Pub Date : 2023-12-01DOI: 10.46690/capi.2024.02.01
Fatemah Alhammad, Mujahid Ali, Nurudeen Yekeen, Muhammad Ali, Hussein Hoteit, S. Iglauer, A. Keshavarz
{"title":"The effect of methylene blue and organic acids on the wettability of sandstone formation: Implications for enhanced oil recovery","authors":"Fatemah Alhammad, Mujahid Ali, Nurudeen Yekeen, Muhammad Ali, Hussein Hoteit, S. Iglauer, A. Keshavarz","doi":"10.46690/capi.2024.02.01","DOIUrl":"https://doi.org/10.46690/capi.2024.02.01","url":null,"abstract":"","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"145 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139021908","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 : 2023-11-29DOI: 10.46690/capi.2024.02.02
Qinzhi Li, Yiwen Wang, B. Wei, Lele Wang, Jun Lu, Jinyu Tang
: Despite the promising results obtained from the utilization of interfacial-active additives in enhancing imbibition-based oil recovery from tight reservoirs, the predominant mechanisms governing this process remain inadequately understood. In this work, a meticulously designed workflow is implemented to conduct experiments and modeling focusing on imbibition tests performed on tight sandstone cores while utilizing surfactant and microemulsion. Our primary objective is to investigate the response of oil recovery to these additives and to develop a robust and reliable model that incorporates the intricate interactions, thereby elucidating the underlying mechanisms. Two imbibition fluids are designed, namely, surfactant and microemulsion. A comprehensive investigation is performed to analyze the physicochemical properties of these fluids, encompassing phase behavior, density, viscosity, and wettability alteration, with the aim of establishing fundamental knowledge in the field. Three imbibition tests are carried out to observe the response of oil production and optimize the experimental methodology. A numerical model is developed that fully couples the evolution of relative permeability and capillary pressure with the dynamic processes of emulsification, solubilization and molecular diffusion. The results demonstrate the crucial role of emulsification/solubilization in the imbibition process.
{"title":"Imbibition oil recovery from tight reservoir cores using microemulsion: Experiment and simulation","authors":"Qinzhi Li, Yiwen Wang, B. Wei, Lele Wang, Jun Lu, Jinyu Tang","doi":"10.46690/capi.2024.02.02","DOIUrl":"https://doi.org/10.46690/capi.2024.02.02","url":null,"abstract":": Despite the promising results obtained from the utilization of interfacial-active additives in enhancing imbibition-based oil recovery from tight reservoirs, the predominant mechanisms governing this process remain inadequately understood. In this work, a meticulously designed workflow is implemented to conduct experiments and modeling focusing on imbibition tests performed on tight sandstone cores while utilizing surfactant and microemulsion. Our primary objective is to investigate the response of oil recovery to these additives and to develop a robust and reliable model that incorporates the intricate interactions, thereby elucidating the underlying mechanisms. Two imbibition fluids are designed, namely, surfactant and microemulsion. A comprehensive investigation is performed to analyze the physicochemical properties of these fluids, encompassing phase behavior, density, viscosity, and wettability alteration, with the aim of establishing fundamental knowledge in the field. Three imbibition tests are carried out to observe the response of oil production and optimize the experimental methodology. A numerical model is developed that fully couples the evolution of relative permeability and capillary pressure with the dynamic processes of emulsification, solubilization and molecular diffusion. The results demonstrate the crucial role of emulsification/solubilization in the imbibition process.","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139209192","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 : 2023-11-23DOI: 10.46690/capi.2023.12.02
S. Tangparitkul, Anupong Sukee, Jiatong Jiang, Chesada Tapanya, Nawamin Fongkham, Hongbin Yang
