Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981913
P. P. B. Machado, G. C. Tenaglia, D. Ramos, J. Hunt
Considering a system based on hydroelectricity, with a significant penetration of renewables (wind and solar) and high barriers to build new dams and reservoirs; this paper presents the benefits that the installation of pumped-storage power plants (PSP) could add to such system, improving its efficiency and respecting the expanding boundaries. A case study was developed considering sixteen hydroelectric plants from a real cascade, one equivalent PSP and five wind farms. Through an evolutionary algorithm, the PSP operation was optimized focusing on minimizing the spillage that could be used to generate power in a convenient moment. To prove this concept, three different hydrologic scenarios were analyzed: wet, dry and medium seasons; based on the real water inflow of the river, according to historical measurements. This investigation makes possible to conclude that a PSP can effectively reduce the effects of intermittency of wind and solar generation, optimizing a subsystem having a topological structure commonly found in the Brazilian Interconnected System.
{"title":"Pumped-storage plants improving Brazilian interconnected system operation when facing high solar and wind sources participation","authors":"P. P. B. Machado, G. C. Tenaglia, D. Ramos, J. Hunt","doi":"10.1109/EEM.2017.7981913","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981913","url":null,"abstract":"Considering a system based on hydroelectricity, with a significant penetration of renewables (wind and solar) and high barriers to build new dams and reservoirs; this paper presents the benefits that the installation of pumped-storage power plants (PSP) could add to such system, improving its efficiency and respecting the expanding boundaries. A case study was developed considering sixteen hydroelectric plants from a real cascade, one equivalent PSP and five wind farms. Through an evolutionary algorithm, the PSP operation was optimized focusing on minimizing the spillage that could be used to generate power in a convenient moment. To prove this concept, three different hydrologic scenarios were analyzed: wet, dry and medium seasons; based on the real water inflow of the river, according to historical measurements. This investigation makes possible to conclude that a PSP can effectively reduce the effects of intermittency of wind and solar generation, optimizing a subsystem having a topological structure commonly found in the Brazilian Interconnected System.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122244835","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981931
Susanne Rieß, Christoph Neumann, Samuel Glismann, Michael Schoepf, G. Fridgen
Electricity market design varies across countries throughout Europe. Thereby the provision and remuneration of flexibility always takes place in short-term market segments. Taking into consideration the fundamental changes of the power system, this paper discusses options for the future short-term market design. We develop a conceptual basis for a possible integration of currently separated short-term market segments. Market segment integration (MSI) is defined as the interaction between and possible combination of market segments, i.e. intraday market (ID), congestion management (CM) and balancing market (BA). The paper especially focusses on two options, namely an integrated BA and CM market and an integrated ID and CM market. For these options we determine the basic design features. We propose a criteria catalogue which allows the evaluation of the market design options. Based on several criteria we discuss possible positive and negative consequences as well as potential solutions.
{"title":"Rethinking short-term electricity market design: Options for market segment integration","authors":"Susanne Rieß, Christoph Neumann, Samuel Glismann, Michael Schoepf, G. Fridgen","doi":"10.1109/EEM.2017.7981931","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981931","url":null,"abstract":"Electricity market design varies across countries throughout Europe. Thereby the provision and remuneration of flexibility always takes place in short-term market segments. Taking into consideration the fundamental changes of the power system, this paper discusses options for the future short-term market design. We develop a conceptual basis for a possible integration of currently separated short-term market segments. Market segment integration (MSI) is defined as the interaction between and possible combination of market segments, i.e. intraday market (ID), congestion management (CM) and balancing market (BA). The paper especially focusses on two options, namely an integrated BA and CM market and an integrated ID and CM market. For these options we determine the basic design features. We propose a criteria catalogue which allows the evaluation of the market design options. Based on several criteria we discuss possible positive and negative consequences as well as potential solutions.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"350 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131929661","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981856
Luis Boscán, K. Skytte, Emilie Rosenlund Soysal
This paper introduces the concept of flexibility-friendly support policies, i.e. state-of-the-system-dependent sub-sidies given to producers of electricity who base their output on renewable energy sources (RES). Such policies increase with demand, decrease with the availability of Variable Renewable Energy (VRE) producers and, overall, follow the power system's residual load. The paper presents a microeconomic framework to analyze this and other desirable properties of support mechanisms. To illustrate the concept, it uses the present-day policies of Nordic and Baltic countries (Denmark, Estonia, Finland, Latvia, Lithuania, Sweden and Norway) as a case study.
