Geoenergy Science and Engineering最新文献

{"title":"Structural assessment of the Belayim formation for future potential CO2 storage, Gulf of Suez, Egypt","authors":"Heba Atef ,&nbsp;Claire Bossennec ,&nbsp;Jeroen van der Vaart ,&nbsp;Ingo Sass","doi":"10.1016/j.geoen.2025.213921","DOIUrl":"10.1016/j.geoen.2025.213921","url":null,"abstract":"<div><div>Egypt aims to reduce CO₂ emissions by 90.7 million metric tons by 2030, with 65 % of this reduction, equivalent to 1.7 million metric tons of CO₂ equivalent, targeted within the oil and gas sector. To determine whether an oil field can be considered a CO₂ storage site, geological characteristics are a crucial criterion. Therefore, this research focuses on evaluating the structural compatibility of the Belayim reservoir in the Shoab Ali oil field after its depletion for potential future use as a CO₂ storage site. The study utilized 2D seismic lines as well as borehole data to construct a 3D structural model for the targeted units. Three faults were delineated intersecting the Belayim Formation, all inclined in the NW-SE direction with normal slip. Two methods of fault seal analysis, Juxtaposition diagrams and the Shale Gouge Ratio (SGR) algorithm, were applied to identify potential leakage pathways along the fault planes. Fault F2 demonstrates strong fluid trapping potential due to its juxtaposition with the salt of the South Gharib Formation. In contrast, Faults F1 and F3 exhibit greater potential for leakage, attributed to the carbonate self-juxtaposition at the top of the Belayim Formation (Hammam Faraun Member). While Fault 1 and Fault 3 exhibit higher SGR values compared to Fault 2, the depth map of the Belayim Formation reveals a fault-bounded trap defined by Faults F1 and F2, both dipping in the NW-SE direction. The net closure volume is estimated to range from 0.23 × 10⁸ m³ to 0.3 × 10⁸ m³.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213921"},"PeriodicalIF":0.0,"publicationDate":"2025-04-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143879162","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":"Reservoir characterization based on data incorporation throughout production development","authors":"Alexandre Coimbra ,&nbsp;Marcio A. Sampaio","doi":"10.1016/j.geoen.2025.213911","DOIUrl":"10.1016/j.geoen.2025.213911","url":null,"abstract":"<div><div>The oil and gas industry faces multiple challenges, especially in integrating well acquisition data and production planning into flow models early in projects to improve predictive accuracy. This study emulates the production development of an oilfield from exploration to initial development, focusing on reducing uncertainty and enhancing reservoir characterization. The development process follows an industry-standard data acquisition plan, prioritizing exploratory wells initially and gradually decreasing data acquisition for subsequent wells. Initially, wells were assessed with open-hole profiles, drill stem tests (DST), and production logging tools (PLT). In later stages, data acquisition was simplified to open-hole profiles and production histories.</div><div>The project production strategy is iteratively updated with each phase of data incorporation, applied to geostatistical realizations to improve model accuracy. Geological uncertainties are considered, while economic uncertainties are excluded. The methodology is based on a closed-loop field development (CLFD) approach, adapted to enhance reservoir characterization. Preconditioning techniques and adjustments to acquisition scope aimed at improving outcomes were implemented.</div><div>The findings demonstrate effective reduction of uncertainty and optimization of production strategy, achieving accurate predictions for key metrics like monetary value, cumulative oil and water production, water injection, and oil recovery factor. The inclusion of dynamic data early in the project proved instrumental in minimizing uncertainty, leading to optimized production strategies and improved reservoir characterization. These results underscore the value of incorporating dynamic data early in project development for enhanced predictive performance in reservoir management.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213911"},"PeriodicalIF":0.0,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143859904","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 of the crude oil storage in underground salt cavern sediment void with high impurity salt mines","authors":"Xinxing Wei ,&nbsp;Xilin Shi ,&nbsp;Yinping Li ,&nbsp;Hongling Ma","doi":"10.1016/j.geoen.2025.213923","DOIUrl":"10.1016/j.geoen.2025.213923","url":null,"abstract":"<div><div>Using the salt cavern to store crude oil is a mature method widely used in the US, France, and Germany. These countries usually use the top space of the sediment particles of salt caverns to store the crude oil. In China, the bedded rock salt will produce plenty of insoluble sediment particles when solution mining due to the insoluble interlayers and impurities. Thus, a novel crude oil storage method that uses the insoluble sediment particles' void is proposed to enhance the cavern oil storage capacity. Four novel crude oil storage experiments (crude oil preparation, sediment particles preparation, sediment void crude oil storage, and sediment