8 Hours (1 Day)
PDHs: 8

M-2001C and M-2001D Introduction

• Modern Control Needs
• Tapchanger Control Basics
• Universality
• Quick Reference Guide
• Physical Features (Com-ports, display, status indicators, user interface, adapter panel connections, Tap position connector)

Application Features:

Transformer LTC / Substation regulators / Feeder regulators

• Required circuitry w/wo LDC / wiring connections
• Timing options – instantaneous vs integrating – sequential / non-sequential / inter-tap TD / pulsed output – inverse time curve
• Line drop compensation (LDC) – Traditional R&X / selectable LDC-Z – setting examples / operational examples – cap bank effects
• M-2001 first house protection – both LDC types
• Backup control application / coordination / wiring / local control
• Reverse power operation – radial feeds vs DG applications / options
• Data logging capabilities – setting / data collection & reading
• Harmonic analysis capability – examples

Control Features:

Communications – protocols

• Alarms / CT/VT phasing / PT correction / line overcurrent inhibit / voltage limiting & runback / voltage reduction / auto inhibit / configurable tap definition /Bias voltage testing feature / paralleling methods / “Keep track” position knowledge
• Common Communication connections – Direct connection / Modem connection / Network connection / RS-485 Network connection / Fiber Optic loop connection

Paralleling Basics:

Paralleling Basics – LTC transformers or Transformer regulator combo / Need for paralleling equipment / Result of inappropriate positions

• Optional Methods – Master/follower / Negative Reactance / Power Factor / Circulating current / ΔVAR (1&2)
• Application problems – station breaker operations / separate sources / different KVA ratings / different impedances / impedance variation between taps / three winding transformers / tertiary loading / local generation
• Connections – testing / settings / trouble shooting

Control setup:

Using Pushbutton Interface

• Using “TapTalk” software – complete review of all settings and configuration
• Using Palmtop software (Data reader function / “TapTalk” function)

Review, Q&A and Evaluation

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8 Hours (1 Day)
PDHs: 8

Theory

Fundamental reliability consideration in the design, manufacturing and application of Multifunction Digital Relays for Transformer Protection

Product & Software Training

• Use and understanding of the S-3300 IPScom Communications Software for M-3311A relay types
• Basic Application and Features
• Control & Field Wiring to relay types
• Protective Element/Diagnostic Testing
• Downloading of relay event and oscillograph records via IPScom Software
• Recommended Periodic Maintenance
• Front panel indications and controls
• Energize the relay and verify Breaker status and other front panel and fail-safe contact conditions.
• Setting the clock, oscillograh recorder SOE recorder
• Installation and downloading of relay settings, oscillograph data and other fault records.

Testing

• Perform relay functional checks and IPScom Metering, CT and VT Phasing Checks Test communication circuits
• Hands-on testing of protection elements
• Review and demo IPSPlot Plus Oscillograph software

Review, Q&A and Evaluation

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16 Hours (2 Days)
PDHs: 16

Theory

Fundamental reliability consideration in the design, manufacturing and application of Multifunction Digital Relays for Generator Protection

Product & Software Training

• Use and understanding of the S-3400 IPScom Communications Software for M-3425A relay types
• Basic Application and Features
• Control & Field Wiring to relay types
• Protective Element/Diagnostic Testing
• Downloading of relay event and oscillograph records via IPScom Software
• Recommended Periodic Maintenance
• Front panel indications and controls
• Energize the relay and verify Breaker status and other front panel and fail-safe contact conditions.
• Setting the clock, oscillograh recorder SOE recorder
• Installation and downloading of relay settings, oscillograph data and other fault records.

Testing

• Perform relay functional checks and IPScom Metering, CT and VT Phasing Checks Test communication circuits
• Hands-on testing of protection elements
• Review and demo IPSPlot Plus Oscillograph software

Review, Q&A and Evaluation

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16 Hours (2 Days)
PDHs: 16

Theory

• Motor Bus Transfer Overall Principle and Applications
• Motor Bus Transfer Conventional Versus Advanced Techniques
• M-4272 Hardware Configuration
• M-4272 Functional & Operational Details

Product & Software Training

• Overall Software Programming using ISScom System Configuration & Settings
• Functional Settings Details
• Waveform Analysis software: ISSplot Configuration and Operation
• ISSLogic Programming
• Equipment Hands-on Training
• Manuel and Automatic Operation Procedures
• Alarms Signals Identification
• Waveform Capture / Data Downloads
• Oscillograph Analysis

