Pub Date : 2018-03-05DOI: 10.1109/JPETS.2018.2811708
F. Keyrouz
We tackle the problem of a photovoltaic (PV) controller for maximum power point tracking (MPPT) under varying insolation and shading conditions. A general-purpose adaptive maximum power controller is tailored to maintain operation of the PV system at the maximum power point while constantly avoiding local maxima for changing environmental conditions. While a variety of conventional MPPT algorithms have been designed for ideal operating situations, very few were able to deliver true maximum power under abrupt changes in sun shading. Under these dynamic changes, most MPPT techniques fail to rapidly locate the global maximum power point and are stuck at global maxima, leading therefore to inconsistent power generation and low system efficiency. In this paper, we apply Bayesian fusion, a machine learning technique otherwise used for unsupervised classification, curve detection, and image segmentation, in order to achieve global MPPT in record time. Simulation results validated with real-life experimental studies demonstrated the ameliorations of the proposed technique compared to state-of-the-art methods. Using this algorithm, the total output power of the solar system is maximized while minimizing the steady-state oscillations and the tracking time.
{"title":"Enhanced Bayesian Based MPPT Controller for PV Systems","authors":"F. Keyrouz","doi":"10.1109/JPETS.2018.2811708","DOIUrl":"https://doi.org/10.1109/JPETS.2018.2811708","url":null,"abstract":"We tackle the problem of a photovoltaic (PV) controller for maximum power point tracking (MPPT) under varying insolation and shading conditions. A general-purpose adaptive maximum power controller is tailored to maintain operation of the PV system at the maximum power point while constantly avoiding local maxima for changing environmental conditions. While a variety of conventional MPPT algorithms have been designed for ideal operating situations, very few were able to deliver true maximum power under abrupt changes in sun shading. Under these dynamic changes, most MPPT techniques fail to rapidly locate the global maximum power point and are stuck at global maxima, leading therefore to inconsistent power generation and low system efficiency. In this paper, we apply Bayesian fusion, a machine learning technique otherwise used for unsupervised classification, curve detection, and image segmentation, in order to achieve global MPPT in record time. Simulation results validated with real-life experimental studies demonstrated the ameliorations of the proposed technique compared to state-of-the-art methods. Using this algorithm, the total output power of the solar system is maximized while minimizing the steady-state oscillations and the tracking time.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121917929","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 : 2018-02-15DOI: 10.1109/JPETS.2018.2806744
K. Yamashita, H. Renner, S. Martínez Villanueva, G. Lammert, P. Aristidou, José Carvalho Martins, Ling-zhi Zhu, Luis David Pabón Ospina, T. Van Cutsem
Dynamic simulations have played an important role in assessing the power system dynamic studies. The appropriate numerical model is the key to obtain correct dynamic simulation results. In addition, the appropriate model including the selection of the individual model component (such as protections, controls, and capabilities) is different depending on the type of phenomena to be observed or examined. However, the proper selection of the model is not an easy task, especially for inverter-based generators (IBGs). Considerable industry experience concerning power system dynamic studies and the dynamics of the IBGs is required for the proper selection of the IBG model. The established CIGRE C4/C6.35/CIRED joint working group (JWG) has gathered a wide variety of experts, which fully cover the required industry experience. The JWG provides the guidance on the model selection for analyzing the phenomena, such as frequency deviation, large voltage deviation, and long-term voltage deviation, individually. This helps to reduce the computational burden, as well as it clarifies the required characteristics/functions that should be represented for the power system dynamic studies with the IBGs.
