International Journal of Greenhouse Gas Control最新文献

{"title":"The financial implications of injectivity risk in compartmentalized storage formations for geologic carbon sequestration","authors":"Christopher Deranian ,&nbsp;Sahar Bakhshian ,&nbsp;Susan D. Hovorka","doi":"10.1016/j.ijggc.2025.104463","DOIUrl":"10.1016/j.ijggc.2025.104463","url":null,"abstract":"<div><div>Maintaining injectivity over the planned duration is a major driver of risk in CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> storage projects. Current insurance considerations are largely focused on leakage and well remediation, while operational issues from past carbon storage projects have shown injectivity issues due to unanticipated formation compartmentalization is a real risk. The financial penalty due to the disruption of injection operations is large for a site operator. This study explores the effect of storage compartment size and geologic boundary condition on injectivity, and the subsequent financial implications. Risk profiles of injectivity are generated through reservoir simulations constrained by statistics from a CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> storage prospect on the Gulf Coast. A financial tool is built to understand the impact on project value when an injectivity issue occurs and an offset well needs to be drilled. We observe that even in relatively closed boundary conditions, pressure arising from the CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> injection can dissipate in the formation to allow injection over the project life. The economic feasibility of a storage project that does face an injectivity issue depends on the year of the injection issue occurrence. This study helps understand the injectivity risk, project contingency, and the financial feasibility of mitigation options required to establish robust assurance against this risk.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"147 ","pages":"Article 104463"},"PeriodicalIF":5.2,"publicationDate":"2025-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145098136","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"De-risking overburden and caprocks for CO2 storage using machine-learning seismic fault attributes","authors":"Julián L. Gómez ,&nbsp;Ane Elisabet Lothe","doi":"10.1016/j.ijggc.2025.104471","DOIUrl":"10.1016/j.ijggc.2025.104471","url":null,"abstract":"<div><div>Fault and fracture geometries, densities, and distributions play a critical role in assessing and mitigating risks associated with potential CO₂ storage sites in sedimentary basins, particularly saline aquifers. To enhance fault detection in 3D seismic data, we have developed, trained, and deployed a lightweight machine learning segmentation algorithm. This deep learning model, trained on synthetic seismic data, generates fault scores—pixel-scale classifications ranging from 0 to 1—where higher values indicate a greater likelihood of structural discontinuities. These fault scores are used to derive a fault density attribute, which summarizes the expected fault network distribution along seismic sections. Our workflow is computationally efficient and provides interpreters with valuable insight into the lateral and vertical distribution of faults. We apply this methodology to a 3D seismic survey of the Smeaheia area, Norway, covering the N-S trending Vette Fault and sections of the Øygarden Fault Complex (ØFC). Fault mapping was conducted at the reservoir level, as well as in the caprock and overburden. The detected fault patterns at the top of the Draupne Formation, the presumed caprock unit in the region, and fault pattern at the Top Cromer Knoll Group, align well with manual interpretations. Additionally, in the footwall of the deep-crustal ØFC, we identify faults extending to the seafloor, suggesting that a non-negligible fault density may be present within the caprock. Our results are compared with 3D variance and 3D semblance seismic attributes, further validating the efficacy of our approach.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"147 ","pages":"Article 104471"},"PeriodicalIF":5.2,"publicationDate":"2025-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145098135","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Deep learning-assisted THM-integrated InSAR modeling for CO2 storage characterization and surface deformation forecasting","authors":"Eunsil Park,&nbsp;Hyunmin Kim,&nbsp;Hyundon Shin,&nbsp;Honggeun Jo","doi":"10.1016/j.ijggc.2025.104461","DOIUrl":"10.1016/j.ijggc.2025.104461","url":null,"abstract":"<div><div>Accurate characterization of subsurface reservoirs in geological carbon storage (GCS) is essential for ensuring long-term storage security and mitigating leakage risks. This study proposes a novel CO₂ reservoir characterization framework that integrates InSAR-based surface deformation data with a deep learning-based method (pix2pix) to predict subsurface properties, such as rock facies and porosity. To assess the surface deformation before and after CO₂ injection, a THM (thermal-hydrological-mechanical) simulation is employed, and their corresponding results are used as input for the suggested pix2pix-based model. To reveal the robustness of the suggested workflow, sensitivity analysis is conducted by varying signal-to-noise ratio (SNR) of InSAR data and observation time periods, assessing their impact on characterization performance. Furthermore, the model is applied for long-term CO₂ plume and surface deformation predictions, enabling uncertainty quantification of future behavior.