Day 1 Mon, October 03, 2022最新文献

{"title":"Increase in the Oil Recovery Factor through the Injection of Nano-Chemicals Dispersed in Gas","authors":"Jhon Fredy Gallego Arias","doi":"10.2118/212385-stu","DOIUrl":"https://doi.org/10.2118/212385-stu","url":null,"abstract":"\u0000 Tight reservoirs have different challenges, among them, there are several related to the low permeability of the rock and diverse damage mechanisms. Conventional Chemical Injection in these types of reservoirs has some disadvantages such as shallow penetration and the use of high volumes of chemicals. Therefore, new technologies such as chemical dispersion on a gas flow have been developed to achieve deeper penetration of the chemicals and mitigate formation damage in gas- condensate tight reservoirs by mobilizing condensate banks. However, the inclusion of nanoparticles in the dispersed phase for EOR processes is a novelty. Since silica nanoparticles reduce interfacial tension and alter the wettability of the rock, the objective of this study is to evaluate the effect of adding silica nanoparticles (S1) dispersed in two treatments (A and B) at a dosage of (10-100 mg·L−1) on wettability, interfacial tension, emulsion stability, and rock treatment adsorption. To compare them with a silica-based nanofluid, treatment C was also evaluated. The dosage selection of silica nanoparticles was made through static tests such as interfacial tension, contact angle, and static formation of emulsions. The best nanofluid among the ones prepared from treatments A and B was evaluated in dynamic tests to be compared with treatment C through the capillary blockage, oil recovery, and oil recovery in the perdurability scenario tests. Treatments A and C experienced a great affinity for the rock in the adsorption isotherms, while treatment B had less affinity for the rock. The addition of nanoparticles (S1) to treatments A and B at a concentration of 50 and 10 mg·L−1 respectively, led to an interfacial tension reduction of 16% and 40%, each one; and a respective water contact angle reduction of 17% and 2%. Furthermore, the addition of nanoparticles S1 promoted less stable emulsions, which is favorable for these processes. Finally, 26% of the additional increase in oil recovery and a greater perdurability was obtained with treatment B + 10 ppm Nps S1 in core displacement tests.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121611022","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 Measurements and Molecular Simulation of Carbon Dioxide Adsorption on Carbon Surface","authors":"I. Gomaa, Javier Guerrero, Z. Heidari, D. Espinoza","doi":"10.2118/210264-ms","DOIUrl":"https://doi.org/10.2118/210264-ms","url":null,"abstract":"\u0000 Geological storage of carbon dioxide (CO2) in depleted gas reservoirs represents a cost-effective solution to mitigate global carbon emissions. The surface chemistry of the reservoir rock, pressure, temperature, and moisture content are critical factors that determine the CO2 adsorption capacity and storage mechanisms. Shale-gas reservoirs are good candidates for this application. However, the interactions of CO2 and organic content still need further investigation. The objectives of this paper are to (i) experimentally investigate the effect of pressure and temperature on the CO2 adsorption capacity of activated carbon, (ii) quantify the nanoscale interfacial interactions between CO2 and the activated carbon surface using Monte Carlo molecular modeling, and (iii) quantify the correlation between the adsorption isotherms of activated carbon-CO2 system and the actual carbon dioxide adsorption on shale-gas rock at different temperatures and geochemical conditions. Activated carbon is used as a proxy for kerogen. The objectives aim at obtaining a better understanding of the behavior of CO2 injection and storage into shale-gas formations.\u0000 We performed experimental measurements and Grand Canonical Monte Carlo (GCMC) simulations of CO2 adsorption onto activated carbon. The experimental work involved measurements of the high-pressure adsorption capacity of activated carbon using pure CO2 gas. Subsequently, we performed a series of GCMC simulations to calculate CO2 adsorption capacity on activated carbon to validate the experimental results. The simulated activated carbon structure consists of graphite sheets with a distance between the sheets equal to the average actual pore size of the activated carbon sample. Adsorption isotherms were calculated and modeled for each temperature value at various pressures.\u0000 The adsorption of CO2 on activated carbon is favorable from the energy and kinetic point of view. This is due to the presence of a wide micro to meso pore sizes that can accommodate a large amount of CO2 particles. The results of the experimental work show that excess adsorption results for gas mixtures lie in between the results for pure components. The simulation results agree with the experimental measurements. The strength of CO2 adsorption depends on both surface chemistry and pore size of activated carbon. Once strong adsorption sites within nanoscale network are established, gas adsorption even at very low pressure is governed by pore width rather than chemical composition. The outcomes of this paper provides new insights about the parameters affecting CO2 adsorption and storage in shale-gas reservoirs, which is critical for developing standalone representative models for CO2 adsorption on pure organic carbon.