Geoenergy Science and Engineering最新文献

{"title":"Pore-scale insights for steady-state two-phase flow in natural porous sandstone from pore connectivity characterization","authors":"Juncheng Qiao ,&nbsp;Jianhui Zeng ,&nbsp;Ting An ,&nbsp;Shu Jiang ,&nbsp;Yong Ma ,&nbsp;Yazhou Liu ,&nbsp;Dongxia Chen ,&nbsp;Yongchao Zhang ,&nbsp;Xiao Feng ,&nbsp;Zhe Cao ,&nbsp;Chenhao Sun","doi":"10.1016/j.geoen.2025.213891","DOIUrl":"10.1016/j.geoen.2025.213891","url":null,"abstract":"<div><div>Multiphase fluid transport in the subsurface natural porous sandstone governs numerous energetic industrial, and environmental activities. In this work, a nanometer-millimeter pore connectivity quantification is compiled by integration of multiple scale pore structure characterization techniques involving casting thin section (CTS), scanning electron microscope (SEM), X-ray computed tomography (X-μCT), Nuclear magnetic resonance (NMR), pressure-controlled porosimetry (PCP), and rate-controlled porosimetry (RCP), whereby the pore connected pattern, connective ratio, and connected full-range pore size distribution (CPSD) are obtained, upon which the controlling mechanisms for the steady-state two-phase flow (STPF) physics are further explored by incooperating physical displacement experiment. Connectivity evaluation indicates that high permeable sandstone shares a reticular connection network with scale-invariant connected ratio stays at around 0.60, low-permeability sandstone exhibits branch-like pattern with the ratio ranging from 0.53 to 0.60, while tight sandstone is characterized by local chain-like pattern with an average ratio of 0.31. Deviated Darcy linear and power-law flows present successively in the fractional non-wetting phase flow in STPF with reducing connectivity degree. Wetting phase mobility, dynamics of multiphase interaction, dynamic expansion of non-wetting phase flow path interpreted based on the CPSD, incorporating DLVO theory, augmented Young-Laplace equation, and effective hydraulic radius model, explain the pore-scale controls for the flow physics. The CPSD determines multiphase fluid mobility potential and dynamics of multiphase interaction, controlling the accessibility and expansion of flow pathway of non-wetting phase. Preferential non-wetting phase flow path expansions in the outer layer and inner layer of bound water film zone held by interfacial force and capillary force, and accompanying flow resistances in the connected pores &lt;1000 nm control the flow regime primarily. The pores of 30–50 nm in the flow paths are responsible for threshold pressure gradient (TPG), pressure disorders, and snap-offs during non-wetting phase intrusion, resulting in power-law deviations for the fractional flow of non-wetting phase. A dynamic fractional non-wetting phase flux prediction model is proposed by modifying fractal-based Hagen-Poiseuille equation considering flow physics, pore heterogeneity, and critical percolation length scale variations along with connected flow path expansion.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213891"},"PeriodicalIF":0.0,"publicationDate":"2025-04-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143859893","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 study of self-rotating abrasive water jet rotary slotting of rock","authors":"Hongxiang Jiang ,&nbsp;Huihe Zhao ,&nbsp;Zijian Wu ,&nbsp;Mingjin Zhao","doi":"10.1016/j.geoen.2025.213879","DOIUrl":"10.1016/j.geoen.2025.213879","url":null,"abstract":"<div><div>Abrasive water jet rock cutting can alleviate the difficulty of deep fossil energy extraction. The mechanism of active rotational cutting of rocks by an abrasive water jet under the influence of rotational degrees of freedom is still unclear. To reveal the mechanism and influencing factors of abrasive water jet rotary rock cutting, a numerical model is established through smooth particle hydrodynamics (SPH) and the finite element method (FEM). The restart method is used to solve the problem of damage transmission in the repeated cutting of rocks by abrasive water jets. The influences of parameters such as the deflection angle and abrasive concentration on the rock fragmentation effect are analyzed. The failure removal mechanism of rock elements and the weakening effect of repeated abrasive water jet impacts on rocks are studied based on stress and damage data. This study provides a reference for the application of abrasive jets in excavation, top cutting and pressure relief, gas extraction, and hydraulic fracturing of hard rock tunnels in deep coal mines.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213879"},"PeriodicalIF":0.0,"publicationDate":"2025-04-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143815829","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":"Maintaining ESP operational efficiency through machine learning-based anomaly detection","authors":"Evgeny Yudin ,&nbsp;Maria Kovaleva ,&nbsp;Valeriy Shevchenko ,&nbsp;George Bekh ,&nbsp;Mihail Gudilov ,&nbsp;Danil Isaev ,&nbsp;Alexey Zaytsev","doi":"10.1016/j.geoen.2025.213864","DOIUrl":"10.1016/j.geoen.2025.213864","url":null,"abstract":"<div><div>During oil extraction from wells, Electric Submersible Pumps (ESP) often work in Periodic Short-Term Activation (PSA) mode. While efficient, this operational mode is prone to transitioning into abnormal states that can lead to significant operational losses. Therefore, we should aim for prompt detection of these transitions.