Pub Date : 2013-07-21DOI: 10.1109/PESMG.2013.6672785
R. Goldoost, Yateendra Mishra, G. Ledwich
Wide-Area Measurement Systems (WAMS) provide the opportunity of utilizing remote signals from different locations for the enhancement of power system stability. This paper focuses on the implementation of remote measurements as supplementary signals for off-center Static Var Compensators (SVCs) to damp inter-area oscillations. Combination of participation factor and residue method is used for the selection of most effective stabilizing signal. Speed difference of two generators from separate areas is identified as the best stabilizing signal and used as a supplementary signal for lead-lag controller of SVCs. Time delays of remote measurements and control signals is considered. Wide-Area Damping Controller (WADC) is deployed in Matlab Simulink framework and is tested under different operating conditions. Simulation results reveal that the proposed WADC improve the dynamic characteristic of the system significantly.
{"title":"Utilizing Wide-Area Signals for off-center SVCs to damp interarea oscillations","authors":"R. Goldoost, Yateendra Mishra, G. Ledwich","doi":"10.1109/PESMG.2013.6672785","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672785","url":null,"abstract":"Wide-Area Measurement Systems (WAMS) provide the opportunity of utilizing remote signals from different locations for the enhancement of power system stability. This paper focuses on the implementation of remote measurements as supplementary signals for off-center Static Var Compensators (SVCs) to damp inter-area oscillations. Combination of participation factor and residue method is used for the selection of most effective stabilizing signal. Speed difference of two generators from separate areas is identified as the best stabilizing signal and used as a supplementary signal for lead-lag controller of SVCs. Time delays of remote measurements and control signals is considered. Wide-Area Damping Controller (WADC) is deployed in Matlab Simulink framework and is tested under different operating conditions. Simulation results reveal that the proposed WADC improve the dynamic characteristic of the system significantly.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"68 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131978362","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672976
Nikhil Kulkarni, S. Kamalasadan
This paper proposes a new methodology based on observability gramian for optimal placement of phasor measurement units (PMUs) to achieve full observability of power system. This would enable better state measurement and state estimation of large scale power systems. An application to Nine-bus system and Two-area system proves that the proposed architecture is unique and provides better results compared to the existing method for PMU placements. This energy function approach based on observability gramian is simple in structure but perform better than existing methods for the PMU placements. The results illustrates that this method is scalable and the architecture can be implemented in modern power grid.
{"title":"Optimal placement of phasor measurement units (PMU) using a novel method based on observability gramian and full observability rank","authors":"Nikhil Kulkarni, S. Kamalasadan","doi":"10.1109/PESMG.2013.6672976","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672976","url":null,"abstract":"This paper proposes a new methodology based on observability gramian for optimal placement of phasor measurement units (PMUs) to achieve full observability of power system. This would enable better state measurement and state estimation of large scale power systems. An application to Nine-bus system and Two-area system proves that the proposed architecture is unique and provides better results compared to the existing method for PMU placements. This energy function approach based on observability gramian is simple in structure but perform better than existing methods for the PMU placements. The results illustrates that this method is scalable and the architecture can be implemented in modern power grid.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"92 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132366178","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672515
G. Comegys
Post transient power flow simulation methodology to determine the voltage stability transfer limit includes assuming switchable shunt capacitors fixed at precontingency values, unless information demonstrates shunt capacitor switching will reliably occur post contingency in a voltage stability limited load area. This paper describes an efficient simulation method to determine whether shunt capacitors will reliably switch post contingency. The method uses the power flow model with the constant MVA loads replaced with distribution equivalents that represent the distribution voltage regulating transformer, feeder impedance, and load components modeled with the static constant power, constant current, and constant impedance components. Sequential power flow solutions show the system effects of each distribution load voltage regulator tap change. Relay cut-in settings for switchable shunt capacitors can be determined.
