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Workflow for upscaling wettability from the nanoscale to core scale

(2020) PETROPHYSICS. 61(2). p.189-205
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Abstract
Wettability is a key factor influencing multiphase flow in porous media. In addition to the average contact angle, the spatial distribution of contact angles throughout the porous medium is important, as it directly controls the connectivity of wetting and nonwetting phases. The controlling factors may not only relate to the surface chemistry of minerals but also to their texture, which implies that a length-scale range from nanometers to centimeters has to be considered. So far, an integrated workflow addressing wettability consistently through the different scales does not exist. In this study, we demonstrate that such a workflow is possible by combining microcomputed tomography (mu CT) imaging with atomic-force microscopy (AFM). We find that in a carbonate rock, consisting of 99.9% calcite with a dual-porosity structure, wettability is ultimately controlled by the surface texture of the mineral. Roughness and texture variation within the rock control the capillary pressure required for initializing proper crude oil-rock contacts that allow aging and subsequent wettability alteration. AFM enables us to characterize such surface-fluid interactions and to investigate the surface texture. In this study, we use AFM to image nanoscale fluid-configurations in 3D at connate water saturation and compare the fluid configuration with simulations on the rock surface, assuming different capillary pressures.
Keywords
PORE-SCALE, CONTACT-ANGLE, WATER-WET, CAPILLARY-PRESSURE, MIXED-WETTABILITY, MULTIPHASE FLOW, 2-PHASE FLOW, LOW-SALINITY, SPONTANEOUS IMBIBITION, RELATIVE PERMEABILITY

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Citation

Please use this url to cite or link to this publication:

MLA
Rücker, Maja, et al. “Workflow for Upscaling Wettability from the Nanoscale to Core Scale.” PETROPHYSICS, vol. 61, no. 2, 2020, pp. 189–205.
APA
Rücker, M., Bartels, W.-B., Bultreys, T., Boone, M. A., Singh, K., Garfi, G., … Berg, S. (2020). Workflow for upscaling wettability from the nanoscale to core scale. PETROPHYSICS, 61(2), 189–205.
Chicago author-date
Rücker, Maja, Willem-Bart Bartels, Tom Bultreys, Marijn A. Boone, Kamaljit Singh, Gaetano Garfi, Alessio Scanziani, et al. 2020. “Workflow for Upscaling Wettability from the Nanoscale to Core Scale.” PETROPHYSICS 61 (2): 189–205.
Chicago author-date (all authors)
Rücker, Maja, Willem-Bart Bartels, Tom Bultreys, Marijn A. Boone, Kamaljit Singh, Gaetano Garfi, Alessio Scanziani, Catherine Spurin, Sherifat Yesufu-Rufai, Samuel Krevor, Martin J. Blunt, Ove Wilson, Hassan Mahani, Veerle Cnudde, Paul F. Luckham, Apostolos Georgiadis, and Steffen Berg. 2020. “Workflow for Upscaling Wettability from the Nanoscale to Core Scale.” PETROPHYSICS 61 (2): 189–205.
Vancouver
1.
Rücker M, Bartels W-B, Bultreys T, Boone MA, Singh K, Garfi G, et al. Workflow for upscaling wettability from the nanoscale to core scale. PETROPHYSICS. 2020;61(2):189–205.
IEEE
[1]
M. Rücker et al., “Workflow for upscaling wettability from the nanoscale to core scale,” PETROPHYSICS, vol. 61, no. 2, pp. 189–205, 2020.
@article{8660592,
  abstract     = {Wettability is a key factor influencing multiphase flow in porous media. In addition to the average contact angle, the spatial distribution of contact angles throughout the porous medium is important, as it directly controls the connectivity of wetting and nonwetting phases. The controlling factors may not only relate to the surface chemistry of minerals but also to their texture, which implies that a length-scale range from nanometers to centimeters has to be considered. So far, an integrated workflow addressing wettability consistently through the different scales does not exist. In this study, we demonstrate that such a workflow is possible by combining microcomputed tomography (mu CT) imaging with atomic-force microscopy (AFM). We find that in a carbonate rock, consisting of 99.9% calcite with a dual-porosity structure, wettability is ultimately controlled by the surface texture of the mineral. Roughness and texture variation within the rock control the capillary pressure required for initializing proper crude oil-rock contacts that allow aging and subsequent wettability alteration. AFM enables us to characterize such surface-fluid interactions and to investigate the surface texture. In this study, we use AFM to image nanoscale fluid-configurations in 3D at connate water saturation and compare the fluid configuration with simulations on the rock surface, assuming different capillary pressures.},
  author       = {Rücker, Maja and Bartels, Willem-Bart and Bultreys, Tom and Boone, Marijn A. and Singh, Kamaljit and Garfi, Gaetano and Scanziani, Alessio and Spurin, Catherine and Yesufu-Rufai, Sherifat and Krevor, Samuel and Blunt, Martin J. and Wilson, Ove and Mahani, Hassan and Cnudde, Veerle and Luckham, Paul F. and Georgiadis, Apostolos and Berg, Steffen},
  issn         = {1529-9074},
  journal      = {PETROPHYSICS},
  keywords     = {PORE-SCALE,CONTACT-ANGLE,WATER-WET,CAPILLARY-PRESSURE,MIXED-WETTABILITY,MULTIPHASE FLOW,2-PHASE FLOW,LOW-SALINITY,SPONTANEOUS IMBIBITION,RELATIVE PERMEABILITY},
  language     = {eng},
  number       = {2},
  pages        = {189--205},
  title        = {Workflow for upscaling wettability from the nanoscale to core scale},
  url          = {http://dx.doi.org/10.30632/pjv61n2-2020a5},
  volume       = {61},
  year         = {2020},
}

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