International Journal of Greenhouse Gas Control最新文献

{"title":"Capillary pinning in sedimentary rocks for CO2 storage: Mechanisms, terminology and State-of-the-Art","authors":"Qin Zhang ,&nbsp;Sebastian Geiger ,&nbsp;Joep E.A. Storms ,&nbsp;Denis V. Voskov ,&nbsp;Matthew D. Jackson ,&nbsp;Gary J. Hampson ,&nbsp;Carl Jacquemyn ,&nbsp;Allard W. Martinius","doi":"10.1016/j.ijggc.2025.104385","DOIUrl":"10.1016/j.ijggc.2025.104385","url":null,"abstract":"<div><div>Capillary pinning refers to the immobilization of CO₂ at capillary barriers when the uprising CO₂ pressure is lower than the capillary entry pressure of the overlaying pore throats. Also known as local capillary trapping, it has been proposed as a fifth geologic CO₂ storage mechanism, alongside structural, solubility, residual, and mineral trapping. Despite extensive research, the fragmented terminology surrounding capillary pinning has led to confusion, making it challenging to synthesize findings effectively. Often conflated with mechanisms such as residual and hysteresis trapping, capillary pinning is commonly underestimated or completely overlooked in reservoir-scale models. Furthermore, difficulties in characterizing and upscaling small-scale geologic heterogeneities that influence capillary pinning contribute to significant uncertainties, with estimates of CO₂ trapped via this mechanism ranging from 3 % to 100 % of total CO₂ trapped via capillary actions. This review explores the fundamental mechanisms, experimental findings, and modeling approaches for assessing CO₂ capillary pinning in carbon capture and storage (CCS). It seeks to bridge the gap between the reservoir engineering community, with its extensive expertise in hydrocarbon recovery but that needs adjustments for CCS applications, and the subsurface storage community, which stands to benefit from this knowledge but often lacks access to relevant literature. Additionally, the study identifies key research opportunities to advance the understanding of capillary pinning in sedimentary rocks, ultimately enhancing the efficacy and reliability of CCS operations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104385"},"PeriodicalIF":4.6,"publicationDate":"2025-04-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143881451","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":"Assessing the feasibility of retrofitting legacy wells for CO2 geological sequestration","authors":"Mohamed L. Malki ,&nbsp;Joseph Heimerl ,&nbsp;Zhiwei Ma,&nbsp;Bailian Chen,&nbsp;Jolante Van Wijk,&nbsp;Mohamed Mehana","doi":"10.1016/j.ijggc.2025.104389","DOIUrl":"10.1016/j.ijggc.2025.104389","url":null,"abstract":"<div><div>In the United States (U.S.), the Environmental Protection Agency (EPA) oversees geologic sequestration (GS) wells, designating them as <em>“Class VI wells”</em>. However, the few operational Class VI wells and those in the permitting process are insufficient for the scale of sequestration needed. An effective solution to boost storage capacity is retrofitting legacy oil and gas wells into sequestration wells. Our analysis applies the <strong>R</strong>eusing <strong>EX</strong>isting wells for CO₂ Storage Operations (REX-CO₂) qualitative screening tool to evaluate the feasibility of retrofitting legacy Class II wells into Class VI wells for geological CO₂ sequestration. We examine regulatory requirements, well integrity factors, and publicly available data from a pilot study on 15 wells in New Mexico. In addition to the REX-CO₂ assessment, we propose primary and secondary barriers based on individual well documentation to address key integrity challenges. We find that wellbore retrofits for long-term carbon dioxide sequestration are only suitable for wells that possess the correct combination of well factors. For these wells, retrofitting could offer significant time and cost savings over drilling new wells. The study highlights the importance of improving publicly available wellbore data and regulatory coordination to enhance future well retrofit evaluations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104389"},"PeriodicalIF":4.6,"publicationDate":"2025-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873871","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":"Intermittent injection of supercritical CO2 in oil-brine-saturated rocks: Experimental data and numerical modelling","authors":"Nikolai Andrianov,&nbsp;Samira Mohammadkhani,&nbsp;Behzad Rostami,&nbsp;Wael Fadi Al-Masri","doi":"10.1016/j.ijggc.2025.104382","DOIUrl":"10.1016/j.ijggc.2025.104382","url":null,"abstract":"<div><div>We present both experimental and numerical modelling results for an unsteady-state core flooding experiment, designed to mitigate risks associated with CO₂ injection in a depleted oil field offshore Denmark. The change in the samples’ permeability before and after the experiment is shown to be minimal, suggesting that a potential reduction in injectivity is unlikely. The experimental data include differential pressure measurements across the sample and brine saturation measurements in the sample as a function of time. We demonstrate that the experimental data can be history-matched with a range of parameters defining the relative permeability and capillary pressure functions for the three-phase oil-brine-CO₂ system. Two numerical models are developed for solving the forward problem: a computationally expensive, comprehensive equation-of-state based model and a faster incompressible immiscible proxy model. The inverse problem solutions are estimated using the proxy model, and the best-obtained saturation functions are utilized to solve the forward problem with the comprehensive model. The obtained indicative uncertainty ranges can be useful in the absence of more complex and costly experimental data, such as in-situ X-ray saturation measurements.