{"title":"Post contingency shunt reactive switching in voltage stability limited load areas","authors":"G. Comegys","doi":"10.1109/PESMG.2013.6672515","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672515","url":null,"abstract":"Post transient power flow simulation methodology to determine the voltage stability transfer limit includes assuming switchable shunt capacitors fixed at precontingency values, unless information demonstrates shunt capacitor switching will reliably occur post contingency in a voltage stability limited load area. This paper describes an efficient simulation method to determine whether shunt capacitors will reliably switch post contingency. The method uses the power flow model with the constant MVA loads replaced with distribution equivalents that represent the distribution voltage regulating transformer, feeder impedance, and load components modeled with the static constant power, constant current, and constant impedance components. Sequential power flow solutions show the system effects of each distribution load voltage regulator tap change. Relay cut-in settings for switchable shunt capacitors can be determined.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130094825","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672981
Yue Zhao, R. Sevlian, R. Rajagopal, A. Goldsmith, H. Poor
An outage detection framework for power distribution networks is proposed. The framework combines the use of optimally deployed real-time power flow sensors and that of load estimates via Advanced Metering Infrastructure (AMI) or load forecasting mechanisms. The distribution network is modeled as a tree network. It is shown that the outage detection problem over the entire network can be decoupled into detection within subtrees, where within each subtree only the sensors at its root and on its boundary are used. Outage detection is then formulated as a hypothesis testing problem, for which a maximum a-posteriori probability (MAP) detector is applied. Employing the maximum misdetection probability Pmaxe as the detection performance metric, the problem of finding a set of a minimum number of sensors that keeps Pmaxe below any given probability target is formulated as a combinatorial optimization. Efficient algorithms are proposed that find the globally optimal solutions for this problem, first for line networks, and then for tree networks. Using these algorithms, optimal three-way tradeoffs between the number of sensors, the load estimate accuracy, and the outage detection performance are characterized for line and tree networks using the IEEE 123 node test feeder system.
{"title":"Outage detection in power distribution networks with optimally-deployed power flow sensors","authors":"Yue Zhao, R. Sevlian, R. Rajagopal, A. Goldsmith, H. Poor","doi":"10.1109/PESMG.2013.6672981","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672981","url":null,"abstract":"An outage detection framework for power distribution networks is proposed. The framework combines the use of optimally deployed real-time power flow sensors and that of load estimates via Advanced Metering Infrastructure (AMI) or load forecasting mechanisms. The distribution network is modeled as a tree network. It is shown that the outage detection problem over the entire network can be decoupled into detection within subtrees, where within each subtree only the sensors at its root and on its boundary are used. Outage detection is then formulated as a hypothesis testing problem, for which a maximum a-posteriori probability (MAP) detector is applied. Employing the maximum misdetection probability Pmaxe as the detection performance metric, the problem of finding a set of a minimum number of sensors that keeps Pmaxe below any given probability target is formulated as a combinatorial optimization. Efficient algorithms are proposed that find the globally optimal solutions for this problem, first for line networks, and then for tree networks. Using these algorithms, optimal three-way tradeoffs between the number of sensors, the load estimate accuracy, and the outage detection performance are characterized for line and tree networks using the IEEE 123 node test feeder system.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"116 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130210978","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672828
M. Lynch, Aonghus Shortt, R. Tol, M. O’Malley
Electricity generation investment decisions are driven by the net present value (NPV) of each generation technology. The value of each technology depends, however, not only on the characteristics of the plant in question but also on the rest of the generation portfolio. Thus the correlations between various generation technologies, as well as the characteristics of the technology itself, will drive the final generation portfolio. Monte Carlo analysis is employed to determine the distribution of returns of and correlations between various electricity generation technologies. The operational costs of each technology are arrived by means of a unit commitment and economic dispatch algorithm. The revenues of each generation unit are calculated according to the marginal cost of electricity provision at each hour; ie a perfectly competitive market is assumed, and the NPV of each generation technology is determined. Significant anti-correlation exists between the value of different technologies depending on operational considerations, while anti-correlation due to varying fuel-types does not feature in the results.
{"title":"The effect of operational considerations on the return of electricity generation investment","authors":"M. Lynch, Aonghus Shortt, R. Tol, M. O’Malley","doi":"10.1109/PESMG.2013.6672828","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672828","url":null,"abstract":"Electricity generation investment decisions are driven by the net present value (NPV) of each generation technology. The value of each technology depends, however, not only on the characteristics of the plant in question but also on the rest of the generation portfolio. Thus the correlations between various generation technologies, as well as the characteristics of the technology itself, will drive the final generation portfolio. Monte Carlo analysis is employed to determine the distribution of returns of and correlations between various electricity generation technologies. The operational costs of each technology are arrived by means of a unit commitment and economic dispatch algorithm. The revenues of each generation unit are calculated according to the marginal cost of electricity provision at each hour; ie a perfectly competitive market is assumed, and the NPV of each generation technology is determined. Significant anti-correlation exists between the value of different technologies depending on operational considerations, while anti-correlation due to varying fuel-types does not feature in the results.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134076185","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672407
Babasaheb Kharbas, M. Fozdar, H. Tiwari
This paper assesses the transmission tariff allocation and revenue reconciliation, using MW-mile and MVA-mile methods and compares them exhaustively. Since load consumers are major beneficiaries of the transmission network therefore, the transmission tariff allocations as well as the revenue reconciliation are being evaluated keeping them in consideration. The impact of power flow through a line due to MW or MVA withdrawal at a load bus has been derived using power flow analysis. The optimal parameters of power flow are determined for both actual and base loading of any circuit. The work presents methodical evaluation of transmission tariff allocation, has been performed with the three variants namely absolute, dominant and reverse. Multiple cases of the circuit utilization are simulated to the support findings more general. The tariff allocation to load buses reduces with increase in the line utilization for any variants used. Therefore, for economical tariff allocation and better revenue reconciliation, it has been recommended that, the average utilization of the network should maximum, for any variant used.