15 Oil displacement by spontaneous imbibition is a capillary-governed process, in which wettability 16 controls fluid displacement direction. Capillarity is a driving force to enhance oil displacement in 17 water-wet system, while in oil-wet system capillarity is a resisting one. To promote oil displacement, 18 the former requires high capillarity, but the latter opposes. Such requisites are hypothesized to be
{"title":"Role of interfacial tension on wettability-controlled fluid displacement in porous rock: A capillary-dominated flow and how to control it","authors":"S. Tangparitkul, Anupong Sukee, Jiatong Jiang, Chesada Tapanya, Nawamin Fongkham, Hongbin Yang","doi":"10.46690/capi.2023.12.02","DOIUrl":"https://doi.org/10.46690/capi.2023.12.02","url":null,"abstract":"15 Oil displacement by spontaneous imbibition is a capillary-governed process, in which wettability 16 controls fluid displacement direction. Capillarity is a driving force to enhance oil displacement in 17 water-wet system, while in oil-wet system capillarity is a resisting one. To promote oil displacement, 18 the former requires high capillarity, but the latter opposes. Such requisites are hypothesized to be","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"211 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139243775","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 : 2023-11-16DOI: 10.46690/capi.2024.01.03
Yingwen Li, Yongfei Yang, Mingzhe Dong
: Capillary trapping is an important strategy to prevent CO 2 from escaping. Meanwhile, under immiscible conditions, CO 2 may travel upwards by gravity. Studying the long-term effects of gravity and layered heterogeneity on CO 2 transport is crucial for ensuring CO 2 storage security in aquifers. In this work, fluid flow experiments driven by inertial force and gravity are conducted in a specially constructed layered sandstone. Whether driven by inertial force or gravity, the variation in CO 2 distribution in the high-permeability layer is consistently the most significant factor. In the low-permeability layer, the saturation and capillary pressure distribution of CO 2 clusters vary less and the geometric shapes are also more complex, thus the CO 2 capillary trapping in this layer is more stable. This work demonstrates that the low-permeability layer can effectively prevent CO 2 from escaping upwards when the permeability ratio between layers approaches two.
:毛细管捕集是防止 CO 2 逸出的重要策略。同时，在不混溶条件下，二氧化碳可能会在重力作用下向上移动。研究重力和层状异质性对二氧化碳迁移的长期影响对于确保含水层中二氧化碳的储存安全至关重要。在这项工作中，我们在专门建造的层状砂岩中进行了由惯性力和重力驱动的流体流动实验。无论是惯性力还是重力驱动，高渗透层中二氧化碳分布的变化始终是最重要的因素。在低渗透率层中，CO 2 团块的饱和度和毛细管压力分布变化较小，几何形状也更为复杂，因此该层的 CO 2 毛细管捕集更为稳定。这项研究表明，当层间渗透率比接近 2 时，低渗透层可有效阻止 CO 2 向上逸出。
{"title":"CO2 capillary trapping in layered sandstone dominated by inertial force and gravity","authors":"Yingwen Li, Yongfei Yang, Mingzhe Dong","doi":"10.46690/capi.2024.01.03","DOIUrl":"https://doi.org/10.46690/capi.2024.01.03","url":null,"abstract":": Capillary trapping is an important strategy to prevent CO 2 from escaping. Meanwhile, under immiscible conditions, CO 2 may travel upwards by gravity. Studying the long-term effects of gravity and layered heterogeneity on CO 2 transport is crucial for ensuring CO 2 storage security in aquifers. In this work, fluid flow experiments driven by inertial force and gravity are conducted in a specially constructed layered sandstone. Whether driven by inertial force or gravity, the variation in CO 2 distribution in the high-permeability layer is consistently the most significant factor. In the low-permeability layer, the saturation and capillary pressure distribution of CO 2 clusters vary less and the geometric shapes are also more complex, thus the CO 2 capillary trapping in this layer is more stable. This work demonstrates that the low-permeability layer can effectively prevent CO 2 from escaping upwards when the permeability ratio between layers approaches two.","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"58 9","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139268190","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 : 2023-11-04DOI: 10.46690/capi.2024.01.01
Hui Cheng, Fuyong Wang
