Pub Date : 2018-06-01DOI: 10.1109/EEM.2018.8469981
K. Poplavskaya, L. D. de Vries
The aggregator has been touted as the key enabler of active engagement of distributed energy resources and promises to contribute to greater economic efficiency in the European balancing markets by providing cheap sources of flexibility. This paper presents an empirical analysis of how aggregators organize themselves in relation to other market participants given the rules of the balancing market and the impact thereof on their participation. We reviewed how market design influences their choices by comparing three countries, Austria, Germany and the Netherlands, in the light of the goals set by the EU. Despite the EU policy drive to integrate aggregators, the participation of independent aggregators in the balancing market is so far limited. Relaxing the agreement requirements, allowing pool-based prequalification and standardizing compensation mechanisms unlocks more possible business models for the aggregator and may help create synergies among aggregators, suppliers and balance responsible parties.
{"title":"A (not so) Independent Aggregator in the Balancing Market Theory, Policy and Reality Check","authors":"K. Poplavskaya, L. D. de Vries","doi":"10.1109/EEM.2018.8469981","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469981","url":null,"abstract":"The aggregator has been touted as the key enabler of active engagement of distributed energy resources and promises to contribute to greater economic efficiency in the European balancing markets by providing cheap sources of flexibility. This paper presents an empirical analysis of how aggregators organize themselves in relation to other market participants given the rules of the balancing market and the impact thereof on their participation. We reviewed how market design influences their choices by comparing three countries, Austria, Germany and the Netherlands, in the light of the goals set by the EU. Despite the EU policy drive to integrate aggregators, the participation of independent aggregators in the balancing market is so far limited. Relaxing the agreement requirements, allowing pool-based prequalification and standardizing compensation mechanisms unlocks more possible business models for the aggregator and may help create synergies among aggregators, suppliers and balance responsible parties.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"73 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127216348","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 : 2018-06-01DOI: 10.1109/EEM.2018.8470005
P. Fonte, C. Monteiro, F. Barbosa
In this paper is studied an approach based on risk assessment to solve the scheduling of a power production system with variable power sources. The spinning reserves resulting from the unit commitment are analyzed too. In this methodology there are no infeasible solutions, only more or less costly solutions associated to the operation risks, such as, load or renewable production curtailment. The uncertainty of forecasted production and load demand are defined by probability distribution functions. The methodology is tested in a real case study, an island with high penetration of renewable power production. Finally, forecasted and measured reserves are compared, once the reserves are strongly linked with the forecasting quality. The results of a real case study are presented and discussed. They show the difficulty to achieve complete robust solutions.
{"title":"Analysis of Spinning Reserves in Systems with Variable Power Sources","authors":"P. Fonte, C. Monteiro, F. Barbosa","doi":"10.1109/EEM.2018.8470005","DOIUrl":"https://doi.org/10.1109/EEM.2018.8470005","url":null,"abstract":"In this paper is studied an approach based on risk assessment to solve the scheduling of a power production system with variable power sources. The spinning reserves resulting from the unit commitment are analyzed too. In this methodology there are no infeasible solutions, only more or less costly solutions associated to the operation risks, such as, load or renewable production curtailment. The uncertainty of forecasted production and load demand are defined by probability distribution functions. The methodology is tested in a real case study, an island with high penetration of renewable power production. Finally, forecasted and measured reserves are compared, once the reserves are strongly linked with the forecasting quality. The results of a real case study are presented and discussed. They show the difficulty to achieve complete robust solutions.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129924367","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469833
W. Zappa, T. Mulder, M. Junginger, M. van den Broek
With the growing penetration of zero-marginal-cost wind and solar photovoltaics leading to falling electricity wholesale prices in the energy-only market, several European countries have implemented capacity remuneration mechanisms (CRMs) in an attempt to ensure security of supply (SoS). However, the literature is far from conclusive whether CRMs are indeed a necessary and/or cost-effective way of ensuring SoS. In this study, we quantitatively compare three different market designs under different levels of wind and PV growth for the interconnected systems of Germany, France, Belgium and the Netherlands. Preliminary results show that average electricity prices decrease in markets supplemented with a CRM, as does the volatility of electricity prices. Whether or not the contribution of a CRM to SoS is worth the cost (and its possible adverse impact on energy market functioning) of implementing a CRM also remains to be evaluated.
