Pub Date : 2013-11-25DOI: 10.1109/NAPS.2013.6666884
J. Slegers, J. McCalley
A very high wind penetration future will require the use of a great deal of land. After the best wind farm sites have been exploited, wind farm developers will have to balance the need for strong winds with the cost of generation interconnection transmission and with the capacity of the bulk transmission system. A method is proposed to identify the optimal locations for large numbers of new wind farms, which balances localized transmission investment costs, capacity factors of candidate sites, and availability of transmission capacity. A model of the state of Iowa is used to test this method for a variety of future wind penetration levels, and the results are discussed.
{"title":"Identification of optimal wind farm sites for a high wind penetration future","authors":"J. Slegers, J. McCalley","doi":"10.1109/NAPS.2013.6666884","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666884","url":null,"abstract":"A very high wind penetration future will require the use of a great deal of land. After the best wind farm sites have been exploited, wind farm developers will have to balance the need for strong winds with the cost of generation interconnection transmission and with the capacity of the bulk transmission system. A method is proposed to identify the optimal locations for large numbers of new wind farms, which balances localized transmission investment costs, capacity factors of candidate sites, and availability of transmission capacity. A model of the state of Iowa is used to test this method for a variety of future wind penetration levels, and the results are discussed.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"6 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":"124502780","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.2013.6666954
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.2013.6666901
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.2013.6666919
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}
Pub Date : 2013-11-25DOI: 10.1109/NAPS.2013.6666866
Samir Dahal, H. Salehfar
Using a combination of Particle Swarm Optimization (PSO) and Newton-Raphson load flow methods this paper investigates the impact of location and size of distributed generators on distribution systems. Similar to the existing improved analytical (IA) method, the proposed approach optimizes the size and location of distributed generators with both real and reactive power capabilities. However, studies show that the proposed method yields much better results than the IA technique and with less computation times. In addition, compared to other evolutionary algorithms such as artificial bee colony (ABC), the proposed method achieves a better distribution system voltage profile with smaller DG sizes. To show the advantages of the proposed method, the IEEE 69-bus distribution system is used as a test bed and the results are compared with those from IA and ABC approaches.
{"title":"Optimal location and sizing of distributed generators in distribution networks","authors":"Samir Dahal, H. Salehfar","doi":"10.1109/NAPS.2013.6666866","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666866","url":null,"abstract":"Using a combination of Particle Swarm Optimization (PSO) and Newton-Raphson load flow methods this paper investigates the impact of location and size of distributed generators on distribution systems. Similar to the existing improved analytical (IA) method, the proposed approach optimizes the size and location of distributed generators with both real and reactive power capabilities. However, studies show that the proposed method yields much better results than the IA technique and with less computation times. In addition, compared to other evolutionary algorithms such as artificial bee colony (ABC), the proposed method achieves a better distribution system voltage profile with smaller DG sizes. To show the advantages of the proposed method, the IEEE 69-bus distribution system is used as a test bed and the results are compared with those from IA and ABC approaches.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"48 21 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":"126038458","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.2013.6666946
A. Esmaeilian, M. Kezunovic
The tapped lines are usually used to supply a customer such as small communities or industrial facilities with an economic solution that is less expensive than building a full substation. Locating faults in such lines are difficult due to the effect of infeed/outfeed current from tapped lines as well as reactance effect. The proposed method applies generalized models of fault loop voltage and current to formulate the fault location algorithm. The derived algorithm has a very simple first-order formula and does not require knowledge of data from the other ends. This feature becomes more significant in the case of isolated rural areas where communicational link to exchange data with other ends may not exist. The result of the algorithm performance evaluation using simulations verifies the high accuracy of the method with regard to various equivalent source impedances, fault inception angles, fault resistances and locations as well as fault types.