</div><div>This study introduces a novel machine learning-based approach for detecting anomalies in ESP operations by leveraging a pre-established library of generalized anomalies and comparing them with current operational modes. Unlike conventional methods that rely on extensive telemetry, our approach focuses on frequency and load time series data, utilizing Dynamic Time Warping (DTW) to identify similar anomaly patterns. The advantage of DTW in this context lies in its superior ability to align sequences with temporal shifts, making it particularly suitable for the erratic data generated by ESP operations, which are often more complex and less predictable than those handled by traditional techniques.</div><div>We have integrated this methodology into real-world SCADA systems to provide early warnings and facilitate timely interventions that optimize oil production. Testing on real data from 1,667 wells in Western Siberia, the proposed approach shows high effectiveness with an accuracy of 93% and an F1 score of 88%. The integration of the anomaly library with automatic feature extraction significantly enhances the quality of predictions, swiftly identifying potential issues and recommending operational adjustments to maintain efficiency and profitability.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213864"},"PeriodicalIF":0.0,"publicationDate":"2025-04-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143815826","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":"Application of molecular dynamics simulation in CO2-EOR and CO2 geological storage: A review","authors":"Yuanxiu Sun ,&nbsp;Yijie Ma ,&nbsp;Feng Yang ,&nbsp;Haitao Liu ,&nbsp;Songqi Li ,&nbsp;Xiuxia Li","doi":"10.1016/j.geoen.2025.213894","DOIUrl":"10.1016/j.geoen.2025.213894","url":null,"abstract":"<div><div>Carbon capture, utilization and storage (CCUS) technology is a strategic solution to the dual challenges of global energy demand growth and greenhouse gas emission reduction. The core components—CO₂ enhanced oil recovery technology (CO₂-EOR) and CO₂ geological storage technology, have become a research hotspot in the field of international energy. As a powerful tool, Molecular Dynamics (MD) simulation can be used to reveal the evolution law of crude oil occurrence state in nano-confined space, the multiphase interface behavior of CO₂-crude oil and the adsorption and storage characteristics of CO₂ on mineral surface. However, the real reservoir environment is very complex. How to accurately characterize the oil displacement process and storage effect of CO₂ by MD simulation has become a bottleneck problem to be solved. From the perspective of MD simulation, this paper reviews the latest research progress in three directions: the occurrence and migration mechanism of hydrocarbon fluids in nanopores; the mechanism of CO₂ on heavy components and miscible displacement; the influence mechanism of different geological storage sites on the long-term sequestration of CO₂. The problems and challenges in the current research are pointed out, and reasonable suggestions are given. Future MD simulation research should center on building more accurate molecular structure models, selecting more suitable molecular force fields and constructing multi-scale simulation methods. This review provides theoretical support for CO₂-EOR and optimization of CO₂ geological storage technology in unconventional reservoirs, which opens up a new path for the development of oilfields and the realization of carbon neutrality goals.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213894"},"PeriodicalIF":0.0,"publicationDate":"2025-04-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143828882","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 meta-learning fusion method for monitoring data prediction of oil wells","authors":"Yancen Shen ,&nbsp;Xiang Wang ,&nbsp;Yixin Xie ,&nbsp;Wei Wang ,&nbsp;Sen Wang ,&nbsp;Rui Zhang","doi":"10.1016/j.geoen.2025.213895","DOIUrl":"10.1016/j.geoen.2025.213895","url":null,"abstract":"<div><div>The advent of the oilfield Internet of Things (IoT) has led to widespread sensor deployment on oil wells, enabling real-time data acquisition and monitoring. The data exhibits highly nonlinear characteristics, posing prediction challenges. Prediction models for specific wells often lack generalization and are not suitable for other wells due to geological and working condition differences. In this study, a meta-learning fusion method based on model-agnostic meta-learning (MAML), convolutional neural networks (CNN), long short-term memory networks (LSTM), and multi-head self-attention mechanisms (MHSA) is proposed for monitoring data prediction tasks. This method employs MAML for generalization enhancement via multi-task training, addressing prediction challenges with limited data. CNN captures local features, LSTM handles temporal dependencies, and MHSA enhances complex data correlation capture. Taking the prediction of oil well dynamometer card data as an example, the experimental results demonstrate that, compared with existing methods, this approach exhibits higher prediction accuracy and generalization capability. Specifically, the MSE loss is reduced by 35 %–72 % when compared to the three existing prediction methods mentioned in this study. Prediction error grows with forecast horizon, highlighting potential for improvement in long-term accuracy. This method provides valuable insights for time series forecasting in the petroleum and related industries.