Spontaneous imbibition in porous materials has received significant attention in recent decades; however, spontaneous liquid-liquid imbibition in fractures has not been well studied. Specifically, the mechanism behind the influence of gravity and buoyancy on the spontaneous imbibition of wetting phase fluid into fractured porous media remains uncertain. In this study, an analytical solution for spontaneous imbibition in fractured porous media under the influence of gravity and buoyancy is presented. The results show that imbibition velocity with buoyancy and gravity is faster than that without these forces. The effect of buoyancy and gravity on imbibition velocity increases with rising fracture aperture and length. When the fracture aperture is less than 1 μm, the relative deviation between imbibition height with and without gravity and buoyancy is about 50%. On the other hand, when the fracture aperture is greater than 1 μm, the relative deviation is proportional to the fracture aperture. The relative reduction in imbibition height over time is not obvious when the fracture aperture is the same. In the process of water-oil spontaneous imbibition, the effect of buoyancy and gravity is more pronounced at low oil-water interfacial tension. Therefore, the effect of buoyancy and gravity on spontaneous imbibition cannot be ignored under this condition. Document Type: Original article Cited as: Cheng, H., Wang, F. Effects of gravity and buoyancy on spontaneous liquid-liquid imbibition in fractured porous media. Capillarity, 2024, 10(1): 1-11. https://doi.org/10.46690/capi.2024.01.01
{"title":"Effects of gravity and buoyancy on spontaneous liquid-liquid imbibition in fractured porous media","authors":"Hui Cheng, Fuyong Wang","doi":"10.46690/capi.2024.01.01","DOIUrl":"https://doi.org/10.46690/capi.2024.01.01","url":null,"abstract":"Spontaneous imbibition in porous materials has received significant attention in recent decades; however, spontaneous liquid-liquid imbibition in fractures has not been well studied. Specifically, the mechanism behind the influence of gravity and buoyancy on the spontaneous imbibition of wetting phase fluid into fractured porous media remains uncertain. In this study, an analytical solution for spontaneous imbibition in fractured porous media under the influence of gravity and buoyancy is presented. The results show that imbibition velocity with buoyancy and gravity is faster than that without these forces. The effect of buoyancy and gravity on imbibition velocity increases with rising fracture aperture and length. When the fracture aperture is less than 1 μm, the relative deviation between imbibition height with and without gravity and buoyancy is about 50%. On the other hand, when the fracture aperture is greater than 1 μm, the relative deviation is proportional to the fracture aperture. The relative reduction in imbibition height over time is not obvious when the fracture aperture is the same. In the process of water-oil spontaneous imbibition, the effect of buoyancy and gravity is more pronounced at low oil-water interfacial tension. Therefore, the effect of buoyancy and gravity on spontaneous imbibition cannot be ignored under this condition. Document Type: Original article Cited as: Cheng, H., Wang, F. Effects of gravity and buoyancy on spontaneous liquid-liquid imbibition in fractured porous media. Capillarity, 2024, 10(1): 1-11. https://doi.org/10.46690/capi.2024.01.01","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-11-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135774595","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 : 2023-10-25DOI: 10.46690/capi.2023.12.01
Shilin Li, Zhongbin Ye, Junqi Wang, Lei Tang, Nanjun Lai