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104382"},"PeriodicalIF":4.6,"publicationDate":"2025-04-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873870","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 accelerated inverse modeling and forecasting for large-scale geologic CO2 sequestration","authors":"Bailian Chen ,&nbsp;Bicheng Yan ,&nbsp;Billal Aslam ,&nbsp;Qinjun Kang ,&nbsp;Dylan Harp ,&nbsp;Rajesh Pawar","doi":"10.1016/j.ijggc.2025.104383","DOIUrl":"10.1016/j.ijggc.2025.104383","url":null,"abstract":"<div><div>Traditional physics-simulation based approaches for inverse modeling and forecasting in geologic CO₂ sequestration (GCS) are very time consuming. For example, a single inverse modeling may take a few weeks for a large-scale CO₂ storage model without leveraging any high-performance computing. To speed up this process, we developed a novel approach that employs machine learning methods to integrate monitoring data into subsurface forecasts more rapidly than current physics-based inverse modeling workflows allow. These updated forecasts with the updated models from the inverse modeling process will be used to provide site operators with decision support by generating real-time performance metrics of CO₂ storage (e.g., CO₂ plume and pressure area of review). First, we developed a deep learning (DL) model to predict the pressure/saturation evolution in large-scale storage reservoirs. A feature coarsening technique was applied to extract the most representative information and perform the training and prediction at the coarse scale, and to further recover the resolution at the fine scale by 2D piecewise cubic interpolation. The accuracy of the feature coarsening-based DL model is validated with a reservoir model built upon a Clastic Shelf storage site. Thereafter, the feature coarsening-based DL model was utilized as forward model in the inverse modeling process where a classical data assimilation approach, ES-MDA-GEO, was applied. The efficiency and effectiveness of the proposed DL-assisted workflow for large-scale inverse modeling and forecasting was demonstrated with the Clastic Shelf storage model.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104383"},"PeriodicalIF":4.6,"publicationDate":"2025-04-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143869527","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":"Characteristics of alkali-activated fly Ash-CO2 mineralization reaction and micro carbon sequestration mechanism","authors":"Lei Qin ,&nbsp;Siheng Lin ,&nbsp;Haifei Lin ,&nbsp;Shugang Li ,&nbsp;Niandong Chen ,&nbsp;Chengang Sun","doi":"10.1016/j.ijggc.2025.104377","DOIUrl":"10.1016/j.ijggc.2025.104377","url":null,"abstract":"<div><div>The mineralization reaction characteristics of alkali-activated fly ash with CO₂ directly influence its carbon sequestration capacity. Investigating the micro-scale carbon sequestration mechanisms in alkali-activated fly ash mineralization reactions is essential for improving the efficiency of mineralization and sequestration of fly ash. This study focuses on lignite fly ash from a coal-fired power plant in Shijiazhuang, China. A closed mineralization reactor experimental platform and a pressure drop method were utilized to characterize carbonation performance. The experimental results indicate that the alkali activation treatment effectively enhances the mineralization and carbon sequestration performance of fly ash. Alkali-activated lignite fly ash post-mineralization reaction surfaces showed significant carbonate material presence. After mineralization reaction, the distribution of particle sizes of alkali-activated lignite fly ash increased. The C-O bonds in mineralized fly ash increase with the degree of alkali activation, indicating that alkali activation treatment enhance the carbon sequestration capability of lignite fly ash.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104377"},"PeriodicalIF":4.6,"publicationDate":"2025-04-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143858989","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":"Similarity of trapping efficiencies for N2, CO2, H2, and air in indiana limestone based on capillary gas displacement and spontaneous water imbibition experiments","authors":"Abdulrauf R. Adebayo ,&nbsp;Mohamed Gamal Rezk ,&nbsp;Zuhair AlYousef ,&nbsp;Rahul S. Babu ,&nbsp;Almohannad Alhashboul","doi":"10.1016/j.ijggc.2025.104386","DOIUrl":"10.1016/j.ijggc.2025.104386","url":null,"abstract":"<div><div>The trapping coefficient is a parameter that describes the relationship between the displacement efficiency and capillary trapping of a gas in a porous medium. Accurate prediction of gas residual trapping is essential in evaluating underground carbon storage projects. The determination of the gas trapping coefficient could