Pub Date : 2014-04-24DOI: 10.1109/CPRE.2014.6799037
S. Hodder, B. Kasztenny, N. Fischer, Yu Xia
This paper addresses the security of transformer differential protection with low levels of second harmonic during magnetizing inrush conditions. The paper explains the phenomenon of ultrasaturation causing the second harmonic to drop below the traditional 15 to 20 percent setting levels and points to possible causes of and conditions for ultrasaturation. A number of field cases are presented and discussed in addition to the engineering analysis of the problem. The paper outlines several simple solutions to address the security problem while minimizing the adverse impact on dependability. Further, the paper presents a new method for inrush detection that considerably improves security without diminishing dependability. Finally, a method to accelerate operation of transformer differential protection is presented.
{"title":"Low second-harmonic content in transformer inrush currents - Analysis and practical solutions for protection security","authors":"S. Hodder, B. Kasztenny, N. Fischer, Yu Xia","doi":"10.1109/CPRE.2014.6799037","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799037","url":null,"abstract":"This paper addresses the security of transformer differential protection with low levels of second harmonic during magnetizing inrush conditions. The paper explains the phenomenon of ultrasaturation causing the second harmonic to drop below the traditional 15 to 20 percent setting levels and points to possible causes of and conditions for ultrasaturation. A number of field cases are presented and discussed in addition to the engineering analysis of the problem. The paper outlines several simple solutions to address the security problem while minimizing the adverse impact on dependability. Further, the paper presents a new method for inrush detection that considerably improves security without diminishing dependability. Finally, a method to accelerate operation of transformer differential protection is presented.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"1 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":"128948312","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.2014.6799019
T. Baker
The integrity and reliability of the bulk power electrical systems could be significantly enhanced by providing redundant or back up protection for the bus differentials, unit differentials, feeder differentials, and transformer differentials applied in generating station high voltage switchyards. These additions could be provided at a modest cost as outlined in the paper. Many existing large generating stations are also not equipped with out-of-step, inadvertent energization, pole flashover, and slow breaker closing during synchronizing protection schemes. The lack of these functions could have a negative impact on the bulk power system. They could be added at a relatively low cost to improve the reliability of the electrical system and at the same time significantly enhance the protection at large generating stations.
{"title":"Improving BES reliability at large generating station locations","authors":"T. Baker","doi":"10.1109/CPRE.2014.6799019","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799019","url":null,"abstract":"The integrity and reliability of the bulk power electrical systems could be significantly enhanced by providing redundant or back up protection for the bus differentials, unit differentials, feeder differentials, and transformer differentials applied in generating station high voltage switchyards. These additions could be provided at a modest cost as outlined in the paper. Many existing large generating stations are also not equipped with out-of-step, inadvertent energization, pole flashover, and slow breaker closing during synchronizing protection schemes. The lack of these functions could have a negative impact on the bulk power system. They could be added at a relatively low cost to improve the reliability of the electrical system and at the same time significantly enhance the protection at large generating stations.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"6 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":"125282146","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.2014.6799030
R. Preston, Cesar Guerriero
A distinct challenge for any electric utility company, be it investor owned, publicly owned or a cooperative, is to be in compliance with regard to testing requirements of modern protective relays. Documented, periodic testing of relays and other IEDs (Intelligent Electronic Device) in power substations must be carried out in order to comply with the requirements of the local regulatory council.
{"title":"Utilizing GOOSE-based protection schemes to attain compliance with regulatory testing requirements","authors":"R. Preston, Cesar Guerriero","doi":"10.1109/CPRE.2014.6799030","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799030","url":null,"abstract":"A distinct challenge for any electric utility company, be it investor owned, publicly owned or a cooperative, is to be in compliance with regard to testing requirements of modern protective relays. Documented, periodic testing of relays and other IEDs (Intelligent Electronic Device) in power substations must be carried out in order to comply with the requirements of the local regulatory council.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"39 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":"125552443","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.2014.6799014
M. McMillan, Stephen Copeland, Joe Perez, Hung-Ming Chou
Flashover operations due to a change in the physical positioning of a foreign object with an energized conductor are a common occurrence seen throughout many transmission and distribution systems. The inception of a fault from a flashover between two stationary conductors, however, is not as prevalent. This is primarily due to extensive protection system coordination and insulation design specifications that, under anticipated fault conditions, will allow the necessary protection devices to operate, thereby clearing the fault. For Bryan Texas Utilities during the summer of 2013, a particular flashover operation brought about a series of atypical events, which resulted in several operations involving two 138kV transmission lines as well as portions of the 12.5kV distribution system. As presented in the following analysis, it is evident that, while the fault conditions experienced by the system were not within anticipated limits, there are some steps that can be taken to mitigate future operations of this nature.
