3rd Annual Protection & Control Conference › ... › PC2015 › files › PCTF2015_Brochure.pdf · 2015-11-16 · CEATI’s 3rd Annual Protection & Control Conference: November

Tel: +1.514.866.5377 • Fax: +1.514.904.5038 • [email protected] • www.ceati.com

Conference Overview

The fast-paced evolution of microprocessor- based protection relays with their ever increasing waveform sampling rates and computing power, combined with availability of high-speed communication links is opening new opportunities for designing more sophisticated protection schemes and their networking and integration into station automation systems. In practical applications, however, incorporation of technological advancements is accompanied by many challenges, such as optimization of protection assets replacement strategies and degree of protection and controls functions integration, implementing adequate cyber security, managing protection system settings, maintenance practices and records, providing utility staff with timely requisite training, etc.

The main objective of the CEATI 2015 Protection & Control Conference is to bring industry professionals together to identify, discuss and develop solutions to common issues by sharing experiences and creating a networking opportunity for engineers concerned with application, optimization and the innovative use of advanced protection and control technologies in their power systems. Who Should Attend?

3rd Annual

Protection & Control Conference

For more information, visit www.ceati.com/event/PC2015

PCTF ParticipantsConference Themes

• Protection Design Practices

• Management of Relay Firmware

Updates

• IEC 61850 Applications

• Power Apparatus Condition

Monitoring Using Protection Relays

• Arc-flash Mitigation

• Protection Aspects of Distributed

Generation & Microgrids

• New and Emerging Protection

Technologies

PCTF Meeting OverviewCEATI’s Protection & Control Task Force (PCTF) will hold their General Meeting on Friday, November 20th, 2015, following the Conference. The full day meeting will place emphasis on the participant driven program development for 2016, as well as sharing of protection & control best practices, issues and solutions. Participants will also review the achievements and activities from 2015.

PCTF at a GlanceParticipation: 20+ Participating Members

Focus Areas:

• Management of Protection Assets and Investment Strategies• Protection Systems Design Standards and Utility Practices• Substation Automation – Experiences and Best Practices • Optimizing Protection System Maintenance and Compliance Reporting• Introduction of New and Emerging Protection Technologies

November 18-19, 2015 • New Orleans, Louisiana

Electric UtilitiesConsultantsService ProvidersManufacturers & Equipment VendorsUniversities

7:30 – 8:30 Registration & Breakfast - Exhibit Hall

8:30 - 8:40 Welcome Address Jerry Lepka, CEATI Intl.

Session 1: Protection Design & Maintenance

8:40 – 9:10 PG&E’s New Protective Relaying Standards Monica Anderson, for 230kV and 500kV lines Pacific Gas & Electric

9:10 – 9:40 Avoiding Potentially Dangerous Relay Scott Cooper, Omicron Testing Practices

9:40 – 10:10 Generic Requirements for Multifunctional Juergen Holbach, Protection Relay Settings Database and Quanta Technologies Data Management

10:10 – 10:40 Morning Refreshment Break - Exhibit Hall

10:40 – 11:10 Modern Applications of Digital Relays in Jeremy Blair, Schweitzer Distribution Systems Engineering Laboratories 11:10 – 11:30 Question & Answer Period: Protection Design & Maintenance

Session 2: IEC 61850 Applications

11:30 – 12:00 Challenges with Cost/Benefit Analyses for Deepak Maragal, New York “Green” and “Brown” Field Projects Design Power Authority Implementing IEC 61850 Protocol

12:00 - 1:00 Lunch - Exhibit Hall

1:00 – 1:30 Practical Example Testing Protection Scheme Nestor Casilla, Doble Performance Based on IEC 61850 Engineering

1:30 – 2:00 Special “Power System Integrity Protection” Matt Efremov Using IEC 61850 Communication Protocol Hydro One and New VLAN Architecture

2:00 – 2:45 Entergy Experience with IEC 61850 Chan Wong, Entergy Implementation & Demonstration of a Test Relay Panel for IEC 61850 Application

2:45 – 3:15 Afternoon Refreshment Break - Exhibit Hall

3:15 – 3:45 Efficient Testing of IEC 61850 Based Digital Alex Apostolov, Omicron Substations

3:45 – 4:00 Question & Answer Period: IEC 61850 Applications

Session 3: Arc Flash Mitigation

4:00– 4:30 Ontario Power Generation’s Approach to Jay Wehrstedt, Ontario Identifying and Mitigating Arc-Flash Hazards Power Generation

4:30 – 5:00 Arc Flash & Transient Voltage Considerations Baldwin Yeung, Leidos Based on OSHA 269

5:00 – 5:20 Question & Answer Period: Arc Flash Mitigation

5:20 – 5:30 Day 1 Concluding Remarks Jerry Lepka, CEATI Intl


DAY 1 • November 18, 2015

The steadily increasing processing power of new generation of protective relays, combined with vast increase in bandwidth offered by modern networking technologies provide opportunities for design of more sophisticated and faster protection schemes. This conference session will focus on the benefits and justification of introducing new technologies, planning and staging changes of standard design, facilitating substa-tion automation and implementing maintenance practices which would ensure regulatory compliance.

IEC61850 is an important new interna-tional standard for substation automa-tion that will have a very significant impact on how electric power systems are designed and built in the future. Use of this standard will enable incor-poration of much higher levels of functionality, with potential to signifi-cantly reduce the implementation costs of substation automation, and in turn positively impact the system operating and maintenance costs, reduce outage response time and improve the overall quality of power. This session is designed to share current experiences with IEC 61850 applications.

The goal of this conference session is to discuss the protective relaying techniques designed to minimize the fault clearing times, yet maintain the selective coordination with down-stream protection for external faults.

Reception 6:00 pm - 7:30pm


Session 6: Relay Firmware Updates

12:00 - 1:00 Lunch - Exhibit Hall

1:00 – 1:30 Relay Firmware Updates - SEL Perspective Mike Collum, Schweitzer Engineering Laboratories

1:30 – 2:10 A Management System for Electical Distri- Steve Greey, S&C Electric bution System Smart Devices and Systems

2:10 – 2:40 Testing Procedure for Relay Firmware Milton Quinteros & Updates Hussain Al Marhoon, Entergy Services

2:40 – 3:00 Question & Answer Period: Relay Firmware Updates

3:00 – 3:30 Afternoon Refreshment Break - Exhibit Hall

Session 7: New & Emerging Technologies

3:30 – 4:00 Implementation of Travelling Wave Fault N. Beeravolu, IK Power System Location Using SEL-411L Transmission Line Solutions & Sal Jadid, Power Protection Relays Engineering Consultants

4:00 – 4:30 Transmission Lines Corridors Intrusion John Puryear, ABS Detection Based on Monitoring EMF Consulting

4:30 – 4:50 Question & Answer Period: New & Emerging Technologies

4:50 – 5:00 Closing Remarks Jerry Lepka, CEATI Intl.

DAY 2 • November 19, 2015

The session is intended to provide information about issues and utility experiences with integration of DG to transmission and/or distribu-tion systems, as well as issues and technical requirement for opera-tion of autonomous, but system connectible microgrids.

