Geoenergy Science and Engineering最新文献

{"title":"LMAFNet: Lightweight multi-scale adaptive fusion network with vertical reservoir information for lithology identification","authors":"Pengwei Zhang ,&nbsp;Jiadong Ren ,&nbsp;Fengda Zhao ,&nbsp;Xianshan Li ,&nbsp;Yuxuan Zhao ,&nbsp;Cheng Zhang","doi":"10.1016/j.geoen.2025.213762","DOIUrl":"10.1016/j.geoen.2025.213762","url":null,"abstract":"<div><div>Lithology identification is fundamental to stratigraphic evaluation and reservoir characterization, which is crucial for assessing the potential value of oil and gas resources. However, traditional models often demonstrate limited accuracy due to the replication of non-linear relationships and class imbalance issues in well log data. In addressing these challenges, a lightweight multi-scale fusion network (LMAFNet) was proposed to mitigate data imbalance bias and improve lithology identification accuracy. The model integrates lithology vertical reservoir information using multi-scale preprocessing and, through its Multi-Scale Adaptive Module (MSAM), autonomously adapts neuron proportions for varying receptive fields based on lithology data size. Furthermore, the model performance is significantly improved by employing the channel attention mechanism and the focal loss function. To validate the efficacy of our proposed approach, extensive experiments were performed on the Daqing and Xinjiang datasets in China. Experimental results from the Daqing and Xinjiang datasets underscore the model’s superior performance, with accuracies reaching 94.25% and 95.91%, respectively, and marked enhancements in recall and F1 scores. Additionally, the method’s practical application in blind well lithology identification on the Daqing dataset has been validated, demonstrating its adaptability and utility across different production environments. This method merits application and promotion in the domain of lithologic reservoir identification.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213762"},"PeriodicalIF":0.0,"publicationDate":"2025-02-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143508779","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 simulation study of segmented hydraulic fracturing in horizontal wells of fractured hot dry rocks, at the U.S. FORGE site","authors":"Yunlong Cao ,&nbsp;Bo Feng ,&nbsp;Zhenpeng Cui ,&nbsp;Xiaofei Duan ,&nbsp;Jichu Zhao","doi":"10.1016/j.geoen.2025.213790","DOIUrl":"10.1016/j.geoen.2025.213790","url":null,"abstract":"<div><div>Enhanced geothermal systems (EGS) are engineered deep rock heat exchangers that require hydraulic fracturing to create artificial heat storage and transfer heat through fissures. The technique involves a complex heat-fluid-solid (THM) coupling process. In this study, based on the Frontier Observatory for Research in Geothermal Energy (FORGE) site 16A(78)-32 horizontal well in Milford, Utah, USA, a hydraulic fracturing model for horizontal wells, distinct from traditional EGS doublet designs, was established. This model combines the three thermal-fluid-mechanical (THM) physical fields and investigates the impact of injection volume, temperature, and injection sequence on ground rock modification during horizontal well hydraulic fracturing. The results show that after 75 h of enhanced production treatment, the model predicts an increased production volume of approximately 8.3 × 10⁶ m³. Increasing the injection fluid volume stimulates shear fracturing in existing fractures, widening the area of greater production. Changing the injection sequence does not increase the volume of fractured rock. With increasing injection temperature, there is a slight decrease in the modified volume produced.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213790"},"PeriodicalIF":0.0,"publicationDate":"2025-02-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143508777","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":"Research on rock breaking mechanism of rotary-percussion drilling in marine hard rock strata and the influence of engineering and tool parameters on ROP","authors":"Yan Xi ,&nbsp;Junhao Xing ,&nbsp;Jiwei Li ,&nbsp;Hang Wang ,&nbsp;Jun Li ,&nbsp;Gonghui Liu","doi":"10.1016/j.geoen.2025.213781","DOIUrl":"10.1016/j.geoen.2025.213781","url":null,"abstract":"<div><div>Rotary-percussion drilling technology was used to improve drilling efficiency in marine deep hard rock formations, but the compatibility among the engineering &amp; tool parameters, PDC cutter, and the hard rock formation has not been sufficiently studied. In response, a theoretical model of the axial impact hammer motion mechanism under drilling fluid driving conditions was established, and the speed and frequency of reciprocating motion of the hammer were analyzed under different drilling fluid and tool structure parameters. A numerical model of stress waves generated by the axial impact hammer on the base was established, and the variation of stress wave parameters (peak value, duration, etc.) with impact velocity was analyzed. Based on the calculation mentioned above, a numerical model of PDC drilling teeth cutting hard rock formations under the coupling effect of dynamic and static loads during rotary-percussion drilling was established, and the changes in penetration depth, rock damage, and rock debris size under different engineering and tool parameter conditions were analyzed. The research results indicated that as the drilling fluid displacement and density increased, the impact velocity and reciprocating frequency presented linear and nonlinear growth trends, respectively, which was beneficial for increasing the penetration depth, but it would increase the size of rock debris. The impact velocity and reciprocating frequency exhibited a nonlinear decreasing trend as the nozzle diameter increased, leading to decreased penetration depth and reduced size of rock debris. As the diameter of the pressure-bearing ring increased, the penetration depth increased initially and subsequently reduced. The findings could offer a reference for the engineering and tool parameter optimization during rotary-percussion drilling.