Pub Date : 2013-11-25DOI: 10.1109/NAPS.2013.6666954
Vivek Joshi, J. Solanki, S. K. Solanki
Distribution Management systems are used by electric utilities for analyzing and controlling the distribution systems. Due to lack of data, the model parameters are not accurate so controller often fails to maintain voltage profile in a smart distribution system. In this paper, we propose a statistical method to maintain the voltage profile of the system with renewable generators. This statistical method based on regression is used to design the capacitor control without the need of any knowledge of entire distribution system. The control is tested on an IEEE 34 node distribution system with a solar generator.
{"title":"Statistical method to improve voltage profile under incomplete distribution system information","authors":"Vivek Joshi, J. Solanki, S. K. Solanki","doi":"10.1109/NAPS.2013.6666954","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666954","url":null,"abstract":"Distribution Management systems are used by electric utilities for analyzing and controlling the distribution systems. Due to lack of data, the model parameters are not accurate so controller often fails to maintain voltage profile in a smart distribution system. In this paper, we propose a statistical method to maintain the voltage profile of the system with renewable generators. This statistical method based on regression is used to design the capacitor control without the need of any knowledge of entire distribution system. The control is tested on an IEEE 34 node distribution system with a solar generator.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"105 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":"132299686","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.2013.6666951
M. Benidris, J. Mitra
This work introduces a new technique to reduce the search space in evaluating reliability indices of power systems. A new formulation for maximum capacity flow of the transmission lines was developed and used in truncating the state space to identify the definite success and definite failure subspaces. A new algorithm based on “directed” Binary Particle Swarm Optimization (BPSO) was developed to search for the designated success or failure states in the remaining part of the state space. The remaining subspace is system dependent, and in case of systems with high capacity and reliability transmission lines in comparison with generation and loading levels, the effect of this subspace on system reliability can be ignored without causing any significant error. This method is very simple and straight forward, yet it reduces the computational time significantly. The method progresses by calculating the total available power carrying capability at every bus and between buses for every system state. Incidence matrix technique was used in building Line Capacity Matrix (LCM). From the LCM and system state (Generation-Transmission-Load), reliability indices can be calculated. This method was applied on two systems, the IEEE RTS and the modified IEEE RTS and it gave promising results.
{"title":"Composite power system reliability assessment using maximum capacity flow and directed Binary Particle Swarm Optimization","authors":"M. Benidris, J. Mitra","doi":"10.1109/NAPS.2013.6666951","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666951","url":null,"abstract":"This work introduces a new technique to reduce the search space in evaluating reliability indices of power systems. A new formulation for maximum capacity flow of the transmission lines was developed and used in truncating the state space to identify the definite success and definite failure subspaces. A new algorithm based on “directed” Binary Particle Swarm Optimization (BPSO) was developed to search for the designated success or failure states in the remaining part of the state space. The remaining subspace is system dependent, and in case of systems with high capacity and reliability transmission lines in comparison with generation and loading levels, the effect of this subspace on system reliability can be ignored without causing any significant error. This method is very simple and straight forward, yet it reduces the computational time significantly. The method progresses by calculating the total available power carrying capability at every bus and between buses for every system state. Incidence matrix technique was used in building Line Capacity Matrix (LCM). From the LCM and system state (Generation-Transmission-Load), reliability indices can be calculated. This method was applied on two systems, the IEEE RTS and the modified IEEE RTS and it gave promising results.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"8 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":"128249884","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.2013.6666901
Dongsheng Li, Fenglong Lu, Q. Lv, Li Shang
This paper presents the use of hybrid energy storage, composed of ultracapacitor and Lithiumion battery, to improve wind power stability. A control algorithm based on artificial neural network is proposed to manage the run-time use of the hybrid energy storage system to (1) optimize wind power predictability hence power grid stability, and (2) minimize the overall lifetime cost of the energy storage system. Evaluations using wind farm data demonstrate that, compared with two recently proposed control methods, the proposed control algorithm can extend system lifetime by 62% and 143%, and reduce the overall lifetime energy storage system cost (20 years) by 41% and 59%, respectively.