{"title":"Industrial Recommendation of Modeling of Inverter-Based Generators for Power System Dynamic Studies With Focus on Photovoltaic","authors":"K. Yamashita, H. Renner, S. Martínez Villanueva, G. Lammert, P. Aristidou, José Carvalho Martins, Ling-zhi Zhu, Luis David Pabón Ospina, T. Van Cutsem","doi":"10.1109/JPETS.2018.2806744","DOIUrl":"https://doi.org/10.1109/JPETS.2018.2806744","url":null,"abstract":"Dynamic simulations have played an important role in assessing the power system dynamic studies. The appropriate numerical model is the key to obtain correct dynamic simulation results. In addition, the appropriate model including the selection of the individual model component (such as protections, controls, and capabilities) is different depending on the type of phenomena to be observed or examined. However, the proper selection of the model is not an easy task, especially for inverter-based generators (IBGs). Considerable industry experience concerning power system dynamic studies and the dynamics of the IBGs is required for the proper selection of the IBG model. The established CIGRE C4/C6.35/CIRED joint working group (JWG) has gathered a wide variety of experts, which fully cover the required industry experience. The JWG provides the guidance on the model selection for analyzing the phenomena, such as frequency deviation, large voltage deviation, and long-term voltage deviation, individually. This helps to reduce the computational burden, as well as it clarifies the required characteristics/functions that should be represented for the power system dynamic studies with the IBGs.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"222 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-02-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133697370","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 : 2017-12-01DOI: 10.1109/JPETS.2017.2764877
William R. Binder, C. Paredis, H. Garcia
In this paper, the impact of incorporating flexibility in the design of hybrid energy systems (HES) is considered. Flexibility is introduced by considering the option to upgrade or reconfigure HES configurations at some point in the future in response to economic and technological changes that are initially unknown and uncertain. Such flexibility has been studied previously in real options analysis. We first investigate the impact of flexibility on the most preferred design alternative and its value. Simply considering the option to upgrade or reconfigure the system affects the design choice. The most preferred design alternative for a flexible system will often sacrifice some initial technical or economic performance to better take advantage of a future option. For the HES case study, the most preferred flexible design alternative is more valuable than the most preferred inflexible alternative. In other words, flexibility adds value as is reflected in an increase of the expected utility of the net present value. Second, we investigate the impact of the size of the uncertainty on the option value. Unexpectedly, for the HES case study considered here, increasing uncertainty does not strongly affect the value of flexibility. Furthermore, investigation is necessary to determine whether this relationship holds more generally or is specific to this case study.
{"title":"The Value of Flexibility in the Design of Hybrid Energy Systems: A Real Options Analysis","authors":"William R. Binder, C. Paredis, H. Garcia","doi":"10.1109/JPETS.2017.2764877","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2764877","url":null,"abstract":"In this paper, the impact of incorporating flexibility in the design of hybrid energy systems (HES) is considered. Flexibility is introduced by considering the option to upgrade or reconfigure HES configurations at some point in the future in response to economic and technological changes that are initially unknown and uncertain. Such flexibility has been studied previously in real options analysis. We first investigate the impact of flexibility on the most preferred design alternative and its value. Simply considering the option to upgrade or reconfigure the system affects the design choice. The most preferred design alternative for a flexible system will often sacrifice some initial technical or economic performance to better take advantage of a future option. For the HES case study, the most preferred flexible design alternative is more valuable than the most preferred inflexible alternative. In other words, flexibility adds value as is reflected in an increase of the expected utility of the net present value. Second, we investigate the impact of the size of the uncertainty on the option value. Unexpectedly, for the HES case study considered here, increasing uncertainty does not strongly affect the value of flexibility. Furthermore, investigation is necessary to determine whether this relationship holds more generally or is specific to this case study.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130528372","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 : 2017-10-11DOI: 10.1109/JPETS.2017.2754139
Steven Wong, G. Gaudet, Louis-Philippe Proulx
The City of Summerside, PE, Canada, has 21MW of wind capacity from which it meets almost half of its electric energy demand. At times, wind power exceeds what is needed locally. To avoid exporting the excess wind to the bulk grid at unfavourable prices, an innovative smart grid program for active control of thermal energy storage systems has been designed and implemented. On the utility-side, fibre has been wired through multiple feeders to coordinate real-time control of load. On the client-side, consumers are incentivized to install time-of-use or real-time controlled electric thermal storage or water heater units in place of oil appliances. To quantify program impacts, a system model is created for simulating many what-if scenarios using system data from 2013 to 2015. It is found that there are compelling, measurable benefits to utility and consumer finances, GHG emissions, and wind integration with little negative impact on utility operations.