{"title":"Comparative assessment of MW-mile and MVA-mile methods of transmission tariff allocation and revenue reconciliation","authors":"Babasaheb Kharbas, M. Fozdar, H. Tiwari","doi":"10.1109/PESMG.2013.6672407","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672407","url":null,"abstract":"This paper assesses the transmission tariff allocation and revenue reconciliation, using MW-mile and MVA-mile methods and compares them exhaustively. Since load consumers are major beneficiaries of the transmission network therefore, the transmission tariff allocations as well as the revenue reconciliation are being evaluated keeping them in consideration. The impact of power flow through a line due to MW or MVA withdrawal at a load bus has been derived using power flow analysis. The optimal parameters of power flow are determined for both actual and base loading of any circuit. The work presents methodical evaluation of transmission tariff allocation, has been performed with the three variants namely absolute, dominant and reverse. Multiple cases of the circuit utilization are simulated to the support findings more general. The tariff allocation to load buses reduces with increase in the line utilization for any variants used. Therefore, for economical tariff allocation and better revenue reconciliation, it has been recommended that, the average utilization of the network should maximum, for any variant used.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"66 3","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131727453","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672197
J. Yoshida, N. Hino, Kazuhiko Takahashi, A. Nakahara, A. Komura, K. Hattori
Recently, the capacity of turbo generators used in power plants is increasing in order to keep up with the growth of electric power consumption in the world. Turbo generators are consequently experiencing problems, including increasing electromagnetic force, temperature rise of armature coils, etc., as we try to increase the armature current to keep pace with the capacity increase. One way of avoiding these problems is to increase the number of parallel armature windings for decreasing the armature current per coil. However, the circulating current in the parallel windings is generated by the difference of the linkage flux of each winding, when the number of parallel windings is not a divisor of pole numbers. In this paper, we propose a simple method to calculate the circulating current by using a magnetic circuit in the design phase. We confirmed the proposed method has a similar accuracy and faster performance in comparison with the finite element method (FEM) analysis. And then we applied the proposed method to a calculation of the circulating current in 2- and 4-pole generators and considered the factors affecting the circulating current.
{"title":"Calculation method of circulating current in parallel armature windings in consideration of magnetic circuit","authors":"J. Yoshida, N. Hino, Kazuhiko Takahashi, A. Nakahara, A. Komura, K. Hattori","doi":"10.1109/PESMG.2013.6672197","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672197","url":null,"abstract":"Recently, the capacity of turbo generators used in power plants is increasing in order to keep up with the growth of electric power consumption in the world. Turbo generators are consequently experiencing problems, including increasing electromagnetic force, temperature rise of armature coils, etc., as we try to increase the armature current to keep pace with the capacity increase. One way of avoiding these problems is to increase the number of parallel armature windings for decreasing the armature current per coil. However, the circulating current in the parallel windings is generated by the difference of the linkage flux of each winding, when the number of parallel windings is not a divisor of pole numbers. In this paper, we propose a simple method to calculate the circulating current by using a magnetic circuit in the design phase. We confirmed the proposed method has a similar accuracy and faster performance in comparison with the finite element method (FEM) analysis. And then we applied the proposed method to a calculation of the circulating current in 2- and 4-pole generators and considered the factors affecting the circulating current.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131837584","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672740
Bo Chen, S. Mashayekh, K. Butler-Purry, D. Kundur
Cyber security is becoming a major concern of smart grids, as the functionality of a smart grid is highly dependent on the cyber communication. Therefore, it is important to study the impact of cyber attacks on smart grids. This paper discusses several types of cyber attacks. Then, it presents results of studies of impacts on transient angle and transient voltage stability due to cyber attacks on two voltage support devices, SVC and STATCOM, in an 8-bus test system. The 8 bus system and voltage devices are simulated and the stability analysis is performed with DSATools™. The results showed that some modification cyber attacks can make the system angle or voltage unstable, following a physical fault in the system.
