Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802982
H. Yonebayashi, Katsumo Takabayashi, Y. Miyagawa, Takumi Watanabe
ery and prevention of early breakthrough. From CCUS point of views, the delay of gas breakthrough has a significant advantage in underground storage of industry-originated CO2. The reviews highlighted that various types of nano-additives have been investigated to develop further advanced foam technology. Key points to be focused on are how achieving more robust foam stability. Even a conventional CO2 foam generated with surfactant agents might be deteriorated in short period, those additives can extend foam half-life time. As additives, the recent researches have paid attention to nano-particles, polymer, viscoelastic surfactant, etc. The investigation measured half-life, viscosity, and differential pressure in core flood as key performance indicators. In addition, “high temperature (HT)” and “high salinity (HS)” are keywords in their researches. Namely, screening criteria of experimental conditions are aiming to more harsh conditions. However, the reviewed reports have not covered up to our target conditions in typical Middle East region. Thus, we have been concentrating to develop nano-additive enhancing CO2 foam technology in HTHS.
{"title":"Foam Stability Enhanced Technology For Mobility Control Of CO2 EOR","authors":"H. Yonebayashi, Katsumo Takabayashi, Y. Miyagawa, Takumi Watanabe","doi":"10.3997/2214-4609.201802982","DOIUrl":"https://doi.org/10.3997/2214-4609.201802982","url":null,"abstract":"ery and prevention of early breakthrough. From CCUS point of views, the delay of gas breakthrough has a significant advantage in underground storage of industry-originated CO2. The reviews highlighted that various types of nano-additives have been investigated to develop further advanced foam technology. Key points to be focused on are how achieving more robust foam stability. Even a conventional CO2 foam generated with surfactant agents might be deteriorated in short period, those additives can extend foam half-life time. As additives, the recent researches have paid attention to nano-particles, polymer, viscoelastic surfactant, etc. The investigation measured half-life, viscosity, and differential pressure in core flood as key performance indicators. In addition, “high temperature (HT)” and “high salinity (HS)” are keywords in their researches. Namely, screening criteria of experimental conditions are aiming to more harsh conditions. However, the reviewed reports have not covered up to our target conditions in typical Middle East region. Thus, we have been concentrating to develop nano-additive enhancing CO2 foam technology in HTHS.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132600571","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802959
E. Skurtveit, Anja Sundal, M. Soldal, G. Sauvin, T. Bjørnarå
Seal integrity during injection operations is a topic of great interest both within the CO2 storage community, for wastewater injection and traditional reservoir pressure support. The Little Grand Wash fault, central Utah, USA, provides an excellent location for studying seal bypass systems in a siliciclastic sedimentary sequence. Two mode I siltstone fractures with significantly different apertures and varying degree of sample bleaching due to alterations from reactive fluid flow are studied together with two intact rock reference samples from the same depth level in the core. The experimental work addresses fracture flow and stiffness relationships. Observed differences in fracture closure trends may be explained as a rapid decrease in stiffness and flow for altered samples due to the fluid rock interaction process altering the fracture surface contact area for this sample.
