Pub Date : 2018-03-01DOI: 10.1109/CPRE.2018.8349790
M. Benitez, Joe Xavier, Karl Smith, D. Minshall
This paper, based on real world event data, introduces a state of the art directional element that has been proven to prevent many of the commonly reported mis-operations caused by traditional directional elements. Such examples include wind farm collector circuits where there have been a significant number of documented occurrences of false trips due to leading power factor loads caused by dynamic VAR controllers. To mitigate, several ‘work around’ solutions have been devised and published. These include creative yet cumbersome approaches that use load encroachment and reverse power functions, both of which have limitations since they were never intended for that purpose. There are also challenges using traditional directional elements for situations where the fault current is capacitive. Such examples include ground fault current in networks that can be operated as either isolated or compensated. All of these challenges can be overcome using an ‘easy to set’ flexible directional element design that allows for the phase angle operating characteristics to be extended or retracted through its minimum/maximum forward and reverse angle settings. For quick and efficient evaluation of study cases, specific directional element settings have been modeled in protection design software as they appear in the relay to ensure the relay will respond securely and reliably for all operating conditions (grounding methods), system variables and fault scenarios encountered. The paper provides test data and oscillography reports from event (COMTRADE) files to validate the directional element's performance.
{"title":"Directional element design for protecting circuits with capacitive fault and load currents","authors":"M. Benitez, Joe Xavier, Karl Smith, D. Minshall","doi":"10.1109/CPRE.2018.8349790","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349790","url":null,"abstract":"This paper, based on real world event data, introduces a state of the art directional element that has been proven to prevent many of the commonly reported mis-operations caused by traditional directional elements. Such examples include wind farm collector circuits where there have been a significant number of documented occurrences of false trips due to leading power factor loads caused by dynamic VAR controllers. To mitigate, several ‘work around’ solutions have been devised and published. These include creative yet cumbersome approaches that use load encroachment and reverse power functions, both of which have limitations since they were never intended for that purpose. There are also challenges using traditional directional elements for situations where the fault current is capacitive. Such examples include ground fault current in networks that can be operated as either isolated or compensated. All of these challenges can be overcome using an ‘easy to set’ flexible directional element design that allows for the phase angle operating characteristics to be extended or retracted through its minimum/maximum forward and reverse angle settings. For quick and efficient evaluation of study cases, specific directional element settings have been modeled in protection design software as they appear in the relay to ensure the relay will respond securely and reliably for all operating conditions (grounding methods), system variables and fault scenarios encountered. The paper provides test data and oscillography reports from event (COMTRADE) files to validate the directional element's performance.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"305 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116219683","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349796
Monir Hossain, I. Leevongwat, P. Rastgoufard
One of the latest fault discrimination algorithms used to supervise bus differential protection schemes, is Alienation Coefficient Algorithm (ACA). ACA uses alienation coefficient of current signals during first one-eighth cycle after fault inception to discriminate between internal and external faults. Therefore, the performance of ACA highly depends on fault detection speed. This paper examines the performance of ACA for currently used fault detection technique and the results reveal that ACA fails to detect external fault in case of fast current transformer (CT) saturation. This paper also proposes an alternative fault detection technique for ACA and presents a simulation study to validate the performance. Documented results show that ACA with the new fault detection technique performs better for fast CT saturation during close-in external faults.
