Geoenergy Science and Engineering最新文献

{"title":"Effects of abrasive particles on the kinetic response and damage behavior of PDC cutters","authors":"Zhongzheng Duan ,&nbsp;Wen Yue ,&nbsp;Tian Tang ,&nbsp;Chang Chen ,&nbsp;Dezhong Meng","doi":"10.1016/j.geoen.2025.213841","DOIUrl":"10.1016/j.geoen.2025.213841","url":null,"abstract":"<div><div>The intrusion of rock debris and sand into the PDC bits results in abrasive wear during geo-drilling. A comprehensive study of this wear mechanism is crucial for enhancing the performance and prolonging the service life of PDC cutters. In this study, a kinetic energy-controlled impact wear tester was utilized to systematically investigate the effects of abrasive type and size on the kinetic response and damage behavior of PDCs. The abrasive type had a significant influence on the impact force. The peak impact force decreased by 60.89 %, 72.44 %, and 80.89 % with corundum, quartz sand, and calcite abrasive particles, respectively. The abrasive size was also critical in affecting the dynamic response of PDC cutters. The peak impact force increased by 30.68 % with increasing corundum abrasive size, while the kinetic energy absorption rate decreased by 3.61 %. For quartz sand, the impact force initially rose with the abrasive size and then declined, whereas the kinetic energy absorption rate first decreased and subsequently increased. In contrast, as the calcite abrasive size increased, the peak impact force decreased by 49.41 %, while the energy absorption rate increased by 0.94 %. The PDC surface was damaged by impact and friction wear, primarily in the form of abrasive and adhesive wear. The damage form of PDC is a type of brittle fracture, which includes both intergranular and transcrystalline fractures. This work provides valuable primary research data to understand and optimize the performance of PDC cutters in complex wear environments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213841"},"PeriodicalIF":0.0,"publicationDate":"2025-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679314","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":"Effect of isomorphic substitution of clay mineral layers on CO2 hydrate formation: Insights from molecular dynamics simulation study","authors":"Ruixue Tang,&nbsp;Chenghua Ou,&nbsp;Dongliang Lyu,&nbsp;Cheng Liu,&nbsp;Hengdi Wu","doi":"10.1016/j.geoen.2025.213843","DOIUrl":"10.1016/j.geoen.2025.213843","url":null,"abstract":"<div><div>Hydrate method for CO₂ sequestration is currently regarded as one of the most promising approaches for carbon capture and storage due to its excellent stability and gas storage density. In this study, molecular dynamics simulations were conducted to investigate the impact of isomorphic substitution in clay minerals layers on CO₂ hydrate formation. The results showed that in pyrophyllite structures without isomorphic substitution, a significant number of CO₂ molecules were adsorbed onto the hydrophobic surfaces, hindering the nucleation of CO₂ hydrates in the bulk solution. However, as the degree of isomorphic substitution increased in montmorillonite, the surface charge also increased, leading to greater adsorption of cations. These cations predominantly accumulated on the montmorillonite surface, while CO₂ hydrate nucleation and growth occurred in the bulk solution, away from the clay mineral surface. Furthermore, among layers with the same degree of substitution, K⁺ cations had a lesser impact on CO₂ hydrate nucleation in the bulk solution compared to Na ⁺ cations. This study highlights the significant role of isomorphic substitution in clay minerals layers in governing CO₂ hydrate nucleation by altering the distribution of CO₂ around the clay mineral surface, thereby influencing CO₂ sequestration in marine sediments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213843"},"PeriodicalIF":0.0,"publicationDate":"2025-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143704569","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":"Mechanism of alcohols enhancing CO2-oil miscibility for carbon storage and enhanced oil recovery: Molecular insights","authors":"Shuyang Liu ,&nbsp;Jiayu Chen ,&nbsp;Minfeng Li ,&nbsp;Jie Zhong ,&nbsp;Junrong Liu ,&nbsp;Wenyue Sun","doi":"10.1016/j.geoen.2025.213837","DOIUrl":"10.1016/j.geoen.2025.213837","url":null,"abstract":"<div><div>Carbon capture utilization and storage (CCUS) is considered one of the most promising approaches for carbon neutrality. Thereinto, it is more realistic and feasible to inject CO₂ into hydrocarbon reservoirs for geological storage and simultaneously enhanced oil recovery (CO₂-EOR). CO₂ miscible flooding is far superior to immiscible flooding in storing more CO₂ and producing more oil, but some reservoirs face the challenge of miscible flooding due to a high minimum miscibility pressure (MMP). Facing this issue, this work analyzes the impact of straight-chain (ethanol, pentanol) and branched-chain alcohols (2-pentanol) on the CO₂-oil MMP by employing molecular dynamics simulation for revealing the mechanism of different types of alcohol additives enhancing the CO₂-oil miscibility from the molecular aspects of interaction energies, and radial distribution function (RDF). Results indicate that the studied alcohols can significantly lower the CO₂-oil MMP due to the ‘amphipathicity’ characteristic of oil-philicity and CO₂-philicity. Ethanol has the best effect to enhance miscibility. The molecular structure of alcohols plays a key role in reducing MMP, and straight-chain alcohols are more effective in aggregating CO₂ around their hydroxyl groups, compared to branched-chain alcohols. The hydroxyl groups of straight-chain alcohols are less hindered by spatial constraints, showing stronger affinities with CO₂, thereby more effectively disrupting the cohesion within the oil phase and reducing MMP. The findings of this work provide some new insights into achieving miscible CO₂ flooding and offer guidance on employing suitable alcohol additives to improve the effect of CO₂-EOR.