Pub Date : 2016-07-17DOI: 10.1109/PESGM.2016.7741295
Xiaoyu Wu, Jinghan He, T. Yip, Pei Zhang
Machine learning methods are the main stream algorithms applied in short term load forecasting. However, typical machine learning methods consisting of Artificial Neural Network (ANN) and Support Vector Regression (SVR) have deficiencies hard to overcome, such as easy to be trapped in local optimization (for ANN) or hard to decide kernel parameter and penalty parameter (for SVR). On the other hand, grey relational analysis is an effective method to select proper historical data as training set for training machine learning models. But it is not comprehensive and accurate enough. In this paper, a new two-stage hybrid algorithm aimed to solve these two problems is proposed. Random Forest (RF) method is introduced as the machine learning method, which will not cause overfitting problem and parameters are easy to be tuned. Furthermore, Grey Relational Projection (GRP) is introduced to select similar historical data to train random forest models. The final forecasting results based on real load data prove this new two-stage method performs better than the other two common methods.
{"title":"A two-stage random forest method for short-term load forecasting","authors":"Xiaoyu Wu, Jinghan He, T. Yip, Pei Zhang","doi":"10.1109/PESGM.2016.7741295","DOIUrl":"https://doi.org/10.1109/PESGM.2016.7741295","url":null,"abstract":"Machine learning methods are the main stream algorithms applied in short term load forecasting. However, typical machine learning methods consisting of Artificial Neural Network (ANN) and Support Vector Regression (SVR) have deficiencies hard to overcome, such as easy to be trapped in local optimization (for ANN) or hard to decide kernel parameter and penalty parameter (for SVR). On the other hand, grey relational analysis is an effective method to select proper historical data as training set for training machine learning models. But it is not comprehensive and accurate enough. In this paper, a new two-stage hybrid algorithm aimed to solve these two problems is proposed. Random Forest (RF) method is introduced as the machine learning method, which will not cause overfitting problem and parameters are easy to be tuned. Furthermore, Grey Relational Projection (GRP) is introduced to select similar historical data to train random forest models. The final forecasting results based on real load data prove this new two-stage method performs better than the other two common methods.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2016-07-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131908259","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 : 2015-09-06DOI: 10.1109/PTC.2015.7232750
A. Bernstein, J. Le Boudec, L. Reyes-Chamorro, M. Paolone
We propose a method to perform a safe unintentional islanding maneuver of microgrids. The method is derived in the context of a framework for the real-time control of microgrids, called Commelec, recently proposed by the Authors. The framework uses a hierarchy of software agents that communicate with each other using a common, device independent protocol in order to define explicit power setpoints without the need of droop controllers. We show that the features of the framework allow to design a generic control method for treating unintentional islanding with the following properties. First, the method is able to choose the best candidate slack resource, based on the information obtained from the agents. Second, as the agent responsible for the grid has a global view of the network's status and its resources, it is possible to optimize the performance of the network during and after the islanding transition. Third, after the islanding maneuver it allows for the online switching of the slack resource to that with the best capabilities to face the network's needs. Finally, the method is suitable for inertia-less systems as the control is performed using explicit power setpoints and it does not rely on the frequency signal. We illustrate the benefits of the proposed method via simulation on the LV microgrid benchmark defined by the CIGRÉ Task Force C6.04.02, by comparing its performance to that of the standard droop-based method called load drop anticipator.