Review, Q&A and Evaluation

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8 Hours (1 Day)
PDHs: 8

Product & Software Training

Settings Review

• Regulator Basics
• Basic Setpoints
  • Band Center
  • Bandwidth
  • Time Delay (Forward/Reverse)
• Other Setpoints
  • LDC
  • Voltage Reduction
  • Limits
  • Runback
• Configuration Settings
• Tap Setting
• Alarm Outputs

Programming

• From front panel
• Via TapTalk (Local or remote)
• Via SD Card

Hands-on Workshop

Review, Q&A and Evaluation

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5 Hours
(5 PDHs)

Generators are subject to internal faults, external faults and abnormal operating conditions impressed by turbine and excitation system issues, as well as power system events the generator has no control over but must cope with. False (nuisance) trips are costly as the generator’s output is lost. Inability to trip due to lack of sensitivity, lack of certain protections or deficiencies in protection application may cause severe damage to generators, resulting in prolonged outage and revenue loss, plus increased system stability risk. Achieving the ideal balance of secure and dependable protection involves use of an array of elements that protect the generator for all operating modes: off-line, start up, synchronizing, various levels of power output and when challenged by system faults and anomalies.

• Generator construction and operation
• Grounding and connections
• IEEE standards for generator protection
  • C37. 102, Guide for Synchronous generator Protection
• Generator and power system interaction
• Generator protection element overview
  • Internal faults (in the generator zone)
  • Abnormal operating conditions
  • External faults
• Protection Application Exploration
  • Stator Ground Fault (27TN, 59N, 59D, 64S, 67N, 87GD)
    • Exploration of stator ground fault injection protection sensitivity and security
  • Rotor Ground Fault/Brush Lift Off (64F, 64B)
  • Stator Phase Fault (87G)
  • Turn-to-Turn Fault
  • Phase Unbalance/Open Conductor (46)
  • Overexcitation (24)
  • Abnormal Voltage (59)
  • Phase Fault Backup (21)
  • Field Loss (40)
  • Loss of Synchronism (78)
  • Abnormal Frequency (81-U, 81A)
  • Inadvertent Energizing (50/27)
  • Blown VT Fuses (60FL)
  • Breaker Failure/Pole Flashover (50BF)
  • Loss of Prime Mover (32)
• Tripping considerations and sequential tripping
• Discuss tactics to improve reliability (security & dependability)
• Generator protection upgrade considerations
  • Lessons learned from NE Blackout (2003)
  • Redundancy concepts

Who Should Attend
This course will benefit power plant protection engineers and technicians, as well as power plant operators and protection generalists who desire a deeper background on the subject.

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2 Hours
(2 PDHs)

• Fault Types
• Short-Circuit Calculations
• Calculations and Settings

Who Should Attend
This course will benefit transmission, distribution and power plant protection engineers and technicians, as well as operations personnel protection generalists who desire a deeper background on the subject.

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6 Hours
(6 PDHs)

Building on the base knowledge covered in Generator Protection Fundamentals, calculations for protective elements are developed. Depending on the element, these calculations use nameplate data, system data or a combination of the two. Margin considerations are explored and impacts on element reliability are discussed, as well as element interdependencies with protection and control in the generator zone, local power plant and system.

• 59N – Neutral Overvoltage
• 27TN – Third Harmonic Neutral Undervoltage
• 3Vo – Neutral Bus Overvoltage
• 46 – Negative Sequence Overcurrent
• 87 – Phase Differential current
• 24 – Volts/Hz/Overexcitation
• 50/27 – Inadvertent Energizing
• 51V – Inverse Time Phase Overcurrent
• 21 – Phase Distance
• 50BF – Breaker Failure
• 32 – Directional Power
• 27 – Phase Undervoltage
• 59 – Phase Overvoltage
• 81 – Over/Under Frequency
• 60FL – VT Fuse-Loss Detection
• 40 – Loss of Field
• 78 – Out of Step
• Isync Trip

Who Should Attend
Engineers responsible for developing and/or checking generator protection settings. Testing Technicians who want to obtain a greater understanding of generator protective element testing, especially for impedance-based elements.