Imbibition is an important mechanism of shale reservoir development. In exploring the factors affecting the enhanced recovery of shale reservoirs by imbibition, laboratory spontaneous and forced imbibition experiments were conducted using outcrop cores of shale reservoirs. The effects of imbibition agent composition, fracture, and pressure on imbibition are obtained in this work based on imbibition recovery test findings and imbibition theory. Results show that the imbibition curve includes three stages, namely, imbibition, transition, and stability. Among the components of compound fracking fluid, surfactants have the greatest impact, whereas emulsifiers have the least impact. Complex crack structures and high-temperature environments can improve imbibition recovery. Pressure is inversely proportional to imbibition recovery in the highly stress-sensitive shale reservoir. In addition, the throughput time of the imbibition agent has an optimal value in the shale reservoir. After the huff-n-puff time exceeds the optimal value, the imbibition agent should be replaced to continuously improve the imbibition effect. The research results can serve as a basis for enhancing oil recovery through imbibition. Document Type: Original article Cited as: Li, S., Ye, Z., Wang, J., Tang, L., Lai, N. Effects of fracturing fluid composition and other factors on improving the oil imbibition recovery of shale reservoir. Capillarity, 2023, 9(3): 45-54. https://doi.org/10.46690/capi.2023.12.01
{"title":"Effects of fracturing fluid composition and other factors on improving the oil imbibition recovery of shale reservoir","authors":"Shilin Li, Zhongbin Ye, Junqi Wang, Lei Tang, Nanjun Lai","doi":"10.46690/capi.2023.12.01","DOIUrl":"https://doi.org/10.46690/capi.2023.12.01","url":null,"abstract":"Imbibition is an important mechanism of shale reservoir development. In exploring the factors affecting the enhanced recovery of shale reservoirs by imbibition, laboratory spontaneous and forced imbibition experiments were conducted using outcrop cores of shale reservoirs. The effects of imbibition agent composition, fracture, and pressure on imbibition are obtained in this work based on imbibition recovery test findings and imbibition theory. Results show that the imbibition curve includes three stages, namely, imbibition, transition, and stability. Among the components of compound fracking fluid, surfactants have the greatest impact, whereas emulsifiers have the least impact. Complex crack structures and high-temperature environments can improve imbibition recovery. Pressure is inversely proportional to imbibition recovery in the highly stress-sensitive shale reservoir. In addition, the throughput time of the imbibition agent has an optimal value in the shale reservoir. After the huff-n-puff time exceeds the optimal value, the imbibition agent should be replaced to continuously improve the imbibition effect. The research results can serve as a basis for enhancing oil recovery through imbibition. Document Type: Original article Cited as: Li, S., Ye, Z., Wang, J., Tang, L., Lai, N. Effects of fracturing fluid composition and other factors on improving the oil imbibition recovery of shale reservoir. Capillarity, 2023, 9(3): 45-54. https://doi.org/10.46690/capi.2023.12.01","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135218056","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 : 2023-10-14DOI: 10.46690/capi.2023.11.02
Han Wang, Jianchao Cai, Yuliang Su, Zhehui Jin, Wendong Wang, Guanqun Li
In shale reservoirs, spontaneous imbibition is an important mechanism of fracturing fluid loss, which has an important impact on enhanced oil recovery and water resource demand. However, spontaneous imbibition behaviors are more complicated to characterize and clarify due to the nanoscale effects of the boundary slip, oil-water interfacial slip, and heterogeneous fluid properties caused by intermolecular interactions. A nanoscale multi-relaxation-time multicomponent and multiphase lattice Boltzmann method was applied to investigate the water imbibition into oil-saturated nanoscale space. The effects of pore size, fluid-surface slip, water film, oil-water interfacial slip, water bridge, and pore structures on the imbibition behaviors in a single nanopore were investigated. Then, the spontaneous imbibition behaviors in nanoporous media based on the pore scale microsimulation parameters obtained from the molecular simulation velocity results were simulated, and the effects of water saturations on imbibition behaviors were discussed. The results show that as the water saturation increases from 0 to 0.1, the imbibition mass in nanoporous media increases because of the oil-water interfacial slip and a completely hydrophilic wall. As water saturation continues to increase, the imbibition mass decreases gradually because the existence of water bridges impedes the water imbibition. Document Type: Original article Cited as: Wang, H., Cai, J., Su, Y., Jin, Z., Wang, W., Li, G. Imbibition behaviors in shale nanoporous media from pore-scale perspectives. Capillarity, 2023, 9(2): 32-44. https://doi.org/10.46690/capi.2023.11.02
