Pub Date : 2016-05-03DOI: 10.1109/TDC.2016.7519959
H. Nazaripouya, B. Wang, Y. Wang, P. Chu, H. Pota, R. Gadh
This paper proposes a new hybrid method for super short-term solar power prediction. Solar output power usually has a complex, nonstationary, and nonlinear characteristic due to intermittent and time varying behavior of solar radiance. In addition, solar power dynamics is fast and is inertia less. An accurate super short-time prediction is required to compensate for the fluctuations and reduce the impact of solar power penetration on the power system. The objective is to predict one step-ahead solar power generation based only on historical solar power time series data. The proposed method incorporates discrete wavelet transform (DWT), Auto-Regressive Moving Average (ARMA) models, and Recurrent Neural Networks (RNN), while the RNN architecture is based on Nonlinear Auto-Regressive models with eXogenous inputs (NARX). The wavelet transform is utilized to decompose the solar power time series into a set of richer-behaved forming series for prediction. ARMA model is employed as a linear predictor while NARX is used as a nonlinear pattern recognition tool to estimate and compensate the error of wavelet-ARMA prediction. The proposed method is applied to the data captured from UCLA solar PV panels and the results are compared with some of the common and most recent solar power prediction methods. The results validate the effectiveness of the proposed approach and show a considerable improvement in the prediction precision.
{"title":"Univariate time series prediction of solar power using a hybrid wavelet-ARMA-NARX prediction method","authors":"H. Nazaripouya, B. Wang, Y. Wang, P. Chu, H. Pota, R. Gadh","doi":"10.1109/TDC.2016.7519959","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519959","url":null,"abstract":"This paper proposes a new hybrid method for super short-term solar power prediction. Solar output power usually has a complex, nonstationary, and nonlinear characteristic due to intermittent and time varying behavior of solar radiance. In addition, solar power dynamics is fast and is inertia less. An accurate super short-time prediction is required to compensate for the fluctuations and reduce the impact of solar power penetration on the power system. The objective is to predict one step-ahead solar power generation based only on historical solar power time series data. The proposed method incorporates discrete wavelet transform (DWT), Auto-Regressive Moving Average (ARMA) models, and Recurrent Neural Networks (RNN), while the RNN architecture is based on Nonlinear Auto-Regressive models with eXogenous inputs (NARX). The wavelet transform is utilized to decompose the solar power time series into a set of richer-behaved forming series for prediction. ARMA model is employed as a linear predictor while NARX is used as a nonlinear pattern recognition tool to estimate and compensate the error of wavelet-ARMA prediction. The proposed method is applied to the data captured from UCLA solar PV panels and the results are compared with some of the common and most recent solar power prediction methods. The results validate the effectiveness of the proposed approach and show a considerable improvement in the prediction precision.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"521 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77033022","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519888
Josh A. Schellenberg, Barney Speckman, J. Eto
Utilities have increasingly been applying customer interruption costs to reliability and resiliency planning, using tools such as the Interruption Cost Estimate (ICE) Calculator. Furthermore, applications of value-based reliability planning can be found in the industry and academic literature for generation, transmission and distribution planning and at the federal policy-making level. With the wealth of guidance documentation and planning examples that is now available, the utility industry is positioned to further expand upon the application of value-based reliability planning by integrating customer interruption costs into outage management systems (OMS) and their associated business processes. This paper summarizes how (and why) to integrate customer interruption costs into OMS and discusses how utilities can act on customer interruption cost information to provide more value to customers.
{"title":"Integrating customer interruption costs into outage management systems","authors":"Josh A. Schellenberg, Barney Speckman, J. Eto","doi":"10.1109/TDC.2016.7519888","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519888","url":null,"abstract":"Utilities have increasingly been applying customer interruption costs to reliability and resiliency planning, using tools such as the Interruption Cost Estimate (ICE) Calculator. Furthermore, applications of value-based reliability planning can be found in the industry and academic literature for generation, transmission and distribution planning and at the federal policy-making level. With the wealth of guidance documentation and planning examples that is now available, the utility industry is positioned to further expand upon the application of value-based reliability planning by integrating customer interruption costs into outage management systems (OMS) and their associated business processes. This paper summarizes how (and why) to integrate customer interruption costs into OMS and discusses how utilities can act on customer interruption cost information to provide more value to customers.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"53 1","pages":"1-4"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88096424","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519980
Saeed Mohajeryami, M. Doostan
This paper examines the outage rate caused by lightning strokes on compact transmission lines (TL). Compact and conventional transmission lines are different in terms of design and structure. Due to such differences, the previous lightning performance studies on conventional TL are useless in understanding the lightning performance of compact TL; hence, such studies have to be updated. In this paper, the aforementioned differences have been taken into the consideration. The lightning performance of compact TL has been studied by application of Monte Carlo method. Moment method is used to determine tower surge impedance by SuperNEC software and an approximate model has been introduced for tower modeling in EMTP-RV. After the accurate modeling of all components, backflashover analysis has been performed and at the end, the number of outages in the simulated sample size has been presented.
