Pub Date : 2019-06-23DOI: 10.1109/PTC.2019.8810980
Igor Delgado de Melo, J. Pereira, C. Duque, M. P. Antunes, L. R. Manso Silva, M. A. de Souza
In this work, synchronized measurements are used for power system monitoring based on hardware-in-the-loop simulations. A metering equipment with phasor measurement unit function is used to monitor in real time electrical and power quality parameters such as voltage phasors, THD (Total Harmonic Distortion), IHD (Individual Harmonic Distortion), system frequency and voltage sags in a power grid. Simulations are carried out using RTDS (Real Time Digital Simulator) in order to compare simulated values with their corresponding measured ones, with the purpose of investigating the metering equipment performance by hardware-in-the-loop tests.
在这项工作中，同步测量被用于电力系统监测基于硬件在环仿真。一种具有相量测量单元功能的计量设备，用于实时监测电网中电压相量、总谐波失真(THD)、个别谐波失真(IHD)、系统频率和电压凹陷等电能质量参数。利用RTDS (Real Time Digital Simulator)进行仿真，将仿真值与相应的实测值进行比较，通过硬件在环测试来研究计量设备的性能。
{"title":"Power Quality Monitoring using Synchronized Phasor Measurements: An approach based on hardware-in-the-loop simulations","authors":"Igor Delgado de Melo, J. Pereira, C. Duque, M. P. Antunes, L. R. Manso Silva, M. A. de Souza","doi":"10.1109/PTC.2019.8810980","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810980","url":null,"abstract":"In this work, synchronized measurements are used for power system monitoring based on hardware-in-the-loop simulations. A metering equipment with phasor measurement unit function is used to monitor in real time electrical and power quality parameters such as voltage phasors, THD (Total Harmonic Distortion), IHD (Individual Harmonic Distortion), system frequency and voltage sags in a power grid. Simulations are carried out using RTDS (Real Time Digital Simulator) in order to compare simulated values with their corresponding measured ones, with the purpose of investigating the metering equipment performance by hardware-in-the-loop tests.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"88 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124144815","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810858
E. Drayer, T. Routtenberg
The extensive measurement infrastructure of smart grids is a vulnerable target for cyber attacks aiming at compromising reliable power supply. Thus, the detection of intrusion into the system and the identification of manipulated and false data is a key security capability required for future power systems. In this paper, we apply principal component analysis (PCA), together with a subspace analysis, to detect the presence of such false data injection (FDI) attacks. A key requirement for this method is a database of historical grid states that is used to compute the PCA transformation matrix. Each new grid state is then transformed based on this matrix to calculate its uncorrelated principal components. The presence of FDI attacks leads to a significant increase in the contribution of principal components that span the residual subspace. By comparing this projection against a threshold, the presence of compromised measurements can be detected. This is demonstrated by several case study simulations.
{"title":"Intrusion Detection in Smart Grid Measurement Infrastructures Based on Principal Component Analysis","authors":"E. Drayer, T. Routtenberg","doi":"10.1109/PTC.2019.8810858","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810858","url":null,"abstract":"The extensive measurement infrastructure of smart grids is a vulnerable target for cyber attacks aiming at compromising reliable power supply. Thus, the detection of intrusion into the system and the identification of manipulated and false data is a key security capability required for future power systems. In this paper, we apply principal component analysis (PCA), together with a subspace analysis, to detect the presence of such false data injection (FDI) attacks. A key requirement for this method is a database of historical grid states that is used to compute the PCA transformation matrix. Each new grid state is then transformed based on this matrix to calculate its uncorrelated principal components. The presence of FDI attacks leads to a significant increase in the contribution of principal components that span the residual subspace. By comparing this projection against a threshold, the presence of compromised measurements can be detected. This is demonstrated by several case study simulations.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124252786","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810892
W. Nzale, J. Mahseredjian, I. Kocar, X. Fu, C. Dufour
This paper presents two variable time-step algorithms for time-domain simulation of electromagnetic transients. The first one has been created to simulate basic switching transients and the second one is intended to simulate power-electronic systems. Each algorithm is tested in a dedicated circuit. Simulation results yield excellent accuracy and significant improvements in computation time when compared to fixed time-step algorithm.
