A study of relative permeability parameters on rock cores using a two-phase flow test

To ensure sequestration safety, confirming the injectivity of the reservoir rock formation is of critical importance, requiring studies of the rock permeability to uncover the fluid migration scenarios within the porous reservoir rock. Two-phase (super-critical CO2-brine) flow behavior following the...

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Main Authors: Chung-Hui Chiao, Chi-Wen Yu, Shih-Chang Lei, Jyun-Yu Lin, Chia-Yu Lu
Format: Article
Language:English
Published: Chinese Geoscience Union 2017-01-01
Series:Terrestrial, Atmospheric and Oceanic Sciences
Online Access: http://tao.cgu.org.tw/media/k2/attachments/v283p177.pdf
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spelling doaj-a8f1e6c8a96c4ef3b58e24e907f5689a2020-11-24T21:25:45ZengChinese Geoscience UnionTerrestrial, Atmospheric and Oceanic Sciences1017-08392311-76802017-01-0128317710.3319/TAO.2013.08.01.01(GSC)A study of relative permeability parameters on rock cores using a two-phase flow testChung-Hui ChiaoChi-Wen YuShih-Chang LeiJyun-Yu LinChia-Yu LuTo ensure sequestration safety, confirming the injectivity of the reservoir rock formation is of critical importance, requiring studies of the rock permeability to uncover the fluid migration scenarios within the porous reservoir rock. Two-phase (super-critical CO2-brine) flow behavior following the post CO2 injection is believed to be a dominating factor; its flooding behavior within the porous rock media needs to be further clarified prior to confirming the feasibility of domestic CO2 geo-sequestration. This study aims to determine the relative permeability of rock cores obtained from field outcropping. A test facility was established to determine the relative permeability during drainage and imbibition processes using a core-flooding test characterized by displacement method. The test facility was assembled locally and is regarded as a pioneering attempt. By relevant data interpretation, the parameters of relative permeability for predicting the movement of super-critical CO2 after injection can be modeled. More reliable parameters can be obtained using history matching processes wherein time-elapsed data calibration is used in conjunction with a computer code, TOUGH2. The test results were iteratively calibrated using numerical simulation by conducting a history matching process. The K-S curves derived from best-fit parameters are believed to be the most relevant relative permeability for the reservoir rock. Through this preliminary study, a better understanding of some of the problems and limitations associated with the determination of the rock relative permeability using two-phase flow test is achieved, but more advanced research is required. http://tao.cgu.org.tw/media/k2/attachments/v283p177.pdf
collection DOAJ
language English
format Article
sources DOAJ
author Chung-Hui Chiao
Chi-Wen Yu
Shih-Chang Lei
Jyun-Yu Lin
Chia-Yu Lu
spellingShingle Chung-Hui Chiao
Chi-Wen Yu
Shih-Chang Lei
Jyun-Yu Lin
Chia-Yu Lu
A study of relative permeability parameters on rock cores using a two-phase flow test
Terrestrial, Atmospheric and Oceanic Sciences
author_facet Chung-Hui Chiao
Chi-Wen Yu
Shih-Chang Lei
Jyun-Yu Lin
Chia-Yu Lu
author_sort Chung-Hui Chiao
title A study of relative permeability parameters on rock cores using a two-phase flow test
title_short A study of relative permeability parameters on rock cores using a two-phase flow test
title_full A study of relative permeability parameters on rock cores using a two-phase flow test
title_fullStr A study of relative permeability parameters on rock cores using a two-phase flow test
title_full_unstemmed A study of relative permeability parameters on rock cores using a two-phase flow test
title_sort study of relative permeability parameters on rock cores using a two-phase flow test
publisher Chinese Geoscience Union
series Terrestrial, Atmospheric and Oceanic Sciences
issn 1017-0839
2311-7680
publishDate 2017-01-01
description To ensure sequestration safety, confirming the injectivity of the reservoir rock formation is of critical importance, requiring studies of the rock permeability to uncover the fluid migration scenarios within the porous reservoir rock. Two-phase (super-critical CO2-brine) flow behavior following the post CO2 injection is believed to be a dominating factor; its flooding behavior within the porous rock media needs to be further clarified prior to confirming the feasibility of domestic CO2 geo-sequestration. This study aims to determine the relative permeability of rock cores obtained from field outcropping. A test facility was established to determine the relative permeability during drainage and imbibition processes using a core-flooding test characterized by displacement method. The test facility was assembled locally and is regarded as a pioneering attempt. By relevant data interpretation, the parameters of relative permeability for predicting the movement of super-critical CO2 after injection can be modeled. More reliable parameters can be obtained using history matching processes wherein time-elapsed data calibration is used in conjunction with a computer code, TOUGH2. The test results were iteratively calibrated using numerical simulation by conducting a history matching process. The K-S curves derived from best-fit parameters are believed to be the most relevant relative permeability for the reservoir rock. Through this preliminary study, a better understanding of some of the problems and limitations associated with the determination of the rock relative permeability using two-phase flow test is achieved, but more advanced research is required.
url http://tao.cgu.org.tw/media/k2/attachments/v283p177.pdf
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