be complicated when a high-pressure and high-temperature experiment is needed to mimic subsurface conditions and when a complex gas is involved. The objective of this study is to investigate the role of gas type and operating conditions on trapping coefficient using Indiana limestone core samples with different permeability ranges and different gases such as CO₂, N₂, H₂, and air. A variety of displacement methods was employed such as a simple benchtop porous plate drainage chamber, an electrical resistivity-based saturation monitoring core flooding equipment, and a vapor desorption chamber to drain water-saturated rock samples to different levels of water saturation. The different methods displaced brine at different levels of capillary pressures. A benchtop spontaneous imbibition chamber was then used to spontaneously imbibe brine again under a capillary-dominated process until a residual gas saturation was attained in each case. A nuclear magnetic resonance (NMR) relaxation technique was used to monitor fluid distribution in the pores of the saturated samples, gas saturations after drainage, and the trapped gas saturations. An initial-residual saturation curve based on Land’s (1968) trapping model was then used to compare the trapping coefficient of the rock samples to the different gases. The trapping coefficients of the rock samples were similar for the tested gases, although hydrogen exhibited a relatively lower residual trapping efficiency. This observation further elucidates previous results and confirms that the trapping coefficient is mainly a function of pore structure. However, this observation is not conclusive until further tests are completed on rocks with a wider range of petrophysical properties and under the same flow conditions.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104386"},"PeriodicalIF":4.6,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143855202","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":"Assessment of CO2 leakage through existing wells and faults for a prospective storage site in the Southern San Joaquin Basin, California","authors":"Tae Wook Kim,&nbsp;Yunan Li,&nbsp;Arjun H. Kohli,&nbsp;Anthony R. Kovscek","doi":"10.1016/j.ijggc.2025.104381","DOIUrl":"10.1016/j.ijggc.2025.104381","url":null,"abstract":"<div><div>A protocol is demonstrated for assessment of CO₂ leakage through existing wellbores and faults at CO₂ storage sites including pre-existing, plugged-and-abandoned wellbores and Quaternary faults. Total injection at the prospective saline aquifer site in the southern San Joaquin Basin, CA is planned as 12.3 Mt CO₂ with variable annual rates over 18 years followed by 100 years of monitoring. Reservoir simulation optimized CO₂ injection by minimizing the pressure build-up and the overall size of the CO₂ plume. The plume pressure and saturation history are input to one of the reduced order models in NRAP-OPEN-IAM to obtain distributions of potential leakage rates. During leakage assessment, the permeability of the plugged wellbores is assumed to be large (1 mD to 10 mD) to obtain worst-case estimates. Faults are considered to stretch from the surface to the storage zone. Leakage rates to the USDW are found to be negligible and within background expectations. The ratio of cumulative CO₂ mass leaked to injected using the optimized well scenarios is estimated to range from 0.0003% to 0.001% after 118 years. Additionally, leakage rates along Quaternary faults are predicted to be at least an order of magnitude less compared to leakage from the existing wellbores. The various injection well trajectory scenarios show different leakage rates due to the relative location of wellbores within the CO₂ and pressure plumes. In all cases, the amount of CO₂ that leaks relative to what is injected is much less than 1%.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104381"},"PeriodicalIF":4.6,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143851767","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":"CO2 mineralization of kimberlite residues from the Gahcho Kué Diamond Mine, Northwest Territories, Canada","authors":"Duncan T.E. McDonald ,&nbsp;Ian M. Power ,&nbsp;Carlos Paulo ,&nbsp;Sasha Wilson","doi":"10.1016/j.ijggc.2025.104376","DOIUrl":"10.1016/j.ijggc.2025.104376","url":null,"abstract":"<div><div>Kimberlite residues generated at diamond mines have the potential to substantially reduce net greenhouse gas emissions and contribute towards carbon-neutral mining. As part of the De Beers CarbonVault™, we conducted experiments using fine kimberlite residues from the Gahcho Kué Diamond Mine, Northwest Territories, Canada, to assess the mine's potential for CO₂ sequestration. Batch CO₂ leach tests indicate a CO₂ sequestration potential of 12 kg CO₂/t based on easily extractable cations from non-carbonate sources. However, an evaluation of the short-term reactivity of the residues post-deposition revealed the ability to sequester 0.86 kg CO₂/t when residues were allowed to dry through optimal water saturation (30–40 %). Furthermore, year-long weathering columns determined a CO₂ removal rate of 0.63 kg CO₂/t/yr, primarily through mineral trapping. Extrapolating these rates to current annual residue production and emissions indicates that 7 % of the mine's estimated CO₂e emissions could be sequestered over the life of mine. These rates are based on optimal storage conditions that keep residues exposed for long periods, which should be a consideration of residue management practices during the operating life of the mine and post closure. Further on-site investigations are necessary to refine rates and account for climatic conditions. Assessments conducted in this study affirm the suitability of Gahcho Kué residues for CO₂ sequestration and present strategies for optimizing this process.