This session is intended to provide information about the utility practices and new developments in design of protection and control systems for large electric power generators and their auxiliary systems.

Unlike many consumer devices where firmware changes may never occur during their economic lifetime, protective relays are subject to periodic firmware changes intended to correct operational deficien-cies, address security issues or add new features to the relays. This session will provide information on the effective ways of managing firmware changes, such as which are mandatory vs discretionary, function testing requirements, effective communication and record keeping, etc. from both utility and relay manufacturers perspectives.

The information presented in this session is intended to introduce new technologies, either available or in various stages of development, that can be used for such applications as detection of high-imped-ance faults, fully automatic feeder restoration, accurate fault location, micro-grid operation, and other technolo-gies aimed at improving power system security and automation.

7:30 – 8:30 Registration & Breakfast - Exhibit Hall

Session 5: Generation Related Topics

The Future of P&C Systems Alex Apostolov, Omicron for Large Electric Power Generators and Their Auxiliary Systems

Hydroelectric Generator Pro- Kirk Chen, USACE tection Upgrades: Common Practices & Lessons Learned

Protection Trips & Oscillations Deepak Maragal, New on Generator Exciter/Govern- York Power Authority or Upgrades at New York Power Authority: Experiences & Solutions

A New Performance Metric for Murty Yalla & Motor Bus Transfer Relays at Tom Beckwith, Generating Plants Beckwith Electric

Question & Answer Period: Generation Related Topics

Session 4: Distributed Generation (DG) & Microgrids

Evaluation of Bidirectional Digital Mansour Jalali, Tap-Changer Controllers for Voltage KinectricsRegulation in Distribution Systems with DG

BCIT’s Smart Microgrid Initiative Minoo Shariat-& Energy Oasis Project Zadeh, BCIT

State of the Art Islanding Detection Ashish Upreti, and Decoupling Systems for Utility Schweitzer and Industrial Power Systems Engineering Laboratories

Protection Considerations for Todd Martin, Installation of Distributed Energy Basler Electric Co.Resources

Question & Answer Period: DG & Microgrids

9:50 - 10:20 Morning Refreshment Break - Exhibit Hall

8:30 – 9:10

9:10 – 9:50

10:20 - 10:50

10:50 - 11:30

11:30 - 12:00

Bio: Mr. Jerry Lepka is the Technical Advisor to the Protection & Control Task Force (PCTF). A graduate of the University of Manitoba, Mr. Lepka has worked both abroad and in Canada managing complex technical operations and implementing new technologies. His most recent project was with GRIDCo power utility in Ghana, performing power system audit, with special focus on protection systems. Past assignments included work with Gestore Rete Transmissione Nazionale in Italy, determining the causes of the September 2003 Italian system blackout.

Mr. Lepka’s career also includes many years in P&C discipline with Ontario Hydro (now Hydro One) as District P&C Engineer in Toronto and Cherrywood Districts. He also spent several years in Ghana, West Africa, as a P&C Instructor and later on as Director of the newly-formed Transmission System Division for the national power utility, Volta River Authority.

Tel: 1.514.866.5377 Fax: 1.514.904.5038 [email protected] www.ceati.com

PG&E’s New Protective Relaying Standards for 230 kV and 500 kV Lines – Monica Anderson, Pacifi c Gas & Electric

Bio: Monica Anderson received her BSEE in 1988 from the University of California, Davis. Monica is a registered professional engineer in California and has been with PG&E system protection since 2003. She is currently supporting the 500 kV system and protection standards. Previously she worked at Western Area Power Administration, First Energy Corp, and Puget Sound Energy.

Presentation Abstract: The presentation will provide an overview of the Pacifi c Gas & Electric 500 kV Line, Breaker, and Bank protection standards.

Welcome Address - Jerry LepkaTechnical Advisor, Protection & Control Task Force, CEATI International

CEATI’s 3rd Annual Protection & Control Conference:

November 18-19, 2015, New Orleans, LA, USA

Session 1: Protection Design & MaintenanceThe steadily increasing processing power of new generation of protective relays, combined with

vast increase in bandwidth off ered by modern networking technologies provide opportunities

for design of more sophisticated and faster protection schemes. This conference session will

focus on the benefi ts and justifi cation of introducing new technologies, planning and staging

changes of standard design, facilitating substation automation and implementing maintenance

practices which would ensure regulatory compliance.

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Avoiding Potentially Dangerous Relay Testing Practices - Scott Cooper, Omicron

Bio: Scott Cooper has twenty-nine years of experience in a variety of roles including substation commissioning, application Engineering, power plant operations, and technical training. He currently works as the Application and Training Engineer for OMICRON in St. Petersburg, Florida.

Presentation Abstract: With multifunction digital relays being the commonplace for power system protection, much confusion still remains as to proper testing principals and procedures. Realizing that relay calibration is no longer a key focus, proper testing is still critical to assure proper settings and functionality. Increased complexity of protection devices, along with fewer resources have led to quick fi x short cuts that can lead to potentially dangerous oversights.

Test procedures for electromechanical relays have long been established and documented in the protective relay industry. Most often, specifi c procedures for testing and calibration were provided in detail from the relay manufacturer leaving little or no room for misinterpretation or error if followed properly. Support from protection engineers to relay technicians responsible for actual testing could regularly be counted on, with calculated test values relative to actual settings. Testing typically was performed manually, or by means of simplifi ed automated macros.

The complexity of today’s multifunction protective relay systems require attention to detail during the diff erent stages of the testing process, but our focus has changed signifi cantly from the electromechanical design. Springs, magnets, variable resistors, and contacts needed periodic testing to assure calibration, as well to verify settings, but since settings were fundamentally simple, concerns were focused on the electrical and mechanical operation of each device.

Unfortunately, those who design, build, and sell modern digital relays are doing very little in practical and realistic terms in providing test procedures. The main reason being that with any one device, there are literally thousands of variable applications and settings. Application specifi c test procedures would be nearly impossible to develop by the manufacturer, aside from basic meter checking and validation of relay health. Relay manufacturers are also unable to determine if the customer is in possession of adequate testing equipment, which is the fi rst step in avoiding dangerous testing practices.

This paper will discuss the testing procedures that should be avoided, and off er testing alternatives to assure proper relay operation. Documented relay mis-operations are often the result of improper relay settings or logic confi gurations, which can be avoided by applying proper testing principles.



Modern Applications of Digital Relays in Distribution Systems – Jeremy Blair, Schweitzer Engineering Laboratories

Bio: Jeremy Blair holds a BSEE from Louisiana Tech University and an MSECE from Georgia Institute of Technology. He has worked for and supported distribution utilities for over 11 years, with experience in protection, automation, planning, and power quality. Jeremy now works as an Application Engineer with SEL, Inc. providing fi eld technical support and customer education for users of SEL’s protective relaying products.

Presentation Abstract: Digital multifunction relays with customizable logic have given protection engineers unprecedented control over the behavior of their protection systems. This new level of control gives protection engineers the ability to meet both old and new challenges in distribution system protection including inrush, limited time-coordination space, automatic service restoration, and integrating distributed generation. This presentation will discuss logical methods, protection principles, and system architectural solutions to these challenges specifi cally.