{"title":"Fast fault detection challenge for alienation coefficient based bus fault discriminator","authors":"Monir Hossain, I. Leevongwat, P. Rastgoufard","doi":"10.1109/CPRE.2018.8349796","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349796","url":null,"abstract":"One of the latest fault discrimination algorithms used to supervise bus differential protection schemes, is Alienation Coefficient Algorithm (ACA). ACA uses alienation coefficient of current signals during first one-eighth cycle after fault inception to discriminate between internal and external faults. Therefore, the performance of ACA highly depends on fault detection speed. This paper examines the performance of ACA for currently used fault detection technique and the results reveal that ACA fails to detect external fault in case of fast current transformer (CT) saturation. This paper also proposes an alternative fault detection technique for ACA and presents a simulation study to validate the performance. Documented results show that ACA with the new fault detection technique performs better for fast CT saturation during close-in external faults.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"167 5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122977876","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349777
A. Salvador, Simón Rodríguez
Smart automation technologies aim to improve efficiency and productivity in several areas. Specifically for power system disturbances, automation can greatly reduce capital and labor costs by not only reducing travel time to substations to collect event data but streamline event response processes. A key concept in fully achieving this type of automation involves solutions that not only support automated fault data collection from IEDs, but automated fault data analysis as well. The fault data collection was a challenging feat for a utility from the Dominican Republic where their power system consisted of a breadth of multi-vendor devices such as SEL, GE, ABB, Siemens, ERLPhase, EMAX, APP, and Qualitrol. This presentation details the integration of three multi-vendor solutions that provided the utility with a complete vendor agnostic system to achieve the following benefits: • A centralized IED management solution that supports automatic multi-vendor event data retrieval • Email notification, version control and archival of ollected records • Secure authentication to a web-based interface to access and conduct in-depth post-event analysis • Automatic conversion of proprietary event record formats to open standards such as COMTRADE • Automatic event record analysis that summarizes disturbances and calculates Takagi, Modified Takagi, and Novosel fault location • Ability to integrate with other business intelligence systems such as Enterprise Resource Planning systems like SAP to historians from OSIsoft, Schneider Wonderware eDNA, and Automsoft that can be utilized for breaker analytics and trending.
{"title":"Automatic multi-vendor IED fault data collection and analysis solution","authors":"A. Salvador, Simón Rodríguez","doi":"10.1109/CPRE.2018.8349777","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349777","url":null,"abstract":"Smart automation technologies aim to improve efficiency and productivity in several areas. Specifically for power system disturbances, automation can greatly reduce capital and labor costs by not only reducing travel time to substations to collect event data but streamline event response processes. A key concept in fully achieving this type of automation involves solutions that not only support automated fault data collection from IEDs, but automated fault data analysis as well. The fault data collection was a challenging feat for a utility from the Dominican Republic where their power system consisted of a breadth of multi-vendor devices such as SEL, GE, ABB, Siemens, ERLPhase, EMAX, APP, and Qualitrol. This presentation details the integration of three multi-vendor solutions that provided the utility with a complete vendor agnostic system to achieve the following benefits: • A centralized IED management solution that supports automatic multi-vendor event data retrieval • Email notification, version control and archival of ollected records • Secure authentication to a web-based interface to access and conduct in-depth post-event analysis • Automatic conversion of proprietary event record formats to open standards such as COMTRADE • Automatic event record analysis that summarizes disturbances and calculates Takagi, Modified Takagi, and Novosel fault location • Ability to integrate with other business intelligence systems such as Enterprise Resource Planning systems like SAP to historians from OSIsoft, Schneider Wonderware eDNA, and Automsoft that can be utilized for breaker analytics and trending.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116152416","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349794
Laura Rogers, Tom Bartman, B. Rowland
Extending reliable and dependable communications for protection and control applications beyond the substation fence to additional sites and field devices can sometimes be a challenging task. Uneven terrain, distance, or other factors can make running cable difficult or impossible. In some cases, wireless communication is a cost-effective and practical alternative to pulling cable. Radios have proven to be an effective means of extending communications for supervisory control and data acquisition (SCADA) and engineering access, as well as for critical protection and control applications using serial communications. Low-latency Ethernet protocols like Generic Object-Oriented Substation Event (GOOSE) are becoming popular for high-speed, point-to-multipoint signaling protection and control applications. Radios used in protection and control should be evaluated for the specific application for which they are intended. This paper examines the application of GOOSE over Ethernet radios and the associated challenges. The paper shares results from a real-world implementation, including results from GOOSE latency tests for protection and control applications.
