Residual oil saturation under mixed-wet conditions

a direct comparison between Indiana limestone and its microfluidic analogue

Yukie Tanino, Magali Christensen, Xanat Zacarias Hernandez

Research output: Chapter in Book/Report/Conference proceedingConference contribution

Abstract

We present laboratory measurements of residual oil saturation established by secondary waterflood in packed beds of crushed calcite assembled in a microfluidic channel under mixed-wet conditions. The measurements are compared with analogous measurements in Indiana limestone cores using the same test fluids and comparable injection rates. The wettability is characterized by the advancing contact angle of the flood water on a mineralogically representative substrate submerged in the oil phase, which ranged from θa = 90° to 160°. While residual oil saturation is larger in the microfluidic analogue than the limestone cores over the full range of θa considered presently, its dependence on θa is qualitatively similar for both media and is well described by a concave-up quadratic function. Maximum recovery occurs at moderately oil-wet conditions of θa = 130° in Indiana limestone and 120° in its microfluidic analogue. These findings demonstrate that salient features of oil/brine flow through O(10)cm-long cores are conserved in two-dimensional microfluidic models under conditions considered presently.
Original languageEnglish
Title of host publicationProceedings of the International Symposium of the Society of Core Analysts
PublisherSociety for Core Analysts
Pages1-11
Number of pages11
Publication statusPublished - 28 Aug 2017
EventThe 31st International Symposium of the Society of Core Analysts - The Hofburg Palace, Vienna, Austria
Duration: 28 Aug 20171 Sep 2017

Conference

ConferenceThe 31st International Symposium of the Society of Core Analysts
CountryAustria
CityVienna
Period28/08/171/09/17

Fingerprint

limestone
saturation
oil
wettability
brine
calcite
comparison
substrate
fluid
water

Keywords

  • Residual oil saturation
  • Indiana Limestone
  • Microfluidic analogue

Cite this

Tanino, Y., Christensen, M., & Zacarias Hernandez, X. (2017). Residual oil saturation under mixed-wet conditions: a direct comparison between Indiana limestone and its microfluidic analogue. In Proceedings of the International Symposium of the Society of Core Analysts (pp. 1-11). [SCA2017-009] Society for Core Analysts.

Residual oil saturation under mixed-wet conditions : a direct comparison between Indiana limestone and its microfluidic analogue. / Tanino, Yukie; Christensen, Magali; Zacarias Hernandez, Xanat.

Proceedings of the International Symposium of the Society of Core Analysts. Society for Core Analysts, 2017. p. 1-11 SCA2017-009.

Research output: Chapter in Book/Report/Conference proceedingConference contribution

Tanino, Y, Christensen, M & Zacarias Hernandez, X 2017, Residual oil saturation under mixed-wet conditions: a direct comparison between Indiana limestone and its microfluidic analogue. in Proceedings of the International Symposium of the Society of Core Analysts., SCA2017-009, Society for Core Analysts, pp. 1-11, The 31st International Symposium of the Society of Core Analysts, Vienna, Austria, 28/08/17.
Tanino Y, Christensen M, Zacarias Hernandez X. Residual oil saturation under mixed-wet conditions: a direct comparison between Indiana limestone and its microfluidic analogue. In Proceedings of the International Symposium of the Society of Core Analysts. Society for Core Analysts. 2017. p. 1-11. SCA2017-009
Tanino, Yukie ; Christensen, Magali ; Zacarias Hernandez, Xanat. / Residual oil saturation under mixed-wet conditions : a direct comparison between Indiana limestone and its microfluidic analogue. Proceedings of the International Symposium of the Society of Core Analysts. Society for Core Analysts, 2017. pp. 1-11
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abstract = "We present laboratory measurements of residual oil saturation established by secondary waterflood in packed beds of crushed calcite assembled in a microfluidic channel under mixed-wet conditions. The measurements are compared with analogous measurements in Indiana limestone cores using the same test fluids and comparable injection rates. The wettability is characterized by the advancing contact angle of the flood water on a mineralogically representative substrate submerged in the oil phase, which ranged from θa = 90° to 160°. While residual oil saturation is larger in the microfluidic analogue than the limestone cores over the full range of θa considered presently, its dependence on θa is qualitatively similar for both media and is well described by a concave-up quadratic function. Maximum recovery occurs at moderately oil-wet conditions of θa = 130° in Indiana limestone and 120° in its microfluidic analogue. These findings demonstrate that salient features of oil/brine flow through O(10)cm-long cores are conserved in two-dimensional microfluidic models under conditions considered presently.",
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N2 - We present laboratory measurements of residual oil saturation established by secondary waterflood in packed beds of crushed calcite assembled in a microfluidic channel under mixed-wet conditions. The measurements are compared with analogous measurements in Indiana limestone cores using the same test fluids and comparable injection rates. The wettability is characterized by the advancing contact angle of the flood water on a mineralogically representative substrate submerged in the oil phase, which ranged from θa = 90° to 160°. While residual oil saturation is larger in the microfluidic analogue than the limestone cores over the full range of θa considered presently, its dependence on θa is qualitatively similar for both media and is well described by a concave-up quadratic function. Maximum recovery occurs at moderately oil-wet conditions of θa = 130° in Indiana limestone and 120° in its microfluidic analogue. These findings demonstrate that salient features of oil/brine flow through O(10)cm-long cores are conserved in two-dimensional microfluidic models under conditions considered presently.

AB - We present laboratory measurements of residual oil saturation established by secondary waterflood in packed beds of crushed calcite assembled in a microfluidic channel under mixed-wet conditions. The measurements are compared with analogous measurements in Indiana limestone cores using the same test fluids and comparable injection rates. The wettability is characterized by the advancing contact angle of the flood water on a mineralogically representative substrate submerged in the oil phase, which ranged from θa = 90° to 160°. While residual oil saturation is larger in the microfluidic analogue than the limestone cores over the full range of θa considered presently, its dependence on θa is qualitatively similar for both media and is well described by a concave-up quadratic function. Maximum recovery occurs at moderately oil-wet conditions of θa = 130° in Indiana limestone and 120° in its microfluidic analogue. These findings demonstrate that salient features of oil/brine flow through O(10)cm-long cores are conserved in two-dimensional microfluidic models under conditions considered presently.

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