{"title":"Investigating the lightning effect on compact transmission lines by employing Monte Carlo method","authors":"Saeed Mohajeryami, M. Doostan","doi":"10.1109/TDC.2016.7519980","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519980","url":null,"abstract":"This paper examines the outage rate caused by lightning strokes on compact transmission lines (TL). Compact and conventional transmission lines are different in terms of design and structure. Due to such differences, the previous lightning performance studies on conventional TL are useless in understanding the lightning performance of compact TL; hence, such studies have to be updated. In this paper, the aforementioned differences have been taken into the consideration. The lightning performance of compact TL has been studied by application of Monte Carlo method. Moment method is used to determine tower surge impedance by SuperNEC software and an approximate model has been introduced for tower modeling in EMTP-RV. After the accurate modeling of all components, backflashover analysis has been performed and at the end, the number of outages in the simulated sample size has been presented.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"33 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91368085","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 : 2016-05-03DOI: 10.1109/TDC.2016.7520055
Guodong Liu, B. Xiao, M. Starke, O. Ceylan, K. Tomsovic
A microgrid is a group of interconnected loads and distributed energy resources. It can operate in either gridconnected mode to exchange energy with the main grid or run autonomously as an island in emergency mode. However, the transition of microgrid from grid-connected mode to islanded mode is usually associated with excessive load (or generation), which should be shed (or spilled). Under this condition, this paper proposes an robust load shedding strategy for microgrid islanding transition, which takes into account the uncertainties of renewable generation in the microgrid and guarantees the balance between load and generation after islanding. A robust optimization model is formulated to minimize the total operation cost, including fuel cost and penalty for load shedding. The proposed robust load shedding strategy works as a backup plan and updates at a prescribed interval. It assures a feasible operating point after islanding given the uncertainty of renewable generation. The proposed algorithm is demonstrated on a simulated microgrid consisting of a wind turbine, a PV panel, a battery, two distributed generators (DGs), a critical load and a interruptible load. Numerical simulation results validate the proposed algorithm.
{"title":"A robust load shedding strategy for microgrid islanding transition","authors":"Guodong Liu, B. Xiao, M. Starke, O. Ceylan, K. Tomsovic","doi":"10.1109/TDC.2016.7520055","DOIUrl":"https://doi.org/10.1109/TDC.2016.7520055","url":null,"abstract":"A microgrid is a group of interconnected loads and distributed energy resources. It can operate in either gridconnected mode to exchange energy with the main grid or run autonomously as an island in emergency mode. However, the transition of microgrid from grid-connected mode to islanded mode is usually associated with excessive load (or generation), which should be shed (or spilled). Under this condition, this paper proposes an robust load shedding strategy for microgrid islanding transition, which takes into account the uncertainties of renewable generation in the microgrid and guarantees the balance between load and generation after islanding. A robust optimization model is formulated to minimize the total operation cost, including fuel cost and penalty for load shedding. The proposed robust load shedding strategy works as a backup plan and updates at a prescribed interval. It assures a feasible operating point after islanding given the uncertainty of renewable generation. The proposed algorithm is demonstrated on a simulated microgrid consisting of a wind turbine, a PV panel, a battery, two distributed generators (DGs), a critical load and a interruptible load. Numerical simulation results validate the proposed algorithm.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"116 8 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84242028","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519915
Q. Guo, Rui Gan
Synchrophasor technology is undergoing rapid changes due to the release of a new standard IEEE Std C37.118.1-2011 and its corresponding amendment IEEE Std C37.118.1a-2014. At present, few Phasor Measurement Units (PMUs) in the market can satisfy all requirements specified in IEEE Std C37.118.1a-2014. To fill this gap, this paper proposes a novel Arbitrary-Resampling-based algorithm for synchrophasor measurement. The proposed algorithm resamples even-time input signals to even-angle signals by measuring the instantaneous signal frequency, which ensures that sample number is the same in each cycle. Further processing can be performed on the resampled signals to precisely measure the magnitude and phase values of the fundamental components. The proposed algorithm is successfully implemented on a Field Programmable Gate Array (FPGA)-based target. Besides, this paper also provides the test results for the compliance tests specified in IEEE Std C37.118.1a-2014, which show that the proposed algorithm is compliant with the standard.