</div><div>The results show that early-stage observation data provide rich subsurface information but are highly sensitive to noise, whereas later observations exhibit greater tolerance to noise but reduced information content. The suggested workflow effectively predicts long-term CO₂ plume migration and surface deformation trends, demonstrating its applicability for reservoir monitoring. This study demonstrates that integrating InSAR-based surface deformation data with deep learning significantly improves CO₂ reservoir characterization. The findings highlight the importance of optimizing InSAR acquisition frequency and noise-handling strategies to enhance monitoring accuracy. The proposed approach provides a foundation for developing time-series-based reservoir characterization models using surface deformation data.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"147 ","pages":"Article 104461"},"PeriodicalIF":5.2,"publicationDate":"2025-09-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145097677","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Feasibility study on large-scale geologic carbon sequestration in Southern Colorado","authors":"Yanrui Ning ,&nbsp;Ali Tura ,&nbsp;David Herman ,&nbsp;Jay Bridgeman ,&nbsp;Dana Clark","doi":"10.1016/j.ijggc.2025.104462","DOIUrl":"10.1016/j.ijggc.2025.104462","url":null,"abstract":"<div><div>This study evaluates the feasibility of storing over 50 million metric tons of CO₂ within a 30-year period in southern Colorado. The target for injection is the 7000 ft (2134 m)-deep Lyons saline aquifer formation, with the overlying alternating layers of anhydrite and shale serving as seals. Geological static models were constructed using seismic, well log and core data, followed by fluid flow modeling to understand the CO₂ injection strategy, saturation distribution and plume size. The results indicate that approximately 60 million metric tons of CO₂ can be injected with 2 wells into the formation over 30 years, with 85 % of the CO₂ existing in a supercritical phase during the injection stage. After 70 years of shut-in, about 30 % of the injected CO₂ becomes immobilized due to hysteresis. Seismic data shows no faulting within the injection and seal formations, and no legacy wells penetrate the Lyons formation within the study area, which reduces the risks of fault slippage and leakage through legacy wells. However, the small dip angle of the structure may present challenges to CO₂ plume containment, highlighting the importance of implementing strategies such as enhanced monitoring systems, detailed geomechanical modeling, and plume migration simulations to mitigate and better understand potential risks. This study offers early insights into CCUS potential in southern Colorado using seismic and limited data, and will ultimately provide valuable guidance for future implementation of CO₂ injection in the region.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"147 ","pages":"Article 104462"},"PeriodicalIF":5.2,"publicationDate":"2025-09-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145097676","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Numerical assessment of triply periodic minimal surfaces for direct air capture of carbon dioxide","authors":"Kellis Kincaid,&nbsp;Filipe L. Brandao,&nbsp;Flavio D.F. Chuahy,&nbsp;Kashif Nawaz","doi":"10.1016/j.ijggc.2025.104457","DOIUrl":"10.1016/j.ijggc.2025.104457","url":null,"abstract":"<div><div>Direct air capture (DAC) systems often consist of packing material wetted by a capture fluid that reacts with CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> in the airstream. The efficiency of the contactor is determined by a complex relationship of fluid dynamics, heat and mass transfer, contactor geometry, and chemical properties. The efficiency of the contactor must be balanced with other factors, primarily pressure drop through the system. Triply periodic minimal surfaces (TPMS) are a class of differential surfaces that have been explored in multiple engineering applications and have been shown to exhibit excellent performance when used in heat exchangers. Their tortuous path provides a high surface-to-volume ratio and favorable trade-off between contact area and pressure drop. In this work, a gyroid-type TPMS contactor was evaluated using computational fluid dynamics for a variety of geometric parameters to explore the potential benefit of TPMS shapes for DAC applications. A thin-film model was employed to model the flow and distribution of the capture solvent, allowing efficient simulations of TPMS structures at scale by eliminating the need for a computationally intensive interface capturing method. A liquid-gas mass transfer model was implemented in the commercial software STAR-CCM+ and used to predict the CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> capture efficiency and study the trade-off between capture performance and pressure drop through analysis of capture rates, mass transfer coefficients, and other relevant variables. TPMS contactors with a variety of geometric parameters and two capture solvent options were investigated to determine the effect of design choices on the operational performance of DAC systems. Results showed that while contactor geometry is the dominant factor in efficiency and pressure drop, the physiochemical properties of the solvent are an important secondary influence on the contactor performance.