Pub Date : 2014-04-24DOI: 10.1109/CPRE.2014.6799043
R. Cimadevilla
Delta-Wye transformer connections create discontinuities in the zero-sequence network as the zero-sequence current can flow at one side of the transformer without flowing at the other side. This effect generates a zero-sequence differential current that can make the differential unit trip. Traditional solutions applied to remove the zero sequence differential current where based on delta connected CTs. Zero-sequence filters in digital relays are software implemented. In many digital relays the zero sequence filter can be enabled or disabled. On the other hand, some relays can remove the zero-sequence current calculated from the phase currents or from the ground currents (currents measured in the neutral grounding). This paper reviews the transformer configurations that require the enabling of the zero-sequence filter by taking into account not only the connection group but also the construction of the magnetic core (this aspect is not always considered), explaining in detail the phantom or virtual tertiary effect of three-legged wyre-wye transformers. Real false trips due to this effect are included. The paper also explains the differences between both methods used for the zero-sequence current calculation (the one based on the phase currents and the one based on the ground current). The influence on the differential unit, harmonic restraint and common external fault detectors is analyzed. The first method can lead to a reduction of the differential current and to an erroneous phase selection during an internal fault. However, "2 out of 3" logics both for harmonic blocking and for a phase directional comparison unit can be implemented increasing the stability The second method provides very good sensibility and phase selection but does not allow the implementation of the "2 out of 3" logics reducing the stability. Cases based on real events and RTDS simulations are reviewed.
{"title":"Application of zero-sequence filter on transformer differential protection","authors":"R. Cimadevilla","doi":"10.1109/CPRE.2014.6799043","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799043","url":null,"abstract":"Delta-Wye transformer connections create discontinuities in the zero-sequence network as the zero-sequence current can flow at one side of the transformer without flowing at the other side. This effect generates a zero-sequence differential current that can make the differential unit trip. Traditional solutions applied to remove the zero sequence differential current where based on delta connected CTs. Zero-sequence filters in digital relays are software implemented. In many digital relays the zero sequence filter can be enabled or disabled. On the other hand, some relays can remove the zero-sequence current calculated from the phase currents or from the ground currents (currents measured in the neutral grounding). This paper reviews the transformer configurations that require the enabling of the zero-sequence filter by taking into account not only the connection group but also the construction of the magnetic core (this aspect is not always considered), explaining in detail the phantom or virtual tertiary effect of three-legged wyre-wye transformers. Real false trips due to this effect are included. The paper also explains the differences between both methods used for the zero-sequence current calculation (the one based on the phase currents and the one based on the ground current). The influence on the differential unit, harmonic restraint and common external fault detectors is analyzed. The first method can lead to a reduction of the differential current and to an erroneous phase selection during an internal fault. However, \"2 out of 3\" logics both for harmonic blocking and for a phase directional comparison unit can be implemented increasing the stability The second method provides very good sensibility and phase selection but does not allow the implementation of the \"2 out of 3\" logics reducing the stability. Cases based on real events and RTDS simulations are reviewed.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129198504","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6799034
Z. Xu, I. Voloh, Terrence Smith
Principles and applications of series capacitor banks and shunt reactors are first introduced. Then, the impacts of these apparatus on power systems are reviewed, including the behaviors of shunt reactors in the normal and fault conditions, the behaviors of series capacitor banks under the fault conditions. The effects of these apparatus on the line differential protection are particularly discussed. Challenges of relay applications are investigated with the emphasis on: advantages and disadvantages of including or excluding reactors in the 87L protection zone, solutions to compensate charging current, switching reactors in and out, voltage and current inversion of capacitor banks, sub-harmonic frequency transients, and effects of MOV conducting. In order to demonstrate challenges of the relay application, a long transmission line is studied, where two series capacitor banks are installed at approximately one third intervals on the transmission line and two shunt reactor banks are installed at both ends. Two configuration schemes are presented. Arrangement of the line current differential communications channels to achieve maximum security and dependability is discussed. The settings selection of the line current differential relays is discussed in detail. A simple method to calculate charging current compensation settings for line differential protection is described as well.