我们提出了一种安全的微电网非故意孤岛机动方法。该方法是在一个名为Commelec的微电网实时控制框架的背景下推导出来的，该框架最近由作者提出。该框架使用软件代理的层次结构，这些代理使用通用的、与设备无关的协议相互通信，以便在不需要下垂控制器的情况下定义明确的功率设定值。我们表明，该框架的特征允许设计一种通用的控制方法，用于处理具有以下属性的非故意孤岛。首先，该方法能够根据从代理处获得的信息选择最佳候选空闲资源;其次，由于负责电网的代理具有网络状态和资源的全局视图，因此可以在孤岛过渡期间和之后优化网络的性能。第三，孤岛机动后，可以将闲置资源在线切换到具有最佳能力的资源，以面对网络的需求。最后，该方法适用于无惯性系统，因为它使用显式功率设定值进行控制，并且不依赖于频率信号。我们通过对CIGRÉ Task Force C6.04.02定义的低压微电网基准进行仿真，并将其性能与称为负载下降预测器的标准基于下垂的方法进行比较，说明了所提出方法的优点。
{"title":"Real-time control of microgrids with explicit power setpoints: Unintentional islanding","authors":"A. Bernstein, J. Le Boudec, L. Reyes-Chamorro, M. Paolone","doi":"10.1109/PTC.2015.7232750","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232750","url":null,"abstract":"We propose a method to perform a safe unintentional islanding maneuver of microgrids. The method is derived in the context of a framework for the real-time control of microgrids, called Commelec, recently proposed by the Authors. The framework uses a hierarchy of software agents that communicate with each other using a common, device independent protocol in order to define explicit power setpoints without the need of droop controllers. We show that the features of the framework allow to design a generic control method for treating unintentional islanding with the following properties. First, the method is able to choose the best candidate slack resource, based on the information obtained from the agents. Second, as the agent responsible for the grid has a global view of the network's status and its resources, it is possible to optimize the performance of the network during and after the islanding transition. Third, after the islanding maneuver it allows for the online switching of the slack resource to that with the best capabilities to face the network's needs. Finally, the method is suitable for inertia-less systems as the control is performed using explicit power setpoints and it does not rely on the frequency signal. We illustrate the benefits of the proposed method via simulation on the LV microgrid benchmark defined by the CIGRÉ Task Force C6.04.02, by comparing its performance to that of the standard droop-based method called load drop anticipator.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128787637","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232319
E. D. de Oliveira, S. M. Mayrink J, M. L. Rodrigues, B. Dias, L. D. de Oliveira, I. Junior
This paper presents a model to include a security constraint for wind power plant in a hydrothermal dispatch problem. The proposed Unit Commitment (UC) is an augmented problem to take into account different scenarios of wind speed during the day. The wind farms are represented by a linear model that the generations are considered proportional to the availability of wind. The proposed optimization model uses DC load flow in which transmission system constraints are included. The hydro plants are considered with constant productivity and the times of starting and stopping of thermal generation units are considered as well as ramp deviation. The results using a test system show that the operation of a hydrothermal system is strongly affected by the inclusion of wind farms.
{"title":"Security constraints for wind power operation","authors":"E. D. de Oliveira, S. M. Mayrink J, M. L. Rodrigues, B. Dias, L. D. de Oliveira, I. Junior","doi":"10.1109/PTC.2015.7232319","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232319","url":null,"abstract":"This paper presents a model to include a security constraint for wind power plant in a hydrothermal dispatch problem. The proposed Unit Commitment (UC) is an augmented problem to take into account different scenarios of wind speed during the day. The wind farms are represented by a linear model that the generations are considered proportional to the availability of wind. The proposed optimization model uses DC load flow in which transmission system constraints are included. The hydro plants are considered with constant productivity and the times of starting and stopping of thermal generation units are considered as well as ramp deviation. The results using a test system show that the operation of a hydrothermal system is strongly affected by the inclusion of wind farms.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115113783","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232579
T. Gu, F. Provoost, Wouter Bos
Spontaneous faults in medium voltage grid are often preceded by a number of self-extinguishing faults. Therefore, it is useful to recognize and localize the self-extinguishing faults. The detected component could then be repaired or replaced in advance, to prevent the persistent fault This paper describes the self-extinguishing fault phenomena and the recognition methodology. The techniques to locate the faulted cable section are proposed, including the rough location by analyzing the measured data and the exact location by applying sophisticated detecting apparatus. In addition, several practical examples from a Dutch distribution system operator are presented.
{"title":"Fault prevention by recognition and localization of self-extinguishing faults","authors":"T. Gu, F. Provoost, Wouter Bos","doi":"10.1109/PTC.2015.7232579","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232579","url":null,"abstract":"Spontaneous faults in medium voltage grid are often preceded by a number of self-extinguishing faults. Therefore, it is useful to recognize and localize the self-extinguishing faults. The detected component could then be repaired or replaced in advance, to prevent the persistent fault This paper describes the self-extinguishing fault phenomena and the recognition methodology. The techniques to locate the faulted cable section are proposed, including the rough location by analyzing the measured data and the exact location by applying sophisticated detecting apparatus. In addition, several practical examples from a Dutch distribution system operator are presented.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116761890","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232517
A. Castro, P. Zuniga, F. Uribe, E. Barocio
The aim of this study is to present a phase compensation scheme that improves the accuracy of a power hardware-in-the-loop simulation. The ideal transformer model interface method along with feedback current filtering is used to connect a synchronous generator simulation to a test system. The generator is modeled using a voltage-behind-reactance representation. Comparison of experimental results against simulations confirms the validity of the proposal.
