 30 October-2 November 2011.
[15]	Mahmud, W. M.: “Experimental Validation of Two-Phase Imbibition Relative Permeability with a Stochastic Model Taking into Account the Effects of Correlations”, ‪MOC - 8th Mediterranean Offshore Conference and Exhibition‬, Alexandria, Egypt, 19-21 April 2016.‬‬‬‬‬‬‬‬‬‬‬‬‬‬‬‬
[16]	Sorbie, K. S. and Skauge, A.: ‘‘Can Network Modelling Predict Two-Phase Flow Functions?’’, paper presented at the International Symposium of the Society of Core Analysts in Austin, Texas, USA 18-21 September, 2011.

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APA Style

Walid Mohamed Mahmud. (2017). Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. International Journal of Oil, Gas and Coal Engineering, 5(5), 90-96. https://doi.org/10.11648/j.ogce.20170505.14

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ACS Style

Walid Mohamed Mahmud. Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. Int. J. Oil Gas Coal Eng. 2017, 5(5), 90-96. doi: 10.11648/j.ogce.20170505.14

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AMA Style

Walid Mohamed Mahmud. Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. Int J Oil Gas Coal Eng. 2017;5(5):90-96. doi: 10.11648/j.ogce.20170505.14

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@article{10.11648/j.ogce.20170505.14,
  author = {Walid Mohamed Mahmud},
  title = {Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {5},
  number = {5},
  pages = {90-96},
  doi = {10.11648/j.ogce.20170505.14},
  url = {https://doi.org/10.11648/j.ogce.20170505.14},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20170505.14},
  abstract = {The effect of topological properties on imbibition relative permeabilities and residual saturations was previously studied by utilizing quasi-static network model topologies extracted from actual sandstones 3D micro-tomographic images. Non-wetting fluid in imbibition displacements can be disconnected by snap-off as a result of swelling of wetting films in the corners of pores and throats. The findings showed that the effect of topology on imbibition relative permeabilities depends on the level of snap-off. For strongly wetting conditions where snap-off dominates the displacement the effect of network topology is significantly smaller than for weakly wet conditions where snap-off is suppressed. The findings were valid for random networks and for networks displaying short-range pore-throat and longer-range spatial correlations. The aim of this study is to validate network model findings by comparing them with laboratory measurements of relative permeabilities. Laboratory measured data include imbibition relative permeability for sandstones of similar petrophysical properties to Fontainebleau sandstone used to extract 3D micro-tomographic images. Laboratory measurements were made at ambient conditions on core samples of different diameters and different porosities and permeabilities. Experimental measurements were in good qualitative agreement with stochastic networks that match the full coordination number distribution and geometric properties of networks obtained from 3D micro-CT images. Experimental measurements were also in good agreement with networks displaying both short-range pore-throat correlations and longer-range spatial correlations.},
 year = {2017}
}

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TY  - JOUR
T1  - Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches
AU  - Walid Mohamed Mahmud
Y1  - 2017/10/24
PY  - 2017
N1  - https://doi.org/10.11648/j.ogce.20170505.14
DO  - 10.11648/j.ogce.20170505.14
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 90
EP  - 96
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20170505.14
AB  - The effect of topological properties on imbibition relative permeabilities and residual saturations was previously studied by utilizing quasi-static network model topologies extracted from actual sandstones 3D micro-tomographic images. Non-wetting fluid in imbibition displacements can be disconnected by snap-off as a result of swelling of wetting films in the corners of pores and throats. The findings showed that the effect of topology on imbibition relative permeabilities depends on the level of snap-off. For strongly wetting conditions where snap-off dominates the displacement the effect of network topology is significantly smaller than for weakly wet conditions where snap-off is suppressed. The findings were valid for random networks and for networks displaying short-range pore-throat and longer-range spatial correlations. The aim of this study is to validate network model findings by comparing them with laboratory measurements of relative permeabilities. Laboratory measured data include imbibition relative permeability for sandstones of similar petrophysical properties to Fontainebleau sandstone used to extract 3D micro-tomographic images. Laboratory measurements were made at ambient conditions on core samples of different diameters and different porosities and permeabilities. Experimental measurements were in good qualitative agreement with stochastic networks that match the full coordination number distribution and geometric properties of networks obtained from 3D micro-CT images. Experimental measurements were also in good agreement with networks displaying both short-range pore-throat correlations and longer-range spatial correlations.
VL  - 5
IS  - 5
ER  -

