Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems最新文献

{"title":"Design and Emulation of a Turbocharged Bio-Fuelled SOFC Plant","authors":"M. L. Ferrari, M. D. Campo, L. Magistri","doi":"10.1115/GT2018-75026","DOIUrl":"https://doi.org/10.1115/GT2018-75026","url":null,"abstract":"This paper presents a steady-state model of an innovative turbocharged solid oxide fuel cell system fed by biofuel. The aim of this plant layout is the development of a reduced-cost solution, which involves the pressurization carried out with a mass production machine such as a turbocharger (instead of a microturbine). The turbocharger pressurizes the solid oxide fuel cell to increase the performance.\u0000 Following the experimental results to choose the suitable machine and for validating the turbocharger model, this tool was implemented to model the whole plant. It was used to calculate the operational conditions and to define the coupling aspects between the turbocharger, the recuperator and the solid oxide fuel cell system (comprising a fuel cell stack, an air preheater, a reformer, an off-gas burner and an anodic ejector).\u0000 The model permitted the component characterization and supported the design of an emulator test rig based on the coupling of a turbocharger and a pressure vessel. This facility was designed to conduct the experimental tests at system level on the matching between the machine and the fuel cell, especially for the dynamic and the control system aspects. To emulate the fuel cell, the rig was based on a specially designed pressure vessel equipped with a burner and inert ceramic materials. Moreover, the facility was designed to produce the turbine inlet conditions in terms of mass flow, temperature, pressure and gas composition (similitude conditions can be evaluated).","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128209907","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":"Economic Optimization of Inlet Air Filtration for Gas Turbines","authors":"D. Grace, Christopher A. Perullo, J. Kee","doi":"10.1115/GT2018-75435","DOIUrl":"https://doi.org/10.1115/GT2018-75435","url":null,"abstract":"Selecting the appropriate level of filtration for a gas turbine helps to minimize overall unit costs and maximize net revenue. When selecting a filter type and configuration, one must consider the initial costs, operational costs, and ongoing maintenance costs for both the filter and corresponding impacts on unit performance. Calculations are complex, and a fully functional framework is needed to properly account for all aspects of the life cycle and provide an opportunity to optimize filter selection and water wash scenarios for specific plant operating conditions. Decisions can generally be based on several different criteria. For instance, one may wish to minimize maintenance costs, maximize revenue, minimize fuel consumption, etc. For criteria that can be expressed in monetary terms, Life Cycle Cost Analysis (LCCA) is a means to simultaneously consider all criteria and reduce them to a single parameter for optimization using present value arithmetic. To be practically applied, the analysis must include all the significant inputs that would have an impact on the relative comparison between alternatives, while excluding minor inputs that would unduly add to complexity.\u0000 This paper provides an integrated, quantitative, and transparent approach to life cycle cost analysis for gas turbine inlet filtration. Most prior art tends to focus either on how to perform the life cycle cost analysis (with simplified assumptions on the impact of filtration on performance), or on a specific technical aspect of filtration such as filter efficiency and performance, the impact of dust on compressor blading and fouling, or the impact of fouling on overall gas turbine performance. Many of these studies provide useful insight into specific aspects of gas turbine degradation due to fouling, but make simplifying assumptions that can lead to inaccuracies in application.\u0000 By heavily leveraging prior work, this paper provides the reader with an overview of all aspects of the functionality required to perform such a life cycle analysis for gas turbine filtration. This work also serves as a technical summary of the underlying physics models that lead to the development of EPRI’s Air Filter Life-Cycle Optimizer (AFLCO) software. The software tool provides a method to account for the influence of gas turbine type, operating conditions, load profile, filtration choices, and wash type and frequency on overall life-cycle costs. The AFLCO tool is focused on guiding the user to make optimum filter selections and water wash scheduling, accounting for all the significant parameters that affect the economic outcome. Revenue and cost quantities are considered simultaneously to determine the net present value of gross revenue minus filtration and water wash costs over a multiple year analysis period. The user defines the scenarios and the software displays the net present value (NPV) and present value difference between the scenarios. The preferred configuration from an LCCA perspecti","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127757484","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":"Start-Up Optimization of a CCGT Power Station Using Model Based Gas Turbine Control","authors":"A. Nannarone, S. Klein","doi":"10.1115/gt2018-76230","DOIUrl":"https://doi.org/10.1115/gt2018-76230","url":null,"abstract":"The