Journal of Natural Gas Science and Engineering最新文献

{"title":"The role of storage systems in hydrogen economy: A review","authors":"T. Amirthan,&nbsp;M.S.A. Perera","doi":"10.1016/j.jngse.2022.104843","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104843","url":null,"abstract":"<div><p><span><span>An economy based on hydrogen is widely regarded as the potential successor of the fossil-fuel-driven present energy sector. One major obstacle in developing the hydrogen economy<span><span> is the suitable storage systems for different applications. This article presents an overview of the role of different storage technologies in successfully developing the hydrogen economy. It reviews the present state of various </span>hydrogen storage systems from the surface and </span></span>underground storage<span><span> methods, their applications, and the associated scientific challenges. The integration of renewable energy in existing energy infrastructure requires developing suitable storage solutions along the energy supply chain. Large-scale seasonal hydrogen storage can be achieved through a subsurface geologic medium such as salt caverns, depleted </span>hydrocarbon reservoirs<span>, aquifers and hard rock caverns<span>. The suitability of the geostructures depends on the desired storage cycles, capacities, and purity of stored hydrogen. The storage of hydrogen for stationary and mobile applications according to end user demands, generally less in capacity and requiring rapid storage cycles, is facilitated by surface storage methods. The physical storage of hydrogen is trapping it in vessels in its different physical states, such as compressed gaseous, cryogenic and cryo-compressed forms. Material-based storage of hydrogen is by adsorbing or absorbing hydrogen using solid-state materials. The performance of surface storage technics is characterized by gravimetric and volumetric densities, storage uptake and release kinetics, the cost involved, and operational safety. The technical insights of each storage technology are presented with recommendations and relevant fields of applications. No storage technic in its ideal conditions can be considered the best fit for all the applications, and each technic requires intense work to become acceptable for </span></span></span></span>energy application.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104843"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1826670","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Methane foam performance evaluation in water-wet unconsolidated porous media: A systematic experimental investigation at elevated pressure and temperature conditions","authors":"Si Le Van ,&nbsp;Magda Ibrahim Youssif ,&nbsp;Alvinda Sri Hanamertani ,&nbsp;Keerti Vardhan Sharma ,&nbsp;Omar Elkhatib ,&nbsp;Kaustubh Rane ,&nbsp;Yun Xie ,&nbsp;Alolika Das ,&nbsp;Mohammad Piri ,&nbsp;Amit Katiyar ,&nbsp;Nagi Nagarajan","doi":"10.1016/j.jngse.2022.104835","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104835","url":null,"abstract":"<div><p>In the petroleum industry<span>, enhanced oil recovery (EOR) techniques employ foam extensively to establish conformance control in heterogeneous and fractured reservoirs in order to increase the sweep efficiency. In such applications, foam performance evaluation under complex subsurface conditions is pivotal for the effective and optimized deployment of foam treatment. However, there is a scarcity of hydrocarbon gas foam generation and evaluation studies that examine the relationships between foam performance and the critical foam parameters at high-pressure and high-temperature conditions.</span></p><p><span>This study aims at methodically investigating the effects of several foam parameters on methane foam performance in water-wet proppant packs<span><span><span> under harsh operating conditions. This is in relation to the technical needs of hydrocarbon foam injection into hydraulically-induced, propped fractures in unconventional oil reservoirs. To this end, a state-of-the-art experimental foam generation apparatus was designed, fabricated, and commissioned. We performed a large number of foam flow experiments on proppant packs using methane gas and different foaming agents at 3500 psi and 115 °C. Anionic and amphoteric surfactants were employed to probe the effect of their ionic nature on foam performance. Foam performance sensitivities to various foam generation parameters and operating conditions, such as surfactant concentration, gas fraction, total </span>injection rate, operating pressure, </span>salinity<span><span>, and proppant pack length were investigated. To this end, steady-state pressure drops across the proppant packs during foam generation and foam's apparent viscosity were measured to quantify the foam performance of surfactants. The results were then analyzed to determine optimum values of the foam parameters and the </span>interplay between these parameters are discussed here. The systematic results achieved from this work are in agreement with the trends available in the literature and provide new insights into complexities of in situ foam generation in water-wet, unconsolidated </span></span></span>porous media at extreme reservoir conditions.