{"title":"Expanding protection and control communications networks with wireless radio links","authors":"Laura Rogers, Tom Bartman, B. Rowland","doi":"10.1109/CPRE.2018.8349794","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349794","url":null,"abstract":"Extending reliable and dependable communications for protection and control applications beyond the substation fence to additional sites and field devices can sometimes be a challenging task. Uneven terrain, distance, or other factors can make running cable difficult or impossible. In some cases, wireless communication is a cost-effective and practical alternative to pulling cable. Radios have proven to be an effective means of extending communications for supervisory control and data acquisition (SCADA) and engineering access, as well as for critical protection and control applications using serial communications. Low-latency Ethernet protocols like Generic Object-Oriented Substation Event (GOOSE) are becoming popular for high-speed, point-to-multipoint signaling protection and control applications. Radios used in protection and control should be evaluated for the specific application for which they are intended. This paper examines the application of GOOSE over Ethernet radios and the associated challenges. The paper shares results from a real-world implementation, including results from GOOSE latency tests for protection and control applications.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130598292","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349824
Robert Wang, C. Pritchard, S. Cooper, P. Hoffman, John Hart, Erich Keller, Bob Westphal
As part of a proof of concept for future distribution schemes, Duke Energy has completed the second phase of a project on a distribution system feeder for the Raleigh Central Business District underground system. The feeder consists of two radially operated 12kV underground circuits. Solid dielectric vacuum switches with integrated visible break were installed in nine network vaults during phase 1 of the project. To achieve high electric service availability for the central business district, a communications-assisted, high-speed protection system was developed. Its unique communication architecture utilizes IEC 61850 GOOSE messaging and serial based communications in parallel, enabling the relays to interrupt, isolate and restore power via the nine vault switches once the project is completed. An important aspect of the acceptance test was testing the protection and control scheme. In this scheme 18 relays and two communication technologies are working together as a system. Due to the interdependency of the network protection system and its components, it was critical to test every component as part of a system. Multiple acceptance criteria were defined by describing the initial state of the power system, the incident fault and the expected system state after the interruption, isolation and restoration of the system had taken place. The acceptance criteria were directly configured into the test environment by using a power system model that calculated the test set outputs. A single PC controlled a total of nine test sets, simultaneously injecting all signals according to the selected test case. A requirement for placing the protection system into live operation after installation was the completion of field site acceptance testing. Site acceptance testing included testing the individual switching nodes during commissioning followed by a series of simultaneous network system response testing involving all of the switches. This paper discusses the network installation, site acceptance test planning, testing contingencies discovered during planning, and the outcomes of the site acceptance testing.
{"title":"Site acceptance testing of a Duke Energy automation project utilizing a simulation based test approach","authors":"Robert Wang, C. Pritchard, S. Cooper, P. Hoffman, John Hart, Erich Keller, Bob Westphal","doi":"10.1109/CPRE.2018.8349824","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349824","url":null,"abstract":"As part of a proof of concept for future distribution schemes, Duke Energy has completed the second phase of a project on a distribution system feeder for the Raleigh Central Business District underground system. The feeder consists of two radially operated 12kV underground circuits. Solid dielectric vacuum switches with integrated visible break were installed in nine network vaults during phase 1 of the project. To achieve high electric service availability for the central business district, a communications-assisted, high-speed protection system was developed. Its unique communication architecture utilizes IEC 61850 GOOSE messaging and serial based communications in parallel, enabling the relays to interrupt, isolate and restore power via the nine vault switches once the project is completed. An important aspect of the acceptance test was testing the protection and control scheme. In this scheme 18 relays and two communication technologies are working together as a system. Due to the interdependency of the network protection system and its components, it was critical to test every component as part of a system. Multiple acceptance criteria were defined by describing the initial state of the power system, the incident fault and the expected system state after the interruption, isolation and restoration of the system had taken place. The acceptance criteria were directly configured into the test environment by using a power system model that calculated the test set outputs. A single PC controlled a total of nine test sets, simultaneously injecting all signals according to the selected test case. A requirement for placing the protection system into live operation after installation was the completion of field site acceptance testing. Site acceptance testing included testing the individual switching nodes during commissioning followed by a series of simultaneous network system response testing involving all of the switches. This paper discusses the network installation, site acceptance test planning, testing contingencies discovered during planning, and the outcomes of the site acceptance testing.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124945381","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349773
Matthew Manley, Tony Limon
NERC PRC standards have been implemented as a comprehensive plan to increase utility reliability in response to the 2003 Northeast United States blackout. The intent of PRC-019 is to verify regulating controls, limiters, equipment capabilities, and protection controls installed at generation facilities are appropriately coordinated so as to not exacerbate adverse power grid conditions during a system disturbance. PRC-019 provides fairly explicit guidance for what is expected to show compliance for synchronous generator facilities. PRC-019 does not contain explicit guidance on how to show compliance for asynchronous or distributed generation resources. This paper describes the approach, challenges, and lessons learned from performing NERC PRC-019 studies of both typical synchronous and asynchronous generators. Both the commonalities and variances of synchronous and asynchronous generation facilities are highlighted to provide the connecting link between what is explicitly stated in PRC-019 requirements and what is commonly expected by compliance authorities. While the interpretation for what is necessary to demonstrate compliance can vary between reliability coordinators; this paper provides examples of proven compliance documentation for a recent PRC-019 wind farm study.