{"title":"87L application on long transmission line with series capacitor banks and shunt reactors","authors":"Z. Xu, I. Voloh, Terrence Smith","doi":"10.1109/CPRE.2014.6799034","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799034","url":null,"abstract":"Principles and applications of series capacitor banks and shunt reactors are first introduced. Then, the impacts of these apparatus on power systems are reviewed, including the behaviors of shunt reactors in the normal and fault conditions, the behaviors of series capacitor banks under the fault conditions. The effects of these apparatus on the line differential protection are particularly discussed. Challenges of relay applications are investigated with the emphasis on: advantages and disadvantages of including or excluding reactors in the 87L protection zone, solutions to compensate charging current, switching reactors in and out, voltage and current inversion of capacitor banks, sub-harmonic frequency transients, and effects of MOV conducting. In order to demonstrate challenges of the relay application, a long transmission line is studied, where two series capacitor banks are installed at approximately one third intervals on the transmission line and two shunt reactor banks are installed at both ends. Two configuration schemes are presented. Arrangement of the line current differential communications channels to achieve maximum security and dependability is discussed. The settings selection of the line current differential relays is discussed in detail. A simple method to calculate charging current compensation settings for line differential protection is described as well.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"89 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124420458","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6799033
Terrence Smith, Mike Childers, P. Caldwell
Microprocessor based relays have advanced algorithms in them to provide enhanced security against transients and other conditions that cannot actually exist on a real power system. This means that test methods should mimic real power system conditions, otherwise the relay may not operate or operate in an unpredictable manner for unrealistic conditions that are presented by a test set. This has given rise to the common phrase “test the tester”. This paper will show common mistakes that are made when testing Microprocessor based relays with unrealistic power system conditions. The paper also explains why these conditions are unrealistic, and explains how typical relay algorithms respond to these conditions. Unrealistic tests to be explored will include: a step change in frequency for under-frequency testing, absence of pre-fault conditions when testing distance elements, change in voltage phase when testing distance elements, improperly set zero sequence compensation factors in test set software, and improper phase direction on bus protection.
{"title":"Testing the tester, common pitfalls testing Microprocessor based relays","authors":"Terrence Smith, Mike Childers, P. Caldwell","doi":"10.1109/CPRE.2014.6799033","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799033","url":null,"abstract":"Microprocessor based relays have advanced algorithms in them to provide enhanced security against transients and other conditions that cannot actually exist on a real power system. This means that test methods should mimic real power system conditions, otherwise the relay may not operate or operate in an unpredictable manner for unrealistic conditions that are presented by a test set. This has given rise to the common phrase “test the tester”. This paper will show common mistakes that are made when testing Microprocessor based relays with unrealistic power system conditions. The paper also explains why these conditions are unrealistic, and explains how typical relay algorithms respond to these conditions. Unrealistic tests to be explored will include: a step change in frequency for under-frequency testing, absence of pre-fault conditions when testing distance elements, change in voltage phase when testing distance elements, improperly set zero sequence compensation factors in test set software, and improper phase direction on bus protection.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114182668","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6798995
J. Schaefer, S. Samineni, C. Labuschagne, S. Chase, Dereje Jada Hawaz
Capacitor banks are critical substation assets that play a vital role in providing reactive power support, thereby increasing the power system capacity. High-voltage capacitor banks are constructed as single-wye, double-wye, or H-bridge configurations and can be grounded or ungrounded. Capacitor banks consist of a number of single-phase capacitor units connected in series and parallel to achieve the desired voltage and VAR rating. The capacitor units can be externally or internally fused, fuseless, or unfused. When the unbalance resulting from unit or element failures becomes too high, the capacitor bank needs to be taken out of service by the protection system before the resulting unit overvoltages lead to a cascading failure and the faulty units must be replaced. If the bank is externally fused, then the unit with the blown fuse is usually the faulty unit, making identification obvious. If the bank is internally fused, fuseless, or unfused, then fault location is difficult because usually there is no visual indication of the problem. The result of a prolonged inspection is an extended outage of the capacitor bank. Although it might not be possible to identify the faulty unit in an internally fused, fuseless, or unfused bank, identifying the faulted phase and section narrows the search area and helps minimize the outage time. This paper analyzes various capacitor bank configurations and proposes an economical method to help locate the faulty elements or units for each configuration. The paper also provides results that verify the proposed methods using a Real Time Digital Simulator (RTDS®).
