Pub Date : 2013-12-11DOI: 10.1109/NAPS.2013.6666846
N. Mohan
This paper describes the experience and lessons learned in teaching a graduate-level course on Power Electronics in Power Systems, which was based on student projects and most of the in-class “lecturing” was done by students.
{"title":"Experience and lessons learned in a graduate-level course based on students as “Teachers”","authors":"N. Mohan","doi":"10.1109/NAPS.2013.6666846","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666846","url":null,"abstract":"This paper describes the experience and lessons learned in teaching a graduate-level course on Power Electronics in Power Systems, which was based on student projects and most of the in-class “lecturing” was done by students.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127082681","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666824
A. Rahimi, M. Zarghami, M. Vaziri, S. Vadhva
This paper discusses a simple method to perform peak load shaving through the means of energy storage systems owned by a utility. Peak load shaving, also referred to as load leveling or peak shifting, consists of the schemes used to eliminate the peaks and valleys in the load profile. This practice offers direct and indirect benefits to utilities in generation costs, line loss reduction, and volt support. Prior work in peak load shaving has been mainly focused on optimization approaches implemented through methods such as non-linear and dynamic programming, or heuristic approaches such as particle-swarm optimization. The proposed algorithm for peak load shaving in this paper is based on a simple approach which compares the aggregated load profile with its average in a certain utilization period and shares the charge/discharge amongst energy storage devices based on the definition of energy bars and weighting factors. In particular, the paper focuses on the usage of Battery Energy Storage Systems (BESS) to accomplish this task. Results show that the proposed algorithm offers a simple, fast and effective way for peak-load shaving without heavy computational burdens often needed in other methods. As a result, it can be easily implemented in a utility main substation for controlling the charge/discharge of storage devices throughout the distribution system.
{"title":"A simple and effective approach for peak load shaving using Battery Storage Systems","authors":"A. Rahimi, M. Zarghami, M. Vaziri, S. Vadhva","doi":"10.1109/NAPS.2013.6666824","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666824","url":null,"abstract":"This paper discusses a simple method to perform peak load shaving through the means of energy storage systems owned by a utility. Peak load shaving, also referred to as load leveling or peak shifting, consists of the schemes used to eliminate the peaks and valleys in the load profile. This practice offers direct and indirect benefits to utilities in generation costs, line loss reduction, and volt support. Prior work in peak load shaving has been mainly focused on optimization approaches implemented through methods such as non-linear and dynamic programming, or heuristic approaches such as particle-swarm optimization. The proposed algorithm for peak load shaving in this paper is based on a simple approach which compares the aggregated load profile with its average in a certain utilization period and shares the charge/discharge amongst energy storage devices based on the definition of energy bars and weighting factors. In particular, the paper focuses on the usage of Battery Energy Storage Systems (BESS) to accomplish this task. Results show that the proposed algorithm offers a simple, fast and effective way for peak-load shaving without heavy computational burdens often needed in other methods. As a result, it can be easily implemented in a utility main substation for controlling the charge/discharge of storage devices throughout the distribution system.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126722101","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666906
M. Kazerooni, Hao Zhu, T. Overbye
Geomagnetically induced currents (GICs) cause half cycle saturation of transformers, which increases harmonic currents and reactive powers in the grid. This paper presents the least-squares (LS) estimation of the geoelectric field using the GIC measurements for model validation purposes. To account for more realistic noise scenarios, a general probabilistic GIC measurement model has been developed. Using the proposed model, the accuracy of the LS estimator and its reliability in assessing the geoelectric field are available analytically. The analytical results are verified through numerical simulations using a practical 20-bus test case.
{"title":"Probabilistic modeling and reliability analysis for validating geomagnetically induced current data","authors":"M. Kazerooni, Hao Zhu, T. Overbye","doi":"10.1109/NAPS.2013.6666906","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666906","url":null,"abstract":"Geomagnetically induced currents (GICs) cause half cycle saturation of transformers, which increases harmonic currents and reactive powers in the grid. This paper presents the least-squares (LS) estimation of the geoelectric field using the GIC measurements for model validation purposes. To account for more realistic noise scenarios, a general probabilistic GIC measurement model has been developed. Using the proposed model, the accuracy of the LS estimator and its reliability in assessing the geoelectric field are available analytically. The analytical results are verified through numerical simulations using a practical 20-bus test case.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"69 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126353610","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666886
Y. Chen, A. Domínguez-García, P. Sauer
This paper proposes a method to compute linear sensitivity distribution factors (DFs) in near real-time without relying on a power flow model of the system. Instead, the proposed method relies on the solution of an underdetermined system of linear equations that arise from high-frequency synchronized measurements obtained from phasor measurement units. In particular, we exploit a sparse representation (i.e., one in which many elements are zero) of the desired DFs obtained via a linear transformation, and cast the estimation problem as an IO-norm minimization. As we illustrate through examples, the proposed approach is able to provide accurate DF estimates with fewer sets of synchronized measurements than earlier approaches that rely on the solution of an overdetermined system of equations via the least-squares errors method.