{"title":"An Arbitrary-Resampling-based synchrophasor measurement algorithm in compliance with IEEE Std C37.118.1a-2014: Design, implementation, and validation","authors":"Q. Guo, Rui Gan","doi":"10.1109/TDC.2016.7519915","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519915","url":null,"abstract":"Synchrophasor technology is undergoing rapid changes due to the release of a new standard IEEE Std C37.118.1-2011 and its corresponding amendment IEEE Std C37.118.1a-2014. At present, few Phasor Measurement Units (PMUs) in the market can satisfy all requirements specified in IEEE Std C37.118.1a-2014. To fill this gap, this paper proposes a novel Arbitrary-Resampling-based algorithm for synchrophasor measurement. The proposed algorithm resamples even-time input signals to even-angle signals by measuring the instantaneous signal frequency, which ensures that sample number is the same in each cycle. Further processing can be performed on the resampled signals to precisely measure the magnitude and phase values of the fundamental components. The proposed algorithm is successfully implemented on a Field Programmable Gate Array (FPGA)-based target. Besides, this paper also provides the test results for the compliance tests specified in IEEE Std C37.118.1a-2014, which show that the proposed algorithm is compliant with the standard.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"49 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83626352","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519940
Xiangqi Zhu, Jiahong Yan, N. Lu
This paper presents a probabilistic-based sizing tool for residential home owners, load serving entities, and utilities to select energy storage (ES) and photovoltaic (PV) based on historical load characteristics and load management options. The inputs of the tool include historical residential load profiles and solar radiation data. The outputs of the tool include ensembles of the net load profiles (load minus solar), with and without applying load energy management for different PV and ES installation capacities. The operation statistics of the ES is used to determine the confidence levels of meeting selected performance criterion. In the simulation, a set of 1-year, 15-minute data collected from 50 actual residential homes is used as the load inputs. A set of 1-year, 5-minute actual solar radiation data is used as the solar inputs. Managing load consumptions for reducing the size of ES is investigated by controlling air conditioning loads. Simulation results show that the probabilistic-based sizing method can give the users a clear comparison of the tradeoffs among different options and assist them make more informed decisions.
{"title":"A probabilistic-based PV and energy storage sizing tool for residential loads","authors":"Xiangqi Zhu, Jiahong Yan, N. Lu","doi":"10.1109/TDC.2016.7519940","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519940","url":null,"abstract":"This paper presents a probabilistic-based sizing tool for residential home owners, load serving entities, and utilities to select energy storage (ES) and photovoltaic (PV) based on historical load characteristics and load management options. The inputs of the tool include historical residential load profiles and solar radiation data. The outputs of the tool include ensembles of the net load profiles (load minus solar), with and without applying load energy management for different PV and ES installation capacities. The operation statistics of the ES is used to determine the confidence levels of meeting selected performance criterion. In the simulation, a set of 1-year, 15-minute data collected from 50 actual residential homes is used as the load inputs. A set of 1-year, 5-minute actual solar radiation data is used as the solar inputs. Managing load consumptions for reducing the size of ES is investigated by controlling air conditioning loads. Simulation results show that the probabilistic-based sizing method can give the users a clear comparison of the tradeoffs among different options and assist them make more informed decisions.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"210 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86733978","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519955
Xian-Chang Guo, He Guo, Haozhong Cheng
Current planning in microgrid includes two decoupled processes: the Distributed Energy Resources (DERs) planning and network topology planning. Each planning process is implemented assuming the other is given, i.e., the DERs planning is implemented assuming the network topology is fixed and vice versa. The decoupled planning processes may result in suboptimal solutions and deteriorate the microgrid reliability under the high penetration of DERs. The coordinated generation and network planning is necessary to maximize the social surplus and improve the system reliability. In this paper, a novel framework to coordinate the planning of DERs capacity and microgrid network topology is proposed. To improve the computational efficiency, the problem is further decomposed into DERs capacity planning sub-problem and microgrid network planning sub-problem. The Adaptive Discrete Particle Swarm Optimization (DPSO) algorithm is applied to solve the capacity planning sub-problem, and improved Genetic Algorithm (GA) is used to solve the network topology planning sub-problem. Case studies on a 29- bus microgrid system in Shanghai is tested to demonstrate the effectiveness of the proposed model.