contents detection) were conducted by a series of self-made devices to evaluate the feasibility of sediment void crude oil storage. The optimization of crude oil type, oil recovery and loss process, void structure evolution were discussed. The results show that the average oil recovery ratio of crude oil (Saudi, Iranian, and UAE) is 90.7 % at 50 °C, which indicates that crude oil is suitable for storing in the salt cavern sediment void. The optimization crude oil kinematic viscosity range is less than 10 mm²/s. The surface and inner pores of the sediment will be filled with the brine, which reduces the oil absorption and adhesion. The sediment weight of extraction oil and oil kinematic viscosity have a positive correlation relationship. The research has a reference to the large-scale underground salt cavern oil energy storage.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213923"},"PeriodicalIF":0.0,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143855312","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":"Innovative soaking-enhanced carbonated water flooding for EOR and CO2 storage","authors":"Faqiang Dang ,&nbsp;Songyan Li ,&nbsp;Shibo Feng ,&nbsp;Shaopeng Li ,&nbsp;Liang Liu ,&nbsp;Lina Su","doi":"10.1016/j.geoen.2025.213922","DOIUrl":"10.1016/j.geoen.2025.213922","url":null,"abstract":"<div><div>This study introduces an innovative soaking-enhanced carbonated water flooding protocol, which significantly enhances oil recovery and CO₂ sequestration by incorporating a soaking stage. The effects of soaking-enhanced carbonated water flooding on oil recovery and CO₂ sequestration were systematically examined through sand-packed tube flooding experiments under varying CO₂ concentrations, reservoir permeabilities, and oil viscosities. The results demonstrate that the soaking stage significantly enhances the performance of carbonated water flooding, improving both oil recovery and CO₂ sequestration across all tested scenarios. This enhancement is achieved by extending the interaction time between carbonated water and reservoir fluids, allowing dissolved CO₂ to fully diffuse into the oil phase. The CO₂-enriched oil undergoes viscosity reduction and volumetric expansion, collectively enhancing oil mobility and recovery efficiency. Simultaneously, pressure equilibration during soaking redistributes CO₂ into micropores and dead-end spaces, increasing storage efficiency and minimizing gas release. These effects are evident in production dynamics, where soaking leads to rapid recovery of oil production, significant reductions in water cut, and minimized gas release. The benefits of soaking are particularly pronounced under conditions of higher CO₂ concentrations, higher reservoir permeability, and lower oil viscosity. For instance, at 0.8 mol/L CO₂, oil recovery increased from 56.35 % to 73.38 %, and CO₂ storage rose from 0.12 to 0.16 pore volumes. High-permeability reservoirs (2103 mD) achieved oil recoveries of 85.12 % and CO₂ storage of 0.18 pore volumes, while low-viscosity oils (16.1 mPa s) exhibited recoveries of 84.40 % and storage efficiencies of 0.19 pore volumes. In summary, the soaking-enhanced carbonated water flooding protocol provides a robust and scalable solution for enhancing oil recovery and CO₂ sequestration. Its broad applicability and adaptability to diverse reservoir conditions make it a transformative technology for sustainable energy production and carbon management.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213922"},"PeriodicalIF":0.0,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143859888","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":"Towards accurate prediction of thermodynamic properties of hydrogen over supercritical conditions using volume-translated cubic equations of state","authors":"Changxu Wu,&nbsp;Huazhou Li","doi":"10.1016/j.geoen.2025.213924","DOIUrl":"10.1016/j.geoen.2025.213924","url":null,"abstract":"<div><div>Hydrogen is a clean energy source that helps reduce fossil fuel dependence, achieve net-zero emissions, and contribute to environmental sustainability. Accurate prediction of the thermodynamic properties of hydrogen plays a crucial role in the design and operation of various hydrogen-based systems. In this study, we propose improved distance-function-based volume translation models in Soave-Redlich-Kwong equation of state (SRK EOS) and Peng-Robinson equation of state (PR EOS) for hydrogen, resulting in the development of volume-translated SRK EOS and volume-translated PR EOS (i.e., VT-SRK EOS and VT-PR EOS). These models are capable of accurately predicting the thermodynamic properties of hydrogen under supercritical conditions (i.e., pressures from 0.01 MPa to 300 MPa and temperatures from critical temperature (i.e., 33.15 K) to 600 K). More specifically, the new VT-SRK EOS yields %AADs of 0.56, 2.07, 5.39, 5.69, 6.71, and 1.92 in predicting density, isobaric thermal expansivity, isothermal compressibility, isobaric heat capacity, isochoric heat capacity, and speed of sound, respectively. The proposed VT-PR EOS also performs well in predicting these six thermodynamic properties, with %AADs of 0.75, 2.68, 6.08, 6.28, 7.14, and 1.72, respectively. Additionally, the proposed volume-translated cubic equations of state (VT-CEOSs) reproduce the true critical volume of hydrogen. The proposed VT-SRK EOS and VT-PR EOS do not lead to the crossover of pressure-volume isotherms within the tested pressure and temperature ranges.