Xiaolong Sun , Keyu Liu , Senyou An , Helge Hellevang , Yingchang Cao , Juan Alcalde , Anna Travé , Guanghui Yuan , Chenguang Deng , Enrique Gomez-Rivas
{"title":"二氧化碳地质封存过程中盐沉淀实验研究综述","authors":"Xiaolong Sun , Keyu Liu , Senyou An , Helge Hellevang , Yingchang Cao , Juan Alcalde , Anna Travé , Guanghui Yuan , Chenguang Deng , Enrique Gomez-Rivas","doi":"10.1016/j.geoen.2024.213451","DOIUrl":null,"url":null,"abstract":"<div><div>Salt precipitation due to formation drying is a critical secondary alteration process that significantly impairs reservoir injectivity in the context of CO<sub>2</sub> geological storage. In this work, salt precipitation during CO<sub>2</sub> injection is reviewed primarily through various experimental studies. First, the experimental systems for salt precipitation studies, namely core-flooding, microfluidic-chip, static batch, and surface drying experimental systems, have been described to present their respective experimental procedures and merits, as well as corresponding applications. Subsequently, following the general description of the formation mechanisms of salt precipitation, the macro and micro salt distribution patterns at the reservoir and pore scales have been summarized. Finally, and most importantly, this study provides a comprehensive analysis of the controlling factors for salt precipitation, categorized into four different groups, according to the brine, rock, gas, and injection scenario aspects. Among all these factors, brine salinity, CO<sub>2</sub> injection rate and initial reservoir properties are considered the most critical in determining the amount and distribution of precipitated salts and the degree of injectivity impairment. The effects of multi-scale reservoir heterogeneity and rock wettability on salt precipitation are attracting growing consideration, while the brine and gas composition studies are receiving less attention due to their relatively minor influences on reservoir alteration. Due to the limited specimen sizes, the ex-situ brine replenishment may be underestimated in core-flooding and microfluidic-chip experiments. This may result in a potentially significant underestimation of the volume of local salts and the potentially inaccurate prediction of the drying process during CO<sub>2</sub> injection in many such experiments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213451"},"PeriodicalIF":0.0000,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":"0","resultStr":"{\"title\":\"A review of experimental investigations on salt precipitation during CO2 geological storage\",\"authors\":\"Xiaolong Sun , Keyu Liu , Senyou An , Helge Hellevang , Yingchang Cao , Juan Alcalde , Anna Travé , Guanghui Yuan , Chenguang Deng , Enrique Gomez-Rivas\",\"doi\":\"10.1016/j.geoen.2024.213451\",\"DOIUrl\":null,\"url\":null,\"abstract\":\"<div><div>Salt precipitation due to formation drying is a critical secondary alteration process that significantly impairs reservoir injectivity in the context of CO<sub>2</sub> geological storage. In this work, salt precipitation during CO<sub>2</sub> injection is reviewed primarily through various experimental studies. First, the experimental systems for salt precipitation studies, namely core-flooding, microfluidic-chip, static batch, and surface drying experimental systems, have been described to present their respective experimental procedures and merits, as well as corresponding applications. Subsequently, following the general description of the formation mechanisms of salt precipitation, the macro and micro salt distribution patterns at the reservoir and pore scales have been summarized. Finally, and most importantly, this study provides a comprehensive analysis of the controlling factors for salt precipitation, categorized into four different groups, according to the brine, rock, gas, and injection scenario aspects. Among all these factors, brine salinity, CO<sub>2</sub> injection rate and initial reservoir properties are considered the most critical in determining the amount and distribution of precipitated salts and the degree of injectivity impairment. The effects of multi-scale reservoir heterogeneity and rock wettability on salt precipitation are attracting growing consideration, while the brine and gas composition studies are receiving less attention due to their relatively minor influences on reservoir alteration. Due to the limited specimen sizes, the ex-situ brine replenishment may be underestimated in core-flooding and microfluidic-chip experiments. This may result in a potentially significant underestimation of the volume of local salts and the potentially inaccurate prediction of the drying process during CO<sub>2</sub> injection in many such experiments.</div></div>\",\"PeriodicalId\":100578,\"journal\":{\"name\":\"Geoenergy Science and Engineering\",\"volume\":\"244 \",\"pages\":\"Article 213451\"},\"PeriodicalIF\":0.0000,\"publicationDate\":\"2024-10-28\",\"publicationTypes\":\"Journal Article\",\"fieldsOfStudy\":null,\"isOpenAccess\":false,\"openAccessPdf\":\"\",\"citationCount\":\"0\",\"resultStr\":null,\"platform\":\"Semanticscholar\",\"paperid\":null,\"PeriodicalName\":\"Geoenergy Science and Engineering\",\"FirstCategoryId\":\"1085\",\"ListUrlMain\":\"https://www.sciencedirect.com/science/article/pii/S2949891024008212\",\"RegionNum\":0,\"RegionCategory\":null,\"ArticlePicture\":[],\"TitleCN\":null,\"AbstractTextCN\":null,\"PMCID\":null,\"EPubDate\":\"\",\"PubModel\":\"\",\"JCR\":\"0\",\"JCRName\":\"ENERGY & FUELS\",\"Score\":null,\"Total\":0}","platform":"Semanticscholar","paperid":null,"PeriodicalName":"Geoenergy Science and Engineering","FirstCategoryId":"1085","ListUrlMain":"https://www.sciencedirect.com/science/article/pii/S2949891024008212","RegionNum":0,"RegionCategory":null,"ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":null,"EPubDate":"","PubModel":"","JCR":"0","JCRName":"ENERGY & FUELS","Score":null,"Total":0}
A review of experimental investigations on salt precipitation during CO2 geological storage
Salt precipitation due to formation drying is a critical secondary alteration process that significantly impairs reservoir injectivity in the context of CO2 geological storage. In this work, salt precipitation during CO2 injection is reviewed primarily through various experimental studies. First, the experimental systems for salt precipitation studies, namely core-flooding, microfluidic-chip, static batch, and surface drying experimental systems, have been described to present their respective experimental procedures and merits, as well as corresponding applications. Subsequently, following the general description of the formation mechanisms of salt precipitation, the macro and micro salt distribution patterns at the reservoir and pore scales have been summarized. Finally, and most importantly, this study provides a comprehensive analysis of the controlling factors for salt precipitation, categorized into four different groups, according to the brine, rock, gas, and injection scenario aspects. Among all these factors, brine salinity, CO2 injection rate and initial reservoir properties are considered the most critical in determining the amount and distribution of precipitated salts and the degree of injectivity impairment. The effects of multi-scale reservoir heterogeneity and rock wettability on salt precipitation are attracting growing consideration, while the brine and gas composition studies are receiving less attention due to their relatively minor influences on reservoir alteration. Due to the limited specimen sizes, the ex-situ brine replenishment may be underestimated in core-flooding and microfluidic-chip experiments. This may result in a potentially significant underestimation of the volume of local salts and the potentially inaccurate prediction of the drying process during CO2 injection in many such experiments.