Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system

This work provides an analysis of the effect of nanofluids on the wettability of sandstone for the application of enhanced oil recovery. The wettability of sandstone with brine and nanofluids of ZnO, BiFeO3, and SrFeO3 is studied experimentally using contact angle calculations. Also, the direct simu...

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Main Authors: Ali, H., Soleimani, H., Yahya, N., Khodapanah, L., Kozlowski, G., Sabet, M., Demiral, B.M.R., Adebayo, L.L., Hussain, T.
Format: Article
Institution: Universiti Teknologi Petronas
Record Id / ISBN-0: utp-eprints.30441 /
Published: Elsevier B.V. 2021
Online Access: https://www.scopus.com/inward/record.uri?eid=2-s2.0-85104970552&doi=10.1016%2fj.petrol.2021.108665&partnerID=40&md5=2cd60c8d76f87051c71b81339ecfd098
http://eprints.utp.edu.my/30441/
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spelling utp-eprints.304412022-03-25T06:52:11Z Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system Ali, H. Soleimani, H. Yahya, N. Khodapanah, L. Kozlowski, G. Sabet, M. Demiral, B.M.R. Adebayo, L.L. Hussain, T. This work provides an analysis of the effect of nanofluids on the wettability of sandstone for the application of enhanced oil recovery. The wettability of sandstone with brine and nanofluids of ZnO, BiFeO3, and SrFeO3 is studied experimentally using contact angle calculations. Also, the direct simulations for the displacement of oil with brine and nanofluids are carried out on a micro-CT scanned porous sandstone structure for the measurement of capillary pressure and relative permeability. Fluid properties such as viscosity and density of the nanofluids, brine, and oil to be used in simulations were obtained using viscometer and densimeter. The experimental results show that the contact angle of crude oil on the sandstone surface has a higher value for nanofluids as 125.89° for ZnO, 122.88° for BiFeO3, and 104.98 for SrFeO3 as compared to brine 28.66°, which means the wettability of the system changes from oil-wet to water-wet by the addition of nanofluids. The simulation results indicate that BiFeO3 nanofluid has a greater tendency to change the wettability of porous medium as compared to brine, ZnO, and SrFeO3 nanofluids, as it shows better values of relative permeability and capillary pressure. © 2021 Elsevier B.V. Elsevier B.V. 2021 Article NonPeerReviewed https://www.scopus.com/inward/record.uri?eid=2-s2.0-85104970552&doi=10.1016%2fj.petrol.2021.108665&partnerID=40&md5=2cd60c8d76f87051c71b81339ecfd098 Ali, H. and Soleimani, H. and Yahya, N. and Khodapanah, L. and Kozlowski, G. and Sabet, M. and Demiral, B.M.R. and Adebayo, L.L. and Hussain, T. (2021) Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system. Journal of Petroleum Science and Engineering, 204 . http://eprints.utp.edu.my/30441/
institution Universiti Teknologi Petronas
collection UTP Institutional Repository
description This work provides an analysis of the effect of nanofluids on the wettability of sandstone for the application of enhanced oil recovery. The wettability of sandstone with brine and nanofluids of ZnO, BiFeO3, and SrFeO3 is studied experimentally using contact angle calculations. Also, the direct simulations for the displacement of oil with brine and nanofluids are carried out on a micro-CT scanned porous sandstone structure for the measurement of capillary pressure and relative permeability. Fluid properties such as viscosity and density of the nanofluids, brine, and oil to be used in simulations were obtained using viscometer and densimeter. The experimental results show that the contact angle of crude oil on the sandstone surface has a higher value for nanofluids as 125.89° for ZnO, 122.88° for BiFeO3, and 104.98 for SrFeO3 as compared to brine 28.66°, which means the wettability of the system changes from oil-wet to water-wet by the addition of nanofluids. The simulation results indicate that BiFeO3 nanofluid has a greater tendency to change the wettability of porous medium as compared to brine, ZnO, and SrFeO3 nanofluids, as it shows better values of relative permeability and capillary pressure. © 2021 Elsevier B.V.
format Article
author Ali, H.
Soleimani, H.
Yahya, N.
Khodapanah, L.
Kozlowski, G.
Sabet, M.
Demiral, B.M.R.
Adebayo, L.L.
Hussain, T.
spellingShingle Ali, H.
Soleimani, H.
Yahya, N.
Khodapanah, L.
Kozlowski, G.
Sabet, M.
Demiral, B.M.R.
Adebayo, L.L.
Hussain, T.
Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
author_sort Ali, H.
title Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
title_short Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
title_full Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
title_fullStr Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
title_full_unstemmed Experimental investigation and two-phase flow simulation of oil and nanofluids on micro CT images of sandstone for wettability alteration of the system
title_sort experimental investigation and two-phase flow simulation of oil and nanofluids on micro ct images of sandstone for wettability alteration of the system
publisher Elsevier B.V.
publishDate 2021
url https://www.scopus.com/inward/record.uri?eid=2-s2.0-85104970552&doi=10.1016%2fj.petrol.2021.108665&partnerID=40&md5=2cd60c8d76f87051c71b81339ecfd098
http://eprints.utp.edu.my/30441/
_version_ 1741197406641324032
score 11.62408

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