{"title":"Impact of cyber attacks on transient stability of smart grids with voltage support devices","authors":"Bo Chen, S. Mashayekh, K. Butler-Purry, D. Kundur","doi":"10.1109/PESMG.2013.6672740","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672740","url":null,"abstract":"Cyber security is becoming a major concern of smart grids, as the functionality of a smart grid is highly dependent on the cyber communication. Therefore, it is important to study the impact of cyber attacks on smart grids. This paper discusses several types of cyber attacks. Then, it presents results of studies of impacts on transient angle and transient voltage stability due to cyber attacks on two voltage support devices, SVC and STATCOM, in an 8-bus test system. The 8 bus system and voltage devices are simulated and the stability analysis is performed with DSATools™. The results showed that some modification cyber attacks can make the system angle or voltage unstable, following a physical fault in the system.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126574299","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672417
T. Wang, D. Yamashita, H. Takamori, R. Yokoyama, T. Niimura
This paper considers a day-ahead coordination problem of electricity consumptions and supplies in a community. The agents involved are three typical types of user groups and a load serving entity as the coordinator. The instrument for coordination is the dynamic pricing drawing on the consumers' responsiveness to the price. The pricing is derived by a complementarity-based model. An example demonstrates that consumers participate in enhancing energy efficiency of the community in line with their own preferences.
{"title":"A dynamic pricing model for price responsive electricity consumers in a smart community","authors":"T. Wang, D. Yamashita, H. Takamori, R. Yokoyama, T. Niimura","doi":"10.1109/PESMG.2013.6672417","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672417","url":null,"abstract":"This paper considers a day-ahead coordination problem of electricity consumptions and supplies in a community. The agents involved are three typical types of user groups and a load serving entity as the coordinator. The instrument for coordination is the dynamic pricing drawing on the consumers' responsiveness to the price. The pricing is derived by a complementarity-based model. An example demonstrates that consumers participate in enhancing energy efficiency of the community in line with their own preferences.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130704813","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 : 2013-07-21DOI: 10.1109/PESMG.2013.6672557
A. Dubey, S. Santoso, M. Cloud
This paper evaluates effects of the distribution circuit parameters on the primary and secondary circuit voltages due to EV loads. The distribution circuit parameters considered here are; location of the service transformer with respect to the substation and location of the EV loads within the secondary service. The voltage analysis is carried out using a 13.8 kV distribution feeder dominated by residential loads. The study reveals that EV charging affects the secondary voltage more significantly than the primary voltage. The short-circuit capacity even at the remote end of the primary distribution line is adequately high; hence, preventing EV loads from affecting its primary voltage. When four 240V/16A EV loads in a secondary service nearby and remote from the substation are charging, the additional voltage drops in their respective primary voltages are 0.023% and 0.13%. However, because the short-circuit capacity at the secondary service wire for both locations (remote/nearby) is significantly lower, additional voltage drops of approximately 4.5% occur in the secondary service voltages. The study also reveals that a single EV load installed on a distant load node from a service transformer leads to comparatively higher additional voltage drop (1.7%) than an EV on a nearby load node (0.81%) in the same secondary service.
{"title":"Understanding the effects of electric vehicle charging on the distribution voltages","authors":"A. Dubey, S. Santoso, M. Cloud","doi":"10.1109/PESMG.2013.6672557","DOIUrl":"https://doi.org/10.1109/PESMG.2013.6672557","url":null,"abstract":"This paper evaluates effects of the distribution circuit parameters on the primary and secondary circuit voltages due to EV loads. The distribution circuit parameters considered here are; location of the service transformer with respect to the substation and location of the EV loads within the secondary service. The voltage analysis is carried out using a 13.8 kV distribution feeder dominated by residential loads. The study reveals that EV charging affects the secondary voltage more significantly than the primary voltage. The short-circuit capacity even at the remote end of the primary distribution line is adequately high; hence, preventing EV loads from affecting its primary voltage. When four 240V/16A EV loads in a secondary service nearby and remote from the substation are charging, the additional voltage drops in their respective primary voltages are 0.023% and 0.13%. However, because the short-circuit capacity at the secondary service wire for both locations (remote/nearby) is significantly lower, additional voltage drops of approximately 4.5% occur in the secondary service voltages. The study also reveals that a single EV load installed on a distant load node from a service transformer leads to comparatively higher additional voltage drop (1.7%) than an EV on a nearby load node (0.81%) in the same secondary service.","PeriodicalId":433870,"journal":{"name":"2013 IEEE Power & Energy Society General Meeting","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2013-07-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117311973","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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