Pub Date : 2017-06-01DOI: 10.1109/EEM.2017.7981923
M. Hinterstocker, Paul Schott, Serafin von Roon
Based on measured load data in high temporal resolution, the time-dependent load shifting potential of residential electricity customers can be assessed. This enables the simulation of their reaction to different variable retail electricity rates, and consequently the evaluation of the suitability of these rate structures for various applications. The focus is on time-of-use rates with two price levels, which incentivize load shifting from high to low prices. The results show that this kind of rate structure is not the optimal choice for the examined applications; therefore, it is recommended to include additional rate elements like demand charges or peak pricing. However, the high computational effort suggests the development of a new rate optimization strategy for the introduction of additional parameters.
{"title":"Evaluation of the effects of time-of-use pricing for private households based on measured load data","authors":"M. Hinterstocker, Paul Schott, Serafin von Roon","doi":"10.1109/EEM.2017.7981923","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981923","url":null,"abstract":"Based on measured load data in high temporal resolution, the time-dependent load shifting potential of residential electricity customers can be assessed. This enables the simulation of their reaction to different variable retail electricity rates, and consequently the evaluation of the suitability of these rate structures for various applications. The focus is on time-of-use rates with two price levels, which incentivize load shifting from high to low prices. The results show that this kind of rate structure is not the optimal choice for the examined applications; therefore, it is recommended to include additional rate elements like demand charges or peak pricing. However, the high computational effort suggests the development of a new rate optimization strategy for the introduction of additional parameters.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"69 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":"127100298","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.2017.7981933
Paul E. Kunz, S. Vögele
We present a structured scenario method for the development of transparent, plausible and consistent scenarios. By a case study on the development of European energy scenarios, the process of the Cross-Impact-Balance approach will be explained and challenges and advantages will be derived.
{"title":"Cross-impact balance as an approach for the development of consistent storylines for the European energy market","authors":"Paul E. Kunz, S. Vögele","doi":"10.1109/EEM.2017.7981933","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981933","url":null,"abstract":"We present a structured scenario method for the development of transparent, plausible and consistent scenarios. By a case study on the development of European energy scenarios, the process of the Cross-Impact-Balance approach will be explained and challenges and advantages will be derived.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"21 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":"125382123","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.2017.7981942
Philipp Hauser, Hannes Hobbie, D. Möst
The German “Energiewende” aims at fostering a de-carbonisation of the entire energy system. In the electricity sector, a shift from traditionally nuclear and coal-based production towards renewable energies and lower carbon intensive gas power plants can be expected. Additionally, heat production from gas fuels will play a more dominant role. This results in a stronger dependence of the electrical power and heat sector on a reliable and secure operation of the underlying natural gas (NG) provision infrastructure. Growing uncertainties in the electricity and NG systems have in and of themselves been widely analysed. With this paper, we question how uncertainties in power and heat production development compromise the NG supply and thereby endanger energy security. We introduce a NG pipeline model with a detailed grid representation of northeast Germany. We utilise two representative days to model the NG demand differentiated by heat, industry and power sector consumption. Using a cost minimisation approach, we investigate possible congestions in the gas grid to assess if and to what extent NG pipelines can be seen as a crucial bottleneck for future energy security. Our results show the resilience of the NG system during a scenario of a MILD winter day. However, simultaneous NG demand peaks in the heat and power sector in the COLD scenario might lead to congestions in some regions.