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213837"},"PeriodicalIF":0.0,"publicationDate":"2025-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679316","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":"Advanced source rock characterization integrating pyrolysis, petrophysical logs, and machine learning in the unconventional Cane Creek reservoir, Utah","authors":"Carlos Vega-Ortiz ,&nbsp;David List ,&nbsp;Gregor Maxwell ,&nbsp;Eric Edelman ,&nbsp;Eiichi Setoyama ,&nbsp;Palash Panja ,&nbsp;Michael Vanden Berg ,&nbsp;Elliot Jagniecki ,&nbsp;Brian McPherson","doi":"10.1016/j.geoen.2025.213835","DOIUrl":"10.1016/j.geoen.2025.213835","url":null,"abstract":"<div><div>The Cane Creek clastic interval of the Paradox Formation in the northern Paradox Basin, presents significant challenges and opportunities for hydrocarbon exploration, particularly in its complex lithologic and structural formations. Through the combination of source rock analysis, petrophysical data and machine learning methods, this innovative predictive model aims to identify highly productive hot-spots in moderate fractured dolomitic intervals. The petrophysical logs of gamma-ray, resistivity, density, porosity are processed including a rigorous log quality control, statistical pre-processing, and lithology controls. Results from laboratory pyrolysis measurements indicated TOC values up to 14.5 wt%, with thermal maturity levels assessed through Tmax values spanning from 431 °C to 484 °C. These findings suggest variable maturity and highlight zones conducive to condensate and gas production. Key findings include total organic carbon (TOC) content across various clastic intervals, notably clastics 2, 3, 10 and 21 (Cane Creek), which exhibited significant hydrocarbon generation potential. This study integrates machine learning models, with legacy petrophysical logs to improve source rock characterization. The GPR model demonstrated superior predictive capabilities compared to other ML models such as Regression Tree Models (RTM), Support Vector Machines (SVM), and Neural Networks (NN). While GPR achieved an R-squared of 0.43 and an RMSE of 1.00 during validation, other models showed lower R-squared values and higher errors, underscoring GPR’s reliability for complex geological data interpretation. The integration of petrophysical, geochemical, and mineralogical data identified fractured dolomitic intervals as key targets, supporting enhanced hydrocarbon migration and accumulation and identification of potential hydrocarbon production zones. Furthermore, the ML predictive model is adapted to other wells in the region that lack source rock analysis.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213835"},"PeriodicalIF":0.0,"publicationDate":"2025-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679313","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 water/CO2 flow of tight oil using HTHP microscopic visualization and NMR technology","authors":"Jitian Ren ,&nbsp;Wenlian Xiao ,&nbsp;Qianrui Cheng ,&nbsp;Peng Song ,&nbsp;Xingyu Bai ,&nbsp;Qichao Xie ,&nbsp;Wanfen Pu ,&nbsp;Lingli Zheng","doi":"10.1016/j.geoen.2025.213834","DOIUrl":"10.1016/j.geoen.2025.213834","url":null,"abstract":"<div><div>The visualization of the transport and distribution of multiphase fluids through images is essential for understanding the mechanisms involved in the utilization of crude oil. In this study, we employed microscopic visualization and nuclear magnetic resonance technologies to monitor oil distribution and investigate fluid flow during water and supercritical CO₂ flooding of tight core. The microscopic visualization experiment results indicate that during water flooding, significant viscous fingering occurred due to capillary pressure and an unfavorable mobility ratio, resulting in substantial volumes of contiguous residual oil and blind-end residual oil. In contrast, CO₂ miscible flooding operates through interdependent interactions, facilitating the efficient extraction and displacement of residual oil, with an oil recovery of 93 % and a reduction in residual oil saturation of approximately 30 %. The NMR results demonstrate that the oil recovery of water flooding oil is 28.06 %, which is considerably lower than that of CO₂ flooding, and the crude oil primarily comes from the macropores. We observed that the oil recovery of CO₂ immiscible flooding, near-miscible flooding and miscible flooding yielded 41.35 %, 59.3 % and 66.22 %, respectively. The interaction between oil and CO₂ resulted in a significant increase in oil recovery of macropores, approximately double that of immiscible flooding. As increasing injection pressure of CO₂ flooding, the flow characteristics transition from capillary finger flow to a network flow, reducing residual oil saturation. This transition transforms significant volumes of contiguous residual oil into isolated oil droplets and smaller fragments, while alterations in water distribution characteristics influence CO₂ flow. These findings provide valuable insights for optimizing displacement mechanisms and enhancing oil recovery in tight oil.