{"title":"A Quantitative Evaluation of Capacity Remuneration Mechanisms in Europe","authors":"W. Zappa, T. Mulder, M. Junginger, M. van den Broek","doi":"10.1109/EEM.2018.8469833","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469833","url":null,"abstract":"With the growing penetration of zero-marginal-cost wind and solar photovoltaics leading to falling electricity wholesale prices in the energy-only market, several European countries have implemented capacity remuneration mechanisms (CRMs) in an attempt to ensure security of supply (SoS). However, the literature is far from conclusive whether CRMs are indeed a necessary and/or cost-effective way of ensuring SoS. In this study, we quantitatively compare three different market designs under different levels of wind and PV growth for the interconnected systems of Germany, France, Belgium and the Netherlands. Preliminary results show that average electricity prices decrease in markets supplemented with a CRM, as does the volatility of electricity prices. Whether or not the contribution of a CRM to SoS is worth the cost (and its possible adverse impact on energy market functioning) of implementing a CRM also remains to be evaluated.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"4565 1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123174685","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469829
Henry Martin, Scott Otterson
This paper presents a market model for the EPEX SPOT German continuous intraday market for electric power trading based on the limit order book (LOB). We use the EPEX SPOT M7 order book data, which contains all orders submitted to the German continuous intraday market, to simulate the historic course of the market. Thereby, we reconstruct the complete state of the LOB at every point in (trading) time. We validate our simulation by comparing the transactions that our simulation generated with the actual historical transactions available from a different data set. The LOB based market model can be used to include price volatility risk and illiquidity risk when simulating trading at the EPEX SPOT continuous intraday market. Furthermore, we present all preprocessing steps and decision rules necessary to correctly identify orders from the often ambiguous EPEX SPOT M7 order book data.
{"title":"German Intraday Electricity Market Analysis and Modeling Based on the Limit Order Book","authors":"Henry Martin, Scott Otterson","doi":"10.1109/EEM.2018.8469829","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469829","url":null,"abstract":"This paper presents a market model for the EPEX SPOT German continuous intraday market for electric power trading based on the limit order book (LOB). We use the EPEX SPOT M7 order book data, which contains all orders submitted to the German continuous intraday market, to simulate the historic course of the market. Thereby, we reconstruct the complete state of the LOB at every point in (trading) time. We validate our simulation by comparing the transactions that our simulation generated with the actual historical transactions available from a different data set. The LOB based market model can be used to include price volatility risk and illiquidity risk when simulating trading at the EPEX SPOT continuous intraday market. Furthermore, we present all preprocessing steps and decision rules necessary to correctly identify orders from the often ambiguous EPEX SPOT M7 order book data.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126236429","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 : 2018-06-01DOI: 10.1109/EEM.2018.8470019
N. Belonogova, V. Tikka, Jouni Haapaniemi, J. Haakana, S. Honkapuro, J. Partanen, P. Heine, Atte Pihkala, H. Hellman, Markku Hvvarinen
The objective of the study is to develop a methodology to define the optimal operating strategy of a battery energy storage system (BESS) on the end-customer's premises that delivers him/her the maximum annual profit. The applications considered are peak shaving and frequency regulation in the FCR-N hourly market. The methodology is applied to a large group of actual end-customers with hourly measured electricity consumption. The results indicate that the operating strategy depends strongly on the shape of the end-customer's load and the reward level in both applications. Finally, the sensitivity parameters and further research needs are listed.
{"title":"Methodology to Define a BESS Operating Strategy for the End-Customer in the Changing Business Environment","authors":"N. Belonogova, V. Tikka, Jouni Haapaniemi, J. Haakana, S. Honkapuro, J. Partanen, P. Heine, Atte Pihkala, H. Hellman, Markku Hvvarinen","doi":"10.1109/EEM.2018.8470019","DOIUrl":"https://doi.org/10.1109/EEM.2018.8470019","url":null,"abstract":"The objective of the study is to develop a methodology to define the optimal operating strategy of a battery energy storage system (BESS) on the end-customer's premises that delivers him/her the maximum annual profit. The applications considered are peak shaving and frequency regulation in the FCR-N hourly market. The methodology is applied to a large group of actual end-customers with hourly measured electricity consumption. The results indicate that the operating strategy depends strongly on the shape of the end-customer's load and the reward level in both applications. Finally, the sensitivity parameters and further research needs are listed.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126621336","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469927
R. Finck, Armin Ardone, W. Fichtner
Flow-Based Market Coupling (FBMC) is an advanced Capacity Calculation and Allocation Mechanism that accounts more appropriately for electricity grid constraints than the traditional Net Transfer Capacity (NTC) approach. While the method accounts for the impact of cross-border trades on the grid by translating commercial exchange into physical flows, the results depend on the underlying assumptions concerning the conditions in the grid at the time of market coupling. This paper focuses on the impact of different Generation Shift Keys (GSK) on the market outcome and generator dispatch. Six different GSK strategies are implemented and the effects are analyzed in a transmission grid representation of Germany, Poland and Czech Republic. The results show that the effect on the zonal level remain marginal compared to the difference between NTC and FBMC approach. However, this effect is limited to few generators, which are impacted significantly. Overall, there is a shift from flexible generation to cheaper base load generation.