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213895"},"PeriodicalIF":0.0,"publicationDate":"2025-04-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143848421","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":"Greening strategy for heavy oil thermal recovery assisted by environmental-friendly solvent dimethyl ether","authors":"Faqiang Dang ,&nbsp;Songyan Li ,&nbsp;Shibo Feng","doi":"10.1016/j.geoen.2025.213889","DOIUrl":"10.1016/j.geoen.2025.213889","url":null,"abstract":"<div><div>The heavy oil recovery process, traditionally fueled by steam derived from burning fossil fuels, is a considerable source of carbon emissions, contributing to the accentuation of environmental concerns. The integration of dimethyl ether (DME) into this process emerges as an innovative and eco-conscious strategy. This study investigates the mechanisms by which DME enhances steam flooding efficiency through the construction of a microscopic visualization model to examine DME-assisted steam flooding. Eleven controlled experiments with varied fluid types, injection modes, and temperatures reveal complex EOR mechanisms. Sandpack flooding experiments, comparing different DME injection rates with pure steam flooding, offer insights into production characteristics. The results show diverse forms of remaining oil in pore spaces—points, strips, clusters, and films. Comparative analysis indicates that DME flooding outperforms hot-water flooding and nitrogen flooding. The coinjection method is more effective than slug injection. High-temperature fluids yield better results. The optimal injection method is DME–steam coinjection flooding at 150 °C. DME addition reduces the heavy oil viscosity by 57.99 %, lowers the injection-production pressure differential from 4.9 MPa to 2.3 MPa, and advances the oil production breakthrough. Additionally, the peak oil production rate is improved by 0.75 mL/min. These effects contribute to a 21.74 % increase in the final oil recovery factor. The strategic integration of DME aligns with global sustainability goals, by mitigating environmental impacts through reduced emissions and improved energy efficiency while maintaining economic viability of heavy oil recovery operations.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213889"},"PeriodicalIF":0.0,"publicationDate":"2025-04-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143826114","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":"Study on carbonation corrosion mechanism and hydration of phosphoaluminate cement for CCUS wells","authors":"Bin Yuan,&nbsp;Xingyang Zhang,&nbsp;Shuo Yang,&nbsp;Bihua Xu,&nbsp;Zehao Zheng","doi":"10.1016/j.geoen.2025.213880","DOIUrl":"10.1016/j.geoen.2025.213880","url":null,"abstract":"<div><div>Phosphoaluminate cement (PAC) known for its superior corrosion resistance and mechanical properties, emerges as a promising material for cementing in Carbon capture utilization and storage (CCUS) wells. Therefore, this paper simulated the conditions of 90 °C, 8 MPa CO₂ partial pressure and 20 MPa formation pressure, analyzed the macroscopic properties and microstructure of PAC before and after corrosion by using the compressive strength test, permeability test, scanning electron microscope (SEM), X-ray diffraction (XRD) and other technological means. The results showed that, with the development of hydration time, the compressive strength of PAC first increased and then decreased, and the permeability first decreased and then increased; its main hydration products were hydrated PAC gel (CAP) and calcium aluminate (CA), and its microstructure evolved from floral to columnar and blocky gels. After corrosion, the compressive strength of the corroded 14d cement samples increased by 5.9 %, and the permeability increased by 82.5 %. The CO₂ corrosion accelerated the hydration process of the hydration products CAP and CA, which led to the transformation of CAP and CA microstructure into 3CaO-Al₂O₃-6H₂O (C₃AH₆) spherical gel. In addition, the carbonation corrosion process of PAC is divided into the dissolution process, induction process, carbonation process, decomposition process and dissolving corrosion process according to stages. Its carbonation corrosion mechanism: hydroxyapatite produced by hydration of PAC can absorb CO₂ to generate CaCO₃, Ca₁₀(PO₄)₆CO₃ and soluble Ca₃(PO₄)₂ and other products.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213880"},"PeriodicalIF":0.0,"publicationDate":"2025-04-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143823544","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":"Wellbore-formation transient temperature distribution considering heat transfer by fluid seepage while drilling in horizontal well","authors":"Guangfu Zhang ,&nbsp;Ming Tang ,&nbsp;Shiming He ,&nbsp;Linghao Kong ,&nbsp;Genghua Yao ,&nbsp;Xinyu Guo ,&nbsp;Haojie Lei ,&nbsp;Yuan Deng ,&nbsp;Xianghua Deng","doi":"10.1016/j.geoen.2025.213886","DOIUrl":"10.1016/j.geoen.2025.213886","url":null,"abstract":"<div><div>Currently, most wellbore-formation temperature field study only considers radial heat conduction in the formation, while neglecting temperature transfer caused by fluid seepage within the formation. Therefore, this paper investigates the impact of seepage between the wellbore and formation on heat transfer and develops a temperature prediction model suitable for horizontal wells. Secondly, detailed explanations are provided regarding the calculation methods for mechanical heat source term, hydraulic heat source term, drilling fluid rheological parameters, thermal physical parameters, and heat transfer coefficient in the