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Bio: Dr. Juergen Holbach, Senior Director has more than 26 years of experience in design and application of protective relaying. He started his career in the development department of a German relay manufacturer and led the development project of numerical line diff erential relays. As an application expert for transmission protection he was responsible for approval test of transmission relays with utility customer around the world. Juergen was one of the lead engineers on the fi rst IEC61850 based Protection and Control, Multi-Vendor Project in the United States (500KV Bradley Station-TVA). He was the trainer of the Siemens training program for the distribution and transmission protection. In recent years, Juergen has been involved in several industrial and utility projects focusing on wide-area protection coordination studies and protection setting calculation.

Juergen contributed to several working groups in CIGRE as well as in IEEE-PSRC and was the chairmen of the working group H5 “Common format for IED confi guration data”. He is also member of the IEEE-PSRC subcommittees “Relay Practices” and “Relay communication”. He published over a dozen papers at the major relay conferences in North America and is member of the Georgia Tech Protective Relaying Conference Planning Committee.

Presentation Abstract: With the growing amount of multifunctional numerical relays in the substations the management of the protection settings and confi guration data faces new challenges. This relays are no longer standalone devices but integrated and exchanging information with diff erent systems (SCADA-System, Equipment Monitor System, Protection System, Metering System, Wider Area Protection and Monitoring Systems, etc.). These multifunctional relays are known as intelligent electronic devices (IEDs) in the industry.

An electromechanically relay had only view settings and a very limited and specialized functionality. The overall protection system was built by the use of several individual relays which were connected via a wring inside of a panel or substation. This setup was seldom changed after commissioning and the settings and confi guration was documented by drawings and paper records.

IED’s on the other side have more than hundreds and in some case thousands of settings. This is the result of integrating many protection function into a single devices as well as making it possible for the user to adjust and customize the relay for special applications. The use of modern IED’s allow that the classical copper wiring and external control hardware becomes more and more replaced by internal relay logic and communication between the protection and control components. This new features of multifunctional numerical relays off ers a much larger functionality and a high degree of fl exibility and adaptability to a much lower cost as compared to electromechanical and electronic relays.

As protection and control functionality becomes more and more replace by software and its correct confi guration, it introduced the inherent problem of any software that the software may not be correct and has to be revised during the lifetime of the system with a new software version for the diff erent components of the system. This is well known and accepted in the PC industry but has serious consequences for protection and control applications in the power system. In addition, during the lifetime of an IED settings itself will have to become changed because of new requirements. It requires a very rigorous management of the settings and confi guration data throughout the lifetime of the protection system to guarantee the correct and up-to date settings and confi guration inside of all components of the protection and control system.

This paper will report on the ongoing work in the CEATI Project PCTF IFP 14.02 “Generic Multifunctional Protection Relay Settings Database and Data Management”. In the project the requirements for an IED settings database and data management system will be defi ned and relevant data will be identifi ed which are needed to enable the creation and maintenance of setting and confi guration fi les for IED’s. In addition the functionality of the Data Management system will be defi ned.


Generic Requirements for Multifunctional Protection Relay Settings Database and

Data Management - Juergen Holbach, Quanta Technologies



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Challenges with Cost/ Benefi t Analyses for “Green“ and “Brown“ Field Projects Design Implementing IEC 61850 Protocol – Deepak Maragal, New York Power Authority

Bio: Deepak Maragal is a Protection & Control Engineer at New York Power Authority (NYPA) specialized in IEC-61850 and electro-magnetic transient studies. His areas of research interests include Adaptive reclosure, Synchrophasor applications, Power system protection & co-ordination studies, non invasive inspection & condition monitoring systems for substation equipment. Deepak graduated Bachelors in Electrical & Electronics Engineering from National Institute of Technology, Surathkal, India in 2003. He received Masters and PhD degrees in Electrical Engineering in 2007 & 2013 from Polytechnic Institute of New York University. His past work experiences include R&D Engineer at NYPA and electrical engineer at Indian Oil Corporation Limited. He is a member of IEC working group-10 and IEEE-PSRC committees.

Presentation Abstract: TBA



Session 2: IEC 61850 ApplicationsIEC61850 is an important new international standard for substation automation that will have a

very signifi cant impact on how electric power systems are designed and built in the future. Use

of this standard will enable incorporation of much higher levels of functionality, with potential

to signifi cantly reduce the implementation costs of substation automation, and in turn positively

impact the system operating and maintenance costs, reduce outage response time and improve

the overall quality of power. This session is designed to share current experiences with IEC 61850

applications.

Practical Example Testing Protection Scheme Performance, Based on IEC 61850 – Nestor Casilla, Doble Engineering

Bio: Nestor Casilla has 28 years of diverse background in power engineering. His expertise includes 17 years within the power generation, transmission and distribution system of Oil Companies in Venezuela and 11 years as Consultant Engineer working as Protection Application Engineer and doing Protection Coordination Studies. As Principal Protection Applications Engineer with Doble Engineering Company he works as Technical Support for the clients in US, Canada and Latin America, training an average of 150 technical and engineer per year in application of the Doble Power System Simulation F6150, evaluating diff erent protection schemes, protection scheme based on IEC 61850; as well as participated as speaker at Technical Conferences of CIGRE, IEEE, Doble Engineering and utilities’ Technical conferences in Colombia, Chile, Peru, Brazil, Puerto Rico, India, USA and Venezuela.

Presentation Abstract: In this paper Doble Engineering will present practical examples testing protection scheme based on IEC 61850, sensing protection function operation with GOOSE messages, simulating GOOSE messages to test IED logic for reclosing and Breaker Failure function, testing Mergin Unit performance, testing the IED in simulation mode based on Ed 2 of the standard.

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Bio: Matt Efremov is a Senior Protection and Control Specialist at Hydro One Inc. He graduated from Ss Cyril and Methodius University in Skopje, R. Macedonia in 1996, with a B.Eng. degree in Electrical Engineering. He has 15 years of experience in electric power industry. He has been working in P&C Design department at Hydro One since 2005. Matt’s fi eld of interest is SCADA systems and substation communication and automation.

Presentation Abstract: Over the last decade, Hydro One Inc. has been faced with a steady increase in new generation and goad connections in the Bruce Corridor, in western Ontario. Hydro One’s Bruce Remedial Action Scheme (B-RAS) protects the high voltage transmission circuits connected to Bruce-Power Nuclear Generation against transient instabilities, thermal overload, and excessive Bulk

Electrical System (BES) voltage declines, by performing a set of control actions such as generation and load Rejection, and reactor tripping based on contingency detection at local and remote stations. The system is an easily expandable, verifi able, maintainable and highly reliable that is engineered using off the shelf substation hardened equipment. B-RAS is based on centralized logic architecture and for eff ective operation relies on fast, dependable and secure wide-area communication. Contingencies are detected at various substations and communicated to the centralized Logic Processing Units (LPU) via IEC 61850 GOOSE messaging. GOOSE messaging between substations is enabled by bridging Ethernet networks over the company SONET network to meet this communication requirement. The LPUs are confi gured in a two-out-of-three voting scheme to provide highly reliable means of computing very large matrices. The outputs are produced based on selections made by the operators and contingencies detected at various substations.