{"title":"Flexibility-friendly support policies: A Nordic and Baltic perspective","authors":"Luis Boscán, K. Skytte, Emilie Rosenlund Soysal","doi":"10.1109/EEM.2017.7981856","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981856","url":null,"abstract":"This paper introduces the concept of flexibility-friendly support policies, i.e. state-of-the-system-dependent sub-sidies given to producers of electricity who base their output on renewable energy sources (RES). Such policies increase with demand, decrease with the availability of Variable Renewable Energy (VRE) producers and, overall, follow the power system's residual load. The paper presents a microeconomic framework to analyze this and other desirable properties of support mechanisms. To illustrate the concept, it uses the present-day policies of Nordic and Baltic countries (Denmark, Estonia, Finland, Latvia, Lithuania, Sweden and Norway) as a case study.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132156780","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7982028
L. Mantzos, N. Matei, Máté Rózsai, P. Russ, A. S. Ramírez
This paper lays out the key features of the new modelling tool POTEnCIA (Policy Oriented Tool for Energy and Climate Change Impact Assessment) for the EU energy system. The model follows a hybrid partial equilibrium approach combining behavioural decision with detailed techno-economic data. Special features are introduced in order to appropriately reflect the implications of an uptake of novel energy technologies and of evolving market structures, allowing for the robust assessment of ambitious policy futures for the EU energy system. The model runs in annual time steps with a typical projection timeline to 2050.
{"title":"POTEnCIA: A new EU-wide energy sector model","authors":"L. Mantzos, N. Matei, Máté Rózsai, P. Russ, A. S. Ramírez","doi":"10.1109/EEM.2017.7982028","DOIUrl":"https://doi.org/10.1109/EEM.2017.7982028","url":null,"abstract":"This paper lays out the key features of the new modelling tool POTEnCIA (Policy Oriented Tool for Energy and Climate Change Impact Assessment) for the EU energy system. The model follows a hybrid partial equilibrium approach combining behavioural decision with detailed techno-economic data. Special features are introduced in order to appropriately reflect the implications of an uptake of novel energy technologies and of evolving market structures, allowing for the robust assessment of ambitious policy futures for the EU energy system. The model runs in annual time steps with a typical projection timeline to 2050.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131614197","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7982017
Clemens Gerbaulet, C. von Hirschhausen, C. Kemfert, Casimir Lorenz, Pao-Yu Gei
Since the climate conferences in Paris and Marrakesh the outstanding question is not if but how and how fast to enable a decarbonization of the European electricity sector. Nuclear power has a difficult time to survive in electricity markets in all Western countries, such as the U.S., Europe, Japan, etc., and is getting increasingly under pressure due to high costs, and the falling costs of alternative sources, such as renewable energies in combination with storage technologies. This paper compares different approaches to decarbonize the electricity sector in Europe using a specific model developed by the authors called dynEL-MOD. We find that, renewables carry the major burden of decarbonization. Scenario analysis suggests that only in the case of a breakthrough of CCTS some biomass-CCTS plants can play a role by 2050 through their negative CO2-emissions. Nuclear power (3rd or 4th generation), on the contrary, is unable to compete with other fuels even by then, and will, therefore, rely on dedicated national programs to survive until 2050. Incorporating the climate targets makes the investment into any additional fossil capacity uneconomic from 2025 onwards, resulting in a coal and natural gas phase-out in the 2040s. The model is run using different foresight assumptions. Limited foresight thus results in stranded investments of fossil capacities in the 2020s. Using a CO2 budgetary approach, on the other hand, leads to an even sharper emission reduction in the early periods before 2030, reducing overall costs.