rapid growth of renewable generation and its intermittent nature has modified the role of combined cycle power stations in the energy industry, and the key feature for the operational excellence is now flexibility. Especially, the capability to start an installation quickly and efficiently after a shutdown period leads to lower operational cost and a higher capacity factor. However, most of existing thermal power stations worldwide are designed for continuous operation, with no special focus on an efficient start-up process. In most current start-up procedures, the gas turbine controls ensure maximum heat flow to the heat recovery steam generator, without feedback from the steam cycle. The steam cycle start-up controls work independently with as main control parameter the limitation of the thermal stresses in the steam turbine rotor. In this paper, a novel start-up procedure of an existing combined cycle power station is presented, and it uses a feedback loop between the steam turbine, the boiler and the gas turbine start-up controls. This feedback loop ensures that the steam turbine can be started up with a significant reduction in stresses.\u0000 To devise and assess this start-up methodology, a flexible and accurate dynamic model was implemented in the Simulink™ environment. It contains more than 100 component blocks (heat exchangers, valves, meters and sensors, turbines, controls, etc.), and the mathematical component sub-models are based on physical models and experimental correlations. This makes the model generally applicable to other power plant installations. The model was validated against process data related to the three start-up types (cold start, warm start, hot start). On this basis, the optimization model is implemented with feedback loops that control for example the exit temperature of the gas turbine based on the actual steam turbine housing temperature, resulting in a smoother heating up of the steam turbine.\u0000 The optimization model was used to define the optimal inlet guide vanes position and gas turbine power output curves for the three types of start-up. These curves were used during real power station start-ups, leading to, for cold and warm starts, reductions in the start-up time of respectively 32.5% and 31.8%, and reductions in the fuel consumption of respectively 47.0% and 32.4%. A reduction of the thermal stress in the steam turbines is also achieved, thanks to the new start-up strategy.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"59 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127730263","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":"Demonstration of ORC System Powered by Waste Heat From the Heuksando Island Internal Combustion Diesel Power Plant","authors":"Sanghyup Lee, Hoon Jung","doi":"10.1115/GT2018-75126","DOIUrl":"https://doi.org/10.1115/GT2018-75126","url":null,"abstract":"Geographical characteristics give the island of Heuksando no choice but to use diesel power generation. This option is not economical, and more than half of the generated energy is released through exhaust gas, cooling water, and other sources of energy loss. In order to reduce these losses and improve power generation efficiency, this research studied Organic Rankine Cycle systems that use waste heat from diesel power plants as a heat source. Unlike previous Rankine cycles, electric power generation and operation are possible because of low heat source and capacity. Cycle design and demonstration-operation logic are required to set the range of waste heat temperature and capacity. In addition, as the overall efficiency may change substantially depending on the efficiency of each component, the operating conditions of various BOPs should be optimized. It is necessary to obtain the optimization and operating conditions of each element of the system through modeling and numerical study of the whole system. In this research, heat source analysis and BOP design were conducted in order to apply the 20kW/30kW ORC systems to the Heuksando Island 1MW diesel power plant. A heat-connecting technique that thermally connects the heat exhaust end piping and the evaporator of the ORC system was developed in this study. The demonstration experiment was conducted sharing the waste heat source with the 20kW and 30kW ORC systems. This paper presents the waste heat analysis and the demonstration operation results of the Heuksando island power plant.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130701526","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":"Inlet Air Filter Elements Site and Laboratory Tests of Four Different Manufacturers","authors":"S. Ingistov, J. Kohn","doi":"10.1115/GT2018-75428","DOIUrl":"https://doi.org/10.1115/GT2018-75428","url":null,"abstract":"This Paper describes three-month onsite testing utilizing travelling laboratory furnished with four dedicated air ducts and required instrumentation needed to determine efficiency of filtration for submicron size particles. It also describes the subsequent testing of seasoned filters in offsite Laboratory furnished with instrumentation and equipment to conduct the dry and wet tests on previously Watson-field tested filters.\u0000 The opportunity to simultaneously test four different IAFE, provided by four different Manufacturers, was unique and helpful in discerning the differences between these filters.