Pub Date : 2018-03-01DOI: 10.1109/CPRE.2018.8349819
Dinesh Baradi, Joe Xavier
Users of protective relays apply these devices specific to their needs and applications. In order to perform this task, schemes are developed and applied to protective relays in the form of relay logic. These methods vary depending on the age of the relay as well as the manufacturer's standard of programming. This paper is developed as a tutorial to examine the methods used to develop relay logic schemes. It will look at past methods of discrete contact/switch logic as well as the methods used today such as Boolean and IEC 61131-3 mapping. Logical mapping methods and simplification are considered. A comparison of the various programming methods will ultimately educate the reader as to the tools available to perform the development task. Relay-to-relay logical bit transfer is a method by which automated and protection specific schemes are developed. An examination of these methods is performed as well. Testing relay logic is an additional subject that is examined. Critical to performance of any relay logic scheme are the comprehensive testing methods used to prove the functionality performs according to design intentions. The goal of the paper is to provide a user of any type of relay, electromechanical, solid state or microprocessor, the knowledge of how to properly develop logic schemes and the proper testing methods associated with these schemes.
{"title":"Relay logic programming explained","authors":"Dinesh Baradi, Joe Xavier","doi":"10.1109/CPRE.2018.8349819","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349819","url":null,"abstract":"Users of protective relays apply these devices specific to their needs and applications. In order to perform this task, schemes are developed and applied to protective relays in the form of relay logic. These methods vary depending on the age of the relay as well as the manufacturer's standard of programming. This paper is developed as a tutorial to examine the methods used to develop relay logic schemes. It will look at past methods of discrete contact/switch logic as well as the methods used today such as Boolean and IEC 61131-3 mapping. Logical mapping methods and simplification are considered. A comparison of the various programming methods will ultimately educate the reader as to the tools available to perform the development task. Relay-to-relay logical bit transfer is a method by which automated and protection specific schemes are developed. An examination of these methods is performed as well. Testing relay logic is an additional subject that is examined. Critical to performance of any relay logic scheme are the comprehensive testing methods used to prove the functionality performs according to design intentions. The goal of the paper is to provide a user of any type of relay, electromechanical, solid state or microprocessor, the knowledge of how to properly develop logic schemes and the proper testing methods associated with these schemes.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"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":"131303101","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.2018.8349823
Eduardo Colmenares
Simplicity is one of the key elements of a good Relay Protection System design together with Reliability, Selectivity and Speed. However, with the evolution of the protection relays, protection schemes have evolved in a way that they can be described to be anything but simple. This paper analyzes the evolution of protection system design and the advantages and disadvantages of the current approach.
{"title":"Simplicity in relay protection system design; is it still a valid element?","authors":"Eduardo Colmenares","doi":"10.1109/CPRE.2018.8349823","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349823","url":null,"abstract":"Simplicity is one of the key elements of a good Relay Protection System design together with Reliability, Selectivity and Speed. However, with the evolution of the protection relays, protection schemes have evolved in a way that they can be described to be anything but simple. This paper analyzes the evolution of protection system design and the advantages and disadvantages of the current approach.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"49 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":"117159697","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.2018.8349836
R. B. Kazimier
The proliferation of Distributed Energy Resources (DER) has led to an increased number of utility interconnection requests. Utility interconnection agreements can be confusing to DER developers and are often misunderstood, not only in scope, but in spirit. In the case of co-ops and municipalities without a full engineering staff, these documents may not be well-understood internally. Still, once established, these guidelines must be followed or negotiated in an intelligent manner. One topic that is routinely questioned by DER developers and frequently required by the interconnection agreement is Directional Power (ANSI device number 32) protection. Therefore, it begs the question, “Who has the power?”