This paper explores innovative Ethernet network topology and technology for communication of contingencies from remote substations to the centralized LPUs. It will demonstrate use of Virtual Local Area Networks (VLAN) for traffi c engineering and separation of protection and SCADA traffi c. Additionally, it demonstrates use of Layer 2 Tunneling protocol over the SONET system for establishing GOOSE communication links between substations. Data from in lab testing and real installation measurements will be present to demonstrate the performance, reliability and cyber-security of this method.


Special “Power System Integrity Protection” Using IEC 61850 Communication

Protocol and New VLAN Architecture - Matt Efremov, Hydro One



Bio: Chan Wong received his BSEE and MSEE from Tulane University and his Ph.D. in Automotive Engineering from the Clemson University International Center for Automotive Research (CU-ICAR). Chan works as a senior engineer at Entergy Transmission Standards Group and also serve as the Transmission Engineering liaison in the Entergy Technology Council. Currently, he is leading the research and development on IEC 61850 Multivendor Eff ort in which his team works closely with several research institutes, IEC 61850 Subject Matter Experts, and other disciplinary groups within Entergy. In addition, Chan is an active member and leader in multiple professional organizations. He is the Chair of the New Orleans IEEE PES Chapter, Organization Committee Chair of IEEE USA Student and Young Professional Conference 2016 and Organization Committee member for IEEE Photovoltaic Specialist Conference

2015. Recently, he was invited to be the Board of Advisor of the Tulane Physics and Engineering Department.

Presentation Abstract: This paper presents the challenges and experience from developing a multivendor test lab to deploying a data acquisition system for a pilot substation. One of the main benefi ts of implementing the protection system based on IEC 61850 is to be interoperable with Intelligent Electronic Device (IED) from diff erent vendors. Before a full implementation of the IEC 6180 system to a substation, a multivendor IEC 61850 lab was created to integrate the IEDs such as merging unit, relay, Human Machine Interface (HMI), communication switches and etc. to 1) ensure the interoperability between vendors, 2) train internal engineers on the new hardware and software and 3) serves as the open testing platform for vendors to meet at one location to test and integrate their products with others. Currently, four relay vendors, two testset vendors and one fi ber duct vendor are collaborating with Entergy to provide products and technical support. In addition, this lab works closely with an independent power research institute to share fi ndings and results, enhancing the learning/debugging process before deploying the system to the pilot substation. IEC 61850 subject matter experts were invited to serve as the project’s Board of Advisors.

Entergy Experience with IEC 61850 Implementation & Demonstration of a Test Relay Panel

for IEC 61850 Application - Chan Wong, Entergy

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Effi cient Testing of IEC 61850 Based Digital Substations – Alex Apostolov, Omicron

Bio: Dr. Alexander Apostolov received MS degree in Electrical Engineering, MS in Applied Mathematics and Ph.D. from the Technical University in Sofi a, Bulgaria. He has 40 years’ experience in power systems protection, automation, control and communications. He is presently Principal Engineer for OMICRON electronics in Los Angeles, CA. He is IEEE Fellow and Member of the Power Systems Relaying Committee and Substations C0 Subcommittee. He is past Chairman of the Relay Communications Subcommittee, serves on many IEEE PES Working Groups and is Chairman of Working Groups C2 “Role of Protective Relaying in Smart Grid”.

He is a member of IEC TC57 working groups 10, 17, 18 and 19 and Convenor of CIGRE WG B5.53 ”Test Strategy for Protection, Automation and Control (PAC) functions in a full digital substation based on IEC 61850 applications” and member of several other CIGRE B5 working groups. He is Distinguished Member of CIGRE. He holds four patents and has authored and presented more than 400 technical papers. He is IEEE Distinguished Lecturer and Adjunct Professor at the Department of Electrical Engineering, Cape Peninsula University of Technology, Cape Town, South Africa. He is Editor-in-Chief of PAC World.

Presentation Abstract: The wide spread development and implementation of IEC 61850 based substation protection, automation and control systems has convinced the industry of the benefi ts of this communications based technology and is expanding into a wider use of digital substations. The paper fi rst describes the concept of the digital substation based on fi ber optic interfaces to non-conventional current and voltage sensors or merging units. Process Interface Units (PIU) supporting IEC 61850 GOOSE and sampled values eliminate hardwired interfaces to the multifunctional devices or central substation computer running the diff erent protection, automation and control functions.

This approach off ers some signifi cant benefi ts that are described in the paper. At the same time it is raising a lot of issues related to the testing of devices and systems based on the standard. The main reason is the replacement of the hardwired interfaces between the protection IEDs that work together in diff erent protection, automation and control schemes with communications messages. While many specialists know how to test conventional hard wired systems and how to isolate them using test switches, they don’t feel comfortable with the challenge of IED isolation in a pure communications based system. The paper describes the testing features defi ned in IEC 61850 Edition 2 and presents innovative methods for their testing that are not possible in conventional systems.



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Session 3: Arc Flash MitigationThe goal of this conference session is to discuss the protective relaying techniques designed

to minimize the fault clearing times, yet maintain the selective coordination with downstream

protection for external faults.

Bio: Jay Wehrstedt, P.Eng, has played the role of Senior Plant Engineer (Electrical) at Ontario Power Generators, Central Operations (Small Hydro Group) since 2009. His responsibilities focus on arc fl ash, temporary and station grounding, plant condition and engineering risk assessments, generator condition, as well as assessment and equipment failure investigations. The projects include work on SCADA modernization, power output and grounding system upgrades.

Presentation Abstract: This presentation with discuss OPG Inc. Hydro-Thermal Operations and the organization’s general approach to the Arc Flash Program. This is a small hydro approach to planning and executing the arc fl ash program. Topics to be discussed include a Roadmap, software, labels and limitations, drawings, fi eld settings and on-site assessment, development of concise arc fl ash guidelines, simulations, verifi cations and results, arc fl ash reduction, barriers and procedures, training – engineering, trades and operators, results and benefi ts beyond arc fl ash, as well as documentation.

Ontario Power Generation’s Approach to Identifying and Mitigating Arc-Flash Hazards

- Jay Wehrstedt, Ontario Power GenerationS

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Bio: Baldwin Yeung, a Project Manager with Leidos Engineering, LLC, has nearly ten years of experience in distribution planning, generation and substation design, coal power plants, combined cycle, and cogeneration plants. His expertise includes arc fl ash calculations, transient overvoltage studies, grounding studies, load fl ow, grounding, short-circuit, motor starting, protective coordination, and transmission protection. Mr. Yeung also has experience in brownfi eld substation breaker and supervisory control and data acquisition (SCADA) replacements. He has designed new combined-cycle plants and air quality control system upgrades to existing power plants. Mr. Yeung holds a B.S.E.E from the University of Illinois Urbana – Champaign and is a professional engineer in Delaware, New York, and Pennsylvania.