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104457"},"PeriodicalIF":5.2,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145010395","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The effect of supercritical CO2, pressure, and temperature on the acoustic and mechanical properties of soft caprock mudstone","authors":"Zeenat Maniar ,&nbsp;Anna Stroisz ,&nbsp;Mohammad Hossain Bhuiyan ,&nbsp;Pierre Cerasi ,&nbsp;Cathrine Ringstad ,&nbsp;Lars Nielsen","doi":"10.1016/j.ijggc.2025.104459","DOIUrl":"10.1016/j.ijggc.2025.104459","url":null,"abstract":"<div><div>Safe storage of carbon dioxide (CO₂) in a reservoir depends on the caprock's sealing efficiency and mechanical integrity. For long-term containment of CO₂, knowledge of rock property alterations due to CO₂-caprock interaction is crucial. Potentially accessible and permeable reservoirs for CO₂ storage in the southeastern North Sea include Miocene sands, which are topped by mudstones that should act as seals. Here, we expose upper Miocene caprock mudstone recovered from the Lille John-2 well in the Danish North Sea to supercritical CO₂ at field-representative pressure and temperature conditions to simulate the effect of CO₂ sequestration in a laboratory setting. We investigate acoustic, mechanical, and chemical variations in the rock before and after CO₂ exposure, which are essential for understanding the caprock’s strength and integrity. To isolate the geochemical effects, a control set of samples was exposed to inert Ar-gas under equivalent pressure and temperature conditions. The acoustic velocities were measured on cutting-sized (diameter:15 mm, thickness: 3–5 mm) samples using the continuous wave and through-transmission techniques, while shear strength was determined by the punch method. X-ray diffraction studies recorded chemically driven mineralogical alterations. After exposure, both compressional and shear wave velocities, as well as the shear strength of the material, increased by about 10 %, 10–50 %, and 85–130 %, respectively. However, no considerable change in mineralogy was detected. Exposure to scCO₂ displaced pore fluid out of the samples, leading to increased strength and stiffness, possibly due to pore fluid drying. The individual impacts of scCO₂, Ar-gas, and temperature treatment were ambiguous.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104459"},"PeriodicalIF":5.2,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144931970","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Using earth tides to monitor CO2  storage: Field trials at the Otway International Test Centre, Victoria","authors":"Charles Jenkins ,&nbsp;Jonathan Ennis-King ,&nbsp;Chris Green ,&nbsp;James Gunning ,&nbsp;Samuel Jackson ,&nbsp;Andy Wilkins","doi":"10.1016/j.ijggc.2025.104458","DOIUrl":"10.1016/j.ijggc.2025.104458","url":null,"abstract":"<div><div>Tidal forces from the Sun, Moon and other astronomical bodies cause daily variable strains in the solid earth. These strains cause variations in the pressure in fluid-saturated rocks. Their amplitude and phase are affected by the in-situ fluids, so that CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> <!--> <!-->may be detectable when injected into an aquifer for a CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> <!--> <!-->storage site. We report comprehensive monitoring of earth tides from six deep observation wells surrounding a 15 kt CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> <!--> <!-->plume injected into the Paaratte aquifer in the Otway Basin, Australia. This plume was repeatedly monitored with time-lapse seismic. The observation wells were up to 500 meters from the edge of the CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> <!--> <!-->plume, but the observed pressure amplitudes and phases of the earth tides responded to its creation and propagation. This response is at distances from the plume comparable to the pressure diffusion length in a day, which in this setting is about 350 meters. Earth tides may be a useful passive, supplementary method of monitoring CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> <!--> <!-->plumes created by geological storage.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104458"},"PeriodicalIF":5.2,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144988226","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Cost assessment of optimal seawater monitoring for unexpected CO2 leakage from an offshore reservoir","authors":"Yuki Okamoto ,&nbsp;Toru Sato ,&nbsp;Shunsuke Kanao","doi":"10.1016/j.ijggc.2025.104455","DOIUrl":"10.1016/j.ijggc.2025.104455","url":null,"abstract":"<div><div>Carbon Capture and Storage (CCS) has garnered attention as a mitigation strategy for the global warming and a means to achieve carbon neutrality. In Japan, monitoring CO₂ concentration in the sea is mandatory for subsea geological CO₂ storage due to concerns about the potential negative impact on marine environments in the event of accidental CO₂ leakage. However, the monitoring method currently conducted in Japan is not only expensive but also lacks fully scientific grounding. In this study, we aimed to develop a method for optimising the observation point placement to detect biologically significant CO₂ seepage. In the