{"title":"CO2 Flow, Alteration And Geomechanical Response In Confining Units – An Experimental Approach","authors":"E. Skurtveit, Anja Sundal, M. Soldal, G. Sauvin, T. Bjørnarå","doi":"10.3997/2214-4609.201802959","DOIUrl":"https://doi.org/10.3997/2214-4609.201802959","url":null,"abstract":"Seal integrity during injection operations is a topic of great interest both within the CO2 storage community, for wastewater injection and traditional reservoir pressure support. The Little Grand Wash fault, central Utah, USA, provides an excellent location for studying seal bypass systems in a siliciclastic sedimentary sequence. Two mode I siltstone fractures with significantly different apertures and varying degree of sample bleaching due to alterations from reactive fluid flow are studied together with two intact rock reference samples from the same depth level in the core. The experimental work addresses fracture flow and stiffness relationships. Observed differences in fracture closure trends may be explained as a rapid decrease in stiffness and flow for altered samples due to the fluid rock interaction process altering the fracture surface contact area for this sample.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"80 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134560640","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802963
K. Bisdom, M. Dean, J. Snippe, N. Kampman, A. Busch, S. Zihms, F. Doster, R. March, P. Bertier, H. Claes, R. Fink, B. Krooss, S. Hurst, A. Lidstone, P. V. Rossum
To verify and demonstrate successful long-term geological CO2 storage to regulatory bodies and the public, it is critical to improve our understanding of the potential for CO2 migration from storage reservoirs along natural pathways. Currently, there are significant gaps in our understanding of multi-phase fluid migration in faulted and fractured caprocks. Caprocks are typically fine-grained mudstones, carbonates or evaporites, with low matrix permeability and high geochemical reactivity. Potential leakage rates depend on pressure gradients, fluid densities, viscosities and saturations, and the flow properties of the fracture networks. Fracture permeability is highly sensitive to fluid pressure and stress regime, and physical and chemical interactions taking place in the fracture network, including mineral dissolution and precipitation, swelling or shrinkage of clay minerals and hydro-mechanically driven fracture propagation. These combined effects can result in an increase or decrease in fracture permeability and network connectivity over different temporal and spatial scales. The highly coupled nature of these processes makes experimental parameterization and predictive modelling highly challenging, especially at the large temporal and spatial scales relevant to CO2 storage. Although some fundamental laboratory and modelling studies are available in the literature, an integrated study, involving a complete life cycle risk assessment of CO2 leakage through fractured caprocks is lacking. Risk analysis is further complicated by the fact that a leak can only be detected and quantified when geophysical or chemical monitoring tools are able to distinguish relevant changes in gas saturation, pressures or compositions compared to baseline levels. The DETECT research program, cofunded by the European Union and national governments as part the ACT initiative, intends to determine realistic flow rates across fractured and faulted mudstone caprocks, and aims to identify existing monitoring tools capable of detecting such fluid migration. For this purpose, the monitoring performance of state-of-the-art technologies will be compared with flow rate predictions from coupled hydro-mechanical flow and reactive transport simulations at single fracture, fracture network and reservoir-scales, which in turn have incorporated insights from a comprehensive laboratory study of stress and reactivity dependent fracture permeability. This improved understanding of the potential flow rates will feed into an integrated life cycle risk assessment using the established bowtie method to provide an overall picture of the natural paths via which CO2 leaks could occur from subsurface storage reservoirs. The bowtie model will be expanded to include quantitative risk assessment, with the goal of calculating the probability/likelihood of leakage across the caprock and estimating the risk reduction provided by monitoring.
{"title":"Quantifying The Risk Of CO2 Leakage Along Fractures Using An Integrated Experimental, Multiscale Modelling And Monitoring Approach","authors":"K. Bisdom, M. Dean, J. Snippe, N. Kampman, A. Busch, S. Zihms, F. Doster, R. March, P. Bertier, H. Claes, R. Fink, B. Krooss, S. Hurst, A. Lidstone, P. V. Rossum","doi":"10.3997/2214-4609.201802963","DOIUrl":"https://doi.org/10.3997/2214-4609.201802963","url":null,"abstract":"To verify and demonstrate successful long-term geological CO2 storage to regulatory bodies and the public, it is critical to improve our understanding of the potential for CO2 migration from storage reservoirs along natural pathways. Currently, there are significant gaps in our understanding of multi-phase fluid migration in faulted and fractured caprocks. \u0000 \u0000Caprocks are typically fine-grained mudstones, carbonates or evaporites, with low matrix permeability and high geochemical reactivity. Potential leakage rates depend on pressure gradients, fluid