Presentation Abstract: This paper presents how the new Occupational Safety and Health Administration 29 CFR,§1910. 269 (OSHA 269) transient overvoltage (TOV) requirements aff ect a sample investor-owned utility (IOU) client’s current safety approach distance to energized electrical equipment for transmission and distribution system. The new requirement could adversely impact many of the industry’s current work practices as regulations go into eff ect January 31, 2016. It is anticipated that, if a utility solely utilizes the conservative TOV values supplied by OSHA without performing the appropriate an engineering analysis, then working distances will increase to values much greater than current working distances. The distances at high-voltage equipment may increase 50 percent or greater. Thus, prior to the deadline, utilities have the option of using the OSHA stipulation stating that, if the utility performs an engineering analysis using an electromagnetic transient program such as PSCAD or EMTP-RV, the amount of TOV could be reduced and consequently the MAD is decreased.

In 2014, OSHA updated its 29 CFR Parts 1910 and 1926, commonly referred to as the “269 Standard,” which entails implementing new OSHA rules for electric power generation, transmission, and distribution, electrical protective equipment. Specifi cally, OSHA’s update aff ects many electric utilities’ MAD to energized equipment greater than 72.5 kV. As stated in OSHA 269 Paragraph (c)(1)(ii) of §1926.960, OSHA “requires the employer to determine the maximum anticipated per-unit TOV, phase-to-ground, through an engineering analysis or assume a maximum anticipated per-unit TOV, phase-to-ground, in accordance with OSHA Table V-8, which specifi es the following maximums for AC systems.”

Furthermore, if the TOV remains above OSHA’s threshold, mitigation could be evaluated. A signifi cant associated concern is that arc fl ash studies are dependent on TOV distances and consequently values will need to be recalculated to align with the TOV study. In other words, there is a resultant push-pull scenario between TOV and arc fl ash to help shape the future of safety distances to energized equipment. All substations over 69 kV will be needed to be analyzed for TOV and arc fl ash in order to be OSHA compliant.


Arc Flash & Transient Voltage Considerations Based on OSHA 269 - Baldwin Yeung, Leidos



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Session 4: Distributed Generation (DG) & MicrogridsThe session is intended to provide information about issues and utility experiences with

integration of DG to transmission and/or distribution systems, as well as issues and technical

requirement for operation of autonomous, but system connectible microgrids.

Bio: Mansour Jalali has over 23 experiences in research, design, commissioning and Training of protection and modern substation automation application. He has been involved in deployment of numerous world class protection, automation and IEC61850 based system in North America and worldwide. Mansour specialize in Transmission and generator protection applications, he has extensive experience in conducting, power system, protection application and IEC61850 training for utility and industrial customers around the world. He is active, member of IEC-TC57, working group 10, signor member of IEEE power system group, active in the several working group in IEEE PSRC and member of Cigre. He is currently fi nishing his PHD research in the area of PMU application in the distribution network in the University of Western Ontario, holds an M.A. Sc. Computer & Electrical Engineering, University of

Waterloo, ON Canada as well as a B.Sc., Electrical Engineering, University of Science & Technology, Tehran.

Evaluation of Bidirectional Digital Tap-Changer Controllers for Voltage Regulation in Distribution

Systems with DG - Mansour Jalali, Kinectrics

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Presentation Abstract: For more than 20 years, utilities have been using regular tap-changer control relays to regulate the voltage of the transformer station and primary distribution feeders. The operating principle of conventional tap-changer control relays is based on the radial structure of distribution networks. However, these relays are not designed to manage low voltages and reverse power fl ows that may occur due the presence of Distributed Generation (DG). Therefore, it is essential to evaluate the performance of tap-changer control relays in distribution systems with high penetration of DG. In this study, a benchmark distribution system has been developed in Real-Time Digital Simulator (RTDS) to conduct closed-loop testing on a new digital tap changer control relay. The real-time simulation allows for the simulation of realistic scenarios such that the performance of the bidirectional relay can be thoroughly evaluated in the presence of DG. The paper also discusses the issues associated with conventional voltage regulation schemes in the presence of DG, and potential solutions are described.

Bio: Minoo Shariat-zadeh received her B.Sc. degree in electrical engineering from Azad University of Tehran in 1995. She is a research associate at the Smart Microgrid Applied Research Team (SMART) within the Centre for Applied Research and Innovation of British Columbia Institute of Technology (BCIT) in Vancouver, Canada. She functions as a team leader and participant; and designs, plans and conducts Smart Microgrid projects, renewable energy resources integration, power automation systems and substation automation systems. She has worked in manufacturing, consulting engineering fi rms, and R&D for over 19 years. She is a member of Association of Professional Engineers and Geoscientists of British Columbia (APEGBC). Her main research interests are Smart Grids, Smart Microgrids, Renewable energies and Control & Automation systems.

Presentation Abstract: Energy OASIS (Open Access to Sustainable Intermittent Sources) is a demonstration facility developed by BCIT and BC Hydro, and funded by the Government of Canada and BC Hydro. Energy OASIS is the next chapter in the evolution of BCIT/ BC Hydro’s Smart Microgrid on the Burnaby Campus of BCIT. The project aims to study the impact of clustered Electric Vehicle Fast Charging (EVFC) on utility feeders. This facility comprises of arrays of Solar Photovoltaic panels, a Lithium-Ion Battery Energy Storage System, a Power Conversion System, Microgrid loads including DC EVFC and EVSE stations, System Protection and Control, an Energy Optimization and Management System, Networking and Data communication and also a web-based mobile application. Energy OASIS is designed to demonstrate and validate the blueprint of Canada’s future EV Charging Infrastructure, where charging services could be provided to Electric Vehicles with minimal impact on the power quality or service reliability of the electricity grid which feeds it. It is also designed to optimize its charging services based on the total cost of available energy sources, which could be from one or more of the utility feed, energy storage system and/or the Photovoltaic installation. Energy OASIS is integrated with BCIT’s internal distribution network, and then through that with BC Hydro’s downstream network .Given the need to have access to the available power on the utility feeder, interconnection of such a system with the utility grid is critical. Such an interconnection needs to meet the applicable technical requirements of IEEE-1547 Standard (Standard for interconnection of distributed resources with Electric Power Systems) as well as jurisdictional requirements set by BC Hydro for reliable operation and safety. Energy OASIS needs to demonstrate that its operation will not adversely impact the reliability, safe operation and maintenance of interconnecting networks. These requirements aim to ensure safe isolation for maintenance, islanding, grid-tied operation, protection, fail safe, transient stability and harmonics propagation. Solutions to meet these requirements are implemented as part of the protection and control system for Energy OASIS and validated through series of system functional testing. Analysis were conducted to prove full compliance with these requirements and results are then captured in an Interconnection Agreement document concluded by relevant stakeholders. This presentation provides an overview of Energy OASIS, followed by a discussion of the technical requirements for interconnection and measures that are taken to comply with the applicable standards and codes.

BCIT’s Smart Microgrid Initiative & Energy Oasis Project - Minoo Shariat-Zadeh, British Columbia Institute of Technology (BCIT)

Evaluation of Bidirectional Digital Tap-Changer Controllers for Voltage Regulation in Distribution

Systems with DG - Mansour Jalali, Kinectrics (continued)

Bio: Ashish Upreti is a protection engineer in the engineering services division at Schweitzer Engineering Laboratories, Inc. in Pullman, Washington. He received his B . S . E . E . and M . S . E . E . degrees from the University of Idaho. He is a registered professional engineer in the state of Washington, member of the IEEE and has experience in the fi eld of power system protection and automation, including power management schemes for large -scale industrial power plants.

