Pub Date : 2013-11-25DOI: 10.1109/NAPS.2013.6666885
Brett Robbins, Hao Zhu, A. Domínguez-García
In this paper, we propose a method to optimally set the taps of voltage regulation transformers in distribution networks. Specifically, we cast the problem of optimally choosing the tap settings as a rank-constrained semidefinite program (SDP) with the transformer tap positions removed from the network's admittance matrix and replaced by additional constraints and optimization variables. Then, the non-convex rank-1 constraint that arises from this rank-constrained SDP formulation is relaxed, which leads to a convex SDP program. The tap positions are obtained from the primary- and secondary-side bus voltages yielded by the optimal solution. We present several case studies with a 14-bus single-phase and a 15-bus three-phase distribution system to demonstrate the validity of our method.
{"title":"Optimal tap settings for voltage regulation transformers in distribution networks","authors":"Brett Robbins, Hao Zhu, A. Domínguez-García","doi":"10.1109/NAPS.2013.6666885","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666885","url":null,"abstract":"In this paper, we propose a method to optimally set the taps of voltage regulation transformers in distribution networks. Specifically, we cast the problem of optimally choosing the tap settings as a rank-constrained semidefinite program (SDP) with the transformer tap positions removed from the network's admittance matrix and replaced by additional constraints and optimization variables. Then, the non-convex rank-1 constraint that arises from this rank-constrained SDP formulation is relaxed, which leads to a convex SDP program. The tap positions are obtained from the primary- and secondary-side bus voltages yielded by the optimal solution. We present several case studies with a 14-bus single-phase and a 15-bus three-phase distribution system to demonstrate the validity of our method.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129592356","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666935
N. Singhal, K. Hedman
This paper presents an iterative approach to integrate the transmission and distribution systems together. The ideal approach is to solve a single transmission and distribution systems optimal power flow (OPF) model. However, this is computationally intractable with existing technologies due to the size of the system. Therefore, the integrated OPF problem is decomposed into two subsequent problems: the transmission OPF and the distribution OPF. With the proposed algorithm, the distribution system is modeled by a residual demand curve in the transmission system OPF while the transmission system is modeled by a transmission-constrained residual supply curve in the distribution system OPF.
{"title":"An integrated transmission and distribution systems model with distribution-based LMP (DLMP) pricing","authors":"N. Singhal, K. Hedman","doi":"10.1109/NAPS.2013.6666935","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666935","url":null,"abstract":"This paper presents an iterative approach to integrate the transmission and distribution systems together. The ideal approach is to solve a single transmission and distribution systems optimal power flow (OPF) model. However, this is computationally intractable with existing technologies due to the size of the system. Therefore, the integrated OPF problem is decomposed into two subsequent problems: the transmission OPF and the distribution OPF. With the proposed algorithm, the distribution system is modeled by a residual demand curve in the transmission system OPF while the transmission system is modeled by a transmission-constrained residual supply curve in the distribution system OPF.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125333349","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666918
L. F. Fuerte-Ledezma, G. Gutiérrez-Alcaraz, M. Javadi
This paper discusses static transmission expansion planning (STEP) in terms of minimizing the costs of investment and operations. We propose a transmission expansion model that divides into investment and operations problems. We use a binary particle swarm optimization algorithm (BPSO) to solve the investment problem and a DC optimal power flow (DCOPF) to solve the operations problem. We model uncertainty as stochastic demand at each node. A simulated case study numerically evaluates the efficiency of the proposed method.
{"title":"Static transmission expansion planning considering uncertainty in demand using BPSO","authors":"L. F. Fuerte-Ledezma, G. Gutiérrez-Alcaraz, M. Javadi","doi":"10.1109/NAPS.2013.6666918","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666918","url":null,"abstract":"This paper discusses static transmission expansion planning (STEP) in terms of minimizing the costs of investment and operations. We propose a transmission expansion model that divides into investment and operations problems. We use a binary particle swarm optimization algorithm (BPSO) to solve the investment problem and a DC optimal power flow (DCOPF) to solve the operations problem. We model uncertainty as stochastic demand at each node. A simulated case study numerically evaluates the efficiency of the proposed method.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"504 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122207847","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666911
Rui Yang, G. Hug
In security constrained economic dispatch, the generation is determined such as to minimize cost to supply the load while fulfilling all of the operational constraints in normal operation and contingency cases. The formulation of a security index provides a quantitative measure for the security in the system and also allows for the determination of the impact of generators on security. Hence, in this paper, first two different security indices are formulated: a violation-based security index and a risk-based security index. These security index formulations are used to introduce locational security impact factors which similarly to the information that locational marginal prices provide for generation economics, give insights into the location dependent impact on system security. These impact factors are then integrated into an iterative approach for the determination of the optimal generation settings given a specific bound on the desired level of system security.