model. Finally, the finite difference method is employed to solve the temperature model, and an analysis is conducted on the impact of mud density, formation permeability, seepage and drilling time on the annulus-formation temperature. The main conclusions are as follows: due to a large amount of mechanical friction, the temperature of the inclined section may exceed that of the initial position of the horizontal section. In the case of underbalanced drilling in high permeability formations, the consideration of seepage's influence on annulus temperature is paramount. Neglecting seepage results in a maximum error of 55.4 % in annulus temperature. The wellbore-formation temperature is positively correlated with formation permeability during overbalanced drilling, but negatively correlated during underbalanced drilling. The higher the drilling fluid density, the higher the wellbore-formation temperature. In the process of underbalanced drilling, there is minimal change in bottom hole temperature over time, while the wellhead temperature gradually increases. Conversely, during overbalanced drilling, the bottom hole temperature steadily rises as drilling progresses, with little variation observed at the wellhead.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213886"},"PeriodicalIF":0.0,"publicationDate":"2025-04-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143799590","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 CO2 storage with enhanced gas recovery (CSEGR) and geothermal energy extraction: A new semi-closed loop horizontal well structure for high-temperature depleted gas reservoirs","authors":"Lei Wang ,&nbsp;Kewen Li","doi":"10.1016/j.geoen.2025.213884","DOIUrl":"10.1016/j.geoen.2025.213884","url":null,"abstract":"<div><div>As the global energy crisis intensifies and environmental challenges mount, the pursuit of clean and sustainable energy sources has become paramount. This paper explores the integration of Carbon Capture, Utilization, and Storage (CCUS) technologies with geothermal energy development. A novel semi-closed loop horizontal well structure (SCHW) is proposed for the combined CO₂-Enhanced Gas Recovery and Carbon Plume Geothermal Systems (CSEGR-CPG system). A numerical model is established to evaluate the performance of CSEGR-CPG system with SCHW. The research results indicate that in the CSEGR-CPG system with SCHW, under the reservoir and injection-production conditions described in this paper, the backward cycle of SCHW is used in the CSEGR phase and forward cycle of SCHW is used in the CPG phase to obtain the best performance. The study highlights the influence of permeability and thickness on the migration of CO₂ and heat recovery effect within reservoir. Overall, this study demonstrates the effectiveness of this integrated approach in enhancing gas recovery while enabling geothermal energy production, offering a viable pathway for the reutilization of depleted gas reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213884"},"PeriodicalIF":0.0,"publicationDate":"2025-04-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143815830","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":"Production characteristics of methane hydrate reservoirs in the near wellbore region: Insight from depressurization rate","authors":"Tao Lv ,&nbsp;Jie Pan ,&nbsp;Lihong Wang ,&nbsp;Yang Li ,&nbsp;Yalong Ding ,&nbsp;Wujie Wang","doi":"10.1016/j.geoen.2025.213887","DOIUrl":"10.1016/j.geoen.2025.213887","url":null,"abstract":"<div><div>In this work, we experimentally simulated the production process of three-phase saturated hydrate reservoirs through single-vertical well depressurization, focusing on the effects of depressurization rate on the phase change, heat and mass transfer behaviors near the wellbore. Based on the reservoir characteristics of Shenhu area in the South China Sea, the samples with a three-phase coexistence of free gas, free water, and hydrate were prepared in laboratory. We analyzed the potential impacts of depressurization rate on the region near wellbore during actual reservoir production. Experimental results showed that in the initial stage of depressurization, a low depressurization rate could cause more hydrates to form, whereas a high depressurization rate tended to concentrate gas and water production at wellhead. During depressurization stage, the cumulative gas production at wellhead increased as the depressurization rate decreased, while in the subsequent constant pressure stage, a low depressurization rate could lead to a reduction in the average gas production rate. Apart from the Joule-Thomson effect caused by gas flow, the reservoir temperatures were significantly controlled by the formation and dissociation of hydrates in various locations. Throughout the production period, a significant negative correlation was observed between the depressurization rate and the hydrate dissociation rate. A low depressurization rate helped to reduce the amounts of water production near wellbore and the consumption of hydrate dissociation on the sensible heat from the surrounding sediments. For actual reservoir production, an excessive depressurization rate may cause fluids with high velocity to impact the wellbore, resulting in its damage or collapse, while an insufficient depressurization rate is not conducive to hydrate dissociation.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213887"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143821386","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}