{"title":"Who has the 32?","authors":"R. B. Kazimier","doi":"10.1109/cpre.2018.8349836","DOIUrl":"https://doi.org/10.1109/cpre.2018.8349836","url":null,"abstract":"The proliferation of Distributed Energy Resources (DER) has led to an increased number of utility interconnection requests. Utility interconnection agreements can be confusing to DER developers and are often misunderstood, not only in scope, but in spirit. In the case of co-ops and municipalities without a full engineering staff, these documents may not be well-understood internally. Still, once established, these guidelines must be followed or negotiated in an intelligent manner. One topic that is routinely questioned by DER developers and frequently required by the interconnection agreement is Directional Power (ANSI device number 32) protection. Therefore, it begs the question, “Who has the power?”","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"51 3 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":"130198545","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.2018.8349804
V. Madani, Yujie Yin, Yong Fu, S. Chidurala, Xiangmin Gao, J. Sykes
Microprocessor based protective relays have been widely used to provide many benefits including system performance, monitoring, technology and compliance. Recently utilities have started to replace earlier generation of microprocessor-based protective devices with modern protection and control Intelligent Electronic Devices (IEDs). The upgrade is partially due to increased failure rates of the earlier generation of devices, as well as to benefit from the new functionalities including system integration, Synchrophasor applications, IEC61850 communication and cyber security. The process to upgrade numerical relays is quite different and is more complex than upgrading of traditional electromechanical or solid-state relays with a functionally equivalent device. In addition to the hardware replacement, functions related to cyber security, protection, automation and control, event recording and digital communications must be considered. The protection and control system practitioners need to manage the asset and set the strategies, with inputs from other stakeholders across lines of business as well as externally with manufacturers, regulators, consultants or even neighboring utilities because the selection and application criteria have expanded with the introduction of new features and functions. This paper discusses the existing asset management, performance, replacement, and technology considerations based on utility practices at the T&D level. Strategies and practical concerns including hardware and firmware compatibility, protection settings, or other features such as automation or other possible functions integrated and associated set point considerations, as well as commissioning and testing when upgrading or replacing a microprocessor device are described in detail. This paper will assist utility or industry electrical engineers that have an on-going relay upgrade project or are planning to upgrade their aging microprocessor relays in lessons learned from some major power companies in North America.
{"title":"Life cycle experiences with micro-processor based relays and roadmap to sustainability","authors":"V. Madani, Yujie Yin, Yong Fu, S. Chidurala, Xiangmin Gao, J. Sykes","doi":"10.1109/CPRE.2018.8349804","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349804","url":null,"abstract":"Microprocessor based protective relays have been widely used to provide many benefits including system performance, monitoring, technology and compliance. Recently utilities have started to replace earlier generation of microprocessor-based protective devices with modern protection and control Intelligent Electronic Devices (IEDs). The upgrade is partially due to increased failure rates of the earlier generation of devices, as well as to benefit from the new functionalities including system integration, Synchrophasor applications, IEC61850 communication and cyber security. The process to upgrade numerical relays is quite different and is more complex than upgrading of traditional electromechanical or solid-state relays with a functionally equivalent device. In addition to the hardware replacement, functions related to cyber security, protection, automation and control, event recording and digital communications must be considered. The protection and control system practitioners need to manage the asset and set the strategies, with inputs from other stakeholders across lines of business as well as externally with manufacturers, regulators, consultants or even neighboring utilities because the selection and application criteria have expanded with the introduction of new features and functions. This paper discusses the existing asset management, performance, replacement, and technology considerations based on utility practices at the T&D level. Strategies and practical concerns including hardware and firmware compatibility, protection settings, or other features such as automation or other possible functions integrated and associated set point considerations, as well as commissioning and testing when upgrading or replacing a microprocessor device are described in detail. This paper will assist utility or industry electrical engineers that have an on-going relay upgrade project or are planning to upgrade their aging microprocessor relays in lessons learned from some major power companies in North America.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"157 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":"132814838","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.2018.8349780
Terrence Smith, Christine Crites
Time synchronization of protective LEDs can be critical for analyzing events, compensating for channel asymmetry in distance protection and streaming synchro-phasors. Satellite-based IRIG-B time can be used to provide a precise time signal but still has limitations. This paper examines some of the limitations of IRIG-B as a time source and discusses solutions to many issues as well as alternate timing signals. Case studies examined include: time synchronization across a large industrial facility using IEEE 1588 with multiple vintages of devices, distance limits of IRIG-B signals and time offset coordination for local times.