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213781"},"PeriodicalIF":0.0,"publicationDate":"2025-02-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143527216","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":"The plugging of lost circulation in deep fractured formations: A review","authors":"Honglin Zhang ,&nbsp;Chi Peng ,&nbsp;Jianhong Fu ,&nbsp;Han Zhang ,&nbsp;Tianyi Tan ,&nbsp;Yu Su ,&nbsp;Zhiqiang Hu ,&nbsp;Chong Lin","doi":"10.1016/j.geoen.2025.213789","DOIUrl":"10.1016/j.geoen.2025.213789","url":null,"abstract":"<div><div>Lost circulation in fractured formations represents a significant technical challenge that hinders the safe drilling of deep geothermal and petroleum reservoirs. Improving the once plugging success rate in deep fractured formations is essential to achieve a safe, efficient, and economical drilling. This paper provides an overview of the foundation theory of fluid loss and lost circulation control in fractured formations, introduces the application of various lost circulation materials (LCMs) in the loss control of fractured formation., and elaborates on the experimental devices and methods currently used to study the mechanism of fracture plugging. Disparities among these devices and methods can yield differing evaluation results, potentially leading to more conservative perspectives on fracture plugging. Additionally, it examines the current research status and shortcomings regarding the formation and structural evolution mechanisms of the fracture plugging zone. Focusing on three key aspects—plugging mechanisms, LCMs, and plugging formulations—this study outlines the future directions for the development of plugging technologies tailored for deep fractured formations. These efforts will support the intelligent advancement of plugging technology.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213789"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143508780","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":"Classification evaluation of the suitability of CO2 storage in Saline Aquifers","authors":"Linlin Zhang ,&nbsp;Fengpeng Lai ,&nbsp;Ya Meng ,&nbsp;Zhiping Li","doi":"10.1016/j.geoen.2025.213796","DOIUrl":"10.1016/j.geoen.2025.213796","url":null,"abstract":"<div><div>It is crucial to evaluate the suitability of storing CO₂ in saline aquifers before determining storage locations and implementing efficient CO₂ storage plan. To assess the suitability of CO₂ storage in saline aquifers more quickly and accurately, this study established an evaluation system based on four aspects: salt solution properties, reservoir conditions, cap characteristics, and fault sealing. Grey correlation analysis and the numerical simulation approach were used to identify the primary governing parameters influencing storage effectiveness. Additionally, a categorization system and appropriateness evaluation model for CO₂ storage in saline aquifers were developed. The grading criteria for each influencing factor were defined. The results reveal that: (1) The suitability evaluation index system comprises 9 evaluation factors and 2 evaluation objectives. (2) Reservoir conditions, fault characteristics and saline salinity most significantly influence CO₂ dissolution and sealing capacity. Meanwhile, reservoir permeability, reservoir pressure, cap sealing, and fault characteristics have the greatest impact on CO₂ storage security. (3) By analyzing the relationship between the two evaluation objectives and each index, a comprehensive suitability evaluation factor F was established through weighted summation of the reciprocal of the dissolution storage evaluation factor (R) and storage safety evaluation factor (S) after standardization. (4) Based on F, the suitability of CO₂ storage in saline aquifers can be categorized into three groups: I (0.61–1), II (0.50–0.61), and III (0∼0.50).</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213796"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143511875","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":"A study of high-intensity high voltage electric pulse fracturing - A perspective on the energy distribution of shock waves","authors":"Zhehao Zhang ,&nbsp;Baisheng Nie ,&nbsp;Chao Ma ,&nbsp;Xianfeng Liu ,&nbsp;Yaoqian Li ,&nbsp;Changxing Li","doi":"10.1016/j.geoen.2025.213791","DOIUrl":"10.1016/j.geoen.2025.213791","url":null,"abstract":"<div><div>High voltage electrical pulse is regarded as a new fracturing technology. High voltage electrical pulse under electro-hydraulic conditions produces shock waves to destroy an object. However, the energy generation mechanism of shock waves is still unclear. In this study, image evolution and vibration time-frequency analysis are used to analyze the fracture mode and shock energy action mode of concrete. The high voltage electrical pulse fracturing process produces an intense flash of light. The rise in voltage leads to an increase in peak particle velocity and maximum amplitude. The discharge conditions for concrete fracture were 12 kV and 500 μF. The peak shock waves vibrational energy occurs in the time domain near 0 s, and at a frequency of 1.07 Hz. The energy of shock waves is concentrated in the frequency domain from 0 to 100 Hz. When concrete fractures, the energy of shock waves is shifted in the frequency domain from 0 to 10 Hz. The difference of amplitude integral is 276.14 when the voltage rises from 8 kV to 12 kV.