{"title":"Capturing Wind With Thermal Energy Storage—Summerside’s Smart Grid Approach","authors":"Steven Wong, G. Gaudet, Louis-Philippe Proulx","doi":"10.1109/JPETS.2017.2754139","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2754139","url":null,"abstract":"The City of Summerside, PE, Canada, has 21MW of wind capacity from which it meets almost half of its electric energy demand. At times, wind power exceeds what is needed locally. To avoid exporting the excess wind to the bulk grid at unfavourable prices, an innovative smart grid program for active control of thermal energy storage systems has been designed and implemented. On the utility-side, fibre has been wired through multiple feeders to coordinate real-time control of load. On the client-side, consumers are incentivized to install time-of-use or real-time controlled electric thermal storage or water heater units in place of oil appliances. To quantify program impacts, a system model is created for simulating many what-if scenarios using system data from 2013 to 2015. It is found that there are compelling, measurable benefits to utility and consumer finances, GHG emissions, and wind integration with little negative impact on utility operations.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-10-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117229228","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 : 2017-10-05DOI: 10.1109/JPETS.2017.2749256
Hao Fu, Zhi Wu, Xiao-Ping Zhang, Joachim Brandt
This paper presents the strategic proposition for a micro virtual power plant ($mu $ VPP) to participate in the distribution level energy-reserve pool managed by a distribution system operator. A chance-constrained two-stage stochastic formulation is proposed to derive the bidding strategy for $mu $ VPP maximizing its daily profit. The stochastic nature of renewable generation and load profile of the $mu $ VPP is captured by the Monte Carlo method. The security of supply is guaranteed by controlling the loss of load probability, which is modeled as chance constraint. The numerical tests are performed on $mu $ VPPs with different penetration levels of distributed energy resource (DER) and renewable energy source (RES), where the impact of the DER and RES indexes and the impact of uncertainty levels are demonstrated. Also, the advantages of chance-constrained formulation as the means of risk-hedging are addressed. Finally, the impact of rival $mu $ VPPs on the bidding behaviors and the impact of carbon taxes on the profit are analyzed.
{"title":"Contributing to DSO’s Energy-Reserve Pool: A Chance-Constrained Two-Stage $mu $ VPP Bidding Strategy","authors":"Hao Fu, Zhi Wu, Xiao-Ping Zhang, Joachim Brandt","doi":"10.1109/JPETS.2017.2749256","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2749256","url":null,"abstract":"This paper presents the strategic proposition for a micro virtual power plant (<inline-formula> <tex-math notation=\"LaTeX\">$mu $ </tex-math></inline-formula> VPP) to participate in the distribution level energy-reserve pool managed by a distribution system operator. A chance-constrained two-stage stochastic formulation is proposed to derive the bidding strategy for <inline-formula> <tex-math notation=\"LaTeX\">$mu $ </tex-math></inline-formula> VPP maximizing its daily profit. The stochastic nature of renewable generation and load profile of the <inline-formula> <tex-math notation=\"LaTeX\">$mu $ </tex-math></inline-formula> VPP is captured by the Monte Carlo method. The security of supply is guaranteed by controlling the loss of load probability, which is modeled as chance constraint. The numerical tests are performed on <inline-formula> <tex-math notation=\"LaTeX\">$mu $ </tex-math></inline-formula> VPPs with different penetration levels of distributed energy resource (DER) and renewable energy source (RES), where the impact of the DER and RES indexes and the impact of uncertainty levels are demonstrated. Also, the advantages of chance-constrained formulation as the means of risk-hedging are addressed. Finally, the impact of rival <inline-formula> <tex-math notation=\"LaTeX\">$mu $ </tex-math></inline-formula> VPPs on the bidding behaviors and the impact of carbon taxes on the profit are analyzed.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-10-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126813640","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 : 2017-09-08DOI: 10.1109/JPETS.2017.2750479
Harsha V. Padullaparti, P. Chirapongsananurak, S. Santoso, J. Taylor
This paper proposes and compares two effective approaches to deploy low-voltage advanced voltage control devices connected at edge-of-grid to improve voltage regulation. The goal is to determine effective locations for deploying these devices to eliminate undervoltage violations during heavy loading conditions. Two commercially available devices, namely universal power flow controller and static var compensator, are studied in this paper. Practical limitations of installation space and device ratings are considered in determining the locations. The device specifications, characteristics, and modeling are also discussed in detail. The efficacy of the proposed methods is validated by simulations on a distribution circuit model of a utility with actual load profile information. Additional analysis provided on the device deployment offers insights into device placement under different application considerations. The results showed that the proposed methods are effective in mitigating undervoltage violations, reducing voltage unbalance and improving voltage regulation overall.