{"title":"An introduction to completing a NERC PRC-019 study for traditional and distributed generation sources","authors":"Matthew Manley, Tony Limon","doi":"10.1109/CPRE.2018.8349773","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349773","url":null,"abstract":"NERC PRC standards have been implemented as a comprehensive plan to increase utility reliability in response to the 2003 Northeast United States blackout. The intent of PRC-019 is to verify regulating controls, limiters, equipment capabilities, and protection controls installed at generation facilities are appropriately coordinated so as to not exacerbate adverse power grid conditions during a system disturbance. PRC-019 provides fairly explicit guidance for what is expected to show compliance for synchronous generator facilities. PRC-019 does not contain explicit guidance on how to show compliance for asynchronous or distributed generation resources. This paper describes the approach, challenges, and lessons learned from performing NERC PRC-019 studies of both typical synchronous and asynchronous generators. Both the commonalities and variances of synchronous and asynchronous generation facilities are highlighted to provide the connecting link between what is explicitly stated in PRC-019 requirements and what is commonly expected by compliance authorities. While the interpretation for what is necessary to demonstrate compliance can vary between reliability coordinators; this paper provides examples of proven compliance documentation for a recent PRC-019 wind farm study.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124974769","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349834
William C. Edwards, S. Manson
This paper explains how microprocessor-based protective relays are used to provide both control and protection functions for small microgrids. Features described in the paper include automatic islanding, reconnection to the electric power system, dispatch of distributed generation, compliance to IEEE specifications, load shedding, volt/VAR control, and frequency and power control at the point of interface.
{"title":"Using protective relays for microgrid controls","authors":"William C. Edwards, S. Manson","doi":"10.1109/CPRE.2018.8349834","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349834","url":null,"abstract":"This paper explains how microprocessor-based protective relays are used to provide both control and protection functions for small microgrids. Features described in the paper include automatic islanding, reconnection to the electric power system, dispatch of distributed generation, compliance to IEEE specifications, load shedding, volt/VAR control, and frequency and power control at the point of interface.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125831400","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349815
B. Cook, M. Thompson, K. Garg, M. Malichkar
San Diego Gas & Electric (SDG&E) initiated a project to add two parallel 400 MVA (+31.3° to −80.1°) phase-shifting transformers (PSTs) at a 230 kV interconnection substation. California ISO (CAISO) proposed the PST project to provide flow control between SDG&E and Comisión Federal de Electricidad (CFE) 230 kV systems during critical N-1 or N-1-1 500 kV line contingencies. With the need to integrate renewable generation, many utilities are using PSTs to manage the grid (e.g., American Electric Power [AEP] has eight PSTs in their system). SDG&E is presently reviewing the need for additional PST projects. The authors collaborated to address the unique challenges of parallel PST protection and control for this wide-ranging PST application, including implementation of CAISO control and automatic contingency-based tap-changer runback. This paper discusses SDG&E's process to execute the project, including settings development, simulation, lab and field testing, and in-service testing. The authors discuss oscillography analysis used during lab testing, energization, and loading to verify the overall design and programming.