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104835"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3270823","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Capillary trapping characteristics of CO2 sequestration in fractured carbonate rock and sandstone using MRI","authors":"Ying Teng ,&nbsp;Pengfei Wang ,&nbsp;Heping Xie ,&nbsp;Jianbo Zhu","doi":"10.1016/j.jngse.2022.104809","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104809","url":null,"abstract":"<div><p>Capillary trapping is a prominent short-term trapping mechanism that achieves the maximum storage capacity and ensures the integrity of CO₂<span><span><span> sequestration in deep saline aquifers on an industrial scale. To maximize capillary trapping, fluid injection scenarios need to be investigated, and the fluid flowing characteristics in porous reservoir media need to be acknowledged. In this study, </span>magnetic resonance<span><span><span> imaging (MRI) technology was used to examine the distribution of three fluid pairs in fractured </span>carbonate rock and sandstone under reservoir conditions, and the </span>relative permeability<span> and capillary pressure<span> were determined based on their capillary end saturation profiles. The initial </span></span></span></span>gas saturation<span><span><span> increased with the injection rate<span>, and the fractured structure created a preferential flow channel that affected the </span></span>saturation distribution. Differences in interfacial tension and </span>wettability lead to different capillary pressures. The low interfacial tension of the scCO</span></span>₂/water fluid pair and its strong water-wet properties in sandstone caused high relative permeability and residual gas saturation. These results imply that the influence of the fluid injection method and reservoir properties on capillary trapping characteristics should be investigated in detail before implementing CO₂<span> geological sequestration.</span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104809"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"2631314","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Research progress of the kinetics on natural gas hydrate replacement by CO2-containing mixed gas: A review","authors":"Xuemin Zhang ,&nbsp;Shanling Zhang ,&nbsp;Shaoqi Yin ,&nbsp;Guanyu HE ,&nbsp;Jinping Li ,&nbsp;Qingbai Wu","doi":"10.1016/j.jngse.2022.104837","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104837","url":null,"abstract":"<div><p>A clear understanding of the replacement characteristics and kinetic mechanism of CO₂–CH₄<span> hydrate has great significance for natural gas hydrate (NGH) exploitation. This paper presents a comprehensive overview on the research progress of kinetics on CH</span>₄ recovery from NGH by CO₂ replacement, especially with CO₂-containing mixed gas. The promoting effect of small molecule gas such as H₂ and N₂ on the replacement process of CO₂–CH₄ hydrate and its internal mechanism are deeply analyzed. Furthermore, based on the current conclusions obtained, the existing problems and future development directions of the CH₄ recovery from NGH by CO₂-containing gas mixture are pointed out.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104837"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3137327","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Improved method and practice for site selection of underground gas storage under complex geological conditions","authors":"Wenpeng Guo ,&nbsp;Bo Zhang ,&nbsp;Yongtu Liang ,&nbsp;Rui Qiu ,&nbsp;Xuemei Wei ,&nbsp;Pengtao Niu ,&nbsp;Haoran Zhang ,&nbsp;Zhuochao Li","doi":"10.1016/j.jngse.2022.104813","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104813","url":null,"abstract":"<div><p>Increasing attention has been paid to the site selection of Underground Gas Storage<span> (UGS) due to the growing demand for natural gas peak shaving. Existing studies have made a practical contribution to this field based on the multidimensional geological exploration<span> data and the multi-criteria decision-making method. However, previous studies mainly focused on screening or ranking technologies with different principles, which means only the attributes of UGS in the design period were considered while the performance in the operation period was ignored. The operation plan and economic performance are considerable concerns to the UGS investors especially when this type of storage facility was unbundling from other sectors in natural gas companies. To solve the UGS site selection problems more comprehensively and practically, the geological conditions and the injection &amp; extraction plan in the operation period are considered Simultaneously. A case from the S-X area in China indicates that: 1. The improved multi-period optimization model of the natural gas (NG) supply chain can obtain the injection and production plan of UGS which are the basic parameters for the economic analysis. 2. The top potential UGS estimated by geological conditions may take inferior performance in the operation stage (less peak shaving amount, low economic profits, and high freight of NG supply chain), so the UGS investors should consider the potential profits when the finished UGS is put into operation. The proposed framework can be a new theoretical guideline for the site selection problems of UGSs and can help UGS investors judge their investment.