{"title":"Resilience in the German natural gas network: Modelling approach for a high-resolution natural gas system","authors":"Philipp Hauser, Hannes Hobbie, D. Möst","doi":"10.1109/EEM.2017.7981942","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981942","url":null,"abstract":"The German “Energiewende” aims at fostering a de-carbonisation of the entire energy system. In the electricity sector, a shift from traditionally nuclear and coal-based production towards renewable energies and lower carbon intensive gas power plants can be expected. Additionally, heat production from gas fuels will play a more dominant role. This results in a stronger dependence of the electrical power and heat sector on a reliable and secure operation of the underlying natural gas (NG) provision infrastructure. Growing uncertainties in the electricity and NG systems have in and of themselves been widely analysed. With this paper, we question how uncertainties in power and heat production development compromise the NG supply and thereby endanger energy security. We introduce a NG pipeline model with a detailed grid representation of northeast Germany. We utilise two representative days to model the NG demand differentiated by heat, industry and power sector consumption. Using a cost minimisation approach, we investigate possible congestions in the gas grid to assess if and to what extent NG pipelines can be seen as a crucial bottleneck for future energy security. Our results show the resilience of the NG system during a scenario of a MILD winter day. However, simultaneous NG demand peaks in the heat and power sector in the COLD scenario might lead to congestions in some regions.","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":"125804259","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.2017.7981986
K. Forbes, Ernest M. Zampelli
Wind energy forecast errors, while modest when weighted by wind energy capacity, are quite large relative to the average level of actual wind energy generation. For example, while the capacity weighted root mean squared error (CWRMSE) of day-ahead wind energy forecasts for the 50Hertz control area in Germany over the period 1 January 2015 through 31 December 2015 is just 4.5 percent, the energy-weighted root-mean-squared-error (EWRMSE) is almost five times as large at 21.67 percent. Our analysis also indicates that the errors in 50Hertz's wind energy forecasts are statistically related to forecasted weather conditions. Based on this finding and the time-series attributes of the forecast errors, an ARCH/ARMAX model was formulated to predict wind energy generation. The model's forecasting accuracy was evaluated using out-of-sample data over the period 1 January 2015 through 31 December 2015. The out-of-sample period-ahead predictions have a EWRMSE of about 2.93 percent and CWRMSE of about 0.60 percent.
{"title":"The accuracy of wind energy forecasts and prospects for improvement","authors":"K. Forbes, Ernest M. Zampelli","doi":"10.1109/EEM.2017.7981986","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981986","url":null,"abstract":"Wind energy forecast errors, while modest when weighted by wind energy capacity, are quite large relative to the average level of actual wind energy generation. For example, while the capacity weighted root mean squared error (CWRMSE) of day-ahead wind energy forecasts for the 50Hertz control area in Germany over the period 1 January 2015 through 31 December 2015 is just 4.5 percent, the energy-weighted root-mean-squared-error (EWRMSE) is almost five times as large at 21.67 percent. Our analysis also indicates that the errors in 50Hertz's wind energy forecasts are statistically related to forecasted weather conditions. Based on this finding and the time-series attributes of the forecast errors, an ARCH/ARMAX model was formulated to predict wind energy generation. The model's forecasting accuracy was evaluated using out-of-sample data over the period 1 January 2015 through 31 December 2015. The out-of-sample period-ahead predictions have a EWRMSE of about 2.93 percent and CWRMSE of about 0.60 percent.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"28 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":"125790250","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.2017.7981991
R. Dzikowski, B. Olek
This paper deals with home batteries and their economic viability under a service in which a prosumer possessing a roof-top PV system can purchase a battery system with the special price from an electricity provider and obtains annual fees for assumed time period. It is done in exchange for sharing some part of battery capacity with the entity. The aim of this study is to check whether it is economically viable from a prosumer perspective, basing on a service offered by one of the EU electricity providers. Authors do that by comparison of computed economic indicators in several prosumer system scenarios and by applying various commercially available solar home battery systems. Additionally, identification of selected conditions that should be satisfied to ensure the financial return from the investment in battery storage is provided. Apart from LCOE, relative annual cash flow is used as the economic indicator of financial outcome. The obtained results as well as conclusions pose the basis for further researches on development of economic models of dispersed home battery systems coupled with small renewable energy sources.
{"title":"Capacity sharing — Economic analysis of home battery systems","authors":"R. Dzikowski, B. Olek","doi":"10.1109/EEM.2017.7981991","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981991","url":null,"abstract":"This paper deals with home batteries and their economic viability under a service in which a prosumer possessing a roof-top PV system can purchase a battery system with the special price from an electricity provider and obtains annual fees for assumed time period. It is done in exchange for sharing some part of battery capacity with the entity. The aim of this study is to check whether it is economically viable from a prosumer perspective, basing on a service offered by one of the EU electricity providers. Authors do that by comparison of computed economic indicators in several prosumer system scenarios and by applying various commercially available solar home battery systems. Additionally, identification of selected conditions that should be satisfied to ensure the financial return from the investment in battery storage is provided. Apart from LCOE, relative annual cash flow is used as the economic indicator of financial outcome. The obtained results as well as conclusions pose the basis for further researches on development of economic models of dispersed home battery systems coupled with small renewable energy sources.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"25 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":"121538972","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.2017.7982014
J. Hörsch, Carla Mendes
The current electricity market is facing new challenges as the sector moves towards a low-carbon energy system. Germany's power system is currently moving to a regional concentration of electricity supply and demand, which increases network congestion. In order to solve possible contingencies, reserve requirements are used to ensure that enough energy is available to re-balance the system. However, this measure might not be reliable in congested systems. To that extent, zones are used to address inter-zonal congestion, but intra-zonal congestion is still a problem that lacks efficient ways to solve it. We focus on quantifying the benefit of managing intra-zonal congestion using tertiary reserve capacities and of additionally splitting the reserve market into zones. The results show that the combination of balancing and congestion market is the most efficient solution since it decreases the total reserve demand quantities needed to solve possible contingencies.