{"title":"Impact of Flow-Based Market Coupling on Generator Dispatch in CEE Region","authors":"R. Finck, Armin Ardone, W. Fichtner","doi":"10.1109/EEM.2018.8469927","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469927","url":null,"abstract":"Flow-Based Market Coupling (FBMC) is an advanced Capacity Calculation and Allocation Mechanism that accounts more appropriately for electricity grid constraints than the traditional Net Transfer Capacity (NTC) approach. While the method accounts for the impact of cross-border trades on the grid by translating commercial exchange into physical flows, the results depend on the underlying assumptions concerning the conditions in the grid at the time of market coupling. This paper focuses on the impact of different Generation Shift Keys (GSK) on the market outcome and generator dispatch. Six different GSK strategies are implemented and the effects are analyzed in a transmission grid representation of Germany, Poland and Czech Republic. The results show that the effect on the zonal level remain marginal compared to the difference between NTC and FBMC approach. However, this effect is limited to few generators, which are impacted significantly. Overall, there is a shift from flexible generation to cheaper base load generation.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115317005","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469950
Charlotte Scouflaire
Capacity remuneration mechanisms (CRMs) are designed to improve investment incentives primarily through reducing revenue uncertainty. Replacing, partially or totally, the scarcity rent by a fixed annual capacity remuneration stabilizes revenues and mechanically lowers the risk premium required by investors. Numerous studies using numerical or analytical models compare the performance of systems with CRM to alternative market designs. The diversity of methods and results makes it difficult for non specialists to have a comprehensive view on CRMs efficiency. This analysis attempts to synthesize the current literature to assess whether the results of a panel of 23 papers indicate an improvement in investment conditions with capacity remuneration. The efficiency of market designs is assessed through the mainstream concerns in the literature: security of supply, welfare, price volatility and investment cycles performances. Our effort highlights the difficulty of capturing the issue of CRMs in a single unifying framework. The 23 studies analyzed do not converge towards one simple conclusion. Surprisingly, modeling decisions have little impact on results. Most studies in our panel agree on the efficiency of CRMs to reduce both price volatility and investment cycles compared to the energy only market. With respect to security of supply (SoS) and consumer surplus, the effects are overall beneficial although less consensual, mainly due to heterogeneous definition of SoS and surplus. With this respect, a more systematic effort of the research community to develop a common approach and language would certainly help advancing our understanding of CRMs further and send clearer signals to power systems regulators.
{"title":"What do Models tell us About Capacity Remuneration Mechanisms?","authors":"Charlotte Scouflaire","doi":"10.1109/EEM.2018.8469950","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469950","url":null,"abstract":"Capacity remuneration mechanisms (CRMs) are designed to improve investment incentives primarily through reducing revenue uncertainty. Replacing, partially or totally, the scarcity rent by a fixed annual capacity remuneration stabilizes revenues and mechanically lowers the risk premium required by investors. Numerous studies using numerical or analytical models compare the performance of systems with CRM to alternative market designs. The diversity of methods and results makes it difficult for non specialists to have a comprehensive view on CRMs efficiency. This analysis attempts to synthesize the current literature to assess whether the results of a panel of 23 papers indicate an improvement in investment conditions with capacity remuneration. The efficiency of market designs is assessed through the mainstream concerns in the literature: security of supply, welfare, price volatility and investment cycles performances. Our effort highlights the difficulty of capturing the issue of CRMs in a single unifying framework. The 23 studies analyzed do not converge towards one simple conclusion. Surprisingly, modeling decisions have little impact on results. Most studies in our panel agree on the efficiency of CRMs to reduce both price volatility and investment cycles compared to the energy only market. With respect to security of supply (SoS) and consumer surplus, the effects are overall beneficial although less consensual, mainly due to heterogeneous definition of SoS and surplus. With this respect, a more systematic effort of the research community to develop a common approach and language would certainly help advancing our understanding of CRMs further and send clearer signals to power systems regulators.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116551815","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469782
L. Petrichenko, Z. Broka, A. Sauhats, D. Bezrukovs
The paper is focused on economic feasibility analysis of battery energy storage providing load shifting to the end-user. Electro-chemical storage technology is considered, as it is envisioned to play an important role in future power systems by reducing costs, deferring investments and increasing reliability of system operation. In the study, cash-flows arising from battery investment and operation in a representative distribution grid are considered for a planning period of 33 years. Forecasting methodology based on Fourier transform for the hourly electricity market price is proposed and performed for a particular bidding area of the Nord Pool day-ahead market. Results of the case study demonstrate that with the current trends of market price and tariff structure of electricity paid by the end-users, investments in BESS may not be profitable and some additional incentives should be introduced.
