Day 2 Tue, March 21, 2023最新文献

{"title":"Design and Drilling Performance of Two Exploratory Wells in Argentinean Parva Negra Oeste Shale Gas Field from the Vaca Muerta Formation. Experiences and Lessons Learnt.","authors":"Martin Matesanz, S. Bodini, Jesus Quintero Ramirez, Raul Diz, Luis Pablo Forni, Nicolas Alberto Fumagalli","doi":"10.2118/212413-ms","DOIUrl":"https://doi.org/10.2118/212413-ms","url":null,"abstract":"\u0000 Parva Negra Oeste field is located 90 km north-west far from Añelo City in Neuquén Province, Argentina. It is considered an unconventional dry gas field targeting Vaca Muerta Formation in exploration phase. It is located on the east flank of Dorso de los Chihuidos with presence of over-pressure and faulting. Several wells were drilled in the area in order to test production and acquire information, which showed a complex drilling scenario and an abandonment rate of 40%.\u0000 In order to define well architecture, nearby well's events were studied in a radius of 15 km, detecting gas kicks and mud losses at different depths and formations. With this information shoe depth, operative mud window and contingency casing were defined with focus in well integrity and operational hazard control. These problematic events were integrated with the seismic data and zones of structural quietness were selected in order to reduce the probability of occurrence.\u0000 Both wells were successfully drilled. Although gas kicks were detected, at similar depths to nearby wells and at new zones or formations, with the use of Managed Pressure Drilling (MPD) and appropriate mechanical design, these events overcome successfully in a short period of time. Depth Interval from 1000 to 2000 mts (Agrio and Huitrin Formations) had a higher hardness than expected and abundant carbonates, decreasing rop for this interval of the first well. For second well, with the rock hardness log of the first well, the Bottom Hole Assembly (BHA) and drilling parameters were modified, with better results. A contingency liner was considered in order to isolate Quintuco Formation from Vaca Muerta Formation, but it was not needed. In both cases, all logging information were effectively acquired and 90 mts of core were extracted in the second well, with a recovery factor of 100%.\u0000 This paper provides experiences and techniques to successfully drill in a zone where information is scarce and neighbor wells were abandoned in a high rate.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127459483","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":"Vaca Muerta Corrosiveness and Its Impact in Production Strategy","authors":"Lelio Alberto Gawantka da Silva, Roberto Toro Padilla, Mariano Sebastián Molina, Claudio Fabián Benedetto, Pedro Olivo, R. Mazzina","doi":"10.2118/213886-ms","DOIUrl":"https://doi.org/10.2118/213886-ms","url":null,"abstract":"\u0000 The complexity of the problem and the severity of corrosion found at certain fields of shale gas in Vaca Muerta made necessary to develop a program that included predictive analysis through semi-empirical corrosion-erosion models, comparison of materials through the installation of coupons in downhole wells and, finally, the execution of several pilots in the field under real operating conditions. On top of this, an exhaustive monitoring of the physical-chemical conditions of the fluids and the performance of the analyzed materials was executed.\u0000 The corrosion problem associated with the development of Vaca Muerta is extremely complex. Aggressive agents such as CO2 were observed in a wide range of quantities, accompanied by a high concentration of chlorides in the flow-back water together with high initial flows and the presence of a high concentration of sand of fracture (proppant) in the early stage of the well. The combination of these agents presupposes a risky scenario for some tubular materials.\u0000 Therefore, to limit the probability of failure and ensure the integrity of the installations during the production life, a coupon evaluation program was carried out in the field with alloys containing 3% and 13% Cr, accompanied by predictive analysis, loss of thickness in pipe through different models known in the industry. Finally, a pilot program has been executed at the field, monitoring the pipes with successive multi-fingers calipers to determine the impact of corrosion on the materials.\u0000 The conclusion of this entire process made it possible to establish a production strategy that minimizes the risk of failure due to corrosion and contributes to the integrity of the downhole installations during their service life, minimizing interventions and ensuring the operational continuity of the well.\u0000 All this process is going to be presented at this work, detailing the engineering process prior to propose an alternative to mitigate the problem from the joint vision of an operator in the region and a tubular manufacturer.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121380723","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":"Enhancing Stimulation Efficiency in a Highly Fractured Open-Hole Carbonate Reservoir Section by Diversion Design Using Advanced Modelling Techniques","authors":"M. Omer, Diana L. Velázquez, Carmen J. Ramírez, F. Fragachán, Juan Briceño","doi":"10.2118/212424-ms","DOIUrl":"https://doi.org/10.2118/212424-ms","url":null,"abstract":"\u0000 Stimulation fluids injected into a reservoir take the path of least resistance, leaving behind under-stimulated areas. As a result, the stimulation efficiency and effectiveness are reduced, affecting the overall production potential. The placement efficiency of a stimulation treatment depends on maximizing fluids contact in the zone of interest (good penetration) and uniform distribution across the section. To achieve uniform distribution, existing higher permeability areas or natural fractures must be efficiently and temporarily blocked, diverting the treatment towards the section with low permeability and higher skin. This process is known as diversion.