{"title":"Scenarios for decarbonizing the European electricity sector","authors":"Clemens Gerbaulet, C. von Hirschhausen, C. Kemfert, Casimir Lorenz, Pao-Yu Gei","doi":"10.1109/EEM.2017.7982017","DOIUrl":"https://doi.org/10.1109/EEM.2017.7982017","url":null,"abstract":"Since the climate conferences in Paris and Marrakesh the outstanding question is not if but how and how fast to enable a decarbonization of the European electricity sector. Nuclear power has a difficult time to survive in electricity markets in all Western countries, such as the U.S., Europe, Japan, etc., and is getting increasingly under pressure due to high costs, and the falling costs of alternative sources, such as renewable energies in combination with storage technologies. This paper compares different approaches to decarbonize the electricity sector in Europe using a specific model developed by the authors called dynEL-MOD. We find that, renewables carry the major burden of decarbonization. Scenario analysis suggests that only in the case of a breakthrough of CCTS some biomass-CCTS plants can play a role by 2050 through their negative CO2-emissions. Nuclear power (3rd or 4th generation), on the contrary, is unable to compete with other fuels even by then, and will, therefore, rely on dedicated national programs to survive until 2050. Incorporating the climate targets makes the investment into any additional fossil capacity uneconomic from 2025 onwards, resulting in a coal and natural gas phase-out in the 2040s. The model is run using different foresight assumptions. Limited foresight thus results in stranded investments of fossil capacities in the 2020s. Using a CO2 budgetary approach, on the other hand, leads to an even sharper emission reduction in the early periods before 2030, reducing overall costs.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133574553","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981859
R. Massa, Juan Rosellón
Understanding the causal directions between electricity consumption (EC)/electricity production (EP) and Gross Domestic Product (GDP) is helpful for policymakers in order to design, redesign, and implement effective energy policies. Although there are many studies on this issue, no consistent conclusion exists. In this paper, we provide an updated analysis of such relationship for Mexico. We employ three causality tests and find no evidence of causal relation between EC/EP and GDP between 1965 and 2014. This has implications for the Mexican energy legislation liberalizing the electricity generation sector. Our results suggest that Mexican policymakers should consider enriching the bill by further designing policies that seek to promote enhanced generation output and capacity.
{"title":"Links between production and consumption of electricity with economic performance in Mexico","authors":"R. Massa, Juan Rosellón","doi":"10.1109/EEM.2017.7981859","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981859","url":null,"abstract":"Understanding the causal directions between electricity consumption (EC)/electricity production (EP) and Gross Domestic Product (GDP) is helpful for policymakers in order to design, redesign, and implement effective energy policies. Although there are many studies on this issue, no consistent conclusion exists. In this paper, we provide an updated analysis of such relationship for Mexico. We employ three causality tests and find no evidence of causal relation between EC/EP and GDP between 1965 and 2014. This has implications for the Mexican energy legislation liberalizing the electricity generation sector. Our results suggest that Mexican policymakers should consider enriching the bill by further designing policies that seek to promote enhanced generation output and capacity.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124019415","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981941
Philip Tafarte, Patrick Buck
The decarbonisation of the economy calls for an increase in demand from renewable power supply, that in many countries has to be provided by variable renewable energy source (vRES) like wind and solar. In this article, we will give an outlook on how system friendly wind turbines can contribute to mitigate this challenge today and improve future cross-sectorial use. Therefore we use various time series data to model the market value of wind turbines and provide scenarios for the German power system in 2035 to assess the potential of system friendly wind energy.
{"title":"Integration of wind power — Challenges and options for market integration and its impact on future cross-sectorial use","authors":"Philip Tafarte, Patrick Buck","doi":"10.1109/EEM.2017.7981941","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981941","url":null,"abstract":"The decarbonisation of the economy calls for an increase in demand from renewable power supply, that in many countries has to be provided by variable renewable energy source (vRES) like wind and solar. In this article, we will give an outlook on how system friendly wind turbines can contribute to mitigate this challenge today and improve future cross-sectorial use. Therefore we use various time series data to model the market value of wind turbines and provide scenarios for the German power system in 2035 to assess the potential of system friendly wind energy.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128083566","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}
Pub Date : 2017-06-06DOI: 10.1109/EEM.2017.7981885
G. Goretti, A. Duffy, T. Lie
An increasing number of utilities participating in the energy market require short term (i.e. up to 48 hours) power forecasts for renewable generation in order to optimize technical and financial performances. As a result, a large number of forecast providers now operate in the marketplace, each using different methods and offering a wide range of services. This paper assesses five different day-ahead wind power forecasts generated by various service providers currently operating in the market, and compares their performance against the state-of-the-art of short-term wind power forecasting. The work focuses on how power curve estimations can introduce systematic errors that affect overall forecast performance. The results of the study highlight the importance of: accurately modelling the wind speed-to-power output relationships at higher wind speeds; taking account of power curve trends when training models; and the need to incorporate long-term (months to years) power curve variability into the forecast updating process.