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213834"},"PeriodicalIF":0.0,"publicationDate":"2025-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143628926","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":"Deep reinforcement learning for optimal hydraulic fracturing design in real-time production optimization","authors":"Bingyang Yan ,&nbsp;Zhi Zhong","doi":"10.1016/j.geoen.2025.213815","DOIUrl":"10.1016/j.geoen.2025.213815","url":null,"abstract":"<div><div>Hydraulic fracturing is a common method for improving oil recovery and plays an essential role in optimizing production and managing reservoirs by creating highly permeable channels in subterranean formations. The conventional optimization process, reliant on numerous iterations of numerical simulations, is notably time-intensive and computationally expensive. We introduce an innovative production optimization method that progressively maximizes net present value (NPV) through sequential decision-making. Specifically, the method dynamically adjusts fracture position, length, width, and height in response to newly acquired data on reservoir properties such as porosity and permeability. We formulate the field production optimization challenge as a Markov decision process, examining the hydraulic fracturing pattern as a sequence of decisions. Proximal policy optimization (PPO), a highly stable deep reinforcement learning (DRL) method, is implemented with a deep convolutional neural network (CNN) as the policy function. This network correlates the current state of the reservoir with the optimal actions for the subsequent step. In our DRL approach to formulating the optimal hydraulic fracture design, we define states by the comprehensive reservoir saturation and pressure fields, while actions are the location and characteristics of new induced fractures. Since the trained policy is an explicit function structure, the DRL agent can adjust the fracture locations and properties in real-time under different reservoir states. Comparative tests against genetic algorithm-based optimizations highlight the efficacy of the proposed method. In addition, the durability of the trained policy is confirmed through its application to an untested scenario, the synthetic 3D shale reservoir, where the average NPV attained by our DRL-based approach is 180% of that achieved with the genetic algorithm. This underscores the promise of incorporating DRL into real-time reservoir management and production optimization.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213815"},"PeriodicalIF":0.0,"publicationDate":"2025-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143643528","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 3D fully coupled numerical model for multi-cluster fracturing with perforation erosion","authors":"Yang Li ,&nbsp;Jiahao Wang ,&nbsp;Di Wang ,&nbsp;Zixian Guo ,&nbsp;Huiying Tang ,&nbsp;Liehui Zhang","doi":"10.1016/j.geoen.2025.213805","DOIUrl":"10.1016/j.geoen.2025.213805","url":null,"abstract":"<div><div>This study introduces a high-performance three-dimensional fully coupled finite element-finite volume model specifically developed to simulate multi-cluster fracturing accompanied by perforation erosion. The model employs precisely capture the complex interactions between wellbore fluid dynamics, fracturing mechanisms, and perforation erosion phenomena. By offering a comprehensive approach to predicting the behavior of multi-cluster fracturing, the model provides profound insights into optimizing hydraulic fracturing operations. The robustness and precision of the model are validated through a benchmark testing and a series of field-scale applications. These validations underscore the model’s potential as a powerful tool for significantly enhancing the efficiency of multi-cluster hydraulic fracturing simulations.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213805"},"PeriodicalIF":0.0,"publicationDate":"2025-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143619212","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":"Interaction of elasticity and wettability on enhanced oil recovery in viscoelastic polymer flooding: A case study on oil droplet","authors":"Huiying Zhong ,&nbsp;Bowen Shi ,&nbsp;Yongbin Bi ,&nbsp;Xiutai Cao ,&nbsp;Hao Zhang ,&nbsp;Chengzhi Yu ,&nbsp;Hongli Tang","doi":"10.1016/j.geoen.2025.213827","DOIUrl":"10.1016/j.geoen.2025.213827","url":null,"abstract":"<div><div>The complex distribution of residual oil, influenced by wettability and low sweep efficiency, presents significant challenges to its effective mobilization. Polymer flooding can increase microscopic sweep efficiency by elastic effect. Despite both elasticity and wettability can achieve enhanced oil recovery, current study of the interaction of elasticity and wettability is still not well understood. In this regard, we further investigate their interaction in improving oil recovery by using simplified oil droplet model. The secondary development of the interFoam solver in OpenFOAM is employed. The simulation results indicate that the initial deformation of oil droplet