{"title":"Online estimation of power system distribution factors — A sparse representation approach","authors":"Y. Chen, A. Domínguez-García, P. Sauer","doi":"10.1109/NAPS.2013.6666886","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666886","url":null,"abstract":"This paper proposes a method to compute linear sensitivity distribution factors (DFs) in near real-time without relying on a power flow model of the system. Instead, the proposed method relies on the solution of an underdetermined system of linear equations that arise from high-frequency synchronized measurements obtained from phasor measurement units. In particular, we exploit a sparse representation (i.e., one in which many elements are zero) of the desired DFs obtained via a linear transformation, and cast the estimation problem as an IO-norm minimization. As we illustrate through examples, the proposed approach is able to provide accurate DF estimates with fewer sets of synchronized measurements than earlier approaches that rely on the solution of an overdetermined system of equations via the least-squares errors method.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114433984","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666931
J. Ramos, R. Jimenez, E. Barocio
Online assessment and control of low-damping power system oscillations is a challenging problem. This paper discusses the use of subspace stochastic method to visualize and characterize the time evolution of power system electromechanical modes. Using normalized instantaneous amplitudes of modal components, two time-varying indexes to determine mode distribution maps are proposed and tested. The method is well suited to automation and can be incorporated to existing wide-area monitoring systems. Simulation studies on a 16-machine, 68-bus test system show the applicability of the proposed technique.
{"title":"Visualization of interarea oscillations using an extended subspace identification technique","authors":"J. Ramos, R. Jimenez, E. Barocio","doi":"10.1109/NAPS.2013.6666931","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666931","url":null,"abstract":"Online assessment and control of low-damping power system oscillations is a challenging problem. This paper discusses the use of subspace stochastic method to visualize and characterize the time evolution of power system electromechanical modes. Using normalized instantaneous amplitudes of modal components, two time-varying indexes to determine mode distribution maps are proposed and tested. The method is well suited to automation and can be incorporated to existing wide-area monitoring systems. Simulation studies on a 16-machine, 68-bus test system show the applicability of the proposed technique.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117305686","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666948
P. Dehghanian, M. Kezunovic
Maintenance planning and scheduling of circuit breakers (CBs) always involves the cost and benefit analysis. This paper introduces a new framework for cost/benefit assessments using condition-based monitoring data. The signals monitored at the CB control circuit are first utilized to determine the CB deterioration status. This information is used to decide which type of maintenance, e.g., minor, major, or replacement, needs to be practiced for different CBs. System wide analysis is then performed to assess the cost benefits of the maintenance by calculating the costs imposed to the system in the case of CB mal-operation. A new benefit to cost ratio (BCR) index is introduced to deal with the CB maintenance prioritization process. The proposed approach is implemented on a breaker-and-a-half substation configuration and the results demonstrate the applicability of the presented framework in real world scenarios.
{"title":"Cost/benefit analysis for circuit breaker maintenance planning and scheduling","authors":"P. Dehghanian, M. Kezunovic","doi":"10.1109/NAPS.2013.6666948","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666948","url":null,"abstract":"Maintenance planning and scheduling of circuit breakers (CBs) always involves the cost and benefit analysis. This paper introduces a new framework for cost/benefit assessments using condition-based monitoring data. The signals monitored at the CB control circuit are first utilized to determine the CB deterioration status. This information is used to decide which type of maintenance, e.g., minor, major, or replacement, needs to be practiced for different CBs. System wide analysis is then performed to assess the cost benefits of the maintenance by calculating the costs imposed to the system in the case of CB mal-operation. A new benefit to cost ratio (BCR) index is introduced to deal with the CB maintenance prioritization process. The proposed approach is implemented on a breaker-and-a-half substation configuration and the results demonstrate the applicability of the presented framework in real world scenarios.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124246561","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666880
H. Chamorro, M. Ghandhari, R. Eriksson
The use of high power electronics in the large scale integration of wind power in the transmission and distribution systems can affect the system inertia response and the ability to recover frequency stability after large disturbances. Different approaches have been presented to show the system dynamic behaviour, and to quantify the wind power impact on the system inertial and frequency response. This paper gives a short overview of studies performed regarding the system inertia issues under high penetrations of wind power. Also, it presents the results of a case study to show how the system inertia can be affected by high penetrations of wind power.
