Gas Science and Engineering最新文献

{"title":"Long-term effects of hydrogen and brine on the geomechanical properties of Berea sandstone– An experimental study","authors":"Sugan Raj Thiyagarajan,&nbsp;Hossein Emadi,&nbsp;Athar Hussain,&nbsp;Diana Maury Fernandez,&nbsp;Ion Ispas,&nbsp;Steven K. Henderson,&nbsp;Marshall Watson","doi":"10.1016/j.jgsce.2025.205628","DOIUrl":"10.1016/j.jgsce.2025.205628","url":null,"abstract":"<div><div>The successful implementation of Underground Hydrogen Storage (UHS) in the energy system requires extensive laboratory and field-scale studies. To date, most experimental investigations on UHS have primarily focused on microbial and geochemical effects. However, limited knowledge exists regarding the potential geomechanical changes resulting from interactions between hydrogen, brine, and host rock in depleted oil and gas reservoirs. This study examines the impact of hydrogen (H₂) and brine on the physical and geomechanical properties of Berea sandstone. Cylindrical core samples (7.5 cm in length, 3.81 cm in diameter) were treated with brine, brine + H₂, and H₂ at 10 MPa and 60 <span><math><mrow><mo>°C</mo></mrow></math></span> for 3 and 6 months. Porosity, permeability, and ultrasonic velocities were measured before and after treatment, followed by triaxial compression tests. Results indicate a minimal decrease in porosity and permeability, with inconsistencies in ultrasonic velocities. Strength and static elastic properties exhibited a slight increase across all treatment conditions, except for two samples in 3 months, which showed a minor decrease. These findings suggest that hydrogen and brine have negligible effects on the geomechanical properties of sandstones, supporting the stability and viability of UHS in depleted reservoirs as a long-term energy storage solution.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205628"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143826205","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":"Numerical investigation of the storage efficiency of impure CO2 in faulted sandstone aquifer","authors":"Li Liu ,&nbsp;Guangrong Jin ,&nbsp;Haiyun Ma ,&nbsp;Lihua Liu","doi":"10.1016/j.jgsce.2025.205620","DOIUrl":"10.1016/j.jgsce.2025.205620","url":null,"abstract":"<div><div>Co-injection of CO₂ with common impurities into sandstone saline aquifer is an economical strategy for reducing carbon emission. However, we still have limited knowledge about the storage of gas mixture in faulted reservoirs. To assess the feasibility of co-injection in a faulted reservoir, a two-dimensional radial model referring to the Ordos Shenhua CCS site was developed to numerically investigate the migration and storage efficiency of impure CO₂ in a faulted saline aquifer. The results indicated that the fault altered the distribution of CO₂, and its permeability negligibly impacted the storage efficiency. The impurity and formation slope accelerated the CO₂ migration. The breakthrough of CO₂ was delayed and the partitioning of CO₂ and impurity was significant while the impurity concentration and formation slope increased. The impurity lowered the storage efficiency, and the decline became more evident with the increasing concentration of impurity. Moreover, N₂ could be a suitable tracer to predict leakage in sandstone saline aquifer since the hysteresis of the breakthrough time between CO₂ and N₂ was obvious. This study provides insights into impure CO₂ injection in faulted saline aquifer and is crucial for site selection and long-term risk assessment of the storage system.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205620"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143807847","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":"Multivariate information fusion modeling method and its application in seismic pre-stack inversion of shallow gas reservoir","authors":"Hao Li,&nbsp;Luping Sun,&nbsp;Xiangchun Wang","doi":"10.1016/j.jgsce.2025.205615","DOIUrl":"10.1016/j.jgsce.2025.205615","url":null,"abstract":"<div><div>Shallow gas, recognized as a clean energy source with significant reserves, has attracted increasing attention in recent years. Due to its shallow burial and weak diagenesis, exploration and development are difficult, necessitating advancements in geophysical prediction techniques. The South China Sea is one of the most important shallow gas resource areas in China, with studies revealing that the cumulative thickness of the shallow gas layer in the study area reaches hundreds of meters. However, exploration of shallow gas often encounters challenges including low exploration degree, limited and uneven well information, and strong lateral heterogeneity. This study proposes a multivariate information fusion modeling method, which integrates the seismic velocity field, regional compaction trends, and well-log data to construct a more geologically reasonable initial model of seismic inversion. This method effectively incorporates the lateral seismic information while accounting for regional compaction variations vertically and integrating the sparse, localized drilling data. The pre-stack seismic simultaneous inversion results demonstrate that our method significantly improves the prediction accuracy of shallow gas reservoirs in the study area, providing new insights and technical support for oil and gas exploration. This study emphasizes the potential of seismic inversion driven by multi-information fusion modeling, which can effectively identify favorable shallow gas reservoirs and has broad applicability in similar geological settings.