densities, viscosities and saturations, and the flow properties of the fracture networks. Fracture permeability is highly sensitive to fluid pressure and stress regime, and physical and chemical interactions taking place in the fracture network, including mineral dissolution and precipitation, swelling or shrinkage of clay minerals and hydro-mechanically driven fracture propagation. These combined effects can result in an increase or decrease in fracture permeability and network connectivity over different temporal and spatial scales. The highly coupled nature of these processes makes experimental parameterization and predictive modelling highly challenging, especially at the large temporal and spatial scales relevant to CO2 storage. \u0000 \u0000Although some fundamental laboratory and modelling studies are available in the literature, an integrated study, involving a complete life cycle risk assessment of CO2 leakage through fractured caprocks is lacking. Risk analysis is further complicated by the fact that a leak can only be detected and quantified when geophysical or chemical monitoring tools are able to distinguish relevant changes in gas saturation, pressures or compositions compared to baseline levels. \u0000 \u0000The DETECT research program, cofunded by the European Union and national governments as part the ACT initiative, intends to determine realistic flow rates across fractured and faulted mudstone caprocks, and aims to identify existing monitoring tools capable of detecting such fluid migration. For this purpose, the monitoring performance of state-of-the-art technologies will be compared with flow rate predictions from coupled hydro-mechanical flow and reactive transport simulations at single fracture, fracture network and reservoir-scales, which in turn have incorporated insights from a comprehensive laboratory study of stress and reactivity dependent fracture permeability. \u0000 \u0000This improved understanding of the potential flow rates will feed into an integrated life cycle risk assessment using the established bowtie method to provide an overall picture of the natural paths via which CO2 leaks could occur from subsurface storage reservoirs. The bowtie model will be expanded to include quantitative risk assessment, with the goal of calculating the probability/likelihood of leakage across the caprock and estimating the risk reduction provided by monitoring.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114436682","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802980
M. Macquet, D. Lawton
We present the results of reservoir simulations and feasibility study of surface seismic monitoring applied to the CO2 sequestration at the CaMI Field Research Station (FRS). We first test the influence of injection parameters, as reservoir temperature, maximum bottom-hole pressure and of the ratio vertical permeability over horizontal permeability on the amount of CO2 you can inject and on the gas plume shape. We demonstrate that if the reservoir temperature has a very small influence on the injectivity, the maximum bottom-hole pressure and the ratio of permeabilities play a key role on the gas injection. The next step is fluid substitution, necessitated to estimate the variation in elastic parameters induced by the gas injection. We test different methods to compute the bulk modulus of the fluid (Reuss, Voigt, HRV and Brie) and compare their results. We finally use a 3D finite difference modeling to simulate the seismic response in the elastic models generated for the baseline, for 1 year of injection and for 5 years of injection.
{"title":"Reservoir Simulation And Feasibility Study For Seismic Monitoring At CaMI.FRS, Newell County, Alberta","authors":"M. Macquet, D. Lawton","doi":"10.3997/2214-4609.201802980","DOIUrl":"https://doi.org/10.3997/2214-4609.201802980","url":null,"abstract":"We present the results of reservoir simulations and feasibility study of surface seismic monitoring applied to the CO2 sequestration at the CaMI Field Research Station (FRS). We first test the influence of injection parameters, as reservoir temperature, maximum bottom-hole pressure and of the ratio vertical permeability over horizontal permeability on the amount of CO2 you can inject and on the gas plume shape. We demonstrate that if the reservoir temperature has a very small influence on the injectivity, the maximum bottom-hole pressure and the ratio of permeabilities play a key role on the gas injection. The next step is fluid substitution, necessitated to estimate the variation in elastic parameters induced by the gas injection. We test different methods to compute the bulk modulus of the fluid (Reuss, Voigt, HRV and Brie) and compare their results. We finally use a 3D finite difference modeling to simulate the seismic response in the elastic models generated for the baseline, for 1 year of injection and for 5 years of injection.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116827715","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802960
F. Bertrand, O. Buzzi, F. Collin
Sorption- and stress-induced coal permeability alteration may occur considering injection of carbon dioxide in coal seams for CCS. To take into account properly these phenomena, a microscale model was developed for the modelling of injection experiments carried out in laboratory. This work presents this model and first experimental results obtained from an injection test.