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125429646","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":"Power to Ice: A Novel Approach to Stabilize Non-Programmable Renewable by Means of Gas Turbine IACC","authors":"M. A. Ancona, M. Bianchi, L. Branchini, A. Brilloni, A. D. Pascale, F. Melino, A. Peretto","doi":"10.1115/GT2018-75216","DOIUrl":"https://doi.org/10.1115/GT2018-75216","url":null,"abstract":"Large penetration of non-programmable energy sources, such as wind, is a challenging issue for grid operators and quick ramping fossil fuel generators. Indeed, the variability and fluctuation of renewables (i.e. rapid change in generation over relatively short time periods) is increasing the need for regulating power. In this context and according to Authors knowledge, the innovative approach proposed in this study is to use a gas turbine equipped with continuous cooling in order to stabilize the power output generation of renewable generators. The gas turbine power boost, obtained thanks to inlet air cooling, will compensate for renewable generators underproduction. On the opposite, in case of renewable generators power output surplus, the excess of power is driven to a compressor chiller device for cold water storage, then used to chill gas turbine inlet air whenever needed.\u0000 A detailed performance evaluation on the proposed system is carried out showing the influence of most important parameters (i.e. additional pressure losses introduced with the cooling device, gas turbine models and assumed derating coefficients, etc.).\u0000 A feasibility analysis of the investigated system is presented for several case studies in case of wind generators (two different gas turbine models, different wind farm nameplate capacity, different power output set points), investigating the volume of tanks necessary to stabilize wind fluctuations.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122705403","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":"Compressor Instability Analysis Within an Hybrid System Subject to Cycle Uncertainties","authors":"Alessandra Cuneo, A. Traverso, A. Massardo","doi":"10.1115/gt2018-76504","DOIUrl":"https://doi.org/10.1115/gt2018-76504","url":null,"abstract":"The transient/dynamic modeling of energy systems can be used for different purposes. Important information can be obtained and used for the design phase. The control system and strategies can be safely tested on transient/dynamic models in simulation, increasing the confidence during experimental phase. Furthermore, these models can be used to acquire useful information for safety case. The analysis of energy systems in dynamic conditions is generally performed considering fixed values for both geometrical and operational parameters such as volumes, orifices, but also initial temperatures, pressure, etc. However, such characteristics are often subject to uncertainty, either because they are not known accurately or because they may depend on the operating conditions at the beginning of the relevant transient. With focus on a micro-gas turbine fuel cell hybrid system, compressor surge may or may not occur during transients, depending on the aforementioned cycle characteristics; hence compressor surge events are affected by uncertainty.\u0000 In this paper, a stochastic analysis was performed taking into account an emergency shut-down in a fuel cell gas turbine hybrid system, modelled with TRANSEO, a deterministic tool for the transient and dynamic simulations of energy systems. The aim of the paper is to identify the main parameters that impact on compressor surge margin. The stochastic analysis was performed through the RSA (Response Sensitivity Analysis) method, a sensitivity-based approximation approach that overcomes the computational burden of sampling methods such as MCS (Monte-Carlo Simulation). The results show that the minimum surge margin occurs in two different ranges of rotational speed: a high-speed range and a low-speed range, the latter being more sensitive for surge occurrence. The temperature and geometrical characteristic of the outer pressure vessel, where the fuel cell is installed, are the two main parameters that affect the surge margin during an emergency shut down.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115730965","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":"An Integrated Simulation Tool Proposed for Modeling and Optimization of CCHP Units","authors":"A. Safari, V. Berezkin, M. Assadi","doi":"10.1115/GT2018-75193","DOIUrl":"https://doi.org/10.1115/GT2018-75193","url":null,"abstract":"A novel framework for operation optimization of a combined cooling, heating, and power (CCHP) system has been proposed. The goal of the study was to develop an automatic optimization tool based on the integration of IPSEpro simulation software and the MATLAB programming environment to strategically manage the operation of a hybrid energy system of micro gas turbine (MGT), auxiliary boiler, and absorption chiller. Data exchange between the tools was organized via a COM interface. An experimentally validated model of the commercial AE-T100 CCHP unit was utilized, the objective being to minimize a cost function of operational and capital investments costs, subject to a set of constraints. The micro CCHP plant was considered to be a part of a grid. Electricity trading was therefore taken into account. The performance of the developed framework was investigated through the optimization task, case study data for a 24-hour period in July and December, different electricity and gas price profiles and ambient conditions being used. The operation strategy could be heat-led or power-led. The optimum number and load of the CCHP units and the boilers and the amount of electricity which should be bought from and/or sold to the grid were therefore determined by the optimization strategies. Lastly, the results were analyzed and show that the integrated optimization tool developed provides a valuable contribution to the enhanced management of such a CCHP system, specifically when a large number of distributed units are considered. In other words, the proposed framework was flexible enough and has the potential to be extended and further developed to handle more complicated energy systems and operational conditions.