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205615"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816339","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":"Evaluation of interactions between sandstone, basalt, and granite with CO2 and water based on in-situ pH measurement and geochemical simulation","authors":"Yuna Cai ,&nbsp;Diansen Yang ,&nbsp;Hongwu Lei ,&nbsp;Quan Xue ,&nbsp;Yuyi Liu","doi":"10.1016/j.jgsce.2025.205619","DOIUrl":"10.1016/j.jgsce.2025.205619","url":null,"abstract":"<div><div>As CO₂ geological utilization and storage becomes a promising strategy for reducing excess CO₂, the interactions among host rock, groundwater, and CO₂ become an inevitable process that demands careful consideration. Despite considerable research on this process, few studies have monitored the in-situ pH evolution of the rock-CO₂-water system under high pressure and temperature and integrated these findings with numerical models to deduce the underlying mechanisms. In this study, four different rock-CO₂-water interaction experiments under conditions of 15 MPa and 50 °C, equipped with spectroscopic in-situ pH measurement, are carried out, and the water chemistry and mineral compositions are also determined. Validated geochemical models are then established to investigate the long-term interaction characteristics and identify the controlling reactions in different systems. The results show that pH variations of the sandstone and granite-contained system are mainly controlled by the dissolution of carbonate minerals, while the dissolution of diopside dominates pH in the basalt-contained system. Consequently, pH stabilization occurs significantly ahead of the system's interaction equilibrium. Moreover, the long-term interactions within these systems exhibit obvious stage characteristics, driven by the varying reactivities of the minerals involved. The carbon mineralization potentials of different rock samples are assessed afterwards, with basalt demonstrating superior performance, followed by sandstones, whereas granite exhibits no capacity for carbon fixation. This work provides new experimental data and offers insights into the mechanisms governing rock-CO₂-water interactions. It is hoped that these findings will provide new perspectives on the experimental and simulation approaches, as well as deepen the mechanistic understanding of rock-CO₂-H₂O interactions in the context of CO₂ geological utilization and storage.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205619"},"PeriodicalIF":0.0,"publicationDate":"2025-04-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143835230","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":"Challenges of high temperature on ultrasonic propagation in coal reservoirs: Insights from moisture desorption and fissure expansion","authors":"Junjun Feng ,&nbsp;Shigeng Li ,&nbsp;Yankun Ma ,&nbsp;Yuanfang Qu ,&nbsp;Qisong Huang ,&nbsp;Houcheng Ding","doi":"10.1016/j.jgsce.2025.205616","DOIUrl":"10.1016/j.jgsce.2025.205616","url":null,"abstract":"<div><div>Ultrasonic logging technology is an important tool for geophysical exploration in deep coalbed methane (CBM) reservoirs. However, the technology faces significant challenges in the high temperature environment, mainly due to the thermally induced effects of moisture desorption and fissure expansion. This study aims to address these challenges by elucidating the influencing mechanism of moisture desorption and fissure expansion on ultrasonic propagation and developing a theoretical model for ultrasonic wave propagation in high temperature coal reservoirs. Ultrasonic tests were conducted under high temperature conditions based on the temperature range of deep coal reservoirs. The results show that elevated temperature significantly promotes moisture desorption from coal. As the temperature increases from 30 °C to 70 °C, the amount of moisture desorbed during the rapid stage increases by 60 %, while the desorption time decreases by 56 %. In addition, the moisture desorption process is accompanied by continuous contraction strain and fissure expansion, with the total number of coal fissures increasing by 156 %, and the proportion of small-scale fissures (&lt;100 μm) growing from 76 % to 90 %. In addition, the ultrasonic wave velocity decreases with moisture desorption, and the ultrasonic attenuation coefficient shows a continuously increasing trend. Finally, the mechanisms of moisture desorption and fissure expansion have been elucidated, and a model for the ultrasonic propagation in high temperature coal reservoirs has been established. The results of this study provide a theoretical basis for addressing the challenges of ultrasonic logging technology encountered in deep, high temperature CBM exploration.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205616"},"PeriodicalIF":0.0,"publicationDate":"2025-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816341","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":"Assessing storage, flow, and production of hydrogen in shale reservoirs with tree-like fractures: A quadruple-domain approach","authors":"Marembo Micheal ,&nbsp;Haiyan Zhu ,&nbsp;Shijie Chen ,&nbsp;Peng Zhao ,&nbsp;Fengshou Zhang ,&nbsp;Daobing Wang","doi":"10.1016/j.jgsce.2025.205618","DOIUrl":"10.1016/j.jgsce.2025.205618","url":null,"abstract":"<div><div>The heterogeneity of the pore size distribution and predominance of nanopores in shale reservoirs are one of the primary reasons for reduced storage and flow after hydraulic fracturing. Underground hydrogen storage capacity is influenced by the availability of micropores and mesopores, which are