{"title":"Minimizing capacitor bank outage time through fault location","authors":"J. Schaefer, S. Samineni, C. Labuschagne, S. Chase, Dereje Jada Hawaz","doi":"10.1109/CPRE.2014.6798995","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6798995","url":null,"abstract":"Capacitor banks are critical substation assets that play a vital role in providing reactive power support, thereby increasing the power system capacity. High-voltage capacitor banks are constructed as single-wye, double-wye, or H-bridge configurations and can be grounded or ungrounded. Capacitor banks consist of a number of single-phase capacitor units connected in series and parallel to achieve the desired voltage and VAR rating. The capacitor units can be externally or internally fused, fuseless, or unfused. When the unbalance resulting from unit or element failures becomes too high, the capacitor bank needs to be taken out of service by the protection system before the resulting unit overvoltages lead to a cascading failure and the faulty units must be replaced. If the bank is externally fused, then the unit with the blown fuse is usually the faulty unit, making identification obvious. If the bank is internally fused, fuseless, or unfused, then fault location is difficult because usually there is no visual indication of the problem. The result of a prolonged inspection is an extended outage of the capacitor bank. Although it might not be possible to identify the faulty unit in an internally fused, fuseless, or unfused bank, identifying the faulted phase and section narrows the search area and helps minimize the outage time. This paper analyzes various capacitor bank configurations and proposes an economical method to help locate the faulty elements or units for each configuration. The paper also provides results that verify the proposed methods using a Real Time Digital Simulator (RTDS®).","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"476 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122737988","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6799036
E. Price
Ferroresonance is a widely studied phenomenon but it is still not well understood because of its complex behavior. It is “fuzzy-resonance.” A simple graphical approach using fundamental frequency phasors has been presented to elevate the readers understanding. Its occurrence and how it appears is extremely sensitive to the transformer characteristics, system parameters, transient voltages and initial conditions. More efficient transformer core material has lead to its increased occurrence and it has considerable effects on system apparatus and protection. Power system engineers should strive to recognize potential ferroresonant configurations and design solutions to prevent its occurrence.
{"title":"A tutorial on ferroresonance","authors":"E. Price","doi":"10.1109/CPRE.2014.6799036","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799036","url":null,"abstract":"Ferroresonance is a widely studied phenomenon but it is still not well understood because of its complex behavior. It is “fuzzy-resonance.” A simple graphical approach using fundamental frequency phasors has been presented to elevate the readers understanding. Its occurrence and how it appears is extremely sensitive to the transformer characteristics, system parameters, transient voltages and initial conditions. More efficient transformer core material has lead to its increased occurrence and it has considerable effects on system apparatus and protection. Power system engineers should strive to recognize potential ferroresonant configurations and design solutions to prevent its occurrence.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128394023","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6799025
Adrian G. Zvarych, Iza Pomales, J. Rodríguez, Dolly Villasmil
Very few devices are currently installed in substations without some form of communications connection. There is a clear trend toward establishing data connectivity via Ethernet due to generally higher data rates, and cost effective connections. Whether an application is for Supervisory Control and Data Acquisition (SCADA), line relaying, remote engineering access or Synchrophasors, the Intelligent Electronic Device (IED) is manufactured featuring a variety of communication ports including RS-232, RS-485, Ethernet, and fiber that are connected to, and communicating with at least one other remote device. Protection engineers typically have a limited role in communication applications, thus they may not have a full understanding of a communication networks' capabilities.
{"title":"Practical communications considerations for protection engineers","authors":"Adrian G. Zvarych, Iza Pomales, J. Rodríguez, Dolly Villasmil","doi":"10.1109/CPRE.2014.6799025","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799025","url":null,"abstract":"Very few devices are currently installed in substations without some form of communications connection. There is a clear trend toward establishing data connectivity via Ethernet due to generally higher data rates, and cost effective connections. Whether an application is for Supervisory Control and Data Acquisition (SCADA), line relaying, remote engineering access or Synchrophasors, the Intelligent Electronic Device (IED) is manufactured featuring a variety of communication ports including RS-232, RS-485, Ethernet, and fiber that are connected to, and communicating with at least one other remote device. Protection engineers typically have a limited role in communication applications, thus they may not have a full understanding of a communication networks' capabilities.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"50 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128765269","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6798997
E. Schweitzer, A. Guzman, M. Mynam, V. Skendzic, B. Kasztenny, S. Marx
Faults on overhead transmission lines cause transients that travel at the speed of light and propagate along the power line as traveling waves (TWs). This paper provides an overview of TWs and TW fault locators. It explains the physics, reviews the theory of TWs, explains the foundations of various types of TW fault locators, and provides an in-depth discussion on a number of TW fault locating implementation challenges. Finally, it discusses integration of TW fault locating in microprocessor-based relays and presents Bonneville Power Administration's (BPA's) field experience using these relays.
{"title":"Locating faults by the traveling waves they launch","authors":"E. Schweitzer, A. Guzman, M. Mynam, V. Skendzic, B. Kasztenny, S. Marx","doi":"10.1109/CPRE.2014.6798997","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6798997","url":null,"abstract":"Faults on overhead transmission lines cause transients that travel at the speed of light and propagate along the power line as traveling waves (TWs). This paper provides an overview of TWs and TW fault locators. It explains the physics, reviews the theory of TWs, explains the foundations of various types of TW fault locators, and provides an in-depth discussion on a number of TW fault locating implementation challenges. Finally, it discusses integration of TW fault locating in microprocessor-based relays and presents Bonneville Power Administration's (BPA's) field experience using these relays.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123670337","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 : 2014-04-24DOI: 10.1109/CPRE.2014.6799021
Dennis Tierney, B. Kasztenny, D. Finney, D. Haas, B. Le
This paper reviews the protection requirements for generators during periods of off-nominal frequency operation. It investigates the behavior of instrument transformers during these periods as well as the impact of frequency on the accuracy of protection operating quantities. Traditional methods for frequency tracking and compensation are reviewed. A novel approach, which provides excellent performance for very significant frequency deviations and can accommodate multiple frequency islands, is presented.