Presentation Abstract: Islanding detection and decoupling needs are becoming a crucial part of power system operations due to the increasing penetration of distributed generation in utility power

systems and the self-sustaining operational capabilities of industrial power systems. This paper presents a complete solution for determining a power system islanding condition using state-of-the-art technologies such as synchrophasors and microprocessor-based relays. This solution combines three independent schemes working together in a coordinated fashion to reliably detect an islanding condition under all power import and export scenarios with reliable detection speeds. The solution has been tested using real-time digital simulation in a closed-loop environment. The key objective of this solution is to provide the most reliable and aff ordable islanding detection and decoupling system (IDDS) to utility and industrial power systems for solving the critical challenges of today and tomorrow. This paper presents the functionality, validation, and performance of the IDDS in a simulated model for a real-world application. The schemes are analyzed for speed and reliability in a wide variety of operating scenarios. The eff ectiveness of the overall solution has been tested in a controlled test environment as part of power management system functional testing for a 2 GW microgrid. This solution is currently in service.


State of the Art Islanding Detection and Decoupling Systems for Utility and Industrial Power Systems

- Ashish Upreti, Schweitzer Engineering Laboratories



Bio: Todd Martin is a Relay Application Engineer for Basler Electric Company. He has been employed by Basler for 22 years, with more than 15 years of engineering experience in digital, analog, and fi rmware design for protective relays. Todd received a BSEE and a MBA from the Southern Illinois University at Edwardsville, Illinois.

Presentation Abstract: Electric Utility distribution systems must deal with a variety of non-utility generation in today’s political and policy driven environment. Generation sources from photovoltaic technologies have caused a dramatic increase in inverter based systems in addition to small hydro, diesel, methane, and gas synchronous generator systems. All system types request connection to utility distribution feeders. These generation sources, usually referred to as distributed energy resources (DER), can have both positive and negative eff ects on the utility feeder. This paper will discuss issues often encountered by utility engineers and DER consultants when negotiating protection requirements for intertie protection between the DER and utility grid. The subject matter for the proposed paper will be tutorial/educational in nature based on experience gained working with customers to establish proper protection for given intertie applications. Parallel operation of DER at most utilities has become a part of their distribution operations program where the DER owner and the utility share a mutual interest in successful operation. Safety, security, protection, power quality, etc, are essential to proper operation on both sides of the intertie point.

The presentation will discuss a variety of DER applications including peak shaving, net energy metering, export energy, as well as photovoltaic (stand-alone commercial installations, and interconnected residential). The presentation will also discuss issues and impact of the addition of DER to a radial feeder circuit, including increased fault duty on circuit breakers, infl uence on existing protection systems, types of transformer connections, power quality, islanding utility load and system restoration. The discussion will also visit the continuing work on IEEE P1547 and recent amendments found in IEEE 1547.a and 1547.1a that impact the ability of utilities to operate with high penetrations of inverter based generation.

Protection Considerations for Installation of Distributed Energy Resources

- Todd Martin, Basler Electric Co.

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Bio: Dr. Alexander Apostolov received MS degree in Electrical Engineering, MS in Applied Mathematics and Ph.D. from the Technical University in Sofi a, Bulgaria. He has 40 years’ experience in power systems protection, automation, control and communications. He is presently Principal Engineer for OMICRON electronics in Los Angeles, CA. He is IEEE Fellow and Member of the Power Systems Relaying Committee and Substations C0 Subcommittee. He is past Chairman of the Relay Communications Subcommittee, serves on many IEEE PES Working Groups and is Chairman of Working Groups C2 “Role of Protective Relaying in Smart Grid”.

He is a member of IEC TC57 working groups 10, 17, 18 and 19 and Convenor of CIGRE WG B5.53 ”Test Strategy for Protection, Automation and Control (PAC) functions in a full digital substation based on IEC

61850 applications” and member of several other CIGRE B5 working groups. He is Distinguished Member of CIGRE. He holds four patents and has authored and presented more than 400 technical papers. He is IEEE Distinguished Lecturer and Adjunct Professor at the Department of Electrical Engineering, Cape Peninsula University of Technology, Cape Town, South Africa. He is Editor-in-Chief of PAC World.

Presentation Abstract: TBA.

The Future of P&C Systems for Large Electric Power Generators and Their Auxiliary

Systems - Alex Apostolov, Omicron

Session 5: Generation Related TopicsThis session is intended to provide information about the utility practices and new developments

in design of protection and control systems for large electric power generators and their auxiliary

systems.

Bio: Kirk Chen graduated from the University of Portland with a BSEE. He is a registered PE in the state of Washington, and has worked for the US Army Corps of Engineers since 2007. Kirk specializes in designing plans and developing specifi cations for upgrading protection and control systems for large power-train equipment as well as integrating new equipment into existing systems. This includes developing relay settings and commissioning plans for generators, transformers, switchyards, and transmission line systems.

Presentation Abstract: The US Army Corps of Engineers owns and operates 75 hydroelectric powerhouses throughout the United States. The vast majority of hydroelectric generators have had their protection systems upgraded to digital multifunction relays. These relays contain a wide variety of protection elements, standard and customized, which must be selected for use as desired. Standard and customized multifunction relay protection elements that are commonly used include: • 21 (Distance Backup) • 24 (V/Hz) • 25 (Synch Check) • 27 (Undervoltage) • 32 (Directional Power) • 40 (Loss-of-Field) • 46 (Neg Seq Overcurrent) • 50/51 (Overcurrent) • 50BF (Breaker Failure) • 59 (Overvoltage) • 64G (Generator Ground) • 64F (Field Ground) • 78 (Out-of-Step) • 81 (Frequency) • 87 (Diff erential) Over the years, the US Army Corps of Engineers has also developed application guidance based on lessons learned for selecting, coordinating, and setting various elements. The presentation will summarize commonly used protection elements for hydroelectric generators and lessons learned that resulted in recommended settings.

Hydroelectric Generator Protection Upgrades: Common Practices & Lessons

Learned - Kirk Chen, United States Army Corps of Engineers (USACE)


Protection Trips & Oscillations on Generator Exciter/Governor Upgrades in New York

Power Authority: Experiences & Solutions - Deepak Maragal, New York Power Authority



Bio: Thomas R. Beckwith received a Bachelor of Science degree in Electrical Engineering (BSEE) from Case Western Reserve University and a Master of Business Administration (MBA) degree from the University of South Florida. He is a member of the IEEE PES and the IEEE IAS. Tom has served on working groups in the Power System Relaying Committee since 1972. He was the chair of the working group that produced IEEE C37.90.1-2012 Standard for Surge Withstand Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus. Tom is a co-inventor of a 1993 U.S. patent on a Multifunction Protective Relay System. He is presently CEO of Beckwith Electric Co., Inc. and previously held positions as Production Manager, Vice President of Sales and Marketing and President of the Beckwith Engineering Services and Training (BEST) division. Since 1970, Tom has served as R&D Design Engineer, Systems Engineer, and Field Commissioning Engineer.