not sufficiently interconnected to facilitate effective flow. Besides, shale reservoirs experience changes in their properties at different scales which affects storage, flow and production of gas. A model with multiscale domains is crucial to gain an in-depth understanding of the sorption behavior and the interconnection between the matrix and fracture. Using finite element method, an improved storage and flow model is conducted to simulate the storage, flow, and recovery mechanism of hydrogen across various scales of the shale reservoir based on field data from Chang 7 shale member, Ordos Basin. Multiple layers increase overall storage capacity by providing additional sorption sites in the inter-layer spaces and tree-like hydraulic fractures break the complexity of network pathways by connecting the matrix network to the production well. Specifically, as temperature increases, dissolved gas transforms into adsorbed gas which later becomes free gas with further increase in temperature. This reduces the storage capacity but improves the flowability of gas which then migrates through the interconnected inorganic matrix, natural crack, tree-like hydraulic fracture, and production well. Tree-like fractures enhance permeability by increasing the contact area, which ultimately improves gas flow and production efficiency. Increasing the width of the fracture, stress sensitivity coefficient, and fracture compressibility drastically reduces the production capacity of the gas reservoir due to the likelihood of fracture closure. This research provides a theoretical framework and reference for storage and production evaluation of hydrogen in depleted shale reservoirs.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205618"},"PeriodicalIF":0.0,"publicationDate":"2025-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143792276","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":"Integrating geological model via A multimodal machine learning approach in shale gas production forecast","authors":"Muming Wang ,&nbsp;Xialin Zhang ,&nbsp;Hai Wang ,&nbsp;Gang Hui ,&nbsp;Shengnan Chen","doi":"10.1016/j.jgsce.2025.205617","DOIUrl":"10.1016/j.jgsce.2025.205617","url":null,"abstract":"<div><div>Machine learning (ML) has achieved great success in production prediction for unconventional shale gas reservoirs. However, these methods mostly rely on the discrete data collected from the wells, such as drilling, completion, and production data. In this study, a multimodal ML approach is proposed to incorporate not only the aforementioned tabular data but also the geological property distribution maps surrounding the production wells. More specifically, a visual parameterization method was applied to preprocess the unstructured data from a 3D geological model to account for the geology properties near the horizontal wells. A comprehensive architecture for a multimodal model was then developed, assimilating a convolutional neural network (CNN) module, an artificial neural network (ANN) module, and a fusion module. The CNN module was established to process and extract high-level information from the visual dataset, while the ANN module was devised to learn from traditional tabular datasets. A fusion module combined and interacted with the data from both modalities. Results have shown that the proposed multimodal model achieved the highest testing R² of 0.828 by integrating the formation maps with tabular datasets, compared to 0.736 from ANN. This is owing to the fact that two wells with similar porosity values measured at well sites could penetrate formations with different qualities along their thousand meters of lateral length. Visual feature analysis indicates that while integrating more property distribution maps generally increases model accuracy, considerable improvement (from 0.736 to 0.816) is achieved by solely incorporating porosity maps.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"139 ","pages":"Article 205617"},"PeriodicalIF":0.0,"publicationDate":"2025-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816340","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":"Size effects on the variation in the pressure of CO2 fracturing device based on material point method","authors":"Yun Feng,&nbsp;Houlu Sun,&nbsp;Wei Liu,&nbsp;Guangjin Wang,&nbsp;Sichen Long,&nbsp;Zhongwen Yue","doi":"10.1016/j.jgsce.2025.205614","DOIUrl":"10.1016/j.jgsce.2025.205614","url":null,"abstract":"<div><div>Safe and efficient blasting techniques are of paramount practical importance, and liquid CO₂ fracturing devices have emerged as an innovative and safer alternative for blasting applications. This study employs the material point method (MPM) to simulate the internal pressure of liquid CO₂ fracturing devices equipped with energy release plates of varying thicknesses (2 mm, 2.5 mm, 3 mm, 3.5 mm, 4 mm). The simulation results are validated against experimental data, thereby demonstrating the feasibility of the approach. Furthermore, based on the observation where high-velocity CO₂ gas exiting through different hole shapes (circular, elliptical, slit) generates turbulence and increases localized pressure, the study reveals that slit-shaped holes produce the highest peak pressures, followed by elliptical and circular holes. An orthogonal test is used to analyze the influence of hole shape and area on the peak pressure outside the fracturing tube. A detailed investigation into the aspect ratios of various hole shapes indicates that an elliptical hole with a 2:1 aspect ratio and a slit-shaped hole yield the most effective results. Damage simulations for rocks fractured by elliptical and slit-shaped fracturing devices were conducted, yielding insights into the fracture range for different hole shapes. The study preliminarily identifies elliptical and slit-shaped holes with a 2:1 aspect ratio as the optimal energy release hole designs for liquid CO₂ fracturing devices, thereby providing a new design framework for their practical application.