{"title":"Lifetime cost optimized wind power control using hybrid energy storage system","authors":"Dongsheng Li, Fenglong Lu, Q. Lv, Li Shang","doi":"10.1109/NAPS.2013.6666901","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666901","url":null,"abstract":"This paper presents the use of hybrid energy storage, composed of ultracapacitor and Lithiumion battery, to improve wind power stability. A control algorithm based on artificial neural network is proposed to manage the run-time use of the hybrid energy storage system to (1) optimize wind power predictability hence power grid stability, and (2) minimize the overall lifetime cost of the energy storage system. Evaluations using wind farm data demonstrate that, compared with two recently proposed control methods, the proposed control algorithm can extend system lifetime by 62% and 143%, and reduce the overall lifetime energy storage system cost (20 years) by 41% and 59%, respectively.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"34 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":"123399380","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.2013.6666911
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.2013.6666882
Savo D. Dukic, A. Sarić, A. Stanković
This paper proposes a new approach to reduction of power system dynamic models based on approximate bisimulation relations. Advantages of these relations for time domain analysis over the model reduction techniques commonly used in system theory are pointed out. The approach is applied to the transient stability analysis in power systems. We propose an algorithm that identifies whether the power system is able to maintain the synchronism after a disturbance, based on linearization and approximate bisimulation relations. During the time simulation, the linearized model is transformed into the appropriate form and reduced using the approximate bisimulation relations. This reduced (and linear) model is used in the numerical integration instead of the original nonlinear one, while the accuracy criterion is satisfied. The New England benchmark power system is used to verify the described algorithm.
{"title":"Approximate bisimulation-based reduction of power system dynamic model with application to transient stability analysis","authors":"Savo D. Dukic, A. Sarić, A. Stanković","doi":"10.1109/NAPS.2013.6666882","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666882","url":null,"abstract":"This paper proposes a new approach to reduction of power system dynamic models based on approximate bisimulation relations. Advantages of these relations for time domain analysis over the model reduction techniques commonly used in system theory are pointed out. The approach is applied to the transient stability analysis in power systems. We propose an algorithm that identifies whether the power system is able to maintain the synchronism after a disturbance, based on linearization and approximate bisimulation relations. During the time simulation, the linearized model is transformed into the appropriate form and reduced using the approximate bisimulation relations. This reduced (and linear) model is used in the numerical integration instead of the original nonlinear one, while the accuracy criterion is satisfied. The New England benchmark power system is used to verify the described algorithm.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"4 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":"114494693","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}
This paper proposes an optimal PMU placement (OPP) model to make power system observable for normal operation condition as well as controlled islanding scenario. The optimization objective of proposed model is to minimize the number of installed PMUs and then maximize the measurement redundancy. To take advantage of the power network topology, the effect of zero-injection bus is incorporated into the model. Furthermore, additional observability constraints for single PMU or line loss are also derived. At last, test results on IEEE 118-bus system are presented to demonstrate the effectiveness of the proposed method.
{"title":"Placement of PMUs in power systems with multiple operation scenarios","authors":"Lei Huang, Jian Xu, Yuanzhan Sun, Wenzhong Gao, Xiaoming Li, Jianxun Dong, Chengzhu Qi","doi":"10.1109/NAPS.2013.6666836","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666836","url":null,"abstract":"This paper proposes an optimal PMU placement (OPP) model to make power system observable for normal operation condition as well as controlled islanding scenario. The optimization objective of proposed model is to minimize the number of installed PMUs and then maximize the measurement redundancy. To take advantage of the power network topology, the effect of zero-injection bus is incorporated into the model. Furthermore, additional observability constraints for single PMU or line loss are also derived. At last, test results on IEEE 118-bus system are presented to demonstrate the effectiveness of the proposed method.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"28 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":"114770163","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.2013.6666929
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.2013.6666919
A. Saran
Power system protection is still one of the primary focus of the utility companies. Phasor Measurement Unit (PMU) is used to measure the data of the transmission line, buses and the equipment's associated with it. The data measured by the PMU's at different locations can be used to make the decisions for faulty and healthy zone in the power system. During fault condition at specific location in the power system, the data measured by PMU will show abrupt increase or decrease in the physical quantities like voltage, current, and phase angles. Based on the PMU values the relays associated with the faulty transmission lines will be triggered which in turn helps to isolate only the faulty portion of the system from the rest of the healthy portion of the power system. This paper will compare two protection schemes: one protection scheme is based solely on the protective relays while the other protection scheme utilizes both the protective relays and the PMUs. Both the protection schemes were tested in real time (using RTDS) on the 3-bus power system for all kinds of line-to-ground faults.
{"title":"Comparison between overcurrent relay and developed PMU based protection","authors":"A. Saran","doi":"10.1109/NAPS.2013.6666919","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666919","url":null,"abstract":"Power system protection is still one of the primary focus of the utility companies. Phasor Measurement Unit (PMU) is used to measure the data of the transmission line, buses and the equipment's associated with it. The data measured by the PMU's at different locations can be used to make the decisions for faulty and healthy zone in the power system. During fault condition at specific location in the power system, the data measured by PMU will show abrupt increase or decrease in the physical quantities like voltage, current, and phase angles. Based on the PMU values the relays associated with the faulty transmission lines will be triggered which in turn helps to isolate only the faulty portion of the system from the rest of the healthy portion of the power system. This paper will compare two protection schemes: one protection scheme is based solely on the protective relays while the other protection scheme utilizes both the protective relays and the PMUs. Both the protection schemes were tested in real time (using RTDS) on the 3-bus power system for all kinds of line-to-ground faults.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"3 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":"125807028","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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