{"title":"Performance of generator protection relays during off-nominal frequency operation","authors":"Dennis Tierney, B. Kasztenny, D. Finney, D. Haas, B. Le","doi":"10.1109/CPRE.2014.6799021","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799021","url":null,"abstract":"This paper reviews the protection requirements for generators during periods of off-nominal frequency operation. It investigates the behavior of instrument transformers during these periods as well as the impact of frequency on the accuracy of protection operating quantities. Traditional methods for frequency tracking and compensation are reviewed. A novel approach, which provides excellent performance for very significant frequency deviations and can accommodate multiple frequency islands, is presented.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"150 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127221032","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 : 2014-03-01DOI: 10.1109/CPRE.2014.6799027
A. Apostolov, B. Vandiver
Edition 2 of IEC 61850 introduced many new features that further enhance the power of the standard. There are new features that should make the life of the end user easier - assuming the features are supported by future products. They are designed to support not only automated configuration and execution of test procedures, but also remote testing for some specific test cases. It is expected, that interoperability between engineering tools will be improved - something that is urgently needed. New features supporting functional and system testing should facilitate the ways lEC 61850 based installation needs to be isolated - during commissioning, in case of maintenance problems, as well as for routine testing.
{"title":"Virtual isolation of IEDs for testing in IEC 61850 based substation protection systems","authors":"A. Apostolov, B. Vandiver","doi":"10.1109/CPRE.2014.6799027","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799027","url":null,"abstract":"Edition 2 of IEC 61850 introduced many new features that further enhance the power of the standard. There are new features that should make the life of the end user easier - assuming the features are supported by future products. They are designed to support not only automated configuration and execution of test procedures, but also remote testing for some specific test cases. It is expected, that interoperability between engineering tools will be improved - something that is urgently needed. New features supporting functional and system testing should facilitate the ways lEC 61850 based installation needs to be isolated - during commissioning, in case of maintenance problems, as well as for routine testing.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132907238","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 : 2014-03-01DOI: 10.1109/CPRE.2014.6799040
R. Hunt
Modular protection and control using process bus is really only the first step in modular design of substations. Once the field wiring problem for protection and control systems is solved, then the design of substations can be addressed. Some examples of where the industry can go when are as follows. This paper discusses one possible method to design the protection and control system for replacement. Manufactured protection and control uses the concepts of process bus to factory produce protection and control installations. Every relay system consists of 2 basic modules. One module is the analog interface module that mounts at primary equipment and converts all analog information (currents, voltages, equipment status, and control points) to digital signals. The other module is the relay itself that processes digital signals and makes protection decisions. Both of these modules are designed, built, and tested in a manufacturing environment. These modules install in a substation as faster, or faster, than with traditional protective relays. The use of a modular design results in a reduced cycle time for the entire project, including engineering, installation, and commissioning. The larger benefit is long term: in the future, you can, replace, upgrade, or evolve the protection and control system quickly, by simply changing out these modules. So the future replacement or upgrade, or evolve the protection and control system quickly, by simply changing out these modules. So the future replacement or upgrade project is to replace a field module with a fully tested replacement module.
{"title":"Manufactured protection and control: A modular approach to installing protection and control","authors":"R. Hunt","doi":"10.1109/CPRE.2014.6799040","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799040","url":null,"abstract":"Modular protection and control using process bus is really only the first step in modular design of substations. Once the field wiring problem for protection and control systems is solved, then the design of substations can be addressed. Some examples of where the industry can go when are as follows. This paper discusses one possible method to design the protection and control system for replacement. Manufactured protection and control uses the concepts of process bus to factory produce protection and control installations. Every relay system consists of 2 basic modules. One module is the analog interface module that mounts at primary equipment and converts all analog information (currents, voltages, equipment status, and control points) to digital signals. The other module is the relay itself that processes digital signals and makes protection decisions. Both of these modules are designed, built, and tested in a manufacturing environment. These modules install in a substation as faster, or faster, than with traditional protective relays. The use of a modular design results in a reduced cycle time for the entire project, including engineering, installation, and commissioning. The larger benefit is long term: in the future, you can, replace, upgrade, or evolve the protection and control system quickly, by simply changing out these modules. So the future replacement or upgrade, or evolve the protection and control system quickly, by simply changing out these modules. So the future replacement or upgrade project is to replace a field module with a fully tested replacement module.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2014-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125326301","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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