{"title":"Integrating balancing reserves and congestion management to re-balance the German system","authors":"J. Hörsch, Carla Mendes","doi":"10.1109/EEM.2017.7982014","DOIUrl":"https://doi.org/10.1109/EEM.2017.7982014","url":null,"abstract":"The current electricity market is facing new challenges as the sector moves towards a low-carbon energy system. Germany's power system is currently moving to a regional concentration of electricity supply and demand, which increases network congestion. In order to solve possible contingencies, reserve requirements are used to ensure that enough energy is available to re-balance the system. However, this measure might not be reliable in congested systems. To that extent, zones are used to address inter-zonal congestion, but intra-zonal congestion is still a problem that lacks efficient ways to solve it. We focus on quantifying the benefit of managing intra-zonal congestion using tertiary reserve capacities and of additionally splitting the reserve market into zones. The results show that the combination of balancing and congestion market is the most efficient solution since it decreases the total reserve demand quantities needed to solve possible contingencies.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"25 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":"131372576","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.2017.7982022
L. Ryan, Sarah La Monaca, Linda Mastrandrea
Increasing recognition that current electricity retail tariffs are ill-adapted to future electricity systems and markets has motivated this paper to examine how retail tariffs need to be reformed to facilitate the energy transition. This paper reviews existing residential retail tariff structures and explores through case studies of Ireland, Italy, and California the implications of retail tariff structure and design for the policy targets of energy efficiency, renewable electricity generation, demand response, in addition to electricity system cost recovery. The research should add empirical insights to the body of academic literature on the subject and be of interest to policy makers wishing to consider retail tariff structures that promote decarbonisation of the electricity system through multiple objectives of improved energy efficiency and increased shares of renewable electricity with future electricity markets.
{"title":"Designing retail tariffs to decarbonise the electricity system","authors":"L. Ryan, Sarah La Monaca, Linda Mastrandrea","doi":"10.1109/EEM.2017.7982022","DOIUrl":"https://doi.org/10.1109/EEM.2017.7982022","url":null,"abstract":"Increasing recognition that current electricity retail tariffs are ill-adapted to future electricity systems and markets has motivated this paper to examine how retail tariffs need to be reformed to facilitate the energy transition. This paper reviews existing residential retail tariff structures and explores through case studies of Ireland, Italy, and California the implications of retail tariff structure and design for the policy targets of energy efficiency, renewable electricity generation, demand response, in addition to electricity system cost recovery. The research should add empirical insights to the body of academic literature on the subject and be of interest to policy makers wishing to consider retail tariff structures that promote decarbonisation of the electricity system through multiple objectives of improved energy efficiency and increased shares of renewable electricity with future electricity markets.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"38 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":"114952824","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.2017.7981921
C. Fraunholz, Florian Zimmermann, D. Keles, W. Fichtner
With rising shares of fluctuating renewable energy generation, the role of electricity storage becomes increasingly important. However, European pumped storage plants (PSPs) are currently confronted with economic challenges and their potential for smoothing the residual load curve is consequently not fully exploited. In this paper, the long-term effects of load-smoothing and the typical price-based PSP operation are compared with an emphasis on the development of the wholesale electricity prices and the generation adequacy. The study is conducted using an agent-based simulation model of the day-ahead electricity market that has been extended by a methodology to heuristically dispatch the PSPs in Germany. The results show, that the contribution load-smoothing PSP operation can make to improving generation adequacy is rather small. Putting a strategic reserve in place reduces the differences between price-based and load-smoothing PSP operation even further. Moreover, load-smoothing PSP operation goes along with slightly increased wholesale electricity prices as compared to price-based operation.