{"title":"Locational security impact factors for security index constrained economic dispatch problem","authors":"Rui Yang, G. Hug","doi":"10.1109/NAPS.2013.6666911","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666911","url":null,"abstract":"In security constrained economic dispatch, the generation is determined such as to minimize cost to supply the load while fulfilling all of the operational constraints in normal operation and contingency cases. The formulation of a security index provides a quantitative measure for the security in the system and also allows for the determination of the impact of generators on security. Hence, in this paper, first two different security indices are formulated: a violation-based security index and a risk-based security index. These security index formulations are used to introduce locational security impact factors which similarly to the information that locational marginal prices provide for generation economics, give insights into the location dependent impact on system security. These impact factors are then integrated into an iterative approach for the determination of the optimal generation settings given a specific bound on the desired level of system security.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"50 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122678310","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666929
Abdlmnam Abdlrahem, G. Venayagamoorthy, K. Corzine
Integrating large photovoltaic (PV) plants into the grid poses challenges to maintaining the system's stability during small and large disturbances. A PV system's output power fluctuates according to the weather conditions (irradiance and temperature), season, and geographic location. The power fluctuations of the PV plants raise frequency and voltage stability issues. This paper presents the impact of a large PV plant on the frequency stability of a power system under small and large disturbances. With automatic generation control and phasor measurement unit information, the power generations of conventional generators are adjusted to mitigate the frequency deviation. Furthermore, the effects of increased PV penetration in a given power system area are examined.
{"title":"Frequency stability and control of a power system with large PV plants using PMU information","authors":"Abdlmnam Abdlrahem, G. Venayagamoorthy, K. Corzine","doi":"10.1109/NAPS.2013.6666929","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666929","url":null,"abstract":"Integrating large photovoltaic (PV) plants into the grid poses challenges to maintaining the system's stability during small and large disturbances. A PV system's output power fluctuates according to the weather conditions (irradiance and temperature), season, and geographic location. The power fluctuations of the PV plants raise frequency and voltage stability issues. This paper presents the impact of a large PV plant on the frequency stability of a power system under small and large disturbances. With automatic generation control and phasor measurement unit information, the power generations of conventional generators are adjusted to mitigate the frequency deviation. Furthermore, the effects of increased PV penetration in a given power system area are examined.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126592983","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666930
E. N. Reyes, M. Perez G, A. R. Messina
A theoretical framework to design decentralized power system controllers based on a generalized Relative Gain Array (RGA) concept is suggested. The proposed approach constitutes a natural extension to conventional RGA-based structures and may be used to place controllers as well as to supplement information on the phase or sense of loop interaction. This approach also allows better coordination of control capabilities. Techniques to choose the best input-output pairs that incorporate phase information associated with the control structure are introduced and extensions to the standard RGA-based techniques are proposed. A case study with a 16-machine, 68-bus test system shows that the method is effective and results in improved control performance.
{"title":"A framework for decentralized design of system controllers using an extended Relative Gain approach","authors":"E. N. Reyes, M. Perez G, A. R. Messina","doi":"10.1109/NAPS.2013.6666930","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666930","url":null,"abstract":"A theoretical framework to design decentralized power system controllers based on a generalized Relative Gain Array (RGA) concept is suggested. The proposed approach constitutes a natural extension to conventional RGA-based structures and may be used to place controllers as well as to supplement information on the phase or sense of loop interaction. This approach also allows better coordination of control capabilities. Techniques to choose the best input-output pairs that incorporate phase information associated with the control structure are introduced and extensions to the standard RGA-based techniques are proposed. A case study with a 16-machine, 68-bus test system shows that the method is effective and results in improved control performance.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133609508","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666965
V. Tran, S. Kamalasadan, J. Enslin
This paper presents a novel real-time autonomous dynamic modeling, validation and tuning of a synchronous generator using Real Time Digital Simulator (RTDS) (synchronous generator and controls), synchrophasor capable relay and IEC 61850 protocol. Also, with a unique testbed the paper discusses a method to; a) use synchrophasor capable relays for measuring the voltage and current from the generator and transferring that information to RTDS using IEC 61850 protocol, b) compare voltages and currents of the dynamic model running in real-time and c) generator excitation auto tuning to correct model changes. The advantages of the proposed method are that real-time dynamic model developed can be tuned with the help of real measurements for any system parametric or model issues. This allows dynamic model validation and control using real-time sensors such as Phasor Measurement Units (PMU's).