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"138 ","pages":"Article 205614"},"PeriodicalIF":0.0,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739769","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":"Permeability decline due to fines migration during CO2 injection in sandstones","authors":"A. Keykhosravi ,&nbsp;C. Nguyen ,&nbsp;G. Loi ,&nbsp;T. Russell ,&nbsp;N.N. Zulkifli ,&nbsp;M.I. Mahamad Amir ,&nbsp;A.A. Abdul Manap ,&nbsp;S.R. Mohd Shafian ,&nbsp;A. Badalyan ,&nbsp;P. Bedrikovetsky ,&nbsp;A. Zeinijahromi","doi":"10.1016/j.jgsce.2025.205613","DOIUrl":"10.1016/j.jgsce.2025.205613","url":null,"abstract":"<div><div>One of the key risks for CO₂ storage is injectivity decline. During CO₂ injection, evaporation of the connate brine in the near-wellbore region results in drying-up the rock yielding the influx/backflow of the reservoir brine into the dried-up zone that leads to the accumulation of precipitated salts. Drying the rock also yields the mobilisation, migration, and straining of clay particles. Those phenomena lead to rock permeability decline. We present the results of eight corefloods. The corefloods exhibit intensive fines production at the beginning of injection, followed by a lower rate of fines production rate during the main evaporation period and a gradual decline in fines production during the later stages of evaporation. We also observe an abrupt increase in gas permeability in the middle of the evaporation period and evidence of changing gas pathways after each rock re-saturation and new gas injection.</div><div>The explanation of these observations stems from the three sequential regimes of fines detachment during two-phase displacement, identified in this work: (i) movement of gas-water menisci; (ii) pendular rings of residual water; (iii) dry flux. It was found that, for the conditions of these corefloods, fines detachment is possible in regime (i) only. Fines production during overall injection period is explained by continuous brine evaporation and subsequent transversal menisci advancement during unstable CO₂-water displacement in micro-heterogeneous rocks. Rock permeability for gas declines up to 5 times, while for brine it decreases up to 2.7 times. Typical full evaporation time is up to million pore volumes injected (PVIs). The observed phenomena will lead to significant modification of the mathematical model for CO₂ storage.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"138 ","pages":"Article 205613"},"PeriodicalIF":0.0,"publicationDate":"2025-03-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143724558","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effect of persulfate stimulation on matrix alteration and permeability enhancement of fractured shale: Core-flooding experiments and numerical simulation","authors":"Sen Yang ,&nbsp;Jinhao Yu ,&nbsp;Danqing Liu ,&nbsp;Yilian Li","doi":"10.1016/j.jgsce.2025.205612","DOIUrl":"10.1016/j.jgsce.2025.205612","url":null,"abstract":"<div><div>Persulfate has emerged as a promising oxidative breaker in shale hydraulic fracturing, offering potential advantages over traditional acidizing by combining oxidation and mild acidity to enhance shale permeability. However, the specific reaction pathways and their implications for field applications remain underexplored. In this study, integrated core-flooding experiments and reactive transport modelling were conducted to investigate the mechanisms and efficiency of persulfate stimulation in fractured shale. Results reveal that persulfate triggers coupled geochemical reactions, including carbonate dissolution, pyrite and organic matter oxidation, and clay alteration, leading to controlled pore enlargement and fracture development. Compared with conventional acidizing, persulfate sustains reactions through indigenous reducing minerals, reducing excessive matrix damage while enhancing permeability. The model quantified mineral volume losses (4.40 % calcite, 0.29 % dolomite, 0.16 % pyrite, and 0.76 % organic matter) and predicted secondary precipitation (gypsum, goethite) that may block flow paths, highlighting potential long-term challenges. Further analysis indicates that mineral composition, fracture networks and flow rate critically influence stimulation outcomes. This work provides practical insights for optimizing persulfate treatments, suggesting lower concentrations and controlled injection rates in carbonate-rich, moderately fractured reservoirs to maximize benefits and mitigate clogging risks. Additionally, environmental considerations, such as sulfate scaling and iron hydroxide deposition, are discussed, highlighting the need for research on these byproduct management during production. Overall, this study advances the understanding of persulfate-specific geochemical dynamics, quantifies key reaction products, and offers guidance for its field-scale application as a complementary or alternative stimulation technique to acidizing, contributing to more sustainable and efficient shale gas recovery.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"138 ","pages":"Article 205612"},"PeriodicalIF":0.0,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684607","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}