{"title":"Laboratory-Scale Study On The Swelling Behaviour Of Coal Due To CO2 Injection","authors":"F. Bertrand, O. Buzzi, F. Collin","doi":"10.3997/2214-4609.201802960","DOIUrl":"https://doi.org/10.3997/2214-4609.201802960","url":null,"abstract":"Sorption- and stress-induced coal permeability alteration may occur considering injection of carbon dioxide in coal seams for CCS. To take into account properly these phenomena, a microscale model was developed for the modelling of injection experiments carried out in laboratory. This work presents this model and first experimental results obtained from an injection test.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"291 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124251077","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802974
M. Onoja, S. Shariatipour
{"title":"Predictive Modelling Of CO2 Storage In Aquifers: Integrating The Effects Of Boundary Conditions And Saturation Functions","authors":"M. Onoja, S. Shariatipour","doi":"10.3997/2214-4609.201802974","DOIUrl":"https://doi.org/10.3997/2214-4609.201802974","url":null,"abstract":"","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133276631","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802958
A. Eftekhari, R. Farajzadeh, J. Bruining
We study the enhanced mass transfer of CO2 in water for a CO2 saturated layer on top of a water saturated porous medium, experimentally and theoretically. A relatively large experimental set-up with a length of 0.5 m and a diameter of 0.15 m is used in pressure decay experiments to minimize the error of pressure measurement due to temperature fluctuations and small leakages. The experimental results were compared to the theoretical result in terms of onset time of natural convection and rate of mass transfer of CO2 in the convection dominated process. In addition, a non-isothermal multicomponent flow model in porous media, is solved numerically to study the effect of the heat of dissolution of CO2 in water on the rate of mass transfer of CO2. The effect of the capillary transition zone on the rate of mass transfer of CO2 is also studied theoretically. The simulation results including the effect of the capillary transition zone show a better agreement with experimental results compared to the simulation result without considering a capillary transition zone. The simulation results also show that the effect of heat of dissolution on the rate of mass transfer is negligible
{"title":"Experimental And Theoretical Investigation Of Natural Convection In CCS: Onset Time, Mass-Transfer Rate, Capillary Transition Zone, And Heat Of Dissolution","authors":"A. Eftekhari, R. Farajzadeh, J. Bruining","doi":"10.3997/2214-4609.201802958","DOIUrl":"https://doi.org/10.3997/2214-4609.201802958","url":null,"abstract":"We study the enhanced mass transfer of CO2 in water for a CO2 saturated layer on top of a water saturated porous medium, experimentally and theoretically. A relatively large experimental set-up with a length of 0.5 m and a diameter of 0.15 m is used in pressure decay experiments to minimize the error of pressure measurement due to temperature fluctuations and small leakages. The experimental results were compared to the theoretical result in terms of onset time of natural convection and rate of mass transfer of CO2 in the convection dominated process. In addition, a non-isothermal multicomponent flow model in porous media, is solved numerically to study the effect of the heat of dissolution of CO2 in water on the rate of mass transfer of CO2. The effect of the capillary transition zone on the rate of mass transfer of CO2 is also studied theoretically. The simulation results including the effect of the capillary transition zone show a better agreement with experimental results compared to the simulation result without considering a capillary transition zone. The simulation results also show that the effect of heat of dissolution on the rate of mass transfer is negligible","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132085141","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802967
N. Kampman
Reactions between CO2 and CO2-charged brines and mudrocks may inhibit CO2 leakage via the precipitation of carbonate minerals or via swelling of clay minerals or enhance leakage via the corrosion of carbonate cements. The timescales for the potential self-sealing behaviour, and/or the magnitudes of the permeability enhancements are uncertain. Laboratory experiments can provide constraints on the intrinsic fracture permeabilities, but the quantification of permeability changes following reaction or under conditions of multiphase flow is challenging in the laboratory. Reactive transport modelling (RTM) provides a numerical laboratory in which the intrinsic permeabilities of rough fractures, and the coupling of the flow and reaction processes, can be investigated. A modified local cubic law (MLCL) is used to model rough fracture permeability, and coupling of permeability-porosity changes to mineralization and clay swelling. The results show that the intrinsic permeability of self-affine fractures is primarily dependent on the roughness and degree of correlation between the two fracture surfaces, and that with increasing roughness the simulated fracture permeabilities are systematically lower than permeabilities predicted from the fracture aperture mean using a cubic law. The dependence of fracture permeabilities on reactions is investigated, and the relationship between mineralization behaviour and fluid residence time is discussed.