{"title":"Analysis of a flashover operation on two 138kV transmission lines","authors":"M. McMillan, Stephen Copeland, Joe Perez, Hung-Ming Chou","doi":"10.1109/CPRE.2014.6799014","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799014","url":null,"abstract":"Flashover operations due to a change in the physical positioning of a foreign object with an energized conductor are a common occurrence seen throughout many transmission and distribution systems. The inception of a fault from a flashover between two stationary conductors, however, is not as prevalent. This is primarily due to extensive protection system coordination and insulation design specifications that, under anticipated fault conditions, will allow the necessary protection devices to operate, thereby clearing the fault. For Bryan Texas Utilities during the summer of 2013, a particular flashover operation brought about a series of atypical events, which resulted in several operations involving two 138kV transmission lines as well as portions of the 12.5kV distribution system. As presented in the following analysis, it is evident that, while the fault conditions experienced by the system were not within anticipated limits, there are some steps that can be taken to mitigate future operations of this nature.","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":"129057308","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.2014.6798991
E. Udren
In 2007, FERC Order 693 launched the development of the new NERC Protection System Maintenance Standard PRC-005-2. The new standard was to replace four legacy standards for maintenance of similar types of protection system components, and to specify maximum maintenance intervals and minimum activities for a time based maintenance (TBM) program. The NERC Standard Drafting Team, however, went beyond what FERC ordered and also included provisions for condition based maintenance (CBM) and performance based maintenance (PBM) programs. The new draft Standard was approved by NERC in 2012. On July 18, 2013, FERC issued a Notice of Proposed Rulemaking (NOPR) in which it proposed to make PRC-005-2 [1] mandatory and enforceable, along with a few new action items requesting feedback of supporting information. In October of 2013, PRC-005-2 became mandatory and enforceable. The standard includes and implementation plan that gives affected utilities many years to gradually develop compliance with the new standard.
{"title":"Protection system maintenance program choices - TBM, CBM, and PBM","authors":"E. Udren","doi":"10.1109/CPRE.2014.6798991","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6798991","url":null,"abstract":"In 2007, FERC Order 693 launched the development of the new NERC Protection System Maintenance Standard PRC-005-2. The new standard was to replace four legacy standards for maintenance of similar types of protection system components, and to specify maximum maintenance intervals and minimum activities for a time based maintenance (TBM) program. The NERC Standard Drafting Team, however, went beyond what FERC ordered and also included provisions for condition based maintenance (CBM) and performance based maintenance (PBM) programs. The new draft Standard was approved by NERC in 2012. On July 18, 2013, FERC issued a Notice of Proposed Rulemaking (NOPR) in which it proposed to make PRC-005-2 [1] mandatory and enforceable, along with a few new action items requesting feedback of supporting information. In October of 2013, PRC-005-2 became mandatory and enforceable. The standard includes and implementation plan that gives affected utilities many years to gradually develop compliance with the new standard.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"30 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":"133504317","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.2014.6799028
S. Turner
A numerical generator protection relay provides multiple functions and typically uses algorithms that do not work on the same principles as older electromechanical relays. Often relay test personnel still want to use old test methods developed long ago for electromechanical relays. Test results obtained from these old test methods may not be a good indication of whether or not the numerical relay protection functions properly. One such obsolete technique still often used is referred to as a static test. Fault voltage and/or fault current are injected to see if the selected protection function operates at the setpoint and is in tolerance. Many protection functions have dynamic characteristics and/or hidden features that cannot be properly tested using a static test. This paper demonstrates various techniques how to test numerical protection relays such as dynamic tests.
{"title":"Optimally testing numerical multi-function generator protection elements","authors":"S. Turner","doi":"10.1109/CPRE.2014.6799028","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799028","url":null,"abstract":"A numerical generator protection relay provides multiple functions and typically uses algorithms that do not work on the same principles as older electromechanical relays. Often relay test personnel still want to use old test methods developed long ago for electromechanical relays. Test results obtained from these old test methods may not be a good indication of whether or not the numerical relay protection functions properly. One such obsolete technique still often used is referred to as a static test. Fault voltage and/or fault current are injected to see if the selected protection function operates at the setpoint and is in tolerance. Many protection functions have dynamic characteristics and/or hidden features that cannot be properly tested using a static test. This paper demonstrates various techniques how to test numerical protection relays such as dynamic tests.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"37 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":"132909797","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.2014.6799005
Lihan He, Zhilin Wu, Z. Xu, I. Voloh, Terrence Smith
Accurate fault location in distribution networks of power systems is an essential technology, yet faces more challenges than that in transmission systems. This paper presents a novel method for feeder fault location using current/voltage sensors sparsely deployed in the network. Depending on the available sensor locations relative to the fault and the lateral conditions, the algorithm searches every possible path and calculates the fault distance and fault resistance by reducing the circuit to one of the two representative scenarios. The proposed scheme has been examined and validated in a 24.9 kV IEEE radial feeder system.