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4 Hours
(4 PDHs)

Transformers are subject to internal faults, the effects of external faults and abnormal operating conditions impressed by the power system events the transformer has no control over but must cope with. False (nuisance) trips are costly as the transformer and load are disconnected. Inability to trip due to lack of sensitivity, lack of certain protections or deficiencies in protection application may cause severe damage to transformers, negatively impacting power flows, impacting power quality and compromising stability. Achieving the ideal balance of secure and dependable protection involves use of an array of elements that protect the transformer from prolonged internal faults, excessive through faults and when challenged by power system faults and anomalies.

• Why transformers fail
  • The cost of failures
• IEEE C37.91, Guide for Power Transformer Protection
  • IEEE Devices used in Transformer Protection
  • Transformer Protection Review
  • Transformer Protection Functions
• Explore Protection Functions
  • 87T Phase Differential Characteristic
    • Compensation in Digital Relays
    • Relay Configuration: Winding Arrangement and CT Connection
• Overcurrent based (50, 51, 50N, 51N, 46)
• Through fault protection (TFM)
  • Current Summing & Through-Fault
• Overexcitation (24)
  • Generating plant causes
  • T&D system causes
  • Protection Against Overexcitation – V/Hz versus 5th Harmonic
• Phase Differential (87T)
  • Unique Issues Applying to Transformer Differential Protection
    • CT performance issues (saturation, remnant flux, tolerance, rating)
    • Percentage differential characteristics with variable percentage slopes
    • Internal ground fault sensitivity
    • Restraints for inrush and overexcitation
      • Overexcitation 87T Blocking Restraint – Failure to detect nascent fault
      • Overexcitation Adaptive 87T Pickup Restraint – Detects nascent faults
  • Adaptive restraint for security
  • Point-on-Wave Switching Inrush
  • Cross Phase Averaging
  • Switch-onto-Fault
• High Set Phase Differential (87H)
• Ground Differential (87GD), Restricted Earth Fault (REF)
• Interface and Analysis Software: Desirable Attributes
  • NERC “State of Reliability”
• Elegant Simplicity – Realization of configuration, settings, logic, monitoring

Who Should Attend
This course will benefit transmission, distribution and power plant protection engineers and technicians, as well as operations personnel and protection generalists who desire a deeper background on the subject.

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1 Hour
(1 PDHs)

Building on the base knowledge covered in Transformer Protection Fundamentals, calculations for protective elements are developed. Depending on the element, these calculations use nameplate data, system data or a combination of the two. Margin considerations are explored and impacts on element reliability are discussed, as well as element interdependencies with protection and control in the transformer zone, whether in generation, transmission or distribution.

• Examine CT performance
• Calculate winding “tap” values
• Determine 87T pickup points
  • Determine variable percentage slope breakpoints
  • Determine harmonic restraint values
• Determine 87H pick up
• Determine 87GD pick up
• Determine pick up and time delay settings for 50/51 through fault protection

Who Should Attend
Engineers responsible for developing and/or checking transformer protection settings. Testing Technicians who want to obtain a greater understanding of transformer protective element testing, especially for impedance-based elements.

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3 Hour
(3 PDHs)

Motor Bus Transfer is the process of rapidly transferring sources to a motor bus for planned source switching and unplanned source failure. The rapid transfer allows the process to continue without interruption. To avoid damage to the motors, specialized equipment and methods are employed to cope with the dynamics of motor deceleration, and voltage and phase angle change between the new source and the motor bus. Improper reconnection of the motor bus can cause cumulative or immediate damage to the motors, and result in a process crash.

• Residual Voltage Transfers always thought to be safe even if completed out-of-phase, can cause significant torques on motors, exceeding a 3-phase fault at the motor terminals.
• IEEE C37.96 identifies events that occur or conditions that exist prior to and during transfer where, at transfer initiate, the initial phase angle may be nowhere near zero!
• So at the end of a Residual Voltage Transfer spin down, the close phase angle may be nowhere near zero!
• Research with modeling motors during transfer has proven that in 40% of the cases closing at varied angles, the peak-to-peak torques developed during the Residual Voltage Transfer are higher than the 3-Phase Short Circuit Torques of the motors on the bus.
• This research has revealed that the peak currents in motors during Residual Voltage Transfers are higher than the 3-Phase Short Circuit Currents in more than 60% of these cases.
• This motor modeling research also shows that in 89% of the cases closing at varied angles, the currents during Residual Voltage Transfer are in excess of six times rated current.
• Synchronous In-Phase Transfers may take longer than some arbitrary time limit. Depending on the initial phase angle at transfer initiate, it may take more than 6 or 10 cycles for the motors to rotate back into synchronism.
• Compared to blind Residual Voltage Transfers, these Synchronous In-Phase Transfers are much faster, closing at much higher voltages, at much lower slip frequencies, with closure near zero degrees and low inrush current and torque.
• The 1.33 resultant pu V/Hz transfer criterion in NEMA MG-1, ANSI/NEMA C50.41 and IEEE C37.96 has no correlation to motor torque and actually gives passing grades to severely excessive torques upon transfer.
• Time period transfer criteria, stated in NEMA MG-1, IEEE 666, ANSI/NEMA C50.41 and IEEE C37.96, are arbitrary and would permit severely out-of-phase transfers or conversely may preclude perfectly good synchronous transfers.
• A Motor Torque Ratio T_PK /T_L, introduced as the aggregate peak torque at transfer expressed as a multiple of the aggregate load torque prior to transfer, displays a high correlation to the phase angle at transfer with little effect from voltage or frequency difference.
• If it is torque that reduces the life expectancy and damages motors or driven equipment, or both, as suggested in the C50.41 Standard, then the industry must use a torque-based criterion to assess if transfers are being completed within acceptable torque limits.