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114420945","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":"Well Integrity in the Production Phase - Application of a New Quantitative Operational Risk Model","authors":"L. F. Oliveira, J. Domingues, Danilo Colombo","doi":"10.2118/210314-ms","DOIUrl":"https://doi.org/10.2118/210314-ms","url":null,"abstract":"\u0000 Almost all O&G companies have a well integrity management system based on a well failure model. Until now, they are mostly based on qualitative risk models with only very few claiming to use quantitative risk methods. The objective of this paper is to present a production well integrity managementsystem based on a different type of quantitative risk model. Traditional risk assessment methods were developed to be used in design stage. Therefore, they are not really adequate to manage operational risks during the production phase because they cannot take into account the operational history and the true current asset conditions during operation. Unlike such models, our quantitative risk/reliability model has been developed to be specifically used during the operational phase of a well. Therefore, it can accurately calculate the risk of an uncontrolled leak today and provide good estimates for the future evolution of this risk.This quantitative model has been served as the basis for the development of a web-based computational system which is now implemented in Petrobras and is an important part of the well integrity management system of that company. A descriptionis presented in this paper together with a simplified application to a subsea well.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124407514","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":"Well Control Considerations for CO2 Wells Based on Multiphase Flow Simulations","authors":"Lei Zhou, Bjoern-Tore Anfinsen, Yahya Hashemian, Zhaoguang Yuan, I. Mosti","doi":"10.2118/210132-ms","DOIUrl":"https://doi.org/10.2118/210132-ms","url":null,"abstract":"\u0000 CCUS (Carbon Capture Utilization and Storage) is expected to be an important contributor to the ambition of reaching a net zero objective. Drilling and workover of wells to be used as CO2 injectors, pose a well control risk that needs to be properly understood and minimized.\u0000 The paper will address the significant differences between CO2 wells and traditional hydrocarbon wells. Due to differences in phase behavior, both well design and operational procedures would be impacted and needs to be revised. Traditional well control procedures are not necessarily applicable in CCUS wells without modifications.\u0000 A generic well was used to study the differences between a CO2 well and a hydrocarbon (methane) well with respect to design and procedural changes in case of a well control incident. A well control simulator capable of transient multiphase modeling of hydrocarbon and CO2 systems was used to evaluate the differences. Important operational and design limiting factors like volume, pressure and temperature responses, hydrate formation, phase transition as well as mitigation strategies and contingencies were evaluated. The model showed that with both SOBM and WBM, the CO2 influx entered the well in its supercritical form. Under static conditions, the CO2 remained in its supercritical form and showed no migration in SOBM, making its detection more challenging than for a methane influx. Driller's method was applied while simulating circulating the CO2 influx. For both mud types, the model showed greater liquid velocities compared to methane, which would reduce the time to react and put greater demands on surface equipment. The model also showed a greater drop in temperature than for a methane influx. Due to J-T cooling effect, the model shows that supercritical CO2 expansion near the surface can lead to significant temperature reduction, which in turn can lead to formation of hydrates and block the circulation. This effect also needs to be considered in the well design as the physical properties of the casings and surface pipes can be changed due to variation in temperature. Based on these results, measures to mitigate CO2 well control risks are discussed. This study will provide new knowledge regarding well control incidents related to CO2 wells. Improved understanding can be used to optimize operational procedures and potentially lead to new mitigation techniques.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"67 6","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121016922","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":"Stimulation Efficiency with Significantly Fewer Stages: Perforation Strategy Combined with Multimodal Diverters and Novel Nonintrusive Monitoring Algorithm","authors":"Hashem Alobaid, AbdulMuqtadir Khan, Jon E. Hansen, Aleksandra Khudorozhkova","doi":"10.2118/210472-ms","DOIUrl":"https://doi.org/10.2118/210472-ms","url":null,"abstract":"\u0000 Tight carbonate development is moving towards longer laterals requiring a higher number of fracturing stages to complete a given well. A higher stage count implies longer completion time and higher costs. Therefore, an engineered strategy using technology enablers is indispensable to reducing the number of stages while retaining the well performance objective.\u0000 A 6,250-ft cemented lateral initially planned with 13 fracturing stages was analyzed for lithology and reservoir development to revise the perforation strategy to complete with more clusters per stage and reduced the number of stages to 5 stages. Clusters were designed to be very narrow to effectively divert the fracture fluids using chemical diversion. For a successful stimulation evaluation, a novel pressure monitoring technique was used to analyze the fluid entry points from the water hammers.