{"title":"Coordinated planning of Distributed Energy Resources and microgrid network","authors":"Xian-Chang Guo, He Guo, Haozhong Cheng","doi":"10.1109/TDC.2016.7519955","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519955","url":null,"abstract":"Current planning in microgrid includes two decoupled processes: the Distributed Energy Resources (DERs) planning and network topology planning. Each planning process is implemented assuming the other is given, i.e., the DERs planning is implemented assuming the network topology is fixed and vice versa. The decoupled planning processes may result in suboptimal solutions and deteriorate the microgrid reliability under the high penetration of DERs. The coordinated generation and network planning is necessary to maximize the social surplus and improve the system reliability. In this paper, a novel framework to coordinate the planning of DERs capacity and microgrid network topology is proposed. To improve the computational efficiency, the problem is further decomposed into DERs capacity planning sub-problem and microgrid network planning sub-problem. The Adaptive Discrete Particle Swarm Optimization (DPSO) algorithm is applied to solve the capacity planning sub-problem, and improved Genetic Algorithm (GA) is used to solve the network topology planning sub-problem. Case studies on a 29- bus microgrid system in Shanghai is tested to demonstrate the effectiveness of the proposed model.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"32 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86137865","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 : 2016-05-03DOI: 10.1109/TDC.2016.7519856
Mingyang Li, X. Zou, Wei Wang, Yuguang Niu, Ji-zhen Liu
Making use of the steam heat storage in thermal generators enables them to operate in a “fast mode” to ramp up or down faster than regular, so as to better catch up with the fluctuations of wind power to improve system wind utilization. In such fast mode, generators have MW-dependent ramp rates and, distinguished from regular units, MW and ramp rate dependent coal consumption costs. Existing economic dispatch models usually use MW-dependent generator cost functions and constant ramp rate limits, and are thus not applicable to systems containing fast mode generators. This paper presents a new formulation of dynamic economic dispatch for wind-thermal power systems, to take into account ramping capabilities and costs of generators in their fast mode. In our model, the objective is to minimize a two-variable quadratic generator cost function depending on both output levels and ramp rates, and generator ramp rate limits are MW-dependent piece-wise linear functions. The formulation can be solved by using existing quadratic programming methods. In numerical examples implemented by using CPLEX, our model is demonstrated on the IEEE 30-bus system containing two 600MW thermal units with real data. Results show that by using our model, unit ramping capabilities are better utilized in system dispatch to substantially save curtailed wind energy, and total generator costs are reduced.
{"title":"Economic dispatch of wind-thermal power system with MW and ramp rate dependent generator costs","authors":"Mingyang Li, X. Zou, Wei Wang, Yuguang Niu, Ji-zhen Liu","doi":"10.1109/TDC.2016.7519856","DOIUrl":"https://doi.org/10.1109/TDC.2016.7519856","url":null,"abstract":"Making use of the steam heat storage in thermal generators enables them to operate in a “fast mode” to ramp up or down faster than regular, so as to better catch up with the fluctuations of wind power to improve system wind utilization. In such fast mode, generators have MW-dependent ramp rates and, distinguished from regular units, MW and ramp rate dependent coal consumption costs. Existing economic dispatch models usually use MW-dependent generator cost functions and constant ramp rate limits, and are thus not applicable to systems containing fast mode generators. This paper presents a new formulation of dynamic economic dispatch for wind-thermal power systems, to take into account ramping capabilities and costs of generators in their fast mode. In our model, the objective is to minimize a two-variable quadratic generator cost function depending on both output levels and ramp rates, and generator ramp rate limits are MW-dependent piece-wise linear functions. The formulation can be solved by using existing quadratic programming methods. In numerical examples implemented by using CPLEX, our model is demonstrated on the IEEE 30-bus system containing two 600MW thermal units with real data. Results show that by using our model, unit ramping capabilities are better utilized in system dispatch to substantially save curtailed wind energy, and total generator costs are reduced.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"25 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82152137","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 : 2016-05-03DOI: 10.1109/TDC.2016.7520013
E. Crockett, James T. Kerkhoven, D. Eakins, Brian J. Smith, Carl M. Formento
A primary goal of electric utilities is to maintain reliable and stable service. Therefore utilities forecast and evaluate future power system scenarios and implement the necessary improvements to mitigate adverse impacts. The reliability and age of the existing substation in their northeastern service territory prompted Commonwealth Edison Company (ComEd) to initiate a major substation project. To support reliability and reinforcement improvements to their 138 kV system, a plan was developed to provide an additional source of power into the 138 kV system from the 345 kV system. This involved bisecting an existing 345 kV transmission line and constructing a new 345 kV to 138 kV substation. This paper summarizes engineering solutions to the many challenges involved in a complex transition from old to new facilities. The project was completed with no adverse events and met the stated project objectives.