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125439566","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":"Evolution of MHPS Large Frame Gas Turbines: J to Air-Cooled JAC","authors":"Suzuki Kentaro, Y. Matsumura, Kazumasa Takata, Satoshi Hada, M. Yuri, J. Masada","doi":"10.1115/GT2018-77273","DOIUrl":"https://doi.org/10.1115/GT2018-77273","url":null,"abstract":"Mitsubishi Hitachi Power Systems, Ltd. (MHPS) has continued to contribute to the preservation of the global environment and the stable supply of energy through the constant development of gas turbines. The contribution is based on the abundant operating results, research, and verification of state-of-the-art technology. Since 2014 MHPS has been using progressive knowledge obtained from the Japanese National Project’s “1700°C Class Ultrahigh-Temperature Gas Turbine Component Technology Development.” The highly-efficient M501J gas turbine was successfully developed and has achieved the world’s first turbine inlet temperature of 1600°C because of this effort. Verification operation of the M501J at T-point, the verification plant, which MHPS owns in Takasago, started in 2011. Thereafter, M501J gas turbines have been delivered all over the world, and have accumulated more than 500,000 Actual Operating Hours (AOH). To further improve the efficiency and power output of the gas turbine combined cycle (GTCC), a new enhanced air-cooled system for the combustor was installed replacing the steam-cooled system employed in the J-series. The compressor was also redesigned with an advanced design approach that ensures the mechanical soundness of the parts and the performance upgrade in inlet flow as well as start-up characteristics.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"13 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127724047","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":"Performance of a Semi-Closed Oxy-Fuel Combustion Combined Cycle (SCOC-CC) With an Air Separation Unit (ASU)","authors":"Majed Sammak, Marcus Thern, Magnus Genrup","doi":"10.1115/GT2018-76218","DOIUrl":"https://doi.org/10.1115/GT2018-76218","url":null,"abstract":"The objective of this paper is to evaluate the performance of a semi-closed oxy-fuel combustion combined cycle (SCOC-CC) and its power penalties. The power penalties are associated with CO2 compression and high-pressure oxygen production in the air separation unit (ASU). The paper discusses three different methods for high pressure oxygen (O2) production. Method 1 is producing O2 directly at high pressure by compressing the air before the air separation takes place. Method 2 is producing O2 at low pressure and then compressing the separated O2 to the desired pressure with a compressor. Method 3 is alike the second method, except that the separated liquid O2 is pressurized with a liquid oxygen pump to the desired pressure.\u0000 The studied SCOC-CC is a dual-pressure level steam cycle due to its comparable efficiency with three pressure level steam cycle and less complexity.\u0000 The SCOC-CC, ASU and CO2 compression train are modeled with the commercial heat and mass balance software IPSEpro. The paper analyzed the SCOC-CC performance at different combustion outlet temperatures and pressure ratios. The combustion outlet temperature (COT) varied from 1200 °C to 1550 °C and the pressure ratio varied from 25 to 45.\u0000 The study is concerned with mid-sized SCOC-CC with a net power output 100 MW. The calculations were performed at the selected design point which was at 1400°C and pressure ratio at 37. The calculated power consumption of the O2 separation at a purity of 95 % was 719 kJ/kgO2. The power consumption for pressurizing the separated O2 (method 2) was 345 kJ/kgO2 whereas it was 4.4 kJ/kgO2 for pumping liquid O2 to the required pressure (method 3). The calculated power consumption for pressurizing and pumping the CO2-enriched stream was 323 kJ/kgCO2.\u0000 The SCOC-CC gross efficiency was 57.6 %. The SCOC-CC net efficiency at method 2 for air separation was 46.7 %. The gross efficiency was reduced by 9 % due to ASU and other 2 % due to CO2 compression. The SCOC-CC net efficiency at method 3 of the air separation was 49.6 %. The ASU reduced the gross efficiency by 6 % and additional 2 % by CO2 compression. Using method 3 for air separation gave a 3 % gain in cycle efficiency.","PeriodicalId":131179,"journal":{"name":"Volume 3: Coal, Biomass, and Alternative Fuels; Cycle Innovations; Electric Power; Industrial and Cogeneration; Organic Rankine Cycle Power Systems","volume":"65 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124448400","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}