{"title":"Two Variable Time-Step Algorithms for Simulation of Transients","authors":"W. Nzale, J. Mahseredjian, I. Kocar, X. Fu, C. Dufour","doi":"10.1109/PTC.2019.8810892","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810892","url":null,"abstract":"This paper presents two variable time-step algorithms for time-domain simulation of electromagnetic transients. The first one has been created to simulate basic switching transients and the second one is intended to simulate power-electronic systems. Each algorithm is tested in a dedicated circuit. Simulation results yield excellent accuracy and significant improvements in computation time when compared to fixed time-step algorithm.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130804291","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810592
Giancarlo Noto, V. Hagenmeyer, R. R. Appino, G. Chicco
Active distribution networks are promising to provide ancillary services to the utilities in addition to traditional generation. The idea is to make use of the controllable distributed energy resources within the distribution network to regulate the power exchange with its upper level grid on the basis of a set point determined by the utility. However, determining an interval of feasible set points for this power exchange is challenging because of the uncertainty affecting the uncontrolled generation and demand. This paper proposes a novel methodology to compute feasible variability ranges for the power exchange with the upper level grid. In particular, the method seeks for the range maximizing the probability that a set point within the range is feasible, given a realization of the uncertain generation/demand. The proposed method combines numerical optimization and probabilistic forecasts with concepts from the theory of multi-parametric programming. Simulations based on a modified European CIGRE Low Voltage benchmark grid are used to illustrate the proposed findings.
{"title":"Determination of Feasible Power Variability Ranges in Active Distribution Networks with Uncertain Generation and Demand","authors":"Giancarlo Noto, V. Hagenmeyer, R. R. Appino, G. Chicco","doi":"10.1109/PTC.2019.8810592","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810592","url":null,"abstract":"Active distribution networks are promising to provide ancillary services to the utilities in addition to traditional generation. The idea is to make use of the controllable distributed energy resources within the distribution network to regulate the power exchange with its upper level grid on the basis of a set point determined by the utility. However, determining an interval of feasible set points for this power exchange is challenging because of the uncertainty affecting the uncontrolled generation and demand. This paper proposes a novel methodology to compute feasible variability ranges for the power exchange with the upper level grid. In particular, the method seeks for the range maximizing the probability that a set point within the range is feasible, given a realization of the uncertain generation/demand. The proposed method combines numerical optimization and probabilistic forecasts with concepts from the theory of multi-parametric programming. Simulations based on a modified European CIGRE Low Voltage benchmark grid are used to illustrate the proposed findings.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123514387","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 : 2019-06-23DOI: 10.1109/PTC.2019.8811004
Andreas T. Procopiou, L. Ochoa
The rapid uptake of residential-scale photovoltaic (PV) systems in low-voltage (LV) networks is creating technical issues such as voltage rise and asset congestion (i.e., transformer, cables). An alternative to traditional time-consuming and expensive mitigation approaches, such as network reinforcements, could be to actively manage controllable elements such as PV systems. This work proposes an adaptive centralized asset congestion management (ACACM) technique. It is generic as it only requires knowledge of the total PV installed capacity, the rated capacity of the assets and measurements at the substation. Based on irradiance measurements, it estimates total PV generation and demand, making it possible to constantly calculate the maximum PV generation that avoids congestion issues. Its effectiveness is demonstrated using a real UK LV network with 100% PV penetration. The generic nature of the ACACM makes it a practical and scalable solution to manage PV-rich LV networks.
{"title":"Adaptive Asset Congestion Management in PV-Rich LV Networks","authors":"Andreas T. Procopiou, L. Ochoa","doi":"10.1109/PTC.2019.8811004","DOIUrl":"https://doi.org/10.1109/PTC.2019.8811004","url":null,"abstract":"The rapid uptake of residential-scale photovoltaic (PV) systems in low-voltage (LV) networks is creating technical issues such as voltage rise and asset congestion (i.e., transformer, cables). An alternative to traditional time-consuming and expensive mitigation approaches, such as network reinforcements, could be to actively manage controllable elements such as PV systems. This work proposes an adaptive centralized asset congestion management (ACACM) technique. It is generic as it only requires knowledge of the total PV installed capacity, the rated capacity of the assets and measurements at the substation. Based on irradiance measurements, it estimates total PV generation and demand, making it possible to constantly calculate the maximum PV generation that avoids congestion issues. Its effectiveness is demonstrated using a real UK LV network with 100% PV penetration. The generic nature of the ACACM makes it a practical and scalable solution to manage PV-rich LV networks.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122443121","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810797
Andreas T. Procopiou, L. Ochoa
Residential-scale photovoltaic (PV) inverters available in the market are embedded with two key functions designed to help mitigating voltage rise issues: Volt-Watt and Volt-var. Volt-var has attracted significant attention as it does not involve generation curtailment. However, residential-scale PV inverters are sized (kVA) to meet the peak active power generation of the panels (kW). Since active power generation is typically prioritized, their capabilities to absorb reactive power (kvar) during high generation periods will be limited. Using a real UK LV network, this work provides a comprehensive analysis to understand the extent to which the adoption of Volt-var control helps managing voltage rise issues. Considering different Volt-var curves and PV penetrations, results demonstrate that Volt-var control is ineffective when reactive power is needed the most. Furthermore, reactive power increases currents and, therefore, asset utilization. This highlights the importance of considering the kVA rating of inverters when adopting solutions involving reactive power.