{"title":"Case studies in facility-wide time synchronization","authors":"Terrence Smith, Christine Crites","doi":"10.1109/CPRE.2018.8349780","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349780","url":null,"abstract":"Time synchronization of protective LEDs can be critical for analyzing events, compensating for channel asymmetry in distance protection and streaming synchro-phasors. Satellite-based IRIG-B time can be used to provide a precise time signal but still has limitations. This paper examines some of the limitations of IRIG-B as a time source and discusses solutions to many issues as well as alternate timing signals. Case studies examined include: time synchronization across a large industrial facility using IEEE 1588 with multiple vintages of devices, distance limits of IRIG-B signals and time offset coordination for local times.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"2 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":"114069769","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.2018.8349785
Brian Waldron, Bryan Fazzari
As protection intelligent electronic devices (IEDs) have evolved, their communications and reporting capabilities have become more advanced. Protective relays can store, with high-accuracy time stamps, not only records of protection elements pertinent to the operation of the relay itself but also the arrival and departure of high-speed incoming and outgoing data that are used to coordinate other devices' protection algorithms. All the data can be sifted through and analyzed to locate maintenance indicators and to correct undesirable behaviors before a larger problem is created within the system. Some communications testing requirements are already outlined in NERC PRC-005-02 — Protection System Maintenance. This paper investigates how, by using the communications and reporting capabilities of these modern IEDs, a continuously running monitoring system can quickly identify and report signal transmission timing or delivery degradation in a protection system using high-speed peer-to-peer signals. This monitoring system functions regardless of protection scheme protocol selection or network design variations, and it provides immediately actionable data by delivering reports that indicate the exact contact or internal bit in a specific relay or set of relays involved in the problem.
{"title":"Continuous automated analysis of protection scheme communications leads to improved reliability and performance","authors":"Brian Waldron, Bryan Fazzari","doi":"10.1109/CPRE.2018.8349785","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349785","url":null,"abstract":"As protection intelligent electronic devices (IEDs) have evolved, their communications and reporting capabilities have become more advanced. Protective relays can store, with high-accuracy time stamps, not only records of protection elements pertinent to the operation of the relay itself but also the arrival and departure of high-speed incoming and outgoing data that are used to coordinate other devices' protection algorithms. All the data can be sifted through and analyzed to locate maintenance indicators and to correct undesirable behaviors before a larger problem is created within the system. Some communications testing requirements are already outlined in NERC PRC-005-02 — Protection System Maintenance. This paper investigates how, by using the communications and reporting capabilities of these modern IEDs, a continuously running monitoring system can quickly identify and report signal transmission timing or delivery degradation in a protection system using high-speed peer-to-peer signals. This monitoring system functions regardless of protection scheme protocol selection or network design variations, and it provides immediately actionable data by delivering reports that indicate the exact contact or internal bit in a specific relay or set of relays involved in the problem.","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":"127890354","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.2018.8349818
Josh LaBlanc, M. Thompson
Minnesota Power is assessing ways to improve redundancy of protection systems for compliance with North American Electric Reliability Corporation (NERC) Standard TPL-002 — System Performance Following Loss of a Single BES Element. Historically, buses rarely included dual differential systems and relied on time-delayed remote backup to cover a failure of the bus protection system. Today's highly stressed power system is less tolerant of delayed fault clearing with loss of multiple branch circuits for a single-contingency failure. Therefore, determining ways to achieve dual high-speed protection systems for buses has become important. Historically, Minnesota Power has used high-impedance bus differential (87Z) protection systems. This principle has many advantages, including high performance, virtually no limit to the number of branch circuits, simple current transformer (CT) wiring, and simple settings calculations. This paper examines various options for obtaining redundancy. The paper includes an emphasis on examining various methods of applying dual 87Z relays in an existing bus differential CT circuit.