{"title":"Price-based versus load-smoothing pumpec storage operation: Long-term impacts on generation adequacy","authors":"C. Fraunholz, Florian Zimmermann, D. Keles, W. Fichtner","doi":"10.1109/EEM.2017.7981921","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981921","url":null,"abstract":"With rising shares of fluctuating renewable energy generation, the role of electricity storage becomes increasingly important. However, European pumped storage plants (PSPs) are currently confronted with economic challenges and their potential for smoothing the residual load curve is consequently not fully exploited. In this paper, the long-term effects of load-smoothing and the typical price-based PSP operation are compared with an emphasis on the development of the wholesale electricity prices and the generation adequacy. The study is conducted using an agent-based simulation model of the day-ahead electricity market that has been extended by a methodology to heuristically dispatch the PSPs in Germany. The results show, that the contribution load-smoothing PSP operation can make to improving generation adequacy is rather small. Putting a strategic reserve in place reduces the differences between price-based and load-smoothing PSP operation even further. Moreover, load-smoothing PSP operation goes along with slightly increased wholesale electricity prices as compared to price-based operation.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129526290","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.2017.7981890
Sara Proença, P. Fortes
The European Union (EU) has long been at the forefront of international efforts to tackle climate change. The challenge becomes designing the most cost-eDective policy mix, capable of reducing greenhouse gas (GHG) emissions at the lowest cost to the economy. In this paper, an integrated CGE modelling approach is applied to explore the cost-effectiveness of EU climate policy, taking Portugal as a case study. Results indicate that the current EU climate policy configuration makes GHG reduction more costly than needed. The mitigation targets for 2030 could be achieved at least cost through the implementation of a comprehensive cap-and-trade system instead of the actual emission market segmentation. Moreover, the economic argument on counterproductive overlapping regulation is not corroborated by our results. This finding shows the importance of considering the specificities of each Member State when designing policy mixes. Results also highlight the importance of considering market distortions when assessing policy performance.
{"title":"How cost effective is EU climate policy? Evidence from Portugal using integrated modelling","authors":"Sara Proença, P. Fortes","doi":"10.1109/EEM.2017.7981890","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981890","url":null,"abstract":"The European Union (EU) has long been at the forefront of international efforts to tackle climate change. The challenge becomes designing the most cost-eDective policy mix, capable of reducing greenhouse gas (GHG) emissions at the lowest cost to the economy. In this paper, an integrated CGE modelling approach is applied to explore the cost-effectiveness of EU climate policy, taking Portugal as a case study. Results indicate that the current EU climate policy configuration makes GHG reduction more costly than needed. The mitigation targets for 2030 could be achieved at least cost through the implementation of a comprehensive cap-and-trade system instead of the actual emission market segmentation. Moreover, the economic argument on counterproductive overlapping regulation is not corroborated by our results. This finding shows the importance of considering the specificities of each Member State when designing policy mixes. Results also highlight the importance of considering market distortions when assessing policy performance.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"12 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":"133665538","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.2017.7981874
J. Kong, H. Skjelbred
As a reliable and flexible electric power source, hydropower can quickly adjust its generation level and provide reserve power to balance the power fluctuations in the system. In this paper, we assume that the day-ahead spot market is cleared and the obligation for each reserve type is already contracted in a preceding market. Then the question is how to make the optimal decision to determine, for each unit and for each time step, the dispatched volume for the day-ahead market and the reserved capacity for various types of reserve. We formulate the constraints added to the optimization problem for distributing reserve obligations. The proposed mathematical formulation is based on an operational hydropower scheduling model used by most large hydro-power producers in Scandinavia.
{"title":"Operational hydropower scheduling with post-spot distribution of reserve obligations","authors":"J. Kong, H. Skjelbred","doi":"10.1109/EEM.2017.7981874","DOIUrl":"https://doi.org/10.1109/EEM.2017.7981874","url":null,"abstract":"As a reliable and flexible electric power source, hydropower can quickly adjust its generation level and provide reserve power to balance the power fluctuations in the system. In this paper, we assume that the day-ahead spot market is cleared and the obligation for each reserve type is already contracted in a preceding market. Then the question is how to make the optimal decision to determine, for each unit and for each time step, the dispatched volume for the day-ahead market and the reserved capacity for various types of reserve. We formulate the constraints added to the optimization problem for distributing reserve obligations. The proposed mathematical formulation is based on an operational hydropower scheduling model used by most large hydro-power producers in Scandinavia.","PeriodicalId":416082,"journal":{"name":"2017 14th International Conference on the European Energy Market (EEM)","volume":"14 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":"132059601","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：