Dr. Murty V.V.S. Yalla has been with Beckwith Electric since 1989 and presently holds the position of President. He received BSEE from JNTU, Kakinada, India in 1981; MSEE from Indian Institute of Technology (IIT), Kanpur, India in 1983; and a Ph.D. in EE from the University of New Brunswick, Canada in 1987. From 1988 to 1989, Dr. Yalla taught and conducted research on digital power system protection at Memorial University in Newfoundland, Canada. He has published several research papers in international journals on digital protection. He holds fi ve U.S. patents in the areas of digital controls and protective relays.

Dr. Yalla is the Deputy Technical Advisor to the United States National Committee (USNC) of the International Electrotechnical Commission (IEC, Geneva, Switzerland) Technical Committee 95 (TC 95). He is a U.S. delegate and the chairman of the IEC TC 95 MT4 which developed a number of IEC standards. He was a U.S. delegate to the International Council on Large Electric Systems (CIGRÈ, Paris, France) for several Working Groups. He was a member of the North American Electric Reliability Corporation (NERC) System Protection and Control Subcommittee (SPCS).

Presentation Abstract: Case studies of a number of live motor bus transfers at power generating and industrial facilities are presented and analyzed with a new transfer metric, based on the ratio of the aggregate peak torque after the transfer to the aggregate load torque prior to the transfer. The methodology and calculation of the results are presented. Dynamic conditions that occur during bus transfer are discussed, linking their relevance to the application of both the existing ANSI C50.41 Standard criteria and the new torque-based criteria. The industry ANSI C50.41 Standard criteria, calculated at the instant of transfer, presently used for determining the success of a completed transfer, are discussed and critiqued. In particular, the per unit Volts per Hertz metric is discussed in light of the results of the new torque ratio metric.

The induction motor torque is calculated using the time domain samples of voltage and current signals collected from various live transfer cases from facilities around the world. The time domain samples in COMTRADE format from oscillograph fi les are used in calculating real power drawn by the motors. Assuming copper losses, iron losses, friction and windage losses are negligible, the induction motor torque can be approximated by the air gap power divided by the synchronous speed.

The calculation method is also verifi ed with Matlab simulation of a representative induction motor.

A New Performance Metric for Motor Bus Transfer Relays at Generating

Plants - Murty Yalla & Tom Beckwith, Beckwith Electric

Bio: Deepak Maragal is a Protection & Control Engineer at New York Power Authority (NYPA) specialized in IEC-61850 and electro-magnetic transient studies. His areas of research interests include Adaptive reclosure, Synchrophasor applications, Power system protection & co-ordination studies, non invasive inspection & condition monitoring systems for substation equipment. Deepak graduated Bachelors in Electrical & Electronics Engineering from National Institute of Technology, Surathkal, India in 2003. He received Masters and PhD degrees in Electrical Engineering in 2007 & 2013 from Polytechnic Institute of New York University. His past work experiences include R&D Engineer at NYPA and electrical engineer at Indian Oil Corporation Limited. He is a member of IEC working group-10 and IEEE-PSRC committees.

Presentation Abstract: TBA

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Bio: Mike Collum received his BSEE degree from Mississippi State University and has over 25 years of Protection and Control experience in the Electric Power Industry. Mike began his career at South Mississippi Electric Power Association where his responsibilities included the coordination of all activities relating to the design and implementation of protective relaying schemes, transmission planning, and daily operational planning. In 1997, Mike joined Schweitzer Engineering Laboratories where he is currently a Region Technical Manager for the South Eastern United States. His work at SEL includes product support, customer training, teaching in SEL University, and coordination of regional activities. He is a registered professional engineer in the state of Mississippi and a member of Mississippi Engineering Society.

Presentation Abstract: SEL is proud of our long heritage and proactive methods we use to keep customers informed about the products they own. This presentation will discuss fi rmware quality methods utilized in our development cycle, processes we use to monitor our installed base of products, how SEL decides when customers require notifi cations, and how we ensure fi rmware integrity. We will also discuss methods useful to help decide when to upgrade fi rmware. Additionally, when new fi rmware is required, we will discuss the pros and cons of remote fi rmware management for protective devices and how to ensure the relay is providing adequate fault protection after the new fi rmware is installed.

Relay Firmware Updates - SEL Perspective - Mike Collum, Schweitzer Engineering Laboratories

Session 6: Relay Firmware UpdatesUnlike many consumer devices where fi rmware changes may never occur during their economic

lifetime, protective relays are subject to periodic fi rmware changes intended to correct operational

defi ciencies, address security issues or add new features to the relays. This session will provide

information on the eff ective ways of managing fi rmware changes, such as which are mandatory

vs discretionary, function testing requirements, eff ective communication and record keeping,

etc. from both utility and relay manufacturers perspectives.

Bio: Steve Greey is presently with S&C Electric Canada as Director, Smart Grid Applications. He is a Professional Electrical Engineer who has worked in the electrical industry for over thirty years. His career started at Westinghouse as an Application Engineer after which he joined S&C Electric Canada in 1980. In 1995, he formed his own company Greey Electrical Products which provided SCADA systems to electric utilities, including major utilities, such as Toronto Hydro. In 2006 he again began working with S&C Electric to promote their Smart Grid solutions across Canada.

Presentation Abstract: As greater numbers of electric vehicles and PV panels connect to the electrical distribution system, reliability requirements drastically increase. To meet these increased reliability requirements many utilities have added large numbers of smart devices, often connected through smart systems, to their distribution system. Adding a management system can save the utility both money and time plus increase the overall value of these systems and devices.

A Management System for Electrical Distribution System Smart Devices and Smart

Systems - Steve Greey, S&C Electric


Testing Procedure for Relay Firmware Update - Milton Quinteros & Hussain Al Marhoon, Entergy



Bio: Nagendrakumar Beeravolu, Ph. D. was born in 1986, in India. He completed his bachelors of technology degree in Electrical and Electronics Engineering from JNTU, Hyderabad, India in 2007 with distinction. He fi nished his Masters and PhD in Electrical Engineering from the University of New Orleans in December 2010 and December 2013 respectively. He worked as an intern in summer 2009 at Entergy Services Inc., and worked on several research projects for the same company as Research Assistant. Currently, Dr. Beeravolu is working as a consultant Power Systems Protection Standards Engineer for Design Basis, Entergy Services Inc. through IK Power System Solutions Inc. His areas of interests are real time simulation studies, EMTP modeling, voltage stability, power system protection and relaying, and protection relay testing and commissioning.