{"title":"An impedance based fault location algorithm for tapped lines using local measurements","authors":"A. Esmaeilian, M. Kezunovic","doi":"10.1109/NAPS.2013.6666946","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666946","url":null,"abstract":"The tapped lines are usually used to supply a customer such as small communities or industrial facilities with an economic solution that is less expensive than building a full substation. Locating faults in such lines are difficult due to the effect of infeed/outfeed current from tapped lines as well as reactance effect. The proposed method applies generalized models of fault loop voltage and current to formulate the fault location algorithm. The derived algorithm has a very simple first-order formula and does not require knowledge of data from the other ends. This feature becomes more significant in the case of isolated rural areas where communicational link to exchange data with other ends may not exist. The result of the algorithm performance evaluation using simulations verifies the high accuracy of the method with regard to various equivalent source impedances, fault inception angles, fault resistances and locations as well as fault types.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"40 2 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":"116285960","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.2013.6666878
F. Shariatzadeh, A. Srivastava
One of the most important goals of smart grid is sustainability. Load management in coordinated manner may help in saving more energy and hence move towards sustainability. Advanced metering infrastructures (AMI) and bidirectional communication between electricity grid and endusers, novel technologies and designs are required to exploit full potential of smart grid investments. New analysis tools and control strategies are needed for distribution systems to augment these investments. Heating, ventilation and air conditioning (HVAC) systems, as thermostatic controllable loads, consume major portion of electric energy. In this work, a detailed load model of thermostatic electric loads is used to develop a novel approach of look-ahead controller over different time frames. Developed controller has been tested for cooling mode operation on a typical summer day and shows satisfactory performance.
{"title":"Look-ahead control approach for thermostatic electric load in distribution system","authors":"F. Shariatzadeh, A. Srivastava","doi":"10.1109/NAPS.2013.6666878","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666878","url":null,"abstract":"One of the most important goals of smart grid is sustainability. Load management in coordinated manner may help in saving more energy and hence move towards sustainability. Advanced metering infrastructures (AMI) and bidirectional communication between electricity grid and endusers, novel technologies and designs are required to exploit full potential of smart grid investments. New analysis tools and control strategies are needed for distribution systems to augment these investments. Heating, ventilation and air conditioning (HVAC) systems, as thermostatic controllable loads, consume major portion of electric energy. In this work, a detailed load model of thermostatic electric loads is used to develop a novel approach of look-ahead controller over different time frames. Developed controller has been tested for cooling mode operation on a typical summer day and shows satisfactory performance.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"119 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":"116380499","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.2013.6666926
J. Follum, J. Pierre
With the phasor measurement unit (PMU) networks that have been developed to improve utilities' wide-area situational awareness, it is now possible to obtain high-fidelity observations of forced oscillations (FOs). Due to the large variation in their amplitudes, reliable methods for detecting forced oscillations and estimating their parameters are needed. In this paper, an algorithm designed for the detection and estimation of sinusoids in white Gaussian noise is modified for the colored noise environment of power systems. A novel time-localization algorithm based on the cross-correlation estimator is proposed to estimate the start and end points of a forced oscillation, and an estimator for the forced oscillation's amplitude dependent on these location estimates is developed. Using a simple model, the algorithms are shown to be capable of detecting a forced oscillation, estimating its frequency, locating it within the data, and estimating its amplitude.
{"title":"Initial results in the detection and estimation of forced oscillations in power systems","authors":"J. Follum, J. Pierre","doi":"10.1109/NAPS.2013.6666926","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666926","url":null,"abstract":"With the phasor measurement unit (PMU) networks that have been developed to improve utilities' wide-area situational awareness, it is now possible to obtain high-fidelity observations of forced oscillations (FOs). Due to the large variation in their amplitudes, reliable methods for detecting forced oscillations and estimating their parameters are needed. In this paper, an algorithm designed for the detection and estimation of sinusoids in white Gaussian noise is modified for the colored noise environment of power systems. A novel time-localization algorithm based on the cross-correlation estimator is proposed to estimate the start and end points of a forced oscillation, and an estimator for the forced oscillation's amplitude dependent on these location estimates is developed. Using a simple model, the algorithms are shown to be capable of detecting a forced oscillation, estimating its frequency, locating it within the data, and estimating its amplitude.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"210 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":"131093459","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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