High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents

Abstract CO2 foam helps to increase the viscosity of CO2 flood fluid and thus improve the process efficiency of the anthropogenic greenhouse gas’s subsurface utilization and sequestration. Successful CO2 foam formation mandates the development of high-performance chemicals at close to reservoir cond...

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Autores principales: Ayrat Gizzatov, Scott Pierobon, Zuhair AlYousef, Guoqing Jian, Xingyu Fan, Ali Abedini, Amr I. Abdel-Fattah
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Publicado: Nature Portfolio 2021
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spelling oai:doaj.org-article:ac82a031ee024b50a1749351b0128ec92021-12-02T14:26:54ZHigh-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents10.1038/s41598-021-82839-42045-2322https://doaj.org/article/ac82a031ee024b50a1749351b0128ec92021-02-01T00:00:00Zhttps://doi.org/10.1038/s41598-021-82839-4https://doaj.org/toc/2045-2322Abstract CO2 foam helps to increase the viscosity of CO2 flood fluid and thus improve the process efficiency of the anthropogenic greenhouse gas’s subsurface utilization and sequestration. Successful CO2 foam formation mandates the development of high-performance chemicals at close to reservoir conditions, which in turn requires extensive laboratory tests and evaluations. This work demonstrates the utilization of a microfluidic reservoir analogue for rapid evaluation and screening of commercial surfactants (i.e., Cocamidopropyl Hydroxysultaine, Lauramidopropyl Betaine, Tallow Amine Ethoxylate, N,N,N′ Trimethyl-N′-Tallow-1,3-diaminopropane, and Sodium Alpha Olefin Sulfonate) based on their performance to produce supercritical CO2 foam at high salinity, temperature, and pressure conditions. The microfluidic analogue was designed to represent the pore sizes of the geologic reservoir rock and to operate at 100 °C and 13.8 MPa. Values of the pressure drop across the microfluidic analogue during flow of the CO2 foam through its pore network was used to evaluate the strength of the generated foam and utilized only milliliters of liquid. The transparent microfluidic pore network allows in-situ quantitative visualization of CO2 foam to calculate its half-life under static conditions while observing if there is any damage to the pore network due to precipitation and blockage. The microfluidic mobility reduction results agree with those of foam loop rheometer measurements, however, the microfluidic approach provided more accurate foam stability data to differentiate the foaming agent as compared with conventional balk testing. The results obtained here supports the utility of microfluidic systems for rapid screening of chemicals for carbon sequestration or enhanced oil recovery operations.Ayrat GizzatovScott PierobonZuhair AlYousefGuoqing JianXingyu FanAli AbediniAmr I. Abdel-FattahNature PortfolioarticleMedicineRScienceQENScientific Reports, Vol 11, Iss 1, Pp 1-13 (2021)
institution DOAJ
collection DOAJ
language EN
topic Medicine
R
Science
Q
spellingShingle Medicine
R
Science
Q
Ayrat Gizzatov
Scott Pierobon
Zuhair AlYousef
Guoqing Jian
Xingyu Fan
Ali Abedini
Amr I. Abdel-Fattah
High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
description Abstract CO2 foam helps to increase the viscosity of CO2 flood fluid and thus improve the process efficiency of the anthropogenic greenhouse gas’s subsurface utilization and sequestration. Successful CO2 foam formation mandates the development of high-performance chemicals at close to reservoir conditions, which in turn requires extensive laboratory tests and evaluations. This work demonstrates the utilization of a microfluidic reservoir analogue for rapid evaluation and screening of commercial surfactants (i.e., Cocamidopropyl Hydroxysultaine, Lauramidopropyl Betaine, Tallow Amine Ethoxylate, N,N,N′ Trimethyl-N′-Tallow-1,3-diaminopropane, and Sodium Alpha Olefin Sulfonate) based on their performance to produce supercritical CO2 foam at high salinity, temperature, and pressure conditions. The microfluidic analogue was designed to represent the pore sizes of the geologic reservoir rock and to operate at 100 °C and 13.8 MPa. Values of the pressure drop across the microfluidic analogue during flow of the CO2 foam through its pore network was used to evaluate the strength of the generated foam and utilized only milliliters of liquid. The transparent microfluidic pore network allows in-situ quantitative visualization of CO2 foam to calculate its half-life under static conditions while observing if there is any damage to the pore network due to precipitation and blockage. The microfluidic mobility reduction results agree with those of foam loop rheometer measurements, however, the microfluidic approach provided more accurate foam stability data to differentiate the foaming agent as compared with conventional balk testing. The results obtained here supports the utility of microfluidic systems for rapid screening of chemicals for carbon sequestration or enhanced oil recovery operations.
format article
author Ayrat Gizzatov
Scott Pierobon
Zuhair AlYousef
Guoqing Jian
Xingyu Fan
Ali Abedini
Amr I. Abdel-Fattah
author_facet Ayrat Gizzatov
Scott Pierobon
Zuhair AlYousef
Guoqing Jian
Xingyu Fan
Ali Abedini
Amr I. Abdel-Fattah
author_sort Ayrat Gizzatov
title High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
title_short High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
title_full High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
title_fullStr High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
title_full_unstemmed High-temperature high-pressure microfluidic system for rapid screening of supercritical CO2 foaming agents
title_sort high-temperature high-pressure microfluidic system for rapid screening of supercritical co2 foaming agents
publisher Nature Portfolio
publishDate 2021
url https://doaj.org/article/ac82a031ee024b50a1749351b0128ec9
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