is not influenced by elastic forces, while by viscous forces. Furthermore, oil displacement efficiency of oil droplet, at strong water-wet condition, increases from 65.61 % to 69.06 % as elasticity (<em>We</em>) increases from 0.1 to 50. This reveals that elasticity promotes oil droplet displacement at water-wet. In contrast, oil displacement efficiency at weak oil-wet decreases from 15.53 % to 11.55 %, which reveals that elasticity inhibits the deformation and flow at oil-wet. Moreover, as elasticity increases, the direction of normal stresses varies from the same as flow direction (strong water-wet), to being an angle to flow direction (weak oil-wet), then to being opposite to flow direction (strong oil-wet). These findings can advance the understanding of the micro-flow mechanisms involved in viscoelastic polymer flooding.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213827"},"PeriodicalIF":0.0,"publicationDate":"2025-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143629006","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":"Two-stage domain adaptation for fracture segmentation in electric imaging logging images","authors":"Qifeng Sun ,&nbsp;Shuang Li ,&nbsp;Yong Zhai ,&nbsp;Faming Gong ,&nbsp;Qizhen Du","doi":"10.1016/j.geoen.2025.213809","DOIUrl":"10.1016/j.geoen.2025.213809","url":null,"abstract":"<div><div>Electric imaging logging images are widely used for fracture identification due to their high resolution and intuitive characteristics, which is helpful in guiding the development of oil and gas resources. Nevertheless, existing fracture identification methods often face challenges in complex geological backgrounds and when training samples are limited. To address these challenges, this paper presents a two-stage fracture identification method for electric imaging logging images based on domain adaptation. In the first stage, a pseudo electric imaging logging data generator (PEDG) including style transfer algorithm is designed to generate an labeled dataset that is realistic and diverse in fracture morphologies, mitigating the problem of insufficient training samples through image-level domain adaptation. In the second stage, a patch-based output space multi-scale adversarial learning network (pOMAL) is proposed. pOMAL employs adversarial learning between the semantic segmentation model and a multi-scale discriminator (MSD), encouraging the segmentation results of real images resemble those of pseudo-images and improving the generalization ability and noise resistance of the segmentation model through output-level domain adaptation. Experimental results demonstrate that the proposed method achieves better fracture segmentation results in complex electric imaging images with limited training samples.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213809"},"PeriodicalIF":0.0,"publicationDate":"2025-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143629470","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":"Novel poroperm characteristics design method for cement sheath to improve the long-term sealing integrity in gas storage well","authors":"Sheng Huang ,&nbsp;Tao Mao ,&nbsp;Donghua Su ,&nbsp;Zaoyuan Li ,&nbsp;Weitao Song ,&nbsp;Jinfei Sun","doi":"10.1016/j.geoen.2025.213832","DOIUrl":"10.1016/j.geoen.2025.213832","url":null,"abstract":"<div><div>Poroperm characteristics of the cement sheath are the crucial factors affecting the long-term safe and stable storage of underground gas in gas storage wells. In this paper, the permeability, connected porosity, and average connected pore radius of the cement sheath were characterized using a permeability test system, mercury intrusion, and computed tomography (CT). A dynamic permeability calculation model, which considered the pore compaction effect, was established and validated by test results. On this basis, a gas seepage length analysis model was further derived. The risk and influencing factors of gas seepage were explored and the critical poroperm characteristics indexes of the cement sheath were proposed. The results found that the connected pores inside the cement sheath will cause the risk of gas seepage. Decreasing the gas storage pressure, average connected pore radius, connected porosity, and permeability of the cement sheath can shorten the gas seepage length. The poroperm characteristics requirements charts were designed, and the average connected pore radius (<em>r</em>) and permeability (<em>K</em>_<em>a</em>) of the cement sheath under various well depths (<em>H</em>) and gas storage pressures (<em>P</em>_e) were quantified, that when the <em>r</em> and <em>K</em>_<em>a</em> meet <em>K</em>_<em>a</em> (10³ <em>P</em>_e – 9.8 <em>H</em>–121034 <em>r</em>⁻¹)/(13400 + 1.52 <em>H</em>) &lt; 0, the gas sealing of the gas storage wells' cement sheath can be ensured under different <em>H</em> and <em>P</em>_e. The research presents a novel approach for predicting the cement sheath sealing and proposes a set of specific performance indicators to effectively guide the design of the cement sheath's poroperm characteristics in gas storage wells, which is significant for guaranteeing the long-term safe operation of gas storage wells.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213832"},"PeriodicalIF":0.0,"publicationDate":"2025-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143591395","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}