\u0000 In this paper, we utilize an analytical model based on computational fluid dynamics and discrete element modeling to simulate treatment placement efficiency and diversion effectiveness in high-pressure/high-temperature (HPHT) carbonate formations, from a long open hole highly fractured reservoir interval in a well in South America. The case study demonstrates that parameters playing a key role were flow rate, spacers between diverting pills, type of diversion fluid carrier, rheology of carrier fluid, number of diversion stages, and displacement rate. The modeling calibrated against an actual field case demonstrates the space for improvement that can be customized depending upon the type of application.\u0000 The results indicate that without using diversion, the lower part of the openhole section is left under-stimulated in comparison to the top section as the top section had the presence of natural fractures. When diversion was utilized to optimize the design, the stimulation efficiency in the lower section improved considerably and ultimately had a high impact on the production of the well. This paper uses an actual case study to demonstrate the value created and overall production enhancement despite the excellent results achieved. It also summarizes the engineering workflow to optimize diversion design in carbonates HPHT openhole formations.\u0000 We believe that an engineering approach is critical in the design of a successful stimulation in an open hole with considerable presence of natural fractures in some parts of the section of interest. The results demonstrate the effectiveness of advanced modeling in evenly distributing the stimulation fluid and thereby increasing its effectiveness enhancing the production across the target zone. A case study from a field job in South America will be presented based on job evaluation and actual well production performance. Actual well intervention and treatment design are discussed. The lessons learned from this case study can be applied for stimulation design and planning for future jobs in the area.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124095071","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":"Determining a Flow Zone Indicator in Conventional and Unconventional Reservoirs Using Resistivity Logs","authors":"J. W. González, Alejandro Jose Linares, Diego Armando Rodriguez, Alexander Castro Chacon, J. Vásquez","doi":"10.2118/212572-ms","DOIUrl":"https://doi.org/10.2118/212572-ms","url":null,"abstract":"\u0000 The Flow Zone Indicator (FZI) depends on permeability and porosity. The permeability of a reservoir is one of the most difficult properties to determine, since the models to calculate permeability use input from several logs (gamma ray, density-neutron, sonic, etc.). Permeability modeling is done using complex methodologies such as: matching learning, fuzzy logic, cluster, multiple linear regression, etc., and at the end, permeability models end up being unique for each reservoir. The objective of this work is to determine a flow zone indicator (FZI) from the deep (Rt) and shallow resistivity (Rs) logs in conventional and unconventional reservoirs.\u0000 Basically, the methodology consisted of studying the phenomenon of the invasion of mud filtration during the drilling of the wells, and the behavior of resistivity logs. Invasion affects some properties of porous and permeable formations in the vicinity of a well. In general, the invasion is small in very porous and permeable reservoirs, the opposite is in poorly permeable reservoirs, tight, vuggy carbonates or fractured formations. Based on the above, a mathematical model was proposed to determine the FZI, as a logarithmic function which is applicable in both water and oil-based muds. If the resistivities are equal, then there is no mud filtration invasion, and the permeability is zero. If the difference in resistivity is different from zero, there is invasion of the sludge filtrate and therefore the permeability is greater than zero, indicating flow zones in the reservoir. There are other borehole, formation and tool conditions that may generate difference between RT and RS which are not related to invasion. These will be explained briefly below.\u0000 The FZI model identified the flow zones in the reservoir. FZI from core and Nuclear Magnetic Resonance (NMRI) log data correlated with the FZI calculated with the model. The mobility data of formation testers agreed with the calculated FZI. Also, spectral noise and PLT logs inflow zones showed excellent correlation with the FZI.\u0000 This methodology can be applied in any type of reservoir. In exploration wells the methodology allows to define and propose the best zones to set the formation testers, thus optimizing operational time. Before performing a petrophysical assessment, FZI results can identify prospective zones of the reservoir based on rock quality. Also, the production and injection behavior of the wells can be monitored with the obtained results. And finally, the FZI as an independent variable decreases the uncertainty of a permeability model, because the FZI is intimately related to the texture of the rock and the facies. The simplest expression of this is the resistivity variation with changes of porosity. Therefore, if porosity is related to facies, so is the formation factor (F), and then the resistivity log becomes an excellent facies discriminator.