</span></span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104813"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3453544","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A thermo-hydro-chemo-mechanical coupled model for natural gas hydrate-bearing sediments considering gravity effect","authors":"Zhigang Ye ,&nbsp;Lujun Wang ,&nbsp;Bin Zhu ,&nbsp;Haibing Shao ,&nbsp;Wenjie Xu ,&nbsp;Yunmin Chen","doi":"10.1016/j.jngse.2022.104823","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104823","url":null,"abstract":"<div><p><span><span>Natural gas hydrates<span> have attracted many attentions recently as a promising energy, the exploitation of which will cause complicated multifield coupled behavior of hydrate-bearing sediments. As sediments usually vary from tens to hundreds of meters, the gravity effect on gas-liquid migration and soil deformation may not be completely ignored. This paper develops a new thermo-hydro-chemo-mechanical model to investigate the sediment behavior during the hydrate dissociation<span>. The equations of gas-liquid migration are numerical solved with explicit incorporation of hydrate dissociation process. The numerical stability and efficiency have been improved by expanding the Taylor series of the source terms and making the first-order approximation. Furtherly, pre-calculation procedures have been considered to obtain the initial state of field variables. Pilot-scale model results show that the gas-liquid migration, soil deformation and NGH dissociation are accelerated when the gravity effect is present. During the exploitation, a dissociation front can be observed, and gas-liquid migration and hydrate dissociation dominate the process alternatively, leading to first decrease and subsequent increase of </span></span></span>gas saturation and continuous rise of </span>liquid saturation<span>. Moreover, it is inferred that marginal enhancement of gas production can be achieved with the increase of wellbore lengths, but it should not exceed 75% of the reservoir thickness.</span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104823"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3271725","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dual mechanisms of matrix shrinkage affecting permeability evolution and gas production in coal reservoirs: Theoretical analysis and numerical simulation","authors":"Tiantian Zhao ,&nbsp;Hao Xu ,&nbsp;Dazhen Tang ,&nbsp;Peng Zong","doi":"10.1016/j.jngse.2022.104844","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104844","url":null,"abstract":"<div><p><span>Matrix shrinkage is a factor that must be considered in the dynamic permeability model of coal reservoirs. The mechanism of matrix shrinkage affecting confining pressure (confining pressure mechanism) has been modeled by analogy with thermal expansion, and it is widely used in permeability model construction. However, the mechanism of matrix shrinkage affecting porosity (porosity mechanism) has not been widely recognized and modeled, and this mechanism independently controls porosity even though neither confining pressure nor </span>pore pressure<span> changes (only the replacement of different adsorbed gases occurs). The porosity mechanism and a permeability model that takes into account the dual mechanism have been modeled recently. This study compares the two mechanisms of matrix shrinkage by theoretical analysis of the mathematic relations in the permeability models considering different mechanisms and by finite element numerical simulations of coalbed methane<span> development considering different mechanisms. Theoretical analysis shows that the effect of the porosity mechanism on permeability is more than 1.5 times that of the confining pressure mechanism. the numerical simulations results show that: considering the porosity mechanism and the confining pressure mechanism simultaneously allows for a larger and earlier improvement in permeability and a larger reservoir area to improve, and a significant improvement of 28% in gas production rate occurs compared with the case only the confining pressure mechanism were considered. This study reveals the importance of porosity mechanism in describing the dynamic evolution of reservoir permeability and production dynamics accurately, and provides a scientific basis for coalbed methane development.</span></span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104844"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1813507","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental study on stress and permeability response with gas depletion in coal seams","authors":"Beichen Yu ,&nbsp;Dongming Zhang ,&nbsp;Kui Zhao ,&nbsp;Bin Xu ,&nbsp;Jiabo Geng ,&nbsp;Chongyang Wang ,&nbsp;Yu Chen","doi":"10.1016/j.jngse.2022.104824","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104824","url":null,"abstract":"<div><p><span><span>The gas extraction environment in </span>coal seam<span><span> exhibits uniaxial strain condition with constant overlying strata stress and horizontal strain. Simulating this environment in laboratory often ignores true triaxial stress state, so the difference in horizontal stresses reduction and the accompanying permeability evolution remain ambiguous. Therefore, this study conducted the true triaxial stress and permeability response tests simulating gas extraction environment under shallow and deep in-situ stress conditions. To quantify </span>gas adsorption effect, the adsorbed (CO</span></span>₂) and non-adsorbed (He) gases were also used. The results indicated that the intermediate and minimum principal