{"title":"Wind power impact on power system frequency response","authors":"H. Chamorro, M. Ghandhari, R. Eriksson","doi":"10.1109/NAPS.2013.6666880","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666880","url":null,"abstract":"The use of high power electronics in the large scale integration of wind power in the transmission and distribution systems can affect the system inertia response and the ability to recover frequency stability after large disturbances. Different approaches have been presented to show the system dynamic behaviour, and to quantify the wind power impact on the system inertial and frequency response. This paper gives a short overview of studies performed regarding the system inertia issues under high penetrations of wind power. Also, it presents the results of a case study to show how the system inertia can be affected by high penetrations of wind power.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"39 8","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120919244","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666868
M. Gol, A. Abur
Least Absolute Value (LAV) estimators that are based solely on phasor measurements are known to be robust against bad data provided that there is enough redundancy in the measurement set. This paper investigates the required level of redundancy and develops a systematic approach to place Phasor Measurement Units (PMU). The optimal placement will be such that it will guarantee robustness of the LAV state estimation while using a minimum number of PMUs.
{"title":"PMU placement for robust state estimation","authors":"M. Gol, A. Abur","doi":"10.1109/NAPS.2013.6666868","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666868","url":null,"abstract":"Least Absolute Value (LAV) estimators that are based solely on phasor measurements are known to be robust against bad data provided that there is enough redundancy in the measurement set. This paper investigates the required level of redundancy and develops a systematic approach to place Phasor Measurement Units (PMU). The optimal placement will be such that it will guarantee robustness of the LAV state estimation while using a minimum number of PMUs.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131747442","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 : 2013-12-11DOI: 10.1109/NAPS.2013.6666947
J. Berardino, C. Nwankpa
This paper reviews a method of load forecasting specifically for predicting a building's electrical load for demand resource planning. The authors introduced a general problem formulation for building-specific load forecasting in previous works. This paper will enhance this idea with extensive forecaster performance and results based on studies done using historical building demand and thermal data collected for the main library building at Drexel University. These results demonstrate the improvement obtained by including building-specific parameters in the load forecast. Additionally, the variability of this method and how it can inform demand-side decision making is explored, particularly in allowing the manager of a controllable load to assess his or her risk and capabilities when participating in the energy market.
{"title":"Statistics of building-specific load forecasting models","authors":"J. Berardino, C. Nwankpa","doi":"10.1109/NAPS.2013.6666947","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666947","url":null,"abstract":"This paper reviews a method of load forecasting specifically for predicting a building's electrical load for demand resource planning. The authors introduced a general problem formulation for building-specific load forecasting in previous works. This paper will enhance this idea with extensive forecaster performance and results based on studies done using historical building demand and thermal data collected for the main library building at Drexel University. These results demonstrate the improvement obtained by including building-specific parameters in the load forecast. Additionally, the variability of this method and how it can inform demand-side decision making is explored, particularly in allowing the manager of a controllable load to assess his or her risk and capabilities when participating in the energy market.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127562848","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.2013.6666867
Shayan Behzadirafi, H. Salehfar
Demand response (DR) is the largest underutilized reliability resource in North America. This is partly due to the non-existence of a reasonably accurate model for DR in the energy industry to allow utilities to properly apply and manage their current programs. Such models could help utilities in evaluating the impact of DR programs on their system performance and determine which programs are more favorable in view of certain conditions. In this paper a new DR model is developed that is more consistent with demand dynamics compared to previous models. Using this model, various types of common DR programs are modeled and compered on different buses of the IEEE RBTS test system with various load profiles. Results of such studies would allow for a proper planning of the available DR resources based on the system adequacy and reliability needs.
{"title":"A utility control panel for demand response planning","authors":"Shayan Behzadirafi, H. Salehfar","doi":"10.1109/NAPS.2013.6666867","DOIUrl":"https://doi.org/10.1109/NAPS.2013.6666867","url":null,"abstract":"Demand response (DR) is the largest underutilized reliability resource in North America. This is partly due to the non-existence of a reasonably accurate model for DR in the energy industry to allow utilities to properly apply and manage their current programs. Such models could help utilities in evaluating the impact of DR programs on their system performance and determine which programs are more favorable in view of certain conditions. In this paper a new DR model is developed that is more consistent with demand dynamics compared to previous models. Using this model, various types of common DR programs are modeled and compered on different buses of the IEEE RBTS test system with various load profiles. Results of such studies would allow for a proper planning of the available DR resources based on the system adequacy and reliability needs.","PeriodicalId":421943,"journal":{"name":"2013 North American Power Symposium (NAPS)","volume":"164 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":"115146919","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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