{"title":"Opening Versus Self-Sealing Behaviour Of Single Fractures In Mudstone Caprocks During CO2 Migration","authors":"N. Kampman","doi":"10.3997/2214-4609.201802967","DOIUrl":"https://doi.org/10.3997/2214-4609.201802967","url":null,"abstract":"Reactions between CO2 and CO2-charged brines and mudrocks may inhibit CO2 leakage via the precipitation of carbonate minerals or via swelling of clay minerals or enhance leakage via the corrosion of carbonate cements. The timescales for the potential self-sealing behaviour, and/or the magnitudes of the permeability enhancements are uncertain. Laboratory experiments can provide constraints on the intrinsic fracture permeabilities, but the quantification of permeability changes following reaction or under conditions of multiphase flow is challenging in the laboratory. Reactive transport modelling (RTM) provides a numerical laboratory in which the intrinsic permeabilities of rough fractures, and the coupling of the flow and reaction processes, can be investigated. A modified local cubic law (MLCL) is used to model rough fracture permeability, and coupling of permeability-porosity changes to mineralization and clay swelling. The results show that the intrinsic permeability of self-affine fractures is primarily dependent on the roughness and degree of correlation between the two fracture surfaces, and that with increasing roughness the simulated fracture permeabilities are systematically lower than permeabilities predicted from the fracture aperture mean using a cubic law. The dependence of fracture permeabilities on reactions is investigated, and the relationship between mineralization behaviour and fluid residence time is discussed.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132697933","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2018-11-21DOI: 10.3997/2214-4609.201802966
M. Abbaszadeh, S. Shariatipour
Different injection methods have been already proposed by different researchers to improve the solubility of CO2 in the formation brine. In this study an injection technique is presented to cool down (liquefy) the supercritical CO2 in the wellbore by the use of a downhole cooler equipment. CO2 with a higher temperature enters the cooling equipment and exits the equipment with a lower temperature at the down-stream in a same injection pressure. The colder (liquid) CO2 has a higher solubility in brine, higher density and viscosity which increases the security of CO2 storage. With this method the supercritical CO2 is cooled down to a liquid phase to increase the solubility at the wellbore and thus it eliminated the risk of phase change or pressure and rate fluctuation in liquid CO2 injection from the surface. To simulate this technique two cases have been considered by changing the relative permeability curves. The results show that using the combination of CO2STORE and THERMAL options shows a higher dissolution compared with only inserting the relative permeability curves corresponding the injection condition.
{"title":"Investigating The Impact Of Relative Permeability Curves On Cold CO2 Injection","authors":"M. Abbaszadeh, S. Shariatipour","doi":"10.3997/2214-4609.201802966","DOIUrl":"https://doi.org/10.3997/2214-4609.201802966","url":null,"abstract":"Different injection methods have been already proposed by different researchers to improve the solubility of CO2 in the formation brine. In this study an injection technique is presented to cool down (liquefy) the supercritical CO2 in the wellbore by the use of a downhole cooler equipment. CO2 with a higher temperature enters the cooling equipment and exits the equipment with a lower temperature at the down-stream in a same injection pressure. The colder (liquid) CO2 has a higher solubility in brine, higher density and viscosity which increases the security of CO2 storage. With this method the supercritical CO2 is cooled down to a liquid phase to increase the solubility at the wellbore and thus it eliminated the risk of phase change or pressure and rate fluctuation in liquid CO2 injection from the surface. To simulate this technique two cases have been considered by changing the relative permeability curves. The results show that using the combination of CO2STORE and THERMAL options shows a higher dissolution compared with only inserting the relative permeability curves corresponding the injection condition.","PeriodicalId":254996,"journal":{"name":"Fifth CO2 Geological Storage Workshop","volume":"124 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116317323","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：