{"title":"Edge-of-Grid Voltage Control: Device Modeling, Strategic Placement, and Application Considerations","authors":"Harsha V. Padullaparti, P. Chirapongsananurak, S. Santoso, J. Taylor","doi":"10.1109/JPETS.2017.2750479","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2750479","url":null,"abstract":"This paper proposes and compares two effective approaches to deploy low-voltage advanced voltage control devices connected at edge-of-grid to improve voltage regulation. The goal is to determine effective locations for deploying these devices to eliminate undervoltage violations during heavy loading conditions. Two commercially available devices, namely universal power flow controller and static var compensator, are studied in this paper. Practical limitations of installation space and device ratings are considered in determining the locations. The device specifications, characteristics, and modeling are also discussed in detail. The efficacy of the proposed methods is validated by simulations on a distribution circuit model of a utility with actual load profile information. Additional analysis provided on the device deployment offers insights into device placement under different application considerations. The results showed that the proposed methods are effective in mitigating undervoltage violations, reducing voltage unbalance and improving voltage regulation overall.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128741828","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 : 2017-09-04DOI: 10.1109/JPETS.2017.2740227
Keyhaneh Janfeshan, M. Masoum
This paper proposes a two-level hierarchical supervisory control system for plug-in electric vehicles (PEVs) participating in frequency regulation in microgrids with interconnected areas. At the lower level, decentralized fuzzy logic control systems are designed for individual PEVs which locally adjust the V2G power flow rates from each vehicle to the grid according to the frequency deviation in each area and the vehicle’s current state of charge (SOC), while maintaining the SOC level above the driver’s requested SOC lower limit. At the grid level, a centralized supervisory control system is used to coordinate the injected power from generating units and PEVs based on the grid demand. Simulation results are presented and analyzed to investigate the performance of the proposed two-level system in a network consisting of three interconnected areas populated with PEVs under load disturbances and wind power fluctuations.
{"title":"Hierarchical Supervisory Control System for PEVs Participating in Frequency Regulation of Smart Grids","authors":"Keyhaneh Janfeshan, M. Masoum","doi":"10.1109/JPETS.2017.2740227","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2740227","url":null,"abstract":"This paper proposes a two-level hierarchical supervisory control system for plug-in electric vehicles (PEVs) participating in frequency regulation in microgrids with interconnected areas. At the lower level, decentralized fuzzy logic control systems are designed for individual PEVs which locally adjust the V2G power flow rates from each vehicle to the grid according to the frequency deviation in each area and the vehicle’s current state of charge (SOC), while maintaining the SOC level above the driver’s requested SOC lower limit. At the grid level, a centralized supervisory control system is used to coordinate the injected power from generating units and PEVs based on the grid demand. Simulation results are presented and analyzed to investigate the performance of the proposed two-level system in a network consisting of three interconnected areas populated with PEVs under load disturbances and wind power fluctuations.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-09-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114937462","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 : 2017-08-29DOI: 10.1109/JPETS.2017.2744559
Yong Liu, Shutang You, Yilu Liu
Renewable generations, such as variable-speed wind and photovoltaic (PV) power plants, have been expected to contribute to power systems’ frequency response. This paper studies wind and PV power plants’ frequency control in the U.S. Eastern Interconnection (EI) and Texas Interconnection (TI). Wide-area frequency measurement-validated EI and TI dynamic models and realistically projected renewable distribution information make these two case studies much more practical than previous studies based on only small test system models. A set of wind and PV power plant frequency controls, such as inertia control and governor control, are employed. This paper serves as a practical guidance on how to implement wind and PV frequency controls in a bulk power system with a high renewable penetration.
{"title":"Study of Wind and PV Frequency Control in U.S. Power Grids—EI and TI Case Studies","authors":"Yong Liu, Shutang You, Yilu Liu","doi":"10.1109/JPETS.2017.2744559","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2744559","url":null,"abstract":"Renewable generations, such as variable-speed wind and photovoltaic (PV) power plants, have been expected to contribute to power systems’ frequency response. This paper studies wind and PV power plants’ frequency control in the U.S. Eastern Interconnection (EI) and Texas Interconnection (TI). Wide-area frequency measurement-validated EI and TI dynamic models and realistically projected renewable distribution information make these two case studies much more practical than previous studies based on only small test system models. A set of wind and PV power plant frequency controls, such as inertia control and governor control, are employed. This paper serves as a practical guidance on how to implement wind and PV frequency controls in a bulk power system with a high renewable penetration.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"132 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-08-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131303114","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 : 2017-07-28DOI: 10.1109/JPETS.2017.2732360
Zhiyin Zhou, V. Dinavahi
Electromagnetic transient (EMT) simulation is one of the most complex power system studies that requires detailed modeling of the study system including all frequency-dependent and nonlinear effects. Large-scale EMT simulation is becoming commonplace due to the increasing growth and interconnection of power grids, and the need to study the impact of system events of the wide area network. To cope with enormous computational burden, the massively parallel architecture of the graphics processing unit (GPU) is exploited in this paper for large-scale EMT simulation. A fine-grained network decomposition, called shattering network decomposition, is proposed to divide the power system network exploiting its topological and physical characteristics into linear and nonlinear networks, which adapt to the unique features of the GPU-based massive thread computing system. Large-scale systems, up to 240 000 nodes, with typical components, including synchronous machines, transformers, transmission lines, and nonlinear elements, and multiple levels modular multilevel converter with up to 6144 submodules, are tested and compared with mainstream simulation software to verify the accuracy and demonstrate the speed-up improvement with respect to sequential computation.