{"title":"Phase compensation scheme to improve the accuracy of a power hardware-in-the-loop experiment based on a synchronous generator","authors":"A. Castro, P. Zuniga, F. Uribe, E. Barocio","doi":"10.1109/PTC.2015.7232517","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232517","url":null,"abstract":"The aim of this study is to present a phase compensation scheme that improves the accuracy of a power hardware-in-the-loop simulation. The ideal transformer model interface method along with feedback current filtering is used to connect a synchronous generator simulation to a test system. The generator is modeled using a voltage-behind-reactance representation. Comparison of experimental results against simulations confirms the validity of the proposal.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116940181","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232299
Guangyu Feng, A. Abur
This paper introduces a robust fault location method that utilizes wide area phasor measurements and sparse estimation technique. The proposed method transforms the fault location problem into estimating sparse bus injections in the network, based upon the equivalence in the change of bus voltages between a fault current drawn at an arbitrary point along a line and virtual superimposed current injections at the terminal nodes of the same line. This equivalence not only works for two terminal lines but also three terminal lines. Assuming limited placement of phasor measurements, an underdetermined linear estimation problem whose solution is sparse will be formed. This problem can be solved via sparse estimation especially L1 regularization technique. Considering possible failure of individual measurement units, an extended formulation incorporating sparse error vector is used to increase the method's robustness. Extensive simulation results have verified the effectiveness of the proposed method.
{"title":"Robust fault location for two and three terminal lines using synchronized phasor measurements","authors":"Guangyu Feng, A. Abur","doi":"10.1109/PTC.2015.7232299","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232299","url":null,"abstract":"This paper introduces a robust fault location method that utilizes wide area phasor measurements and sparse estimation technique. The proposed method transforms the fault location problem into estimating sparse bus injections in the network, based upon the equivalence in the change of bus voltages between a fault current drawn at an arbitrary point along a line and virtual superimposed current injections at the terminal nodes of the same line. This equivalence not only works for two terminal lines but also three terminal lines. Assuming limited placement of phasor measurements, an underdetermined linear estimation problem whose solution is sparse will be formed. This problem can be solved via sparse estimation especially L1 regularization technique. Considering possible failure of individual measurement units, an extended formulation incorporating sparse error vector is used to increase the method's robustness. Extensive simulation results have verified the effectiveness of the proposed method.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"320 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121350873","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232296
V. Gabrion, D. Klaja, S. Emelin, S. Grenard, Antoine Minaud
New requirements on the stability of the European interconnected power system may lead to a lesser use or even the complete removal of interface protections based on narrow frequency ranges (e.g. [49,5 - 50,5 Hz] in France) for distributed generators connected to the distribution network. As this type of protection allows detecting rapidly most islanding situations, its disappearance would reduce the efficiency of both fast reclosing schemes and islanding detection. A palliative solution must be found that combines technical feasibility, efficiency, low cost and ability to be applied to both MV and LV connected generators. This paper first proposes a method to evaluate the risk of islanding on a MV feeder and then considers the cons and pros of various alternatives to a narrow frequency range interface protection before focusing on a solution currently investigated for the French Distribution network.
{"title":"Requirement to enlarge interface protections frequency ranges for generators connected to distribution networks: Study of alternatives and solution proposal","authors":"V. Gabrion, D. Klaja, S. Emelin, S. Grenard, Antoine Minaud","doi":"10.1109/PTC.2015.7232296","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232296","url":null,"abstract":"New requirements on the stability of the European interconnected power system may lead to a lesser use or even the complete removal of interface protections based on narrow frequency ranges (e.g. [49,5 - 50,5 Hz] in France) for distributed generators connected to the distribution network. As this type of protection allows detecting rapidly most islanding situations, its disappearance would reduce the efficiency of both fast reclosing schemes and islanding detection. A palliative solution must be found that combines technical feasibility, efficiency, low cost and ability to be applied to both MV and LV connected generators. This paper first proposes a method to evaluate the risk of islanding on a MV feeder and then considers the cons and pros of various alternatives to a narrow frequency range interface protection before focusing on a solution currently investigated for the French Distribution network.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127498044","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232341
H. Patel, S. Chowdhury
Electrification is a persisting problem all over the world. The worst affected are people who live in rural areas of developing countries. South Africa is no different as they have still to attain 100% electrification. Due to their small-scale nature, off-grid microgrids are well suited to rural electrification purposes. Independent solar, wind, biomass and microhydro microgrids form the main scope of this paper. In order to compare various renewable resources the Levelised Cost of Electricity (LCOE) can be used as a reasonable metric. The technical and economic factors affecting microgrids across the globe are reviewed and interpreted with respect to South Africa in this paper. It is expected that that South Africa can implement microgrids successfully by taking note of these economic factors as well as factors specific to itself, and use them to their advantage so as to solve its rural electrification problem.