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213791"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143478684","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":"Experimental study on the formation and storage characteristics of CO2 hydrate under condition of grain gradating: Influence of different particle sizes and ratios","authors":"Xuemin Zhang ,&nbsp;Pengyu Li ,&nbsp;Hongbin Song ,&nbsp;Huan Sun ,&nbsp;Wenqiang Cui ,&nbsp;Jinping Li ,&nbsp;Qingbai Wu ,&nbsp;Peng Zhang","doi":"10.1016/j.geoen.2025.213794","DOIUrl":"10.1016/j.geoen.2025.213794","url":null,"abstract":"<div><div>CO₂ sequestration in seabed sediments is considered to be a promising way to reduce CO₂ emissions in atmosphere. The formation characteristics and gas storage capacity of hydrate are the critical indicators for measuring the effectiveness of geological sequestration of CO₂ by hydrate method. In this work, the formation processes and storage characteristics of CO₂ hydrate were studied in porous media composed of two single grain sizes (10 and 63 μm), porous media with grain gradatings (10–90 μm and 63–90 μm) of different mass ratios (30%, 50% and 70%) were further investigated. The influence of different gradation ratios on gas consumption rate and gas storage capacities of hydrate was discussed. The results showed that whether the difference in grain gradating between two mixtures was large or small, the larger the ratios of large grains in porous was, the more favorable for the formation of hydrate. The gas storage capacity is far from the gas storage theoretical upper limit of hydrate in the experiment. And geological transformation is necessary in order to increase the gas storage capacity. The gas storage capacity of hydrate decreased in porous media with grain gradating of 63–90 μm as the ratios of large grains increased. The variation of gas storage capacity was non-linear in porous media with grain gradating of 10–90 μm to a certain degree. Compared to the porous media composed of a single grain size (10 μm and 63 μm), the porous media system with 63–90 μm has an inhibitory effect on hydrate formation. However, the porous media system with 10–90 μm can promote the formation process of hydrate. The relevant results will provide essential theoretical support and guidance for CO₂ geological storage in seabed sediments by hydrate method.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213794"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143508778","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":"Enhanced prediction and uncertainty analysis for hydrogen production rate in depleted oil and gas reservoirs using advanced machine learning techniques","authors":"Zhengyang Du ,&nbsp;Lulu Xu ,&nbsp;Shangxian Yin ,&nbsp;Shuning Dong ,&nbsp;Zhenxue Dai ,&nbsp;Yue Ma ,&nbsp;Hung Vo Thanh ,&nbsp;Mohamad Reza Soltanian","doi":"10.1016/j.geoen.2025.213795","DOIUrl":"10.1016/j.geoen.2025.213795","url":null,"abstract":"<div><div>Climate change has driven a global shift from fossil fuels to renewable energy sources. However, the inherent variability of renewable energy, influenced by temporal and climatic factors, presents significant challenges. Underground hydrogen storage offers a promising solution for retaining surplus energy. The complexity and heterogeneity of geological formations are difficult to accurately quantify, leading to large uncertainties in storage assessment results, and computation of forward modeling for large-scale sites is often time-consuming. This study introduced a numerical modeling framework incorporating the complex geological structures into the uncertainty analysis of formation porosity and permeability. We developed surrogate models to predict the hydrogen storage process using three machine learning (ML) algorithms: Extreme Gradient Boosting (XGBoost), Random Forest (RF), and Support Vector Regression (SVR). The study utilized the Sobol algorithm to examine the impact of variations in porosity and permeability on model output. This study applied and analyzed the numerical modeling framework at Wangjiawan in China. The findings indicated that the average final stability of hydrogen injection mass approximates 1800 tons, with the average production mass of hydrogen reaching approximately 950 tons. The XGBoost model demonstrated excellent predictive performance (R² = 0.9679 and RMSE = 0.0318). Hydrogen production mass and rate are primarily influenced by the permeability of the formations, including injection and production wells during stable periods, while the impact of formation porosity is relatively minor. This study quickly and accurately predicts hydrogen storage processes under different geological parameters by employing ML algorithms. It also evaluates the importance of various geological parameters, providing crucial insights for effectively designing underground hydrogen storage facilities.