\u0000 Pills of multimodal particulate near-wellbore diverters were used across the lateral to stimulate the perforated clusters in only five fracture stages effectively. The multimodal particle distribution model allows for bridging and then creating an impermeable flow barrier to ensure diversion. Effective diversion was seen through a pressure increase when diverter entered the formation. Correlations were analyzed for diversion pressure dependence on pill volume and injection rate to improve diversion. A new algorithm for nonintrusive diagnostics was also deployed. The algorithm combines advanced signal processing with a tube wave velocity model based on Bayesian statistics and has no additional operational footprint. The program allowed a timely interpretation to evaluate the fluid entry points based on the water hammer events. This evaluation was compared to the intuitive stimulation sequence based on the lithology to explain the results. The comprehensive analysis demonstrated the lateral was stimulated effectively. Finally, the production performance was compared with two offset horizontal wells intersecting the same carbonate sublayer. Offset 1 was a cemented lateral completed with 12 stages, and offset 2 was an openhole packer and sleeve lateral completed with 7 stages. Analysis of the post-fracturing absolute production enhancement showed 11 to 15% improvement and production index (PI) improvement was 40 to 63% when normalized by stage count.\u0000 The paper presents a rare and unique strategic integration of multiple technologies. This success paves the way for similar future developments to enhance operational efficiency and allow significant cost savings.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"334 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133666181","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":"Stranger Things 4: Placement Simulators Accuracy For ECD and Pressure Predictions","authors":"J. Shine, Thomas Heinold, Don Lawrence","doi":"10.2118/210443-ms","DOIUrl":"https://doi.org/10.2118/210443-ms","url":null,"abstract":"\u0000 Cement placement simulators are valuable tools predicting anticipated pressures and equivalent circulating densities (ECD) for a given application. The simulators guide users in maintaining wellbore stability for a range of operating conditions unique to the application while helping to achieve the isolation requirements. There are various functions in the simulators, based upon the inputs, which contribute to the pressure and ECD predictions. Most of the available literature shows consistency for the solving the various transport equations of fluid dynamics including pressure losses as a function of flow regime, wellbore geometry, and fluid rheological model. Therefore, a comparison study should demonstrate consistency to avoid uncertainties in a given simulators prediction accuracy. The manuscript investigates the prediction differences in four available simulators that depending on the type of variability observed, could affect a well's integrity.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"31 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125704059","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":"Biomineralization: A Natural Solution to Eliminate Gas Migration","authors":"R. Hiebert, Lauren Panzo, R. Hyatt","doi":"10.2118/210258-ms","DOIUrl":"https://doi.org/10.2118/210258-ms","url":null,"abstract":"\u0000 A Seneca Resources Company, LLC (Seneca) natural gas well in Pennsylvania was leaking methane from both the 13-3/8 in × 9-5/8 in (55 psi) and the 9-5/8 in × 7 in (85 psi) cemented annuli. Previous attempts to mitigate the problem had proven unsuccessful, which prompted the trial of a new method using the natural process of biomineralization.\u0000 BioSqueeze Inc. (BSI) was contracted by Seneca to apply their proprietary biomineralization technology to the well. To prepare the well, circumferential notches were cut through all casing strings all the way to the formation to allow fluid injection into the annuli. Biomineralizing fluids were then pumped into the well, where they formed crystalline calcium carbonate in the micro annuli.\u0000 After 1.5 days of treatment, the injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator determined surface pressure had been eliminated and there were no escaping hydrocarbons.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"310 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133469783","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":"Digital Tool Allows Simultaneous Operation and Facilities Optimization in Limited-Budget Projects","authors":"Luis Gonzalez Muro, Diego Calderon Ruiz, Byron Fun Sang Robinson, Fabian Florez Florez","doi":"10.2118/210074-ms","DOIUrl":"https://doi.org/10.2118/210074-ms","url":null,"abstract":"\u0000 This paper presents an example of how small oil fields can approach digital transformation aiming higher digital maturity and becoming a \"smart asset\". The asset targeted to integrate the well performance and the available capacity of the existing processing facilities, and with that allocate resources to actionable optimization opportunities. The optimization is driven by allocating the facilities volume (in oil) to those wells with higher oil output.\u0000 The methodology uses the classic well by well production optimization approach (find the highest incremental oil with the lowest investment), the novelty is to rank the wells based on the main bottlenecks of the processing facilities. In this way the ranking of the wells is dictated by the overall production system analysis from the pore to the export pipeline.\u0000 Once a constraint is identified a baseline is set and a target status is defined. The gap between current and target states is overcame by robust data structure that enables business and artificial intelligence workflows for well and facility smart analytics.\u0000 The enhanced workflow allows surface facilities surveillance in a relative high frequency, this in combination with the well monitoring improve optimization decision dramatically.