Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions

High-quality supercritical CO2 (sCO2) foam as a fracturing fluid is considered ideal for fracturing shale gas reservoirs. The apparent viscosity of the fracturing fluid holds an important role and governs the efficiency of the fracturing process. In this study, the viscosity of sCO2 foam and its emp...

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Main Authors: Ahmed, S., Elraies, K.A., Hashmet, M.R., Alnarabiji, M.S.
Format: Article
Institution: Universiti Teknologi Petronas
Record Id / ISBN-0: utp-eprints.21654 /
Published: MDPI AG 2018
Online Access: https://www.scopus.com/inward/record.uri?eid=2-s2.0-85045409994&doi=10.3390%2fen11040782&partnerID=40&md5=773376b62aa4b638021b7e2cb6e03757
http://eprints.utp.edu.my/21654/
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spelling utp-eprints.216542018-08-01T02:12:40Z Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions Ahmed, S. Elraies, K.A. Hashmet, M.R. Alnarabiji, M.S. High-quality supercritical CO2 (sCO2) foam as a fracturing fluid is considered ideal for fracturing shale gas reservoirs. The apparent viscosity of the fracturing fluid holds an important role and governs the efficiency of the fracturing process. In this study, the viscosity of sCO2 foam and its empirical correlations are presented as a function of temperature, pressure, and shear rate. A series of experiments were performed to investigate the effect of temperature, pressure, and shear rate on the apparent viscosity of sCO2 foam generated by a widely used mixed surfactant system. An advanced high pressure, high temperature (HPHT) foam rheometer was used to measure the apparent viscosity of the foam over a wide range of reservoir temperatures (40-120°C), pressures (1000-2500 psi), and shear rates (10-500 s-1). A well-known power law model was modified to accommodate the individual and combined effect of temperature, pressure, and shear rate on the apparent viscosity of the foam. Flow indices of the power law were found to be a function of temperature, pressure, and shear rate. Nonlinear regression was also performed on the foam apparent viscosity data to develop these correlations. The newly developed correlations provide an accurate prediction of the foam's apparent viscosity under different fracturing conditions. These correlations can be helpful for evaluating foam-fracturing efficiency by incorporating them into a fracturing simulator. © 2018 by the authors. MDPI AG 2018 Article NonPeerReviewed https://www.scopus.com/inward/record.uri?eid=2-s2.0-85045409994&doi=10.3390%2fen11040782&partnerID=40&md5=773376b62aa4b638021b7e2cb6e03757 Ahmed, S. and Elraies, K.A. and Hashmet, M.R. and Alnarabiji, M.S. (2018) Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions. Energies, 11 (4). http://eprints.utp.edu.my/21654/
institution Universiti Teknologi Petronas
collection UTP Institutional Repository
description High-quality supercritical CO2 (sCO2) foam as a fracturing fluid is considered ideal for fracturing shale gas reservoirs. The apparent viscosity of the fracturing fluid holds an important role and governs the efficiency of the fracturing process. In this study, the viscosity of sCO2 foam and its empirical correlations are presented as a function of temperature, pressure, and shear rate. A series of experiments were performed to investigate the effect of temperature, pressure, and shear rate on the apparent viscosity of sCO2 foam generated by a widely used mixed surfactant system. An advanced high pressure, high temperature (HPHT) foam rheometer was used to measure the apparent viscosity of the foam over a wide range of reservoir temperatures (40-120°C), pressures (1000-2500 psi), and shear rates (10-500 s-1). A well-known power law model was modified to accommodate the individual and combined effect of temperature, pressure, and shear rate on the apparent viscosity of the foam. Flow indices of the power law were found to be a function of temperature, pressure, and shear rate. Nonlinear regression was also performed on the foam apparent viscosity data to develop these correlations. The newly developed correlations provide an accurate prediction of the foam's apparent viscosity under different fracturing conditions. These correlations can be helpful for evaluating foam-fracturing efficiency by incorporating them into a fracturing simulator. © 2018 by the authors.
format Article
author Ahmed, S.
Elraies, K.A.
Hashmet, M.R.
Alnarabiji, M.S.
spellingShingle Ahmed, S.
Elraies, K.A.
Hashmet, M.R.
Alnarabiji, M.S.
Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
author_sort Ahmed, S.
title Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
title_short Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
title_full Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
title_fullStr Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
title_full_unstemmed Empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
title_sort empirical modeling of the viscosity of supercritical carbon dioxide foam fracturing fluid under different downhole conditions
publisher MDPI AG
publishDate 2018
url https://www.scopus.com/inward/record.uri?eid=2-s2.0-85045409994&doi=10.3390%2fen11040782&partnerID=40&md5=773376b62aa4b638021b7e2cb6e03757
http://eprints.utp.edu.my/21654/
_version_ 1741196495075409920
score 11.62408

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