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Title: Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO 2 storage in saline aquifers

Abstract

Complex fluid-rock interactions can occur during the injection of carbon dioxide (CO 2) into saline aquifers for sequestration, which may affect CO 2 injectivity and storage capacity. A comprehensive reactive transport model is established to analyze salt precipitation, CO 2-water-rock geochemical reactions, and their effects on reservoir physical properties and injectivity. In addition, sensitivity analyses are conducted to investigate the main factors that affect fluid-rock interactions and injectivity with relevance for site selection for CO 2 storage. Results show that the back flow of formation water not only affects the salt precipitation but also affects the CO 2-water-rock geochemical reactions, resulting in salt and calcite precipitations mainly occurring in the dry-out zone. However, most of the mineral dissolution/precipitation caused by CO 2-water-rock reaction occurs in the two-phase and aqueous-phase zones, and their effect on reservoir porosity and permeability are small. A considerable amount of sodium chloride precipitates in the dry-out zone as brine is drawn by capillary action into this zone, with significant consequences for porosity, permeability and injectivity. The injection rate, salinity, capillary pressure–saturation relationships, and reservoir permeability strongly affect the distribution of salt precipitation. Finally, moderate injection rates, salinities, capillary pressures, and permeabilities all lead to favorable COmore » 2 injectivity.« less

Authors:
 [1];  [1];  [2];  [3];  [1];  [1]
  1. China Univ. of Petroleum, Qingdao (China). School of Petroleum Engineering
  2. Massachusetts Inst. of Technology (MIT), Cambridge, MA (United States). Dept. of Mechanical Engineering
  3. Los Alamos National Lab. (LANL), Los Alamos, NM (United States)
Publication Date:
Research Org.:
Los Alamos National Lab. (LANL), Los Alamos, NM (United States); China Univ. of Petroleum, Qingdao (China)
Sponsoring Org.:
USDOE; National Natural Science Foundation of China (NNSFC); Fundamental Research Funds for the Central Universities (China); China Univ. of Petroleum (China); Changjiang Scholars and Innovative Research (China); National Oil and Gas Major Projects (China)
OSTI Identifier:
1479993
Report Number(s):
LA-UR-18-23944
Journal ID: ISSN 0360-5442
Grant/Contract Number:  
AC52-06NA25396; 51674282; 17CX06006; 18CX05009A; YCX2017022; IRT 1294; 1086/14R58; 2016ZX05056004-003
Resource Type:
Journal Article: Accepted Manuscript
Journal Name:
Energy (Oxford)
Additional Journal Information:
Journal Volume: 155; Journal ID: ISSN 0360-5442
Publisher:
Elsevier
Country of Publication:
United States
Language:
English
Subject:
54 ENVIRONMENTAL SCIENCES; geologic CO2 storage; saline aquifers; salt precipitation; geochemical reactions; CO2 injectivity

Citation Formats

Cui, Guodong, Wang, Yi, Rui, Zhenhua, Chen, Bailian, Ren, Shaoran, and Zhang, Liang. Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers. United States: N. p., 2018. Web. doi:10.1016/j.energy.2018.05.024.
Cui, Guodong, Wang, Yi, Rui, Zhenhua, Chen, Bailian, Ren, Shaoran, & Zhang, Liang. Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers. United States. doi:10.1016/j.energy.2018.05.024.
Cui, Guodong, Wang, Yi, Rui, Zhenhua, Chen, Bailian, Ren, Shaoran, and Zhang, Liang. Sat . "Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers". United States. doi:10.1016/j.energy.2018.05.024. https://www.osti.gov/servlets/purl/1479993.
@article{osti_1479993,
title = {Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers},
author = {Cui, Guodong and Wang, Yi and Rui, Zhenhua and Chen, Bailian and Ren, Shaoran and Zhang, Liang},
abstractNote = {Complex fluid-rock interactions can occur during the injection of carbon dioxide (CO2) into saline aquifers for sequestration, which may affect CO2 injectivity and storage capacity. A comprehensive reactive transport model is established to analyze salt precipitation, CO2-water-rock geochemical reactions, and their effects on reservoir physical properties and injectivity. In addition, sensitivity analyses are conducted to investigate the main factors that affect fluid-rock interactions and injectivity with relevance for site selection for CO2 storage. Results show that the back flow of formation water not only affects the salt precipitation but also affects the CO2-water-rock geochemical reactions, resulting in salt and calcite precipitations mainly occurring in the dry-out zone. However, most of the mineral dissolution/precipitation caused by CO2-water-rock reaction occurs in the two-phase and aqueous-phase zones, and their effect on reservoir porosity and permeability are small. A considerable amount of sodium chloride precipitates in the dry-out zone as brine is drawn by capillary action into this zone, with significant consequences for porosity, permeability and injectivity. The injection rate, salinity, capillary pressure–saturation relationships, and reservoir permeability strongly affect the distribution of salt precipitation. Finally, moderate injection rates, salinities, capillary pressures, and permeabilities all lead to favorable CO2 injectivity.},
doi = {10.1016/j.energy.2018.05.024},
journal = {Energy (Oxford)},
issn = {0360-5442},
number = ,
volume = 155,
place = {United States},
year = {2018},
month = {5}
}

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