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Author Information

Walid Mohamed Mahmud

Department of Petroleum Engineering, Faculty of Engineering, University of Tripoli, Tripoli, Libya

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Plain Text BibTeX RIS

APA Style

Walid Mohamed Mahmud. (2017). Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. International Journal of Oil, Gas and Coal Engineering, 5(5), 90-96. https://doi.org/10.11648/j.ogce.20170505.14

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ACS Style

Walid Mohamed Mahmud. Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. Int. J. Oil Gas Coal Eng. 2017, 5(5), 90-96. doi: 10.11648/j.ogce.20170505.14

Copy | Download

AMA Style

Walid Mohamed Mahmud. Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches. Int J Oil Gas Coal Eng. 2017;5(5):90-96. doi: 10.11648/j.ogce.20170505.14

Copy | Download

@article{10.11648/j.ogce.20170505.14,
  author = {Walid Mohamed Mahmud},
  title = {Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {5},
  number = {5},
  pages = {90-96},
  doi = {10.11648/j.ogce.20170505.14},
  url = {https://doi.org/10.11648/j.ogce.20170505.14},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20170505.14},
  abstract = {The effect of topological properties on imbibition relative permeabilities and residual saturations was previously studied by utilizing quasi-static network model topologies extracted from actual sandstones 3D micro-tomographic images. Non-wetting fluid in imbibition displacements can be disconnected by snap-off as a result of swelling of wetting films in the corners of pores and throats. The findings showed that the effect of topology on imbibition relative permeabilities depends on the level of snap-off. For strongly wetting conditions where snap-off dominates the displacement the effect of network topology is significantly smaller than for weakly wet conditions where snap-off is suppressed. The findings were valid for random networks and for networks displaying short-range pore-throat and longer-range spatial correlations. The aim of this study is to validate network model findings by comparing them with laboratory measurements of relative permeabilities. Laboratory measured data include imbibition relative permeability for sandstones of similar petrophysical properties to Fontainebleau sandstone used to extract 3D micro-tomographic images. Laboratory measurements were made at ambient conditions on core samples of different diameters and different porosities and permeabilities. Experimental measurements were in good qualitative agreement with stochastic networks that match the full coordination number distribution and geometric properties of networks obtained from 3D micro-CT images. Experimental measurements were also in good agreement with networks displaying both short-range pore-throat correlations and longer-range spatial correlations.},
 year = {2017}
}

Copy | Download

TY  - JOUR
T1  - Effect of Network Topology on Relative Permeability; Network Model and Experimental Approaches
AU  - Walid Mohamed Mahmud
Y1  - 2017/10/24
PY  - 2017
N1  - https://doi.org/10.11648/j.ogce.20170505.14
DO  - 10.11648/j.ogce.20170505.14
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 90
EP  - 96
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20170505.14
AB  - The effect of topological properties on imbibition relative permeabilities and residual saturations was previously studied by utilizing quasi-static network model topologies extracted from actual sandstones 3D micro-tomographic images. Non-wetting fluid in imbibition displacements can be disconnected by snap-off as a result of swelling of wetting films in the corners of pores and throats. The findings showed that the effect of topology on imbibition relative permeabilities depends on the level of snap-off. For strongly wetting conditions where snap-off dominates the displacement the effect of network topology is significantly smaller than for weakly wet conditions where snap-off is suppressed. The findings were valid for random networks and for networks displaying short-range pore-throat and longer-range spatial correlations. The aim of this study is to validate network model findings by comparing them with laboratory measurements of relative permeabilities. Laboratory measured data include imbibition relative permeability for sandstones of similar petrophysical properties to Fontainebleau sandstone used to extract 3D micro-tomographic images. Laboratory measurements were made at ambient conditions on core samples of different diameters and different porosities and permeabilities. Experimental measurements were in good qualitative agreement with stochastic networks that match the full coordination number distribution and geometric properties of networks obtained from 3D micro-CT images. Experimental measurements were also in good agreement with networks displaying both short-range pore-throat correlations and longer-range spatial correlations.
VL  - 5
IS  - 5
ER  -

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