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213795"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143508776","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":"Quantitative macro and micro analysis on enhanced oil recovery (EOR) mechanisms of multi-component composite steam flooding (MCCSF) based on image recognition algorithm","authors":"Qingjing Hong ,&nbsp;Zhanxi Pang ,&nbsp;Xiaohong Liu ,&nbsp;Bo Wang ,&nbsp;Dong Liu ,&nbsp;Hui Liao ,&nbsp;Luting Wang","doi":"10.1016/j.geoen.2025.213766","DOIUrl":"10.1016/j.geoen.2025.213766","url":null,"abstract":"<div><div>Multi-component composite steam flooding (MCCSF) has emerged as a promising method for enhancing oil recovery (EOR) in heavy oil reservoirs. However, its complex EOR mechanisms remain unclear, and a quantitative evaluation method for production performance in the process has not been established. In this paper, one dimensional (1D) displacement experiments were conducted to measure the oil displacement efficiency (ODE), and the optimal composite mode of multi-components was selected. This was coupled with two dimensional (2D) visualization experiments to investigate the macroscopic and microscopic EOR mechanisms during the process of MCCSF. Image recognition algorithms and image segmentation techniques were introduced to quantitatively analyze the volume of remaining oil (VORO) and the sweep efficiency at different locations during the different displacement stages. The results indicated that the integration of foams and viscosity reducer (VR) significantly improved both sweep efficiency and ODE. Finally, the effective oil production period was obviously extended. The ODE in the 1D experiments reached 76.3%, and the overall sweep efficiency in the 2D visualization experiments reached 97.97%. During pure steam flooding (PSF), the swept area was mainly targeted the near-well zone and the main flow channel. However, after adding foams and a VR for along with steam flooding, the remaining oil in the side channels and corner zones was effectively mobilized, and the ODE in the central swept areas and the displacement front were significantly enhanced, resulting in a final oil recovery factor (ORF) of 74.72%, which was 46.71% higher than that of PSF. This study primarily investigated the EOR mechanisms of MCCSF from two perspectives: improving ODE and sweep efficiency. These findings provided valuable insights and offer a quantitative method for the development effect evaluation.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213766"},"PeriodicalIF":0.0,"publicationDate":"2025-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143488422","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":"Thermal-hydro-mechanical coupled dual-medium model of inclined wellbore in fractured anisotropic formations","authors":"Yi Qiu ,&nbsp;Tianshou Ma ,&nbsp;Jinhua Liu ,&nbsp;Ali.M. Fadhel ,&nbsp;Nian Peng ,&nbsp;Honglin Xu ,&nbsp;P.G. Ranjith","doi":"10.1016/j.geoen.2025.213782","DOIUrl":"10.1016/j.geoen.2025.213782","url":null,"abstract":"<div><div>The deep shale formation exhibits anisotropic and fractured properties. Previous models of shale wellbore stability have primarily focused on fractured or mechanical anisotropies of shale. Furthermore, thermal effects are inevitably considered when drilling deep shale formations. Nevertheless, the instability mechanism of a wellbore under the combined effects of anisotropy, fractures, and thermal-hydro-mechanical coupling is unclear. Thus, based on the assumption of generalized plane strain, anisotropic porothermoelastic theory, and dual-porosity medium theory, this study established a thermal-hydro-mechanical coupled dual-porosity medium model for inclined wellbore considering complete material anisotropy. The finite element formulation was employed to solve this model. Parametric analysis was performed to investigate the effect of dual-porosity medium properties and material anisotropy parameters on effective stress, fracture pore pressure(<em>p</em>^II), and matrix pore pressure(<em>p</em>^I). Through model comparison, the effective stress, pore pressure, and failure zone were observed to be completely different from those of the traditional elastic isotropic dual-porosity medium model and elastic anisotropic single-porosity medium model when subjected to the combined action of influence dual-porosity medium and anisotropy. With the elastic anisotropy index increases, the elastic anisotropic <em>p</em>^I is smaller than the elastic isotropic <em>p</em>^I. The effective stiffness of the rock increases with the elastic anisotropy index, which leads to the generation of ‘negative’ thermal stress, reduces the effective radial stress and hoop stress. When the well inclination exceeds 60°, the evolution of the induced <em>p</em>^I in elastic anisotropy is significantly different from that in elastic isotropy in the X direction, but <em>p</em>^II in is not sensitive to the change of well inclination. When a horizontal well is drilled parallel to the bedding direction, the risk of wellbore shear failure will be reduced for a higher ratio of anisotropy in elasticity, solid thermal expansion, and permeability.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213782"},"PeriodicalIF":0.0,"publicationDate":"2025-02-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143488679","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}