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116511355","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":"Flowback and Well Testing Operational Learnings During an Early Production Stage in a Vaca Muerta Field","authors":"Pablo Nicolás Cano, Verónica Laura Irazuzta, Miguel Andrés Curtti, Matias Guillermo Álvarez","doi":"10.2118/212398-ms","DOIUrl":"https://doi.org/10.2118/212398-ms","url":null,"abstract":"\u0000 La Calera is an unconventional wet gas field located close to Añelo city in Neuquén province. There are currently 30 horizontal wells in production from Vaca Muerta formation, drilled at three different landings zones, gathered in 3-well pads. The wells are first opened using testing facilities in order to evaluate their productivity, as well as to prevent liquids and sand from reaching plant facilities. This paper describes the lessons learned after the first wells flowback, the different events that had to be sorted (sand blockage, erosion, hydrates, etc.) and the operational workflows that were created in order to manage sand and fluids production from the wells.\u0000 Testing facilities consist primarily of two gas-oil-water 3-phase separators, a flash medium pressure separator, and a last separation stage used to stabilize the condensate in a flash-tank. There is also one desander per well, and several tanks in order to collect liquids in the pad location. This equipment is necessary because the wells are currently flowing to Early Production Facilities (EPF) that do not allow liquid slugs nor high sand production. Gas, condensate and water rates, well head pressures and sand production are measured in every well hourly. A first choke management strategy for each well is proposed and their productivities are estimated using previous wells information regarding productivity, ratios, sand production, and a choke correlation.\u0000 The first unconventional well was opened in 2019. Three years after and using flowback lessons learned, several testing configurations were changed, liquids heaters removed, sand equipment changed, line diameters modified, chemical injection points and doses adjusted, and different operational criteria established. A sand management workflow was developed and is currently being applied during pads openings.\u0000 During the first clean up period that usually lasts from 3 to 4 months, the initial choke management plan is constantly being modified due to operational challenges such as hydrates formation, excessive sand or liquid production, and operational problems like valve failures or facilities limitations, all of which will be described in this paper.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132110757","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":"Laboratory and Digital Petrophysical Multiscale Analysis of Porosity Types in Vaca Muerta Formation in El Mangrullo Field","authors":"C. Naides, D. Marchal","doi":"10.2118/212427-ms","DOIUrl":"https://doi.org/10.2118/212427-ms","url":null,"abstract":"\u0000 Unconventional shales reservoirs are complex in terms of composition, variable scales of analysis (from centimeter to nanometer) and petrophysical properties. To characterize these reservoirs, detailed analyses are required, including studies of rock samples in a wide range of scales.\u0000 Extracted from a shale gas well (El Mangrullo Field, southwest of Neuquén Basin), the studied core involves a 123 m thick section within the lower enriched section (informally subdivided into Cocina, Parrilla, Orgánico Inferior y Orgánico Superior intervals) of Vaca Muerta Formation.\u0000 This study consists in processing, interpreting, and integrating all the information from routine petrophysical laboratory studies (Tight Rock Analysis - TRA), well logs and high-resolution rock analysis (Digital Rock Analysis - DRA) using a customized and tailored workflow that provides quantitative and qualitative results.\u0000 Permeability, total and effective porosity, organic porosity, and their distribution and another petrophysical properties (like pore size distribution, etc.) are characterized. The integration of the laboratory and DRA results allows the elaboration of a permoporous properties model. This model allowed us to integrate petrophysical model with the production of horizontal wells drilled in different sections of Vaca Muerta Formation.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128819896","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":"Importance of Real-Time Data to Improve Operational Efficiency for Unconventional Drilling in Argentina","authors":"Rui Fernandes, Manuel Adrian Orellana Natera, Carolina S M Barros, Alisson Nogueira, Dismas Bismo Tjitrosoemarto, Stian Skjævesland, Sanna Zainoune","doi":"10.2118/212393-ms","DOIUrl":"https://doi.org/10.2118/212393-ms","url":null,"abstract":"\u0000 YPF is the most active drilling operator in Argentina, and in the last few years, its drilling and workover activities have been growing significantly. In 2018, as part of the digitalisation journey of the company, a Monitoring and Control Centre was established with a long-term vision to standardise and change the way unconventional wells are drilled in Argentina.\u0000 This paper describes an initiative to build infrastructure that manages real-time data across multiple unconventional assets, by using a real-time monitoring platform which follows the WITSML 1.4.1.1 industry standard. This project was divided into three strategic stages: implementation of a tool to acquire real-time data through WITSML, implementation of the tool and new workflows to improve data quality, by working closer with data providers, and improvements in drilling performance with the help of real-time data. Implementing the above strategies improved operational efficiencies and provided lessons learnt for each stage of implementation.