{"title":"Cost-Benefit Analysis of Li-Ion Batteries in a Distribution Network","authors":"L. Petrichenko, Z. Broka, A. Sauhats, D. Bezrukovs","doi":"10.1109/EEM.2018.8469782","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469782","url":null,"abstract":"The paper is focused on economic feasibility analysis of battery energy storage providing load shifting to the end-user. Electro-chemical storage technology is considered, as it is envisioned to play an important role in future power systems by reducing costs, deferring investments and increasing reliability of system operation. In the study, cash-flows arising from battery investment and operation in a representative distribution grid are considered for a planning period of 33 years. Forecasting methodology based on Fourier transform for the hourly electricity market price is proposed and performed for a particular bidding area of the Nord Pool day-ahead market. Results of the case study demonstrate that with the current trends of market price and tariff structure of electricity paid by the end-users, investments in BESS may not be profitable and some additional incentives should be introduced.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131473163","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469799
Michal Klos, Marcin Jakubek, M. Krupa
In pursuit of the security of Power System, TSOs acknowledge the importance of activating demand side. However, any efficient design a DSR framework faces a trade-off between simplicity of a sharp definition of the service and the number of participants meeting the stringent entry requirements. In this work a different paradigm is presented by employing the techniques of operational optimization to settle a tender. The potential service providers are asked to list their available capacity, economic evaluation and other technical qualities in a form of offer. Next, the TSO assesses the offers and constructs a suitable subset of offers using a selection algorithm comparable to those solving Knapsack or Unit Commitment problems. Consequently, a competitive market for curtailment services is created. We prove it by case studies based on real offers for the Polish Emergency DSR.
{"title":"On a Market Design of Emergency DSR in Poland - Valuation and Optimal Acquisition of Services","authors":"Michal Klos, Marcin Jakubek, M. Krupa","doi":"10.1109/EEM.2018.8469799","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469799","url":null,"abstract":"In pursuit of the security of Power System, TSOs acknowledge the importance of activating demand side. However, any efficient design a DSR framework faces a trade-off between simplicity of a sharp definition of the service and the number of participants meeting the stringent entry requirements. In this work a different paradigm is presented by employing the techniques of operational optimization to settle a tender. The potential service providers are asked to list their available capacity, economic evaluation and other technical qualities in a form of offer. Next, the TSO assesses the offers and constructs a suitable subset of offers using a selection algorithm comparable to those solving Knapsack or Unit Commitment problems. Consequently, a competitive market for curtailment services is created. We prove it by case studies based on real offers for the Polish Emergency DSR.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128027829","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 : 2018-06-01DOI: 10.1109/EEM.2018.8469965
K. Lummi, A. Rautiainen, L. Peltonen, S. Repo, P. Jarventausta, Joni Rintala
In the Smart Grid environment, one novel concept is the microgrid, which can be either a very small entity or a larger one. For example, the microgrid can consists of resources of an individual small customer or of several customers each with their own energy resources inside a low-voltage network. The microgrid can also consist of a large area with various energy resources and a connection to the distribution grid. Especially, when the number of these large-scale microgrids increases, a central question is what kind of network tariff structure should be applied to them. The network tariffs can affect whether the microgrids will have a connection to the distribution grid. In this paper, a novel tariff structure for a large-scale microgrid is proposed. The results show that the benefits of the microgrid can be shared more fairly between it and the distribution system by applying a novel network tariff.
{"title":"Microgrids as Part of Electrical Energy System - Pricing Scheme for Network Tariff of DSO","authors":"K. Lummi, A. Rautiainen, L. Peltonen, S. Repo, P. Jarventausta, Joni Rintala","doi":"10.1109/EEM.2018.8469965","DOIUrl":"https://doi.org/10.1109/EEM.2018.8469965","url":null,"abstract":"In the Smart Grid environment, one novel concept is the microgrid, which can be either a very small entity or a larger one. For example, the microgrid can consists of resources of an individual small customer or of several customers each with their own energy resources inside a low-voltage network. The microgrid can also consist of a large area with various energy resources and a connection to the distribution grid. Especially, when the number of these large-scale microgrids increases, a central question is what kind of network tariff structure should be applied to them. The network tariffs can affect whether the microgrids will have a connection to the distribution grid. In this paper, a novel tariff structure for a large-scale microgrid is proposed. The results show that the benefits of the microgrid can be shared more fairly between it and the distribution system by applying a novel network tariff.","PeriodicalId":334674,"journal":{"name":"2018 15th International Conference on the European Energy Market (EEM)","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133459744","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}
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