{"title":"The impact of power curve estimation on commercial wind power forecasts — An empirical analysis","authors":"G. Goretti, A. Duffy, T. Lie","doi":"10.1109/EEM.2017.7981885","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981885","url":null,"abstract":"An increasing number of utilities participating in the energy market require short term (i.e. up to 48 hours) power forecasts for renewable generation in order to optimize technical and financial performances. As a result, a large number of forecast providers now operate in the marketplace, each using different methods and offering a wide range of services. This paper assesses five different day-ahead wind power forecasts generated by various service providers currently operating in the market, and compares their performance against the state-of-the-art of short-term wind power forecasting. The work focuses on how power curve estimations can introduce systematic errors that affect overall forecast performance. The results of the study highlight the importance of: accurately modelling the wind speed-to-power output relationships at higher wind speeds; taking account of power curve trends when training models; and the need to incorporate long-term (months to years) power curve variability into the forecast updating process.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131091228","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}
Pub Date : 2017-06-01DOI: 10.1109/EEM.2017.7981951
Salvador Doménech, J. Villar, F. A. Campos, M. Rivier
Plenty of literature exists about how to model liberalized electricity generation markets for the medium and long terms, contributing to the analyze and understanding of those markets, helping companies to plan cost-efficient shortterm market strategies and/or long-term generation capacity investments, and supporting regulators and policymakers in policy decisions and market designs. However, those models do not explicitly consider the impact on investment decisions, mix of technologies and wholesale market prices; of policy decisions but as an external passive input to the model. This paper reviews existing approaches to model policy decisions in such a context, and provides a theoretical modeling framework that explicitly considers the interaction of policymakers' decisions with the generation investment and operation, and customers' response in a liberalized power system. Such kind of model, based on bi-level optimization, contributes to the longterm assessment of some policy decisions in the electricity sector.
{"title":"Towards a simplified approach for modeling policymaker's decisions in the power sector","authors":"Salvador Doménech, J. Villar, F. A. Campos, M. Rivier","doi":"10.1109/EEM.2017.7981951","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981951","url":null,"abstract":"Plenty of literature exists about how to model liberalized electricity generation markets for the medium and long terms, contributing to the analyze and understanding of those markets, helping companies to plan cost-efficient shortterm market strategies and/or long-term generation capacity investments, and supporting regulators and policymakers in policy decisions and market designs. However, those models do not explicitly consider the impact on investment decisions, mix of technologies and wholesale market prices; of policy decisions but as an external passive input to the model. This paper reviews existing approaches to model policy decisions in such a context, and provides a theoretical modeling framework that explicitly considers the interaction of policymakers' decisions with the generation investment and operation, and customers' response in a liberalized power system. Such kind of model, based on bi-level optimization, contributes to the longterm assessment of some policy decisions in the electricity sector.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124776601","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}
Pub Date : 2017-06-01DOI: 10.1109/EEM.2017.7981968
P. Zolotarev
This paper investigates the social welfare of balancing markets. The technical background of balancing, the load-frequency control processes, is presented along with an overview of the market design options and cost-bearing mechanisms. A social welfare model is derived based on the assumption of an inelastic demand for balancing services. The results show that the social welfare of balancing markets does not depend on the prices of balancing services. The social welfare increase in cross-border cooperations is driven by the reduction of the underlying costs of balancing service provision. Since prices do not affect social welfare of balancing, it remains constant under marginal and pay-as-bid pricing as long as the same bids are selected to supply a given demand. Nonetheless, a market design where bid prices reflect marginal costs of balancing service provision has advantages for cross-border cooperations and practical aspects of market design.
{"title":"Social welfare of balancing markets","authors":"P. Zolotarev","doi":"10.1109/EEM.2017.7981968","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981968","url":null,"abstract":"This paper investigates the social welfare of balancing markets. The technical background of balancing, the load-frequency control processes, is presented along with an overview of the market design options and cost-bearing mechanisms. A social welfare model is derived based on the assumption of an inelastic demand for balancing services. The results show that the social welfare of balancing markets does not depend on the prices of balancing services. The social welfare increase in cross-border cooperations is driven by the reduction of the underlying costs of balancing service provision. Since prices do not affect social welfare of balancing, it remains constant under marginal and pay-as-bid pricing as long as the same bids are selected to supply a given demand. Nonetheless, a market design where bid prices reflect marginal costs of balancing service provision has advantages for cross-border cooperations and practical aspects of market design.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"184 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123225060","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：