{"title":"Review of technical and economic challenges for implementing rural microgrids in south africa","authors":"H. Patel, S. Chowdhury","doi":"10.1109/PTC.2015.7232341","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232341","url":null,"abstract":"Electrification is a persisting problem all over the world. The worst affected are people who live in rural areas of developing countries. South Africa is no different as they have still to attain 100% electrification. Due to their small-scale nature, off-grid microgrids are well suited to rural electrification purposes. Independent solar, wind, biomass and microhydro microgrids form the main scope of this paper. In order to compare various renewable resources the Levelised Cost of Electricity (LCOE) can be used as a reasonable metric. The technical and economic factors affecting microgrids across the globe are reviewed and interpreted with respect to South Africa in this paper. It is expected that that South Africa can implement microgrids successfully by taking note of these economic factors as well as factors specific to itself, and use them to their advantage so as to solve its rural electrification problem.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"205 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123261277","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232266
Zahra Khalafi, M. Dehghani, L. Goel, Wenyuan Li
In this paper, observability reliability (OR) and loss of data expectation indices (LODE) are calculated considering data uncertainty. Single contingency of Phasor Measurement Unit (PMU) and branch outages are considered in the calculations and to achieve more realistic results, it is assumed that failure data (repair time and failure rate) of all branches and PMU components have uncertainty. Fuzzy set theory is used to deal with data uncertainty. A fuzzy Monte Carlo Simulation approach is proposed to calculate OR and LODE indices in the presence of uncertainty. The proposed method can be used to determine the most reliable PMU placement among the multiple optimal solutions. The IEEE 14-bus system is used to evaluate the effectiveness of the proposed method.
{"title":"Observability reliability evaluation in power systems considering data uncertainty","authors":"Zahra Khalafi, M. Dehghani, L. Goel, Wenyuan Li","doi":"10.1109/PTC.2015.7232266","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232266","url":null,"abstract":"In this paper, observability reliability (OR) and loss of data expectation indices (LODE) are calculated considering data uncertainty. Single contingency of Phasor Measurement Unit (PMU) and branch outages are considered in the calculations and to achieve more realistic results, it is assumed that failure data (repair time and failure rate) of all branches and PMU components have uncertainty. Fuzzy set theory is used to deal with data uncertainty. A fuzzy Monte Carlo Simulation approach is proposed to calculate OR and LODE indices in the presence of uncertainty. The proposed method can be used to determine the most reliable PMU placement among the multiple optimal solutions. The IEEE 14-bus system is used to evaluate the effectiveness of the proposed method.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"54 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125526951","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 : 2015-09-03DOI: 10.1109/PTC.2015.7232519
Akshay S. Korad, K. Hedman
In recent years, the penetration of renewable resources in electrical power systems has increased. These renewable resources add more complexities to power system operations, due to their intermittent nature. As a result, operators must acquire additional reserves in order to maintain reliability. However, one persistent challenge is to determine the optimal location and quantity of reserves; this challenge is exacerbated by the inability to predict key transmission bottlenecks due to this added uncertainty. This paper presents robust corrective topology control, as a congestion management tool, to reduce violations caused by contingencies and renewable uncertainties. The day-ahead topology control formulation is based on the direct current optimal power flow; therefore, switching solutions obtained from these algorithms are tested for AC feasibility and system stability. All numerical results are based on the IEEE-118 bus test case.
{"title":"Reliability and stability analysis of corrective topology control actions","authors":"Akshay S. Korad, K. Hedman","doi":"10.1109/PTC.2015.7232519","DOIUrl":"https://doi.org/10.1109/PTC.2015.7232519","url":null,"abstract":"In recent years, the penetration of renewable resources in electrical power systems has increased. These renewable resources add more complexities to power system operations, due to their intermittent nature. As a result, operators must acquire additional reserves in order to maintain reliability. However, one persistent challenge is to determine the optimal location and quantity of reserves; this challenge is exacerbated by the inability to predict key transmission bottlenecks due to this added uncertainty. This paper presents robust corrective topology control, as a congestion management tool, to reduce violations caused by contingencies and renewable uncertainties. The day-ahead topology control formulation is based on the direct current optimal power flow; therefore, switching solutions obtained from these algorithms are tested for AC feasibility and system stability. All numerical results are based on the IEEE-118 bus test case.","PeriodicalId":193448,"journal":{"name":"2015 IEEE Eindhoven PowerTech","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2015-09-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115460249","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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