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213924"},"PeriodicalIF":0.0,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143859891","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":"Automatic detection of borehole breakout for image logs using YOLO algorithm","authors":"Juyeol Yeom ,&nbsp;Hayoung Kim ,&nbsp;Chandong Chang ,&nbsp;Yeonguk Jo ,&nbsp;Zhuoheng Chen ,&nbsp;Kyungbook Lee","doi":"10.1016/j.geoen.2025.213925","DOIUrl":"10.1016/j.geoen.2025.213925","url":null,"abstract":"<div><div>In-situ stress estimation is crucial for subsurface stability, carbon sequestration, and optimizing petroleum resource development, particularly in hydraulic fracturing. Borehole breakout serves as a key stress indicator, but their manual interpretation is time-consuming and subjective. This study proposes an automatic borehole breakout detection model for image logs using you only look once (YOLO) algorithm. The model is trained using image data from Well A2, incorporating domain-knowledge based preprocessing and data augmentation to enhance breakout detection accuracy. The model is evaluated under two scenarios: without data augmentation (Case 1) and with data augmentation (Case 2). Case 2 achieves a 78.81 % improvement in average precision, significantly outperforming Case 1. To validate its performance, the trained model is tested on Wells A2 and B1, comparing its results with expert analysis. The results confirm that Case 2 provides more reliable breakout detection, minimizing error across both wells. Additionally, the proposed model automatically computes breakout geometry, including azimuth, depth, opening angle, and length in under 0.1 s per 3-m image log, offering significantly more efficiency than manual expert analysis performed by experts.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213925"},"PeriodicalIF":0.0,"publicationDate":"2025-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143867892","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":"Seismic efficiency: From hydraulic fracturing-acoustic emission laboratory experiments of shale based on energy budget","authors":"Bofeng Liang ,&nbsp;Li-Yun Fu ,&nbsp;Mian Lin ,&nbsp;Tobias Müller ,&nbsp;Wubing Deng ,&nbsp;Tongcheng Han","doi":"10.1016/j.geoen.2025.213917","DOIUrl":"10.1016/j.geoen.2025.213917","url":null,"abstract":"<div><div>Fluid injection-triggered earthquakes have been documented worldwide and quite a number of events have significant moment magnitudes (<em>M</em>_<em>w</em> ≥ 3). Seismic efficiency (<em>η</em>), defined as the ratio of injection volume to net seismic moment release in hydraulic fracturing operations, is a crucial parameter to evaluate seismic hazard. However, a quantitative assessment of seismic and non-seismic (aseismic) energy release is a key aspect of understanding the intrinsic properties of cracking rocks. Therefore, we develop a novel <em>η</em> model based on the hydraulic-fracturing-propagation energy budget and performed laboratory experiments on hydraulic fracturing in shale by injecting distilled water at different rates under pseudo-triaxial stress conditions with simultaneous monitoring of acoustic emission (AE). We estimate AE energy accurately with absolute value correction of sensors using a laser Doppler vibrometer, and the dissipation of the potential energy using displacement and pressure sensors. The results show that the proposed <em>η</em> model can evaluate the induced seismic characteristics effectively compared with field data and the injection rate controls the change of <em>η</em> to some extent. Moreover, there is a log-linear relationship between seismic efficiency and injection efficiency (ratio of AE energy and injection energy), which may provide an experiential method for evaluating seismicity during the early phase of hydraulic fracturing.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213917"},"PeriodicalIF":0.0,"publicationDate":"2025-04-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143867891","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 novel full hydraulic tractor with large traction force","authors":"Jianguo Zhao ,&nbsp;Penghui Liang ,&nbsp;Qingyou Liu ,&nbsp;Shiji Fang ,&nbsp;Ju Wang","doi":"10.1016/j.geoen.2025.213909","DOIUrl":"10.1016/j.geoen.2025.213909","url":null,"abstract":"<div><div>Coiled tubing (CT) is extensively employed in well drilling and completion operations, yet the issue of CT buckling occurs as the horizontal section extends. Deploying a tractor can effectively address the limitations of CT extension in horizontal sections. In this paper, a novel full hydraulic tractor with large traction force was proposed. The simulation models of the working cylinders under full hydraulic control were established, and the motion characteristics of the supporting cylinder and the traction cylinder of the full hydraulic tractor were obtained. A hydraulic integrated control valve (ICV) combining a sequence valve and a hydraulic check valve with a pilot hydraulic directional valve was proposed, which can realize the automatic reversing mechanism of the tractor. The full hydraulic automatic