{"title":"Redundant bus protection using high-impedance differential relays","authors":"Josh LaBlanc, M. Thompson","doi":"10.1109/CPRE.2018.8349818","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349818","url":null,"abstract":"Minnesota Power is assessing ways to improve redundancy of protection systems for compliance with North American Electric Reliability Corporation (NERC) Standard TPL-002 — System Performance Following Loss of a Single BES Element. Historically, buses rarely included dual differential systems and relied on time-delayed remote backup to cover a failure of the bus protection system. Today's highly stressed power system is less tolerant of delayed fault clearing with loss of multiple branch circuits for a single-contingency failure. Therefore, determining ways to achieve dual high-speed protection systems for buses has become important. Historically, Minnesota Power has used high-impedance bus differential (87Z) protection systems. This principle has many advantages, including high performance, virtually no limit to the number of branch circuits, simple current transformer (CT) wiring, and simple settings calculations. This paper examines various options for obtaining redundancy. The paper includes an emphasis on examining various methods of applying dual 87Z relays in an existing bus differential CT circuit.","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":"128708097","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.2018.8349832
Alberto Becker Soeth, Paulo de Souza, Diogo Totti Custódio, I. Voloh
In order to transmit massive amounts of power generated by remotely located power plants, especially offshore wind farms, and to balance the intermittent nature of renewable energy sources, the need for a reliable high voltage transmission grid is anticipated. Due to power transfer limitations by AC transmission lines and its cost, the most attractive choice for such a power transfer is a high voltage DC (HVDC) lines [1]. The need to detect the fault location in the transmission line as quickly and accurately as possible has increasingly been demanded by utilities, and the use of traveling wave-based fault location technology has been implemented in order to improve the efficiency and to minimize the electrical system downtime and thus to avoid or minimize penalties [2]. The location method consists from measuring accurate time, when the traveling waves (generated by wave fronts caused by transients during line fault) pass through known measurement points, usually substations located at the ends of the transmission line. Different from fault locators using impedance methods, the location methods using traveling waves can achieve much higher accuracy regardless of fault type and line characteristics. The Travelling Wave Fault Locators (TWFL) currently available on the market rely on measurements from inductive CTs and inductive/capacitive VTs, which are not applicable to DC systems. This paper presents a means to acquire the readings of traveling waves in a HVDC transmission system. In addition, results of the field deployment of a TWFL system on a HVDC transmission line are presented. The described system was implemented on the longest in the world IE Madeira HVDC overhead line over a distance of 2375 kilometers, connecting Porto Velho to Araraquara II substations from Northwest to Southeast of Brazil and tested for stage faults during commissioning.
{"title":"Traveling wave fault location on HVDC lines","authors":"Alberto Becker Soeth, Paulo de Souza, Diogo Totti Custódio, I. Voloh","doi":"10.1109/CPRE.2018.8349832","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349832","url":null,"abstract":"In order to transmit massive amounts of power generated by remotely located power plants, especially offshore wind farms, and to balance the intermittent nature of renewable energy sources, the need for a reliable high voltage transmission grid is anticipated. Due to power transfer limitations by AC transmission lines and its cost, the most attractive choice for such a power transfer is a high voltage DC (HVDC) lines [1]. The need to detect the fault location in the transmission line as quickly and accurately as possible has increasingly been demanded by utilities, and the use of traveling wave-based fault location technology has been implemented in order to improve the efficiency and to minimize the electrical system downtime and thus to avoid or minimize penalties [2]. The location method consists from measuring accurate time, when the traveling waves (generated by wave fronts caused by transients during line fault) pass through known measurement points, usually substations located at the ends of the transmission line. Different from fault locators using impedance methods, the location methods using traveling waves can achieve much higher accuracy regardless of fault type and line characteristics. The Travelling Wave Fault Locators (TWFL) currently available on the market rely on measurements from inductive CTs and inductive/capacitive VTs, which are not applicable to DC systems. This paper presents a means to acquire the readings of traveling waves in a HVDC transmission system. In addition, results of the field deployment of a TWFL system on a HVDC transmission line are presented. The described system was implemented on the longest in the world IE Madeira HVDC overhead line over a distance of 2375 kilometers, connecting Porto Velho to Araraquara II substations from Northwest to Southeast of Brazil and tested for stage faults during commissioning.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"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":"126205393","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.2018.8349822