{"title":"Real-time modeling and model validation of synchronous generator using synchrophasor measurements","authors":"V. Tran, S. Kamalasadan, J. Enslin","doi":"10.1109/NAPS.2013.6666965","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666965","url":null,"abstract":"This paper presents a novel real-time autonomous dynamic modeling, validation and tuning of a synchronous generator using Real Time Digital Simulator (RTDS) (synchronous generator and controls), synchrophasor capable relay and IEC 61850 protocol. Also, with a unique testbed the paper discusses a method to; a) use synchrophasor capable relays for measuring the voltage and current from the generator and transferring that information to RTDS using IEC 61850 protocol, b) compare voltages and currents of the dynamic model running in real-time and c) generator excitation auto tuning to correct model changes. The advantages of the proposed method are that real-time dynamic model developed can be tuned with the help of real measurements for any system parametric or model issues. This allows dynamic model validation and control using real-time sensors such as Phasor Measurement Units (PMU's).","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"88 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115886547","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666829
H. Livani, C. Evrenosoglu, V. Centeno
This paper presents a machine learning-based faulty-line identification method in smart distribution networks. The proposed method utilizes postfault root-mean-square (rms) values of voltages measured at the main substation and at selected nodes as well as fault information obtained by fault current identifiers (FCIs) and intelligent electronic re-closers (IE-CRs). The information from FCIs and IE-RCs are first used to identify the faulty region in the network. The normalized rms values of voltages are then utilized as the input to the support vector machine (SVM) classifiers to identify the faulty-line according to the pre-determined fault type. The IEEE 123-node distribution test system is simulated in ATP software. MATLAB is used to process the simulated transients and to apply the proposed method. The performance of the method is tested for different fault inception angles (FIA) and different fault resistances with satisfactory results.
{"title":"A machine learning-based faulty line identification for smart distribution network","authors":"H. Livani, C. Evrenosoglu, V. Centeno","doi":"10.1109/NAPS.2013.6666829","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666829","url":null,"abstract":"This paper presents a machine learning-based faulty-line identification method in smart distribution networks. The proposed method utilizes postfault root-mean-square (rms) values of voltages measured at the main substation and at selected nodes as well as fault information obtained by fault current identifiers (FCIs) and intelligent electronic re-closers (IE-CRs). The information from FCIs and IE-RCs are first used to identify the faulty region in the network. The normalized rms values of voltages are then utilized as the input to the support vector machine (SVM) classifiers to identify the faulty-line according to the pre-determined fault type. The IEEE 123-node distribution test system is simulated in ATP software. MATLAB is used to process the simulated transients and to apply the proposed method. The performance of the method is tested for different fault inception angles (FIA) and different fault resistances with satisfactory results.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"68 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114563153","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666843
N. M. Salgado‐Herrera, A. Medina-Rios, A. Ramos-Paz, J. R. Rodríguez-Rodríguez
This paper deals with the implementation of parallel processing SPWM multilevel techniques through programmable gate arrays (Field Programmable Gate Arrays, FPGAs). It is shown that switching losses in power converters significantly decreases with an increased number of levels in the SPWM signal, thus providing an efficient energy transfer. The multilevel SPWM control response of 3, 9 and 21 levels in VHDL through the FPGA Xilinx Spartan family is illustrated.
{"title":"Generation of a multilevel SPWM technique of 3, 9 and 21 levels with FPGAs","authors":"N. M. Salgado‐Herrera, A. Medina-Rios, A. Ramos-Paz, J. R. Rodríguez-Rodríguez","doi":"10.1109/NAPS.2013.6666843","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666843","url":null,"abstract":"This paper deals with the implementation of parallel processing SPWM multilevel techniques through programmable gate arrays (Field Programmable Gate Arrays, FPGAs). It is shown that switching losses in power converters significantly decreases with an increased number of levels in the SPWM signal, thus providing an efficient energy transfer. The multilevel SPWM control response of 3, 9 and 21 levels in VHDL through the FPGA Xilinx Spartan family is illustrated.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121181507","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 : 2013-11-25DOI: 10.1109/NAPS.2013.6666917
J. Donadee
This paper considers the co-optimization of the operations of a grid scale energy storage resource (ESR) for both energy price arbitrage and sales of secondary frequency regulation capacity. We investigate the application of the infinite horizon Markov decision problem (MDP) framework to this problem. We formulate the ESR's decision optimization problem as an infinite horizon, average reward MDP. This problem is a proof-of-principle which considers the automatic generation control signal as the only random parameter. Example MDPs are solved using the policy iteration algorithm. The optimal operating policies and gains are described. Results show that the value of an ESR can be increased substantially by using it for more than one purpose simultaneously.
{"title":"Optimal operation of energy storage for arbitrage and ancillary service capacity: The infinite horizon approach","authors":"J. Donadee","doi":"10.1109/NAPS.2013.6666917","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666917","url":null,"abstract":"This paper considers the co-optimization of the operations of a grid scale energy storage resource (ESR) for both energy price arbitrage and sales of secondary frequency regulation capacity. We investigate the application of the infinite horizon Markov decision problem (MDP) framework to this problem. We formulate the ESR's decision optimization problem as an infinite horizon, average reward MDP. This problem is a proof-of-principle which considers the automatic generation control signal as the only random parameter. Example MDPs are solved using the policy iteration algorithm. The optimal operating policies and gains are described. Results show that the value of an ESR can be increased substantially by using it for more than one purpose simultaneously.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"65 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-11-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129125157","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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