Foam stability characterization and performance in the presence of surfactant for gas well deliquification

In gas well deliquification, surfactant injection minimises liquid loading in mature gas wells, promoting a stable gas output. It is critical to evaluate the surfactant performance and produced foam stability. To this end, laboratory experiments are conducted to determine the surfactant’s performanc...

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Main Author:	Sabali, Mohd. Alfie
Format:	Thesis
Language:	English
Published:	2022
Subjects:	Q Science (General) TP Chemical technology
Online Access:	http://eprints.utm.my/id/eprint/102507/1/MohdAlfieSabaliMSChE2022.pdf
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spelling	my-utm-ep.1025072023-09-03T06:30:57Z Foam stability characterization and performance in the presence of surfactant for gas well deliquification 2022 Sabali, Mohd. Alfie Q Science (General) TP Chemical technology In gas well deliquification, surfactant injection minimises liquid loading in mature gas wells, promoting a stable gas output. It is critical to evaluate the surfactant performance and produced foam stability. To this end, laboratory experiments are conducted to determine the surfactant’s performance. This study focused on the characterisation study of foam stability and quantify the quantify the foam unloading capacity at different field formation water salinity, temperature, and field hydrocarbon ratios. The foam stability at different field hydrocarbon ratios reduces as the hydrocarbon ratio increases. At 15% and 50% hydrocarbon ratio, the full time collapse is at 203 seconds and 100 seconds. More stable foam is observed as the water salinity increases. It is recorded at 9.85 ppt, showing the full time collapse at 420 seconds, while at 6.31ppt, the full time collapse at 329 seconds. The increase in testing temperature to 90°C shows the lowest foam stability with 140 seconds of full collapse. At 4°C shows 450 seconds of full collapse. In conclusion, the more stable foam formed at higher water salinity. Adding hydrocarbon in the water ratio acts like defoamer agent to reduce the foam stability. At high temperature, foam collapse the fastest as compared to other parameters, with 70 seconds of full collapse at 329 seconds. Based on the unloading performance, at low hydrocatbon ratio, high salinity, and low temperature able have the excellent unloading performance as more stable foam able to entraine the fluids over the testing column. 2022 Thesis http://eprints.utm.my/id/eprint/102507/ http://eprints.utm.my/id/eprint/102507/1/MohdAlfieSabaliMSChE2022.pdf application/pdf en public http://dms.library.utm.my:8080/vital/access/manager/Repository/vital:151996 masters Universiti Teknologi Malaysia, Faculty of Engineering - School of Chemical & Energy Engineering Faculty of Engineering - School of Chemical & Energy Engineering
institution	Universiti Teknologi Malaysia
collection	UTM Institutional Repository
language	English
topic	Q Science (General) TP Chemical technology
spellingShingle	Q Science (General) TP Chemical technology Sabali, Mohd. Alfie Foam stability characterization and performance in the presence of surfactant for gas well deliquification
description	In gas well deliquification, surfactant injection minimises liquid loading in mature gas wells, promoting a stable gas output. It is critical to evaluate the surfactant performance and produced foam stability. To this end, laboratory experiments are conducted to determine the surfactant’s performance. This study focused on the characterisation study of foam stability and quantify the quantify the foam unloading capacity at different field formation water salinity, temperature, and field hydrocarbon ratios. The foam stability at different field hydrocarbon ratios reduces as the hydrocarbon ratio increases. At 15% and 50% hydrocarbon ratio, the full time collapse is at 203 seconds and 100 seconds. More stable foam is observed as the water salinity increases. It is recorded at 9.85 ppt, showing the full time collapse at 420 seconds, while at 6.31ppt, the full time collapse at 329 seconds. The increase in testing temperature to 90°C shows the lowest foam stability with 140 seconds of full collapse. At 4°C shows 450 seconds of full collapse. In conclusion, the more stable foam formed at higher water salinity. Adding hydrocarbon in the water ratio acts like defoamer agent to reduce the foam stability. At high temperature, foam collapse the fastest as compared to other parameters, with 70 seconds of full collapse at 329 seconds. Based on the unloading performance, at low hydrocatbon ratio, high salinity, and low temperature able have the excellent unloading performance as more stable foam able to entraine the fluids over the testing column.
format	Thesis
qualification_level	Master's degree
author	Sabali, Mohd. Alfie
author_facet	Sabali, Mohd. Alfie
author_sort	Sabali, Mohd. Alfie
title	Foam stability characterization and performance in the presence of surfactant for gas well deliquification
title_short	Foam stability characterization and performance in the presence of surfactant for gas well deliquification
title_full	Foam stability characterization and performance in the presence of surfactant for gas well deliquification
title_fullStr	Foam stability characterization and performance in the presence of surfactant for gas well deliquification
title_full_unstemmed	Foam stability characterization and performance in the presence of surfactant for gas well deliquification
title_sort	foam stability characterization and performance in the presence of surfactant for gas well deliquification
granting_institution	Universiti Teknologi Malaysia, Faculty of Engineering - School of Chemical & Energy Engineering
granting_department	Faculty of Engineering - School of Chemical & Energy Engineering
publishDate	2022
url	http://eprints.utm.my/id/eprint/102507/1/MohdAlfieSabaliMSChE2022.pdf
_version_	1776100939492491264

Foam stability characterization and performance in the presence of surfactant for gas well deliquification

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