reversing mechanism and ICV-tractor joint simulation model were established. The simulation results showed that the full hydraulic reversing mechanism could realize the reciprocating motion of the piston of the traction cylinder, and the valve spool could maintain the maximum opening in two positions. In addition, the prototype was developed and the function verification experiment and traction experiment were carried out. The results showed that under full hydraulic control, two cylinders could move steadily in a certain order and cycle. The maximum traction force of the CT tractor for pulling coiled tubing in the casing reached 81.36 kN. This proved the correctness of the full hydraulic tractor with large traction force. This research provides equipment support for CT operations in ultra-long horizontal wells and makes a significant contribution to the lateral extension of horizontal wells.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213909"},"PeriodicalIF":0.0,"publicationDate":"2025-04-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143867893","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":"Amphiphilic polymer with ultra-high salt resistance and emulsification for enhanced oil recovery in heavy oil cold recovery production","authors":"Haizhuang Jiang ,&nbsp;Hongbin Yang ,&nbsp;Changyuan Ning ,&nbsp;Liang Peng ,&nbsp;Shuhe Zhang ,&nbsp;Xin Chen ,&nbsp;Haobin Shi ,&nbsp;Ruichao Wang ,&nbsp;Bauyrzhan Sarsenbekuly ,&nbsp;Wanli Kang","doi":"10.1016/j.geoen.2025.213920","DOIUrl":"10.1016/j.geoen.2025.213920","url":null,"abstract":"<div><div>The thermal recovery is a significant method of developing heavy oil. With global environmental governance and carbon management, the energy loss and carbon emissions caused by thermal recovery restrict its development. The non-thermal recovery (cold recovery), as a nascent green and clean production technology, has garnered attention within the petroleum industry. In this paper, an amphiphilic polymer viscosity reducer (P(AM/AMPS/C16), abbreviated as PAAC) used for cold recovery was synthesized, to solve the weak emulsification and poor flowability control in ultra-high salt heavy oil reservoirs. The PAAC's salt resistance can be contributed by two aspects. Firstly, the inner salt bond formed by the electrostatic interaction between the sulfonic and the ammonium groups can resist the compression double-layer effect of salt ions. Secondly, the association effect enhances the thickening ability. The improvement of salt resistance has been demonstrated to have a substantial impact on the flowability control of polymer in ultra-high salt heavy oil reservoirs. The hexadecyl chain endows PAAC with the ability to emulsify heavy oil, which can significantly reduce the oil-water interfacial tension to 10⁻² mN/m and form an oil in water emulsion (O/W). The PAAC achieves effective heavy oil utilization through three functions: emulsification carrying, peeling, and deformation and stretch. PAAC with an injection volume of 0.5 PV increases the heavy oil recovery by 16.13 %. The study provides valuable insights into the use of polymer viscosity reducers and enhanced heavy oil recovery in cold recovery, representing a new perspective on the application of polymers in ultra-high salt reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213920"},"PeriodicalIF":0.0,"publicationDate":"2025-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143859890","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 corrosion laws of casing steels in CCUS injection wells in simulated cement pore fluids","authors":"Dezhi Zeng ,&nbsp;Xue Han ,&nbsp;Chunyan Zheng ,&nbsp;Zhengpeng Du ,&nbsp;Sirui Cao ,&nbsp;Guangguang Xiang ,&nbsp;Chengxiu Yu ,&nbsp;Jian Yang ,&nbsp;Bo Xu ,&nbsp;Lin Zhang","doi":"10.1016/j.geoen.2025.213908","DOIUrl":"10.1016/j.geoen.2025.213908","url":null,"abstract":"<div><div>Casing corrosion often occurs in CCUS injection wells and affects its safe service life. In a HTHP kettle, corrosion experiments on the inner and outer walls of N80 and L80-13Cr casing were carried out under different CO₂ partial pressures in order to reveal the microscopic corrosion mechanism with characterization methods. Based on the weight-loss corrosion rate, local corrosion rate, collapse resistance strength, residual tensile strength, internal compressive strength and cost of casings, a hierarchical material selection model was established to evaluate the suitability of N80 and L80-13Cr steels and the results for the rational selection of materials. The corrosion rate of casings increased with the increase in CO₂ partial pressure. In a simulated pore environment, CaCO₃ and SiO₂ formed a passivation film to alleviate uniform corrosion. In addition, loose CaCO₃ scale caused the uneven product film, thus intensifying local corrosion. Cr element in L80-13Cr steel repaired the product film and reduced the corrosion rate, thus showing the stronger pitting corrosion sensitivity. It was recommended that N80 steel could meet the corrosion resistance requirements of oil casings in CCUS injection wells.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213908"},"PeriodicalIF":0.0,"publicationDate":"2025-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143881631","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}