Implementation of Travelling Wave Fault Location Using SEL-411L Transmission Line Protection Relays

- Nagendrakumar Beeravolu, IK Power System Solutions & Sal Jadid, Power Engineering Consultants

Bio: Milton I. Quinteros, Ph. D. completed his Bachelor of Science in Electrical Engineering in May 2007, and his Master of Science in Electrical Engineering in May 2009 from the University of New Orleans. He fi nished working on his Doctoral degree at the same University in December 2014. He worked as a Research Assistant in Electrical Engineering under various research grants in the University of New Orleans. He also worked for two years as contractor Engineer for IK Power Systems Solutions Inc. He was Adjunct Professor for Escuela Superior Politecnica (ESPOL) in May 2010 and Adjunct Professor for the University of New Orleans in Summer 2011, and Spring 2012. He is currently working in Entergy Services Inc. as Engineer II in the Standards and Design Group. His research areas include Digital Telecommunications, Data Base design, Neural Networks, Digital, and Communications for Power System Protection and Automation.

Hussain Al Marhoon, Ph. D. completed his associate diploma in Electrical Power Engineering Technology from Jubail Industrial College, Jubail, Saudi Arabia in 2004 with fi rst honor degree. He received his B.S. in Electrical Engineering from the University of New Orleans in December 2008 with Cum Laude honor. He earned his M.S. and Ph.D. in Electrical Engineering from the University of New Orleans in May 2011 and August 2015, respectively. Dr. Al Marhoon is currently a Transmission System Engineer with Entergy Services, Inc. Transmission Protection Department. His areas of interests are power systems simulation, on-line stability and security assessments, and power systems control and protection.

Presentation Abstract: Utility companies devote considerable eff orts and money to acquire, update, test, and distribute fi rmware of substation Intelligent Electronic Devices (IED’s) such as multifunction microprocessor-based relays. Properly testing, documenting and approving fi rmware versions from various relay manufactures is a diffi cult process due to the many possible changes in the digital relay functions and their control logics. However, the implementation of multi-option relay design standards for more than one vendor along with standardized relay setting templates and corresponding test plan ease the process of testing and approving relay fi rmware updates. This presentation shows a fi rmware testing procedure that uses an automated test plan based on standard protection designs to ensure uniformity of the fi rmware update test plan, and to keep track of the eff ectiveness and reliability of each of the protection functions and control logics of the relay after the fi rmware update. The automated test plan procedure minimizes the time to test the changes in the device fi rmware and reduces human error during the testing process. In addition, we also present the steps involved in producing new standard templates, locking down the fi rmware with manufacturer, and the eff orts to store and distribute the fi rmware.

Session 7: New & Emerging TechnologiesThe information presented in this session is intended to introduce new technologies, either

available or in various stages of development, that can be used for such applications as

detection of high-impedance faults, fully automatic feeder restoration, accurate fault location,

micro-grid operation, and other technologies aimed at improving power system security and

automation.

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Sal Jadid holds a Bachelor of Science degree in electrical engineering and a Master of Science degree in Engineering Management from the University of New Orleans. He earned his Ph.D from the University of Idaho in Electrical Engineering specializing in power systems. He started his career at Entergy as an electrical engineer in the engineering services protection group, where he was responsible for fault studies and relay coordination and settings from low voltage to 500 kV. In 2006, he joined Schweitzer Engineering Laboratories, Inc. as a fi eld application engineer. He has also held the position of lead product engineer in the research and development transmission group. Currently he is working with Power Engineering Consultants where he provides various services in power system protection and control.

Presentation Abstract: Traveling wave based fault detection technology has been emerging from long time. The advancement in the technology and manufacturer integration allowed Entergy to implement this methodology in modern microprocessor relays improving accuracy and reducing cost of ownership. This paper will present the strategy chosen by Entergy to implement the traveling wave technology. Entergy adopted the SEL-411L relay as one of the relaying option to protect their transmission lines. These relays have Traveling wave fault location algorithm to report the Distance to fault. Entergy has applied these relays on series compensated transmission lines and some other short transmission lines where the simple impedance based protection have limitations. Entergy performed some testing with the Real Time Digital Simulators and also performed open loop testing to demonstrate the advantages of Travelling Wave DTF algorithm. This paper will also present some of the results of this technology and will also discuss the advantages and the challenges of the Travelling Wave Fault Detection.

Implementation of Travelling Wave Fault Location Using SEL-411L Transmission Line Protection Relays

- Nagendrakumar Beeravolu, IK Power System Solutions & Sal Jadid, Power Engineering Consultants (continued)

Bio: John Puryear’s professional experience includes vulnerability assessment of nuclear power facilities, impact analysis for industrial hazards, industrial drop analysis, industrial accident evidence gathering, consequence modeling for root cause analysis, blast-resistant structural design, including buildings, infrastructure and vehicles, research in extreme loading events, including blast, aircraft impact and progressive collapse, as well as vulnerability assessment and security engineering for buildings and infrastructure He hold a M.S., Civil Engineering from the University of Texas, and a B.S. Mathematics and Philosophy, Wheaton College.

Presentation Abstract: Operators of complicated systems are continually improving data acquisition and interpretation to draw unconventional inferences about system performance. These advances raise the possibility of power lines being used as sensors with a range of potential applications. One possible application is intrusion detection. Metal theft is a persistent threat to utility assets, and the capability of sensing an intruder anywhere along the line would assist in apprehending the intruder and deter future intrusion. In principle, the power line can function like existing electromagnetic devices that sense intrusion. For example, some electromagnetic fi eld (EMF) devices feature a pair of buried leaky coax cables connected to a processing unit. Intrusion into the EMF induced by the cables is identifi ed by the processing unit, which signals an alarm. Improved data acquisition would take the role of the processing unit in the case of power lines. The viability of using transmission lines for intrusion detection has been established through numerical analysis. Specifi cally, a fi nite element model including an energized transmission cable and intruding truck has been used to calculate the change in cable current density due to the presence of the truck. Given suffi cient sampling rate and appropriate algorithmic monitoring of operational data, this change in current density may serve as a signal of the intruding truck’s presence near the line. In this presentation, the author will (a) provide an overview how power lines could be used for intrusion detection, (b) discuss the fi nite element model which serves as proof of concept, (c) detail the signals that must be identifi ed in operational data for a truck intrusion to be detected, and (d) identify other applications for this approach, such as structural health monitoring.

Transmission Lines Corridors Intrusion Detection Based on Monitoring EMF - John Puryear, ABS Consulting

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Our fall 2015 Protection & Control Conference is organized with the support of CEATI’s Protection &

Control Task Force composed exclusively of electrical utility representatives from 21 participating

utilities:

The CEATI Program Model provides electrical utilities with a cost-effective vehicle for sharing experiences and addressing issues pertinent to their day-to-day operations, maintenance and planning. In addition to serving as a strong technical resource tool through 18 focus areas across generation, transmission,

distribution and utilization, our participants periodically support the development of industry-open conferences and training workshops. This is where we invite you to come join us.

Our industry-open events bring manufacturers, service providers, consultants, and world-renowned technical experts together with some of the key-decision makers in the industry. These events present excellent opportunities for targeted networking and exposure to potential clients, placing you directly in front of the end-users of your company’s products and services.

Why Partner with CEATI Events?

THANK YOU

TO OUR EXHIBITORS:

and our Media Partner:

Documents

3rd Annual Protection & Control Conference › ... › PC2015 › files › PCTF2015_Brochure.pdf · 2015-11-16 · CEATI’s 3rd Annual Protection & Control Conference: November