{"title":"On the Limitations of Volt-var Control in PV-Rich Residential LV Networks: A UK Case Study","authors":"Andreas T. Procopiou, L. Ochoa","doi":"10.1109/PTC.2019.8810797","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810797","url":null,"abstract":"Residential-scale photovoltaic (PV) inverters available in the market are embedded with two key functions designed to help mitigating voltage rise issues: Volt-Watt and Volt-var. Volt-var has attracted significant attention as it does not involve generation curtailment. However, residential-scale PV inverters are sized (kVA) to meet the peak active power generation of the panels (kW). Since active power generation is typically prioritized, their capabilities to absorb reactive power (kvar) during high generation periods will be limited. Using a real UK LV network, this work provides a comprehensive analysis to understand the extent to which the adoption of Volt-var control helps managing voltage rise issues. Considering different Volt-var curves and PV penetrations, results demonstrate that Volt-var control is ineffective when reactive power is needed the most. Furthermore, reactive power increases currents and, therefore, asset utilization. This highlights the importance of considering the kVA rating of inverters when adopting solutions involving reactive power.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129702225","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810897
F. E. A. Espejo, S. Grillo, L. Luini
A photovoltaic (PV) power generation system relying on meteorological forecast provided by the European Centre for Medium-Range Weather Forecast (ECMWF) (ERA5 database) is proposed. Three years of data collected from photovoltaic panels deployed in Milan, Italy, have been analyzed, both in clear-sky and cloudy conditions. The Ineichen-Perez model has been used as a reference for clear-sky conditions. The power measurements were compared with the power calculated using ECMWF, based on solar theory and technical characteristics of the PV plant in place. cumulative complementary distribution function (CCDF) and errors, have been calculated to determine the accuracy of the model. Results indicate a good agreement in terms of generated power statistics, showing that ERA5 data can be reliably used to design solar plants as well as to forecast their performance and energy production.
{"title":"Photovoltaic Power Production Estimation Based on Numerical Weather Predictions","authors":"F. E. A. Espejo, S. Grillo, L. Luini","doi":"10.1109/PTC.2019.8810897","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810897","url":null,"abstract":"A photovoltaic (PV) power generation system relying on meteorological forecast provided by the European Centre for Medium-Range Weather Forecast (ECMWF) (ERA5 database) is proposed. Three years of data collected from photovoltaic panels deployed in Milan, Italy, have been analyzed, both in clear-sky and cloudy conditions. The Ineichen-Perez model has been used as a reference for clear-sky conditions. The power measurements were compared with the power calculated using ECMWF, based on solar theory and technical characteristics of the PV plant in place. cumulative complementary distribution function (CCDF) and errors, have been calculated to determine the accuracy of the model. Results indicate a good agreement in terms of generated power statistics, showing that ERA5 data can be reliably used to design solar plants as well as to forecast their performance and energy production.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128724792","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810890
Mustafa Ata, Ayşe Kübra Erenoğlu, İbrahim Şengör, O. Erdinç, Akιn Taşcιkaraoğlu, J. Catalão
Together with the increasing population and prosperity levels of the growing countries, the economic and technological developments and modernized lifestyles of the end users have increased their electrical, heating and cooling energy demands extraordinarily. These services are generally provided to the end users independently, which leads to considerable reductions in the system efficiencies. For the purpose of providing a decrease in the demands of the end users and to transfer the energy carriers to the end users in an integrated and more efficient way, the concept of multi energy systems (MESs) has emerged. MESs could be developed at a district level, a city level and lastly at a country level. In this paper, a smart neighborhood MES model is proposed with the aim of achieving cost optimization by mixed integer linear programming (MILP) based formulation considering a time-of-use (TOU) tariff. In order to testify the effectiveness of the proposed optimization algorithm, two different case studies are conducted by taking into account flexible energy production capability of different energy carriers.