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104376"},"PeriodicalIF":4.6,"publicationDate":"2025-04-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143844265","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":"Investigating radiocarbon isotope anomalies in CO2 for CCS monitoring: Insights from the Aquistore project and the influence of coal mine spoils","authors":"Nadia Tarakki,&nbsp;David Risk","doi":"10.1016/j.ijggc.2025.104378","DOIUrl":"10.1016/j.ijggc.2025.104378","url":null,"abstract":"<div><div>The radiocarbon isotope of CO₂ (Δ¹⁴CO₂) is a valuable tool for investigating soil-respired CO₂ and identifying its sources. At Aquistore, a CCS project in Canada, Δ¹⁴CO₂ is incorporated into surface soil-gas geochemical MMV studies to demonstrate the absence of surface impacts from CO₂ injection. However, some monitoring locations consistently show negative Δ¹⁴CO₂ values (usually indicative of fossil CO₂) that predate CO₂ injections, suggesting these anomalies are natural or linked to soil disturbances. This study investigates the origins of these anomalies. We first hypothesized that CO₂ venting from coal seams underlying parts of the monitoring grid could explain the negative values. A spatial correlation between negative Δ¹⁴CO₂ values, historic open-pit coal mines, and mine spoils supported this hypothesis. However, Δ¹⁴CO₂ analysis from a nearby farm (control site) with intact coal seams but no mine spoils showed modern-age signatures (6.8 ± 16 %), ruling out the venting hypothesis. Next, we tested whether microbial decomposition of weathered coal fragments was responsible. A soil survey revealed a strong correlation between coal fragment concentrations (1.85–40.64 % w/w) and Δ¹⁴CO₂ anomalies. Laboratory incubation experiments further supported this hypothesis, showing that dry soils with weathered coal fragments produced proportionately negative Δ¹⁴CO₂ values, likely due to microbial activity. These findings underscore the need for a more nuanced and site-specific approach to CCS monitoring. In geochemically complex sites like Aquistore, relying solely on Δ¹⁴CO₂ may be misleading, and alternative tracers should be considered to ensure accurate soil-gas anomaly interpretations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104378"},"PeriodicalIF":4.6,"publicationDate":"2025-04-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143847900","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":"Rock mechanical testing of core from the Eos Northern Lights CCS confirmation well and implications for the Geomechanics of North Sea CO2 storage","authors":"L. Griffiths ,&nbsp;N. Thompson ,&nbsp;H. Smith ,&nbsp;E. Skurtveit ,&nbsp;L. Grande","doi":"10.1016/j.ijggc.2025.104371","DOIUrl":"10.1016/j.ijggc.2025.104371","url":null,"abstract":"<div><div>This study presents and analyses the results of rock mechanical testing of sandstone and shale samples from the CO₂ storage confirmation well 31/5–7 (Eos) in EL 001 in the North Sea. Although detailed experimental laboratory programs are performed for many hydrocarbon development projects in the North Sea, only a limited number of site-specific experimentally-derived mechanical data are available in the literature. The tested samples included sandstone from the Cook (2680.25–2680.5 m) and Johansen (2761.00–2761.25 m and 2725–2725.25 m) formations, and shale from the Intra-Drake Formation (2592.00–2595.18 m). For each of the sandstones, Brazilian tests, three drained isotropically-consolidated (CID) triaxial tests, one hydrostatic test, and one anisotropically-consolidated uniaxial strain test (CAUST) were performed. For the shale, the testing comprised four permeability tests conducted on both vertical and horizontal plugs, five undrained isotropically-consolidated triaxial tests (CIU; three on vertical plugs and two on horizontal plugs), seven Brazilian tests (on four horizontal and three vertical plugs), and a uniaxial strain test (CAUST). The tests were designed to characterize the mechanical behaviour of the reservoir and cap rocks within stress and strain regimes relevant to CO₂ injection scenarios. Measurements of the elastic and poroelastic properties, strength, failure criteria, and permeability are provided, including an assessment of the mechanical and hydraulic anisotropy in the case of the shale samples. The data, accessible through CO2Datashare (Northern Lights JV, 2023), significantly enhance the understanding of North Sea lithologies and supply critical parameters for accurately modeling the geomechanical response of the reservoir and overburden in response to CO₂ injection.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104371"},"PeriodicalIF":4.6,"publicationDate":"2025-04-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143839642","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}