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Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery

Minglu Wu, Mingcai Ding, Jun Yao, Chenfeng Li Orcid Logo, Xuan Li, Jiamin Zhu

Journal of Petroleum Science and Engineering

Swansea University Author: Chenfeng Li Orcid Logo

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DOI (Published version): 10.1016/j.petrol.2019.03.077

Abstract

Geologic storage of CO2 in shale formation not only enhances natural gas recovery, but also sequestrates CO2 effectively. According to this technology, a multi-continuum quadruple porosity binary component gas model is developed to investigate carbon dioxide storage capacity and CO2 enhanced shale g...

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Published in: Journal of Petroleum Science and Engineering
ISSN: 0920-4105
Published: 2019
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URI: https://cronfa.swan.ac.uk/Record/cronfa49883
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first_indexed 2019-04-04T16:40:51Z
last_indexed 2019-07-17T15:33:44Z
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spelling 2019-07-17T09:45:56.0971992 v2 49883 2019-04-04 Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery 82fe170d5ae2c840e538a36209e5a3ac 0000-0003-0441-211X Chenfeng Li Chenfeng Li true false 2019-04-04 CIVL Geologic storage of CO2 in shale formation not only enhances natural gas recovery, but also sequestrates CO2 effectively. According to this technology, a multi-continuum quadruple porosity binary component gas model is developed to investigate carbon dioxide storage capacity and CO2 enhanced shale gas recovery, which is based on multiple flow mechanisms, including dissolution, adsorption/desorption, viscous flow, diffusion, slip flow and stress sensitivity of hydraulic fractures. This fully coupled model is divided into quadruple media, including organic matters, organic pore system, matrix system and natural fracture system. The matrix-fracture transfer flow is simulated by modified multiple interacting continua (MINC) method. Embedded discreate fracture model (EDFM) is introduced to describe the gas flow in hydraulic fractures and the transfer flow between hydraulic fractures and natural fractures. Finite difference method (FDM) and quasi-Newton iterative method are applied to solve this model. The reliability and practicability of this model is validated by matching the production history of a fractured horizontal well in shale gas reservoir. The effects of relevant parameters on production curves are analyzed, including adsorption parameters, dissolution parameters, well production pressure, injection pressure, volumetric fraction of kerogen and injection opportunity. The result shows that the model in this work is reliable and practicable, and the model presented here can be used to investigate the injectivity of CO2 and CO2 enhanced shale gas recovery. Journal Article Journal of Petroleum Science and Engineering 0920-4105 CO2 storage, Enhanced shale gas recovery, Multiple flow mechanisms, Quadruple porosity model, Fractured horizontal well 31 12 2019 2019-12-31 10.1016/j.petrol.2019.03.077 COLLEGE NANME Civil Engineering COLLEGE CODE CIVL Swansea University 2019-07-17T09:45:56.0971992 2019-04-04T09:10:10.6093632 Faculty of Science and Engineering School of Aerospace, Civil, Electrical, General and Mechanical Engineering - Civil Engineering Minglu Wu 1 Mingcai Ding 2 Jun Yao 3 Chenfeng Li 0000-0003-0441-211X 4 Xuan Li 5 Jiamin Zhu 6 0049883-04042019091404.pdf wu2019v2.pdf 2019-04-04T09:14:04.3700000 Output 10346064 application/pdf Accepted Manuscript true 2020-04-01T00:00:00.0000000 true eng
title Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
spellingShingle Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
Chenfeng Li
title_short Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
title_full Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
title_fullStr Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
title_full_unstemmed Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
title_sort Development of a multi-continuum quadruple porosity model to estimate CO2 storage capacity and CO2 enhanced shale gas recovery
author_id_str_mv 82fe170d5ae2c840e538a36209e5a3ac
author_id_fullname_str_mv 82fe170d5ae2c840e538a36209e5a3ac_***_Chenfeng Li
author Chenfeng Li
author2 Minglu Wu
Mingcai Ding
Jun Yao
Chenfeng Li
Xuan Li
Jiamin Zhu
format Journal article
container_title Journal of Petroleum Science and Engineering
publishDate 2019
institution Swansea University
issn 0920-4105
doi_str_mv 10.1016/j.petrol.2019.03.077
college_str Faculty of Science and Engineering
hierarchytype
hierarchy_top_id facultyofscienceandengineering
hierarchy_top_title Faculty of Science and Engineering
hierarchy_parent_id facultyofscienceandengineering
hierarchy_parent_title Faculty of Science and Engineering
department_str School of Aerospace, Civil, Electrical, General and Mechanical Engineering - Civil Engineering{{{_:::_}}}Faculty of Science and Engineering{{{_:::_}}}School of Aerospace, Civil, Electrical, General and Mechanical Engineering - Civil Engineering
document_store_str 1
active_str 0
description Geologic storage of CO2 in shale formation not only enhances natural gas recovery, but also sequestrates CO2 effectively. According to this technology, a multi-continuum quadruple porosity binary component gas model is developed to investigate carbon dioxide storage capacity and CO2 enhanced shale gas recovery, which is based on multiple flow mechanisms, including dissolution, adsorption/desorption, viscous flow, diffusion, slip flow and stress sensitivity of hydraulic fractures. This fully coupled model is divided into quadruple media, including organic matters, organic pore system, matrix system and natural fracture system. The matrix-fracture transfer flow is simulated by modified multiple interacting continua (MINC) method. Embedded discreate fracture model (EDFM) is introduced to describe the gas flow in hydraulic fractures and the transfer flow between hydraulic fractures and natural fractures. Finite difference method (FDM) and quasi-Newton iterative method are applied to solve this model. The reliability and practicability of this model is validated by matching the production history of a fractured horizontal well in shale gas reservoir. The effects of relevant parameters on production curves are analyzed, including adsorption parameters, dissolution parameters, well production pressure, injection pressure, volumetric fraction of kerogen and injection opportunity. The result shows that the model in this work is reliable and practicable, and the model presented here can be used to investigate the injectivity of CO2 and CO2 enhanced shale gas recovery.
published_date 2019-12-31T04:01:08Z
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score 11.016235

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