{"title":"345–138 kV substation upgrade project","authors":"E. Crockett, James T. Kerkhoven, D. Eakins, Brian J. Smith, Carl M. Formento","doi":"10.1109/TDC.2016.7520013","DOIUrl":"https://doi.org/10.1109/TDC.2016.7520013","url":null,"abstract":"A primary goal of electric utilities is to maintain reliable and stable service. Therefore utilities forecast and evaluate future power system scenarios and implement the necessary improvements to mitigate adverse impacts. The reliability and age of the existing substation in their northeastern service territory prompted Commonwealth Edison Company (ComEd) to initiate a major substation project. To support reliability and reinforcement improvements to their 138 kV system, a plan was developed to provide an additional source of power into the 138 kV system from the 345 kV system. This involved bisecting an existing 345 kV transmission line and constructing a new 345 kV to 138 kV substation. This paper summarizes engineering solutions to the many challenges involved in a complex transition from old to new facilities. The project was completed with no adverse events and met the stated project objectives.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"98 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82585425","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 : 2016-05-03DOI: 10.1109/TDC.2016.7520034
Marcos H. M. Camillo, R. Fanucchi, Marcel E. V. Romero, T. W. de Lima, L. T. Marques, J. Massignan, Carlos Dias Maciel, A. Soares, A. Delbem, M. Bessani, J. London
It is computationally hard to solve the Service Restoration (SR) problem for large-scale Distribution Systems (DSs) without any system simplification, since this problem is combinatorial and non-linear, involving several constraints and objectives. The methodology named MEAN-MH+ES has proved able to generate feasible solutions (radial configuration attending all the operational constraints) with relatively soft computing and without requiring any network simplification in several tests performed on the real and large-scale DS of Londrina city (Brazil). The MEAN-MH+ES combines Multi-objective Evolutionary Algorithm with Node-Depth Encoding, Multiple-criteria tables, alarming Heuristic and an Exhaustive search. However, as the majority of the methodologies for solving the SR problem, the MEAN-MH+ES does not provide a feasible sequence of switching operations to reach the final configuration (the feasible solution) from the initial configuration (the configuration with the faulted areas identified and isolated). This paper proposes to incorporate a heuristic procedure into MEAN-MH+ES, which enable to provide a Feasible Sequence of Switching Operations (FSSO), that is, a switching operation sequence that generates only intermediate configurations that respect the operational constraints. The proposed heuristic procedure is confirmed on tests performed on the real and large-scale DS of Londrina city.
{"title":"Determination of switching sequence of Service Restoration in Distribution Systems: Application and analysis on a real and large-scale radial system","authors":"Marcos H. M. Camillo, R. Fanucchi, Marcel E. V. Romero, T. W. de Lima, L. T. Marques, J. Massignan, Carlos Dias Maciel, A. Soares, A. Delbem, M. Bessani, J. London","doi":"10.1109/TDC.2016.7520034","DOIUrl":"https://doi.org/10.1109/TDC.2016.7520034","url":null,"abstract":"It is computationally hard to solve the Service Restoration (SR) problem for large-scale Distribution Systems (DSs) without any system simplification, since this problem is combinatorial and non-linear, involving several constraints and objectives. The methodology named MEAN-MH+ES has proved able to generate feasible solutions (radial configuration attending all the operational constraints) with relatively soft computing and without requiring any network simplification in several tests performed on the real and large-scale DS of Londrina city (Brazil). The MEAN-MH+ES combines Multi-objective Evolutionary Algorithm with Node-Depth Encoding, Multiple-criteria tables, alarming Heuristic and an Exhaustive search. However, as the majority of the methodologies for solving the SR problem, the MEAN-MH+ES does not provide a feasible sequence of switching operations to reach the final configuration (the feasible solution) from the initial configuration (the configuration with the faulted areas identified and isolated). This paper proposes to incorporate a heuristic procedure into MEAN-MH+ES, which enable to provide a Feasible Sequence of Switching Operations (FSSO), that is, a switching operation sequence that generates only intermediate configurations that respect the operational constraints. The proposed heuristic procedure is confirmed on tests performed on the real and large-scale DS of Londrina city.","PeriodicalId":6497,"journal":{"name":"2016 IEEE/PES Transmission and Distribution Conference and Exposition (T&D)","volume":"31 1","pages":"1-5"},"PeriodicalIF":0.0,"publicationDate":"2016-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76460757","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：