J. Sykes, Dewey Day, Kevin Fennelly, V. Skendzic, N. Fischer
Protection system communications are increasing in importance because they enable optimal operation of power systems. Because of the high cost of communications systems in the past, protection systems had to be optimized to use minimum bandwidth and were often forced to rely on a single bit of information. A synchronous 64 kbps channel reserved exclusively for the most critical transmission lines was seen as the best-case scenario. Communications system developments over the last three decades have opened a deluge of information, with a single optical fiber now capable of carrying multiple terabits of data simultaneously. Modern protection systems face a totally different problem. Communications bandwidth is almost unlimited, but the channel must be shared with other users and may present multiple challenges, such as channel asymmetry, variable latency, path reconfiguration due to automated failure recovery, packet-based transport, and the need for system-wide time synchronization. This paper reports on an experimental investigation that uses coarse or dense wavelength division multiplexing (CWDM, DWDM) for applications in high-speed traveling-wave protection. The investigation was performed using the latest generation of carrier-grade optical transport network (OTN) equipment. The paper documents the performance, opportunities, and pitfalls associated with this application and outlines practical strategies for the seamless integration of protection systems with the latest generation of OTN technologies.
{"title":"Sharing direct fiber channels between protection and enterprise applications using wavelength division multiplexing","authors":"J. Sykes, Dewey Day, Kevin Fennelly, V. Skendzic, N. Fischer","doi":"10.1109/CPRE.2018.8349822","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349822","url":null,"abstract":"Protection system communications are increasing in importance because they enable optimal operation of power systems. Because of the high cost of communications systems in the past, protection systems had to be optimized to use minimum bandwidth and were often forced to rely on a single bit of information. A synchronous 64 kbps channel reserved exclusively for the most critical transmission lines was seen as the best-case scenario. Communications system developments over the last three decades have opened a deluge of information, with a single optical fiber now capable of carrying multiple terabits of data simultaneously. Modern protection systems face a totally different problem. Communications bandwidth is almost unlimited, but the channel must be shared with other users and may present multiple challenges, such as channel asymmetry, variable latency, path reconfiguration due to automated failure recovery, packet-based transport, and the need for system-wide time synchronization. This paper reports on an experimental investigation that uses coarse or dense wavelength division multiplexing (CWDM, DWDM) for applications in high-speed traveling-wave protection. The investigation was performed using the latest generation of carrier-grade optical transport network (OTN) equipment. The paper documents the performance, opportunities, and pitfalls associated with this application and outlines practical strategies for the seamless integration of protection systems with the latest generation of OTN technologies.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"167 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":"121704802","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.2018.8349813
B. Vandiver
This paper will discuss in detail a capacitor bank protection and control scheme for >100kV systems that are in successful operation today. Including its implementation and testing on a configurable and scalable substation IED that incorporates all the necessary advanced protection and logic control functions.
{"title":"Optimizing HV capacitor bank design, protection, and testing","authors":"B. Vandiver","doi":"10.1109/CPRE.2018.8349813","DOIUrl":"https://doi.org/10.1109/CPRE.2018.8349813","url":null,"abstract":"This paper will discuss in detail a capacitor bank protection and control scheme for >100kV systems that are in successful operation today. Including its implementation and testing on a configurable and scalable substation IED that incorporates all the necessary advanced protection and logic control functions.","PeriodicalId":285875,"journal":{"name":"2018 71st Annual Conference for Protective Relay Engineers (CPRE)","volume":"440 ","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131716673","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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