method, observation areas were identified based on the advection-diffusion simulation of dissolved CO₂ concentration emitted from every location in a possible seepage area when the CO₂ seepage rate was varied from 1000 to 25000 tonnes/year. Then, within the observation area, optimal observation locations were determined using a greedy algorithm. Finally, monitoring costs were calculated based on the number of observation points, the travel distance of an observation boat, and necessary observation days. The results showed a negative nonlinear relationship between detectable seepage rates and monitoring costs, which decreases rapidly up to seepage rates of 5000 tonnes/year and then remains almost constant above 10000 tonnes/year. This study suggests that monitoring policies could be determined according to risk tolerance and budget constraints for seepage that must be detected considering biological impacts.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104455"},"PeriodicalIF":5.2,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144920146","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development and plant validation of a CESAR1 solvent model with an emphasis on water wash conditions","authors":"Jeffrey A. Weinfeld ,&nbsp;Diego D.D. Pinto ,&nbsp;Peter Moser ,&nbsp;Georg Wiechers","doi":"10.1016/j.ijggc.2025.104454","DOIUrl":"10.1016/j.ijggc.2025.104454","url":null,"abstract":"<div><div>CESAR1, an aqueous blend of 1.5 M piperazine (PZ) and 3.0 M 2-amino-2-methyl-1-propanol (AMP) has shown potential to replace monoethanolamine (MEA) as the benchmark solvent for carbon capture with aqueous amines. This is largely due to recently published literature showing CESAR1 reducing the process energy requirement below that of MEA. To properly evaluate CESAR1’s commercial potential as a replacement for MEA, accurate process models are required. When CESAR1 first emerged, little physical property and thermodynamic data was available on the solvent mixture. However, as CESAR1 has attracted more attention, an increasing amount of solvent data has been published. In this study, the CESAR1 model of the ProTreat® process simulator is updated with recently published data from literature, and data that was generated as part of the Sustainable Operation of Post-Combustion Capture Plants (SCOPE) project. The updated model was then validated with data from the RWE Niederaussem pilot plant. Results show high agreement between ProTreat® predictions and pilot plant data across eight cases testing different solvent flowrates, target capture rates, and absorption capacity. As a result, a mass-transfer rate-based CESAR1 model is validated, which can be used as a tool for industry members and researchers to further evaluate the commercial potential of CESAR1.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104454"},"PeriodicalIF":5.2,"publicationDate":"2025-08-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144904068","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Implications of earthquakes triggered by massive injection of produced water in saline aquifers for large-scale geologic storage of CO2","authors":"Mark D. Zoback ,&nbsp;Peter Hennings","doi":"10.1016/j.ijggc.2025.104447","DOIUrl":"10.1016/j.ijggc.2025.104447","url":null,"abstract":"<div><div>It is well-established that to significantly decrease greenhouse gas emissions, CO₂ capture and storage in subsurface geologic formations (CCS) must occur at an enormous scale. In this context, large-scale injection of supercritical CO₂ into saline aquifers is an analogous process to the disposal of large volumes of saltwater co-produced with oil and gas (SWD). However, large-scale SWD in saline aquifers over the past 15 years in the mid-continent of North America has caused a remarkable increase in intraplate seismicity. Since 2010, nearly 4 billion m³ of produced water has been injected into sedimentary layers that are in hydraulic communication with seismogenic geologic basement in Oklahoma and Texas alone, triggering earthquakes as large as magnitude 5.8 and more than 200 M ≥ 4.0 earthquakes that were widely felt. Every case of large-scale SWD in the mid-continent in deep saline aquifers in hydrologic communication with basement has caused significant induced seismicity. If CO₂ storage projects are associated with induced seismicity, they could be perceived by the public as a hazardous activity which should not be allowed to continue, generally regardless of the magnitudes of the induced events. Thus, among many challenges (operational, geologic and economic), large-scale CCS projects will face, they also will need to minimize the occurrence of injection-induced seismicity. In this paper, we review the extensive research carried out in four regions of the central U.S. with abundant seismicity induced by large-scale SWD in central U.S. as an analogous process to large-scale CO₂ injection. Our primary purpose is to inform non-experts of the key findings of the large body of scientific evidence now available in these areas that help guide decision making related to finding viable options for long-term, large-scale CO₂ storage in geologic formations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"146 ","pages":"Article 104447"},"PeriodicalIF":5.2,"publicationDate":"2025-08-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144885455","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}