{"title":"Enhanced distribution feeder fault location","authors":"Lihan He, Zhilin Wu, Z. Xu, I. Voloh, Terrence Smith","doi":"10.1109/CPRE.2014.6799005","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799005","url":null,"abstract":"Accurate fault location in distribution networks of power systems is an essential technology, yet faces more challenges than that in transmission systems. This paper presents a novel method for feeder fault location using current/voltage sensors sparsely deployed in the network. Depending on the available sensor locations relative to the fault and the lateral conditions, the algorithm searches every possible path and calculates the fault distance and fault resistance by reducing the circuit to one of the two representative scenarios. The proposed scheme has been examined and validated in a 24.9 kV IEEE radial feeder system.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"18 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":"115996017","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.2014.6799006
C. Mozina
A significant amount of green power is being installed at the distribution level through the installation of green power generation facilities in many parts of the United States and Canada. Green sources such as solar and wind are some of the green generation being interconnected at the distribution level. These non-conventional generators use inverter-based technologies and operate in parallel with utility distribution feeders. The fault behavior of an inverter-interfaced solar or wind distributed generator (DG) is determined by its control, which is significantly different from conventional synchronous and induction generators. In addition, utilities have expressed a concern that distributed generators interfaced to the grid via inverters could cause a transient overvoltage during a single phase to ground fault, after the substation breaker opens. The concern is that this overvoltage will damage utility equipment such as lightning arresters or saturate line-to-neutral rated utility feeder transformers resulting in transformer failure. This paper examines both the fault current and overvoltage issue and compares inverter based distributed generations (DGs) with conventional synchronous and induction DGs.
{"title":"Impact of green power inverter-based distributed generation on distribution systems","authors":"C. Mozina","doi":"10.1109/CPRE.2014.6799006","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799006","url":null,"abstract":"A significant amount of green power is being installed at the distribution level through the installation of green power generation facilities in many parts of the United States and Canada. Green sources such as solar and wind are some of the green generation being interconnected at the distribution level. These non-conventional generators use inverter-based technologies and operate in parallel with utility distribution feeders. The fault behavior of an inverter-interfaced solar or wind distributed generator (DG) is determined by its control, which is significantly different from conventional synchronous and induction generators. In addition, utilities have expressed a concern that distributed generators interfaced to the grid via inverters could cause a transient overvoltage during a single phase to ground fault, after the substation breaker opens. The concern is that this overvoltage will damage utility equipment such as lightning arresters or saturate line-to-neutral rated utility feeder transformers resulting in transformer failure. This paper examines both the fault current and overvoltage issue and compares inverter based distributed generations (DGs) with conventional synchronous and induction DGs.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"5 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":"121115617","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.2014.6799003
J. Cárdenas, G. Mikhael, J. Kaminski, I. Voloh
This paper briefly discusses the challenges related to the Islanding operation in power systems and presents different methods to detect the islanding condition with an example of photovoltaic applications. Furthermore, it proposes a secure method of islanding detection using synchrophasors. The proposed algorithm has been verified with Real Time Digital Simulator (RTDS) tests, as well as in laboratory environment with an inverter connected to grid. With the help of extensive testing, it is demonstrated that the proposed method successfully performs automatic and manual decisions to assure the correct and secure operation of the distribution grid.
{"title":"Islanding detection with Phasor Measurement Units","authors":"J. Cárdenas, G. Mikhael, J. Kaminski, I. Voloh","doi":"10.1109/CPRE.2014.6799003","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799003","url":null,"abstract":"This paper briefly discusses the challenges related to the Islanding operation in power systems and presents different methods to detect the islanding condition with an example of photovoltaic applications. Furthermore, it proposes a secure method of islanding detection using synchrophasors. The proposed algorithm has been verified with Real Time Digital Simulator (RTDS) tests, as well as in laboratory environment with an inverter connected to grid. With the help of extensive testing, it is demonstrated that the proposed method successfully performs automatic and manual decisions to assure the correct and secure operation of the distribution grid.","PeriodicalId":285252,"journal":{"name":"2014 67th Annual Conference for Protective Relay Engineers","volume":"95 2 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":"125978826","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.2014.6799008
C. Inshaw
It has been over ten years since the first IEEE standard (Std. 1584) related to arc-flash was released. However, facilities are still being designed and built with little or no consideration to limiting the incident energy levels. This results in costly changes in equipment and time when facility owners require lower incident energies to perform energized work. This paper will discuss how to promote a safer work environment by reducing incident energies. This achieves the use of Category 2 PPE or below at for nearly all locations in electrical distributions systems (including both low and medium voltage locations).The discussion will include design options that will lower incident energies, as well as discuss real world attempts that were less successful.
{"title":"Incorporating arc-flash mitigation into the design of new and existing facilities","authors":"C. Inshaw","doi":"10.1109/CPRE.2014.6799008","DOIUrl":"https://doi.org/10.1109/CPRE.2014.6799008","url":null,"abstract":"It has been over ten years since the first IEEE standard (Std. 1584) related to arc-flash was released. However, facilities are still being designed and built with little or no consideration to limiting the incident energy levels. This results in costly changes in equipment and time when facility owners require lower incident energies to perform energized work. This paper will discuss how to promote a safer work environment by reducing incident energies. This achieves the use of Category 2 PPE or below at for nearly all locations in electrical distributions systems (including both low and medium voltage locations).The discussion will include design options that will lower incident energies, as well as discuss real world attempts that were less successful.","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":"130564952","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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