\u0000 As a result, this strategy has allowed the asset to reduce 900 man-hours a year, reduce operative production losses by 40%, lessen artificial lift failure events rate by 40%, increase production in the order of 5% (in a 9K BOPD asset), bringing the project to outstanding production levels. Furthermore, this solution has indirectly helped to reduce CO2 emissions in at least 20 Tons per year, reducing the carbon footprint in a sensitive environmental area in the amazon forest.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"151 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131494493","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 Proppant Transport Using 3d-Printed Rough Fracture Surfaces","authors":"G. Tatman, A. Bahri, D. Zhu, A. Hill, J. Miskimins","doi":"10.2118/210196-ms","DOIUrl":"https://doi.org/10.2118/210196-ms","url":null,"abstract":"\u0000 3D printing is a type of additive manufacturing technology that allows for digital 3D models to be made into physical objects out of a wide range of thermoplastics, resins, and occasionally metals. In previous years, 3D printing models at high-resolution suitable for oil and gas research was either time consuming, cost-prohibitive, or limited to a small model build volume. However, the rapid advancement in resin 3D printing technology recently has allowed for a significant increase in production speeds and model size at little cost. In this study, we utilized 3D printed rough-wall fracture panels in a large-scaled proppant transport apparatus to evaluate the feasibility of repeatable and realistic experimental investigation by the 3D printing technology.\u0000 Understanding proppant transport in hydraulically created fractures helps to answer the questions about proppant distribution, resultant fracture conductivity, effectiveness of fracture fluid and additives, and all leads to fracture treatment efficiency. In the past, lab experiments showed that fracture topography plays an important role on fracture conductivity, and the characteristics of fracture surfaces have been grouped as random distribution, channel, wavy and ledge (step-change). These surface features can be described by geostatistical parameters. For large-scale proppant transport, the realistic surfaces are difficult to create, and thus most studies have used smooth-surfaced parallel acrylic panels for the fracture walls.\u0000 Stereolithography (SLA) resin 3D printers produce a physical model by using an ultraviolet light source to selectively illuminate and cure a photopolymer onto a travelling build platform. The physical models are based on a computer-generated surface with controlled statistical definition. We have successfully printed panels to build a 4ft X 2ft main fracture with a smaller fracture intersecting orthogonally. The panels are carefully printed with transparent resin to allow for video recording. Initial tests showed the mechanical integrity of printed fractures and proppant transport results.\u0000 This paper describes the detailed procedure of generating fractures by 3D printing, experimental setup and the test results of proppant transport.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123544217","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":"Waterflood Optimization on the West Siberia Field with Hydrodynamic Modeling","authors":"Vladislav Dormenev","doi":"10.2118/212388-stu","DOIUrl":"https://doi.org/10.2118/212388-stu","url":null,"abstract":"\u0000 Waterflooding is the main method of developing oil fields both in Western Siberia and in most other oil-producing countries. Most of these fields located in Russia are mature. Creating new technologies or optimizing the existing ones is the key to the effective development of residual hydrocarbon reserves. Optimization of a waterflood pattern is one of the main tasks of the oil industry. It implies planning and implementing a set of measures in the field that will affect the waterflood pattern and either increase the oil recovery factor, production or optimize the complex technical-economic parameter.\u0000 The purpose of the work is to increase the efficiency of oil field development by optimizing the waterflood pattern by means of hydrodynamic modeling on the example of the Western Siberian field.\u0000 Waterflood optimization can be accomplished by sidetracking or changing the development system. An integral element of a waterflood optimization system is always a field model, based on which the implementing different measures is planned. In this paper, hydrodynamic modeling was used to evaluate the effectiveness of waterflood optimization. It is considered one of the most powerful predictive tools available to reservoir engineers.\u0000 RN KIN software was studied, with the help of which the basic data about the field was obtained. The waterflood pattern was selected for the decision to implement a local measure. A hydrodynamic model was used to analyze the effectiveness of the measure. Waterflood pattern model of the field was built and adapted. Four measures, potentially aimed at increasing the efficiency of the waterflood pattern, were proposed. After carrying out calculations, the best of them was selected from a technical and economic point of view. Hydrodynamic modeling and calculation of development parameters were carried out in the Petrel software.\u0000 In the course of the study, the possibility of using hydrodynamic modeling to analyze the efficiency of the waterflood pattern was shown. Sidetracking of the longest length proved to be the most effective measure to increase cumulative oil production and reduce cumulative water production. Thus, the paper obtained results that can serve as a good basis for justifying the effectiveness of well intervention on the example of the oil field in Western Siberia.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123675449","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}