在页岩储层中，自吸是压裂液漏失的重要机制，对提高采收率和水资源需求具有重要影响。然而，由于边界滑移、油水界面滑移和分子间相互作用引起的非均质流体性质的纳米效应，自发吸胀行为的表征和澄清更加复杂。采用纳米尺度多松弛时间、多组分、多相晶格玻尔兹曼方法研究了含油饱和纳米空间的吸水性。研究了孔径、液面滑移、水膜、油水界面滑移、水桥和孔结构对单孔吸胀行为的影响。然后，基于分子模拟速度结果获得的孔尺度微模拟参数，对纳米多孔介质中的自吸行为进行了模拟，并讨论了含水饱和度对自吸行为的影响。结果表明:当含水饱和度从0增加到0.1时，由于油水界面的滑移和完全亲水壁的形成，纳米孔介质中的吸积质量增加;随着含水饱和度的不断增加，由于水桥的存在阻碍了吸积，吸积质量逐渐减小。文档类型:原始文章认为:王,H, Cai, J。,苏,Y,, Z, Wang W。,g .自吸行为在于页岩纳米多孔介质的观点。毛细管学，2023,9(2):32-44。https://doi.org/10.46690/capi.2023.11.02
{"title":"Imbibition behaviors in shale nanoporous media from pore-scale perspectives","authors":"Han Wang, Jianchao Cai, Yuliang Su, Zhehui Jin, Wendong Wang, Guanqun Li","doi":"10.46690/capi.2023.11.02","DOIUrl":"https://doi.org/10.46690/capi.2023.11.02","url":null,"abstract":"In shale reservoirs, spontaneous imbibition is an important mechanism of fracturing fluid loss, which has an important impact on enhanced oil recovery and water resource demand. However, spontaneous imbibition behaviors are more complicated to characterize and clarify due to the nanoscale effects of the boundary slip, oil-water interfacial slip, and heterogeneous fluid properties caused by intermolecular interactions. A nanoscale multi-relaxation-time multicomponent and multiphase lattice Boltzmann method was applied to investigate the water imbibition into oil-saturated nanoscale space. The effects of pore size, fluid-surface slip, water film, oil-water interfacial slip, water bridge, and pore structures on the imbibition behaviors in a single nanopore were investigated. Then, the spontaneous imbibition behaviors in nanoporous media based on the pore scale microsimulation parameters obtained from the molecular simulation velocity results were simulated, and the effects of water saturations on imbibition behaviors were discussed. The results show that as the water saturation increases from 0 to 0.1, the imbibition mass in nanoporous media increases because of the oil-water interfacial slip and a completely hydrophilic wall. As water saturation continues to increase, the imbibition mass decreases gradually because the existence of water bridges impedes the water imbibition. Document Type: Original article Cited as: Wang, H., Cai, J., Su, Y., Jin, Z., Wang, W., Li, G. Imbibition behaviors in shale nanoporous media from pore-scale perspectives. Capillarity, 2023, 9(2): 32-44. https://doi.org/10.46690/capi.2023.11.02","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"249 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135803659","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}
{"title":"Wettability controlling effects on the fluid occurrence and flow in shale gas reservoirs: Present problems and new sights","authors":"Shaojie Zhang, Tengyu Wang, Zhenrui Gao, Yunsheng Zhang","doi":"10.46690/capi.2023.11.01","DOIUrl":"https://doi.org/10.46690/capi.2023.11.01","url":null,"abstract":"","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-10-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"136360243","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}
{"title":"Effects of impurity gases on interfaces of the hydrogen-water-decane three-phase system: A square gradient theory investigation","authors":"Yafan Yang, Jingyu Wan, Jingfa Li, Weiwei Zhu, Guangsi Zhao, Xiangyu Shang","doi":"10.46690/capi.2023.10.02","DOIUrl":"https://doi.org/10.46690/capi.2023.10.02","url":null,"abstract":"","PeriodicalId":34047,"journal":{"name":"Capillarity","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135255832","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}
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