stresses, i.e., <em>σ</em>₂ and <em>σ</em>₃, exhibited a linear decreasing trend during gas depletion, but showed more decreases in stress when the intermediate and minimum principal strains, i.e., <em>ε</em>₂ and <em>ε</em>₃<span>, recover under high gas pressure depletion. High true triaxial stress enhanced the compressibility of pores and fractures in coal, resulting in low horizontal deformation and stress reduction gradient during gas depletion. Similarly, the reduction gradient of </span><em>σ</em>₂, <em>m</em>_{<em>σ</em>2,} was less than that of <em>σ</em>₃<span>. This suggested that the difference between horizontal stresses also increased during coalbed methane (CBM) extraction, which exacerbated the risk of coal body damage. For different gas depletion, the stress reduction gradient exhibited </span><em>m</em>_He &lt; 1 and <em>m</em>_CO2<span> &gt; 1, which was related to the relative affinity of different gas species for the adsorption medium. A significant matrix shrinkage effect resulted in a more pronounced stress reduction. For permeability, the permeability increased exponentially during CO</span>₂<span><span> depletion, while the permeability of helium exhibited a decreasing followed by an increase with decreasing gas pressure. This is related to the competing mechanism and synergistic effect of the adsorptive gas desorption, effective stress effect, and </span>slippage effect<span>. We quantified the contribution and mechanism of the three to the permeability separately. The permeability anisotropy ratio (</span></span><em>A</em>_r) decreased exponentially during gas depletion.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104824"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3271723","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Machine learning for drilling applications: A review","authors":"Ruizhi Zhong ,&nbsp;Cyrus Salehi ,&nbsp;Ray Johnson Jr","doi":"10.1016/j.jngse.2022.104807","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104807","url":null,"abstract":"<div><p>In the past several decades, machine learning has gained increasing interest in the oil and gas industry<span><span>. This paper presents a comprehensive review of machine learning studies for drilling applications in the following categories: (1) drilling fluids; (2) drilling hydraulics; (3) </span>drilling dynamics; (4) drilling problems; and (5) miscellaneous drilling applications. In each study, the machine learning algorithm(s), sample size, inputs and output(s), and performance are extracted. In addition, similarities of studies in each category are summarized and recommendations are made for future development.</span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104807"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1696553","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental study on alleviating water-blocking effect and promoting coal gas desorption by gas wettability alteration","authors":"Liang Wang ,&nbsp;Bo Wang ,&nbsp;Jintuo Zhu ,&nbsp;Xiaoxue Liao ,&nbsp;Sijia Ni ,&nbsp;Siliang Shen","doi":"10.1016/j.jngse.2022.104805","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104805","url":null,"abstract":"<div><p><span><span>To alleviate the water-blocking effect in the hydraulic fracturing process and promote </span>coal seam<span> gas extraction, the influence of gas </span></span>wettability<span><span><span> alteration on the water-blocking effect and gas desorption was investigated. First, according to the contact angle, infrared spectrum, and </span>surface energy<span> measurement experiments, 3.5% polyacrylamide (PAM) was selected as the gas wettability alteration agent and used to treat the coal samples. After treatment with PAM, the hydroxyl and surface energy of the coal decreased, which altered the gas wettability. Second, the water injection desorption experiment results show that both 4% alkyl polyglucoside (APG) and 3.5% PAM solution can alleviate the water-blocking effect and promote coal gas desorption during water injection. The same experiment was performed by varying the gas pressure. When the gas pressure exceeds 3.25 MPa, APG inhibits gas desorption, indicating that it is unsuitable for alleviating the water-blocking effect. Furthermore, the mechanism by which gas wettability alteration relieves the water-blocking effect was analyzed from macroscopic and microscopic perspectives. Macroscopically, PAM had a high removal rate of the liquid-phase retention effect in coal and can hardly be retained in coal. Microscopically, after gas wettability alteration, the number of </span></span>hydrophilic<span> functional groups on the surface of coal decreased. The above results in the system changing from hydrophilic to hydrophobic, and correspondingly, the capillary pressure in pores or fractures of coal changes from resistance to a driving force. Therefore, compared with the original coal sample, the water in the coal is more likely to flow back, which alternates the water-blocking effect and promotes gas desorption. This study provided a laboratory prediction method for verifying the effects of gas wettability alteration agents on coal gas extraction.</span></span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"108 ","pages":"Article 104805"},"PeriodicalIF":4.965,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3137328","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}