{"title":"Fine-Grained Network Decomposition for Massively Parallel Electromagnetic Transient Simulation of Large Power Systems","authors":"Zhiyin Zhou, V. Dinavahi","doi":"10.1109/JPETS.2017.2732360","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2732360","url":null,"abstract":"Electromagnetic transient (EMT) simulation is one of the most complex power system studies that requires detailed modeling of the study system including all frequency-dependent and nonlinear effects. Large-scale EMT simulation is becoming commonplace due to the increasing growth and interconnection of power grids, and the need to study the impact of system events of the wide area network. To cope with enormous computational burden, the massively parallel architecture of the graphics processing unit (GPU) is exploited in this paper for large-scale EMT simulation. A fine-grained network decomposition, called shattering network decomposition, is proposed to divide the power system network exploiting its topological and physical characteristics into linear and nonlinear networks, which adapt to the unique features of the GPU-based massive thread computing system. Large-scale systems, up to 240 000 nodes, with typical components, including synchronous machines, transformers, transmission lines, and nonlinear elements, and multiple levels modular multilevel converter with up to 6144 submodules, are tested and compared with mainstream simulation software to verify the accuracy and demonstrate the speed-up improvement with respect to sequential computation.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"180 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-07-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115723252","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 : 2017-03-27DOI: 10.1109/JPETS.2017.2688020
M. Esmaili, M. Ghamsari-Yazdel
In this paper, a channel-oriented method is proposed for optimal placement of phasor measurement units (PMUs) with the objective function of explicit cost of PMUs and their channels. PMU measurement channels are treated as optimization binary variables, and a PMU installed at a bus assigns channels to observe its adjacent buses only if it is economically justified. Since power system substations have different reliability levels, in order to enhance reliability of the measurement system, PMUs and their channels are encouraged to be employed at more reliable buses and branches. In addition, in order to monitor fragile areas of power systems for prevention of voltage collapse, PMUs and their channels are assigned to observe buses with vulnerable voltage stability status. Furthermore, in order for a more economical and practical solution, the most probable contingencies are identified using the Monte Carlo simulation to be incorporated in the problem. Also, PMU failures and branch outages are modeled with a technique resulting in a less cost than existing methods. Channel failure is also modeled as a new type of contingency. The efficiency of the proposed method is evaluated by testing it on standard and practical large-scale test systems.
{"title":"Voltage Stability-Constrained Optimal Simultaneous Placement of PMUs and Channels Enhancing Measurement Reliability and Redundancy","authors":"M. Esmaili, M. Ghamsari-Yazdel","doi":"10.1109/JPETS.2017.2688020","DOIUrl":"https://doi.org/10.1109/JPETS.2017.2688020","url":null,"abstract":"In this paper, a channel-oriented method is proposed for optimal placement of phasor measurement units (PMUs) with the objective function of explicit cost of PMUs and their channels. PMU measurement channels are treated as optimization binary variables, and a PMU installed at a bus assigns channels to observe its adjacent buses only if it is economically justified. Since power system substations have different reliability levels, in order to enhance reliability of the measurement system, PMUs and their channels are encouraged to be employed at more reliable buses and branches. In addition, in order to monitor fragile areas of power systems for prevention of voltage collapse, PMUs and their channels are assigned to observe buses with vulnerable voltage stability status. Furthermore, in order for a more economical and practical solution, the most probable contingencies are identified using the Monte Carlo simulation to be incorporated in the problem. Also, PMU failures and branch outages are modeled with a technique resulting in a less cost than existing methods. Channel failure is also modeled as a new type of contingency. The efficiency of the proposed method is evaluated by testing it on standard and practical large-scale test systems.","PeriodicalId":170601,"journal":{"name":"IEEE Power and Energy Technology Systems Journal","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2017-03-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129219712","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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