{"title":"Optimal Operation of a Smart Multi-Energy Neighborhood","authors":"Mustafa Ata, Ayşe Kübra Erenoğlu, İbrahim Şengör, O. Erdinç, Akιn Taşcιkaraoğlu, J. Catalão","doi":"10.1109/PTC.2019.8810890","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810890","url":null,"abstract":"Together with the increasing population and prosperity levels of the growing countries, the economic and technological developments and modernized lifestyles of the end users have increased their electrical, heating and cooling energy demands extraordinarily. These services are generally provided to the end users independently, which leads to considerable reductions in the system efficiencies. For the purpose of providing a decrease in the demands of the end users and to transfer the energy carriers to the end users in an integrated and more efficient way, the concept of multi energy systems (MESs) has emerged. MESs could be developed at a district level, a city level and lastly at a country level. In this paper, a smart neighborhood MES model is proposed with the aim of achieving cost optimization by mixed integer linear programming (MILP) based formulation considering a time-of-use (TOU) tariff. In order to testify the effectiveness of the proposed optimization algorithm, two different case studies are conducted by taking into account flexible energy production capability of different energy carriers.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"53 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129028512","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810514
Rafael Espejo, S. Lumbreras, A. Ramos, Tao Huang, E. Bompard
Power networks are highly vulnerable to deliberate attacks. Whilst power-network design usually considers the protection of the system against network-component failure, it does not consider the protection against deliberated attacks. The inclusion of deliberated-attack analyses with traditional power-system methods may results in computational-intensive models. However, the introduction of complex-network methods in the analysis of power systems will support vulnerability studies by reducing their computational burden. Extended topological metrics, which endows topological metrics with electrical considerations, have resulted to give satisfactory results with lower computational requirements. This paper proposes a new extended metric to rank lines according to the impact that line failures have on power networks. The proposed metric is based on the idea of betweenness centrality and it considers parameters related to demand, generation and transmission lines. This paper confirms the accuracy of the proposed metric with two test cases.
{"title":"An Extended Metric for the Analysis of Power-Network Vulnerability: the Line Electrical Centrality","authors":"Rafael Espejo, S. Lumbreras, A. Ramos, Tao Huang, E. Bompard","doi":"10.1109/PTC.2019.8810514","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810514","url":null,"abstract":"Power networks are highly vulnerable to deliberate attacks. Whilst power-network design usually considers the protection of the system against network-component failure, it does not consider the protection against deliberated attacks. The inclusion of deliberated-attack analyses with traditional power-system methods may results in computational-intensive models. However, the introduction of complex-network methods in the analysis of power systems will support vulnerability studies by reducing their computational burden. Extended topological metrics, which endows topological metrics with electrical considerations, have resulted to give satisfactory results with lower computational requirements. This paper proposes a new extended metric to rank lines according to the impact that line failures have on power networks. The proposed metric is based on the idea of betweenness centrality and it considers parameters related to demand, generation and transmission lines. This paper confirms the accuracy of the proposed metric with two test cases.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127862745","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 : 2019-06-23DOI: 10.1109/PTC.2019.8810571
N. Stevanato, F. Lombardi, Emanuela Colmbo, S. Balderrama, S. Quoilin
Robust sizing of rural micro-grids is hindered by uncertainty associated with the expected load demand and its potential evolution over time. This study couples a stochastic load generation model with a two-stage stochastic micro-grid sizing model to take into account multiple probabilistic load scenarios within a single optimisation problem. As a result, the stochastic-optimal sizing of the system ensures an increased robustness to shocks in the expected load compared to a best-case (lowest-demand) sizing, though with a lower cost and better dispatch flexibility compared to a worst-case (highest-demand) sizing. What is more, allowing just a 1% unmet demand enables to significantly improve the cost-competitiveness and the renewables penetration as all the not supplied energy is located in a negligible fraction of the unlikeliest highest demand scenarios.
{"title":"Two-Stage Stochastic Sizing of a Rural Micro-Grid Based on Stochastic Load Generation","authors":"N. Stevanato, F. Lombardi, Emanuela Colmbo, S. Balderrama, S. Quoilin","doi":"10.1109/PTC.2019.8810571","DOIUrl":"https://doi.org/10.1109/PTC.2019.8810571","url":null,"abstract":"Robust sizing of rural micro-grids is hindered by uncertainty associated with the expected load demand and its potential evolution over time. This study couples a stochastic load generation model with a two-stage stochastic micro-grid sizing model to take into account multiple probabilistic load scenarios within a single optimisation problem. As a result, the stochastic-optimal sizing of the system ensures an increased robustness to shocks in the expected load compared to a best-case (lowest-demand) sizing, though with a lower cost and better dispatch flexibility compared to a worst-case (highest-demand) sizing. What is more, allowing just a 1% unmet demand enables to significantly improve the cost-competitiveness and the renewables penetration as all the not supplied energy is located in a negligible fraction of the unlikeliest highest demand scenarios.","PeriodicalId":187144,"journal":{"name":"2019 IEEE Milan PowerTech","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129349208","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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