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122655317","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":"Increasing Infill Recovery by Drilling Extended Lateral Wells in Vaca Muerta Unconventional Reservoir","authors":"Nicolas Calegari, Leonel Vera, Cristian Bahl, T. Aparicio, J. Cabanilla","doi":"10.2118/212434-ms","DOIUrl":"https://doi.org/10.2118/212434-ms","url":null,"abstract":"\u0000 Vaca Muerta is main UCR in Argentina and most of the concessions in country, drill horizontal wells with lateral lengths (landing point to well TD) of 2500-2800 m. Loma Campana Project developed strategy to develop complex areas by changing well architecture and methodology to drill wells with lateral lengths >4000 m. The team evaluated the feasibility of the project by generating potential well scenarios, prepared specific procedures and documentation during the Planning Phase and defined the Engineering and tools required to drill. Team executed pilot wells and immediately optimized results to massify development with new architecture.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121621798","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":"Adapting Digital Environment to Sustain Operations Remotely","authors":"A. Abbasgholipour, N. Panwar, Chulakorn Yosakrai, V. Wibowo, Pham Nam Hieu, Sorawit Amranand","doi":"10.2118/212714-ms","DOIUrl":"https://doi.org/10.2118/212714-ms","url":null,"abstract":"\u0000 Oil and gas remote operations (RO) enabled by automation and digital solutions are reducing the number of people required to work in the wellsite; many subject matter experts can now complete their daily tasks from the safety of the office in town. We have been transitioning to these new ways of working for some time, and the progress has been greatly accelerated to help ensure business continuity for customers during COVID-19 restrictions, allowing high numbers of wellsite operatives the freedom to work from home.\u0000 For the Oil & Gas companies that have experimented with more technology, the results have been incredible. Digital transformation has finally hit the industry and it’s taking off to meet sustainable goal of upstream companies, this transformation is one such measure by which these goals can be approached. Despite the global availability of technology to handle analytical task from a safe distance, substantial drilling activities have been carried out traditionally across globe.\u0000 Such traditional drilling operations were carried out in Thailand where client and SLB work together in fast paced factory drilling environment where an oil well can drill and complete within 7 days for 2 strings (2-sections only) 2400-2600 m in onshore operation which requires experienced people to monitor and execute tasks.\u0000 To support such operation from town i.e., remotely with systematic monitoring by skilled people, one requires to adapt digitization. This paper demonstrates the ability of SLB to adapt the digital environment by introducing \"Remote Operation Center\" setup enabling to help client achieve their sustainable goals within budget and provided an alternate solution to sustain operations in COVID-19 pandemic.\u0000 Remote Operations is the ability to operate a system or a machine at a distance; one can handle multiple operations from a safe environment of office in town using technology. It unfolds analytical task & physical task; the former is handed over to Remote Operation Center and physical task is left at rig crew. The Remote Operation Center execute both Directional Drilling (DD) and Measurement & Logging While Drilling (MLWD) services at the well site, from town. Executing Directional Drilling Remote Operation was more challenging.\u0000 RO moves industry towards future and pushes all other traditional players to work on sustainable goals while adapting to digital environment. On site presence of crew was reduced by 50% while maintaining same pace of operations with better data analysis.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117002307","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Numerical Simulation of Proppant Transport in Complex Fracture Network","authors":"Nilzon Aguirre, H. Xiaodong","doi":"10.2118/212713-ms","DOIUrl":"https://doi.org/10.2118/212713-ms","url":null,"abstract":"\u0000 The development of extensive networks of fractures, also known as complex fracturing, is necessary for improving performance in very low-permeability, mainly stress-isotropic rocks, particularly shales reservoirs. Proppant transport and placement in these fractures are significantly impacted by the combination of naturally occurring and hydraulically induced fractures, which results in a complex fracture network.\u0000 In this study a three-dimensional hybrid CFD model combined with the kinetic theory of granular flow (KTGF) is used to investigate the effect of complex fractures in the transport and placement of proppant, the simulation was first validated with experimental data, then, the effects of size, velocity and fracturing fluid viscosity for a tortuous complex fracture is investigated.\u0000 The simulation results matched well with the experimental data. According to the parametric analysis, smaller proppant size, and high fluid viscosity help in proppant transit into the secondary fracture and generate a larger effective propped area, the increase in velocity leads to proppants to be able to enter into the secondary fracture, whereas for smaller velocity the proppants stay in the main fracture. Additionally, tortuous complex fractures geometry led to more resistance opposite to the flow direction and make more difficult the proppant transport.\u0000 This research helps to improve the hydraulic fracturing design for shale formations by extending our understanding of proppant transport in complex tortuous fracture systems using a hybrid CFD approach.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123331548","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}