{"title":"Phase-shifting transformer control and protection settings verification","authors":"B. Cook, M. Thompson, K. Garg, M. Malichkar","doi":"10.1109/CPRE.2018.8349815","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349815","url":null,"abstract":"San Diego Gas & Electric (SDG&E) initiated a project to add two parallel 400 MVA (+31.3° to −80.1°) phase-shifting transformers (PSTs) at a 230 kV interconnection substation. California ISO (CAISO) proposed the PST project to provide flow control between SDG&E and Comisión Federal de Electricidad (CFE) 230 kV systems during critical N-1 or N-1-1 500 kV line contingencies. With the need to integrate renewable generation, many utilities are using PSTs to manage the grid (e.g., American Electric Power [AEP] has eight PSTs in their system). SDG&E is presently reviewing the need for additional PST projects. The authors collaborated to address the unique challenges of parallel PST protection and control for this wide-ranging PST application, including implementation of CAISO control and automatic contingency-based tap-changer runback. This paper discusses SDG&E's process to execute the project, including settings development, simulation, lab and field testing, and in-service testing. The authors discuss oscillography analysis used during lab testing, energization, and loading to verify the overall design and programming.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"PC-25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126675732","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 : 2018-03-01DOI: 10.1109/CPRE.2018.8349808
Tom Ernst, Ken Farison
How does a motor thermal overload element know when the motor has used 100% of its thermal capacity? In this paper the authors explore the answer to this question as it relates to the proper selection of the thermal overload curve. We also explore the coordination relationship between the overload curve and upstream time-overcurrent protective devices to better understand the 3-dimensional nature of the thermal over-load curve. Several real-life examples are used to illustrate the issues, challenges and consequences of curve selection.
{"title":"Motor thermal capacity used — How does the relay know when I've reached 100%?","authors":"Tom Ernst, Ken Farison","doi":"10.1109/CPRE.2018.8349808","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349808","url":null,"abstract":"How does a motor thermal overload element know when the motor has used 100% of its thermal capacity? In this paper the authors explore the answer to this question as it relates to the proper selection of the thermal overload curve. We also explore the coordination relationship between the overload curve and upstream time-overcurrent protective devices to better understand the 3-dimensional nature of the thermal over-load curve. Several real-life examples are used to illustrate the issues, challenges and consequences of curve selection.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"117 1-2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132570373","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 : 2018-03-01DOI: 10.1109/cpre.2018.8349770
S. Costa, Terrence Smith, Christopher White
Critical circuit breakers are the objects of careful preventive maintenance programs where utilities require reliable operation. The ability of the asset to operate when needed is a critical component of equipment protection from further damage. These maintenance programs can be very expensive with more frequent and comprehensive tests and inspections and failure of the breaker to operate when needed can cause significant collateral damage. In many cases this becomes a burden on the operation and maintenance budgets as well as time consuming for the engineer to successfully manage. High voltage circuit breakers are valuable assets and monitoring of these assets enables utilities to proactively maintain equipment. This paper will review the different aspects of circuit breaker monitoring such as mechanical integrity, SF6 gas levels, contact wear, control electronics and stored energy system.
{"title":"Advantages of comprehensive monitoring for critical circuit breakers","authors":"S. Costa, Terrence Smith, Christopher White","doi":"10.1109/cpre.2018.8349770","DOIUrl":"https://doi.org/10.1109/cpre.2018.8349770","url":null,"abstract":"Critical circuit breakers are the objects of careful preventive maintenance programs where utilities require reliable operation. The ability of the asset to operate when needed is a critical component of equipment protection from further damage. These maintenance programs can be very expensive with more frequent and comprehensive tests and inspections and failure of the breaker to operate when needed can cause significant collateral damage. In many cases this becomes a burden on the operation and maintenance budgets as well as time consuming for the engineer to successfully manage. High voltage circuit breakers are valuable assets and monitoring of these assets enables utilities to proactively maintain equipment. This paper will review the different aspects of circuit breaker monitoring such as mechanical integrity, SF6 gas levels, contact wear, control electronics and stored energy system.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116671155","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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