Course Outline:

• Introduction
• Why Transfer Motor Load Sources
• Basic Application Configurations
  • Primary-Backup
  • Main-Tie-Main
  • Multiple-Option Source Selection
• IEEE Std C37.96-2012 Motor Bus Transfer Classification – Methods & Modes
  • Automatic and Manual
  • Closed Transition Method – Hot Parallel Transfer
  • Open Transition Method – Fast, In-Phase, Residual Voltage
  • Open Transition Modes – Simultaneous, Sequential
• IEEE Std C37.96-2012 Conditions Across Normally Open Startup or Bus Tie Breaker – Before / During Transfer
  • Effects of a Fault
  • Out-of-Step (OOS) Generator Trip
  • System Separation between Incoming Supply Sources
  • Supply Source Transformer Winding Phase Shift
  • Transient Effects upon Disconnect of Motor Loads
  • Motor and Load Characteristic Effects on MBT
• Failed Residual Voltage Transfer – Case Study
• Transfer Initiate, Inadvertent External Operation, Lockouts
• Load Shed During Transfer
• ANSI/NEMA Standard C50.41-2012 Resultant per unit V/Hz Limits
• Bus Transfer Spin Down Testing, Acceptance Testing, Setting Considerations
• Spin Down Analysis & Settings Calculations – Case Study
• Sequential vs. Simultaneous Transfer, The Need for Speed – Case Study
• IEEE Fast Transfer Sync Check Relay Performance Test Protocol Results
• IEEE Residual Voltage Transfer Relay Performance Test Protocol Results
• Motor Bus Transfer System Dynamic Performance Test Protocol Results and Observations
• A Motor Bus Transfer Torque Ratio Criterion applied to Live Open Transition Transfers Under Normal Operating Load Conditions – Observations and Conclusions
• Test Results from Modeling of Transient Currents and Torques on Motors during Residual Voltage Motor Bus Transfer
• Conclusions

Who Should Attend
Engineers and Technicians responsible for applying, setting and commissioning motor bus transfer systems in both power plants and industrial facilities. Also, Personnel in Plant Operations responsible for process output and continuance.

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3 Hours
(3 PDHs)

Distribution protection is a complex scenario with many elements: relayed feeder breakers, recloser controlled feeder breakers, line reclosers, sectionalizing switches, sectionalizers and fuses. The application and location of the protective and sectionalizing infrastructure predicates the application and coordination of protection. Compounding the complexity is the application of DMS/DA and presence of DER/DG. The session covers the distribution topology and protective infrastructure, and application of settable of relays and recloser controls.

• Distribution System Reliability
• Standards and Practices
• Protection Philosophies
• Causes of Faults
• Fault Types
• Distribution Construction/Configurations
• Impedances Used in Fault Current Analysis
• Fault Calculations and Settings
• Protection Devices and Characteristics
• Protective Device Selection and Application
• Protective Functions of Relays and Controls
• Ground Fault Detection Methods
• Automatic Reclosing
• Time Overcurrent Device Coordination
• Special Protective Applications
• Fault Event Analysis

Who Should Attend
Distribution Engineers and Technicians, and Operations personnel desiring a practical background into the protection of this part of the system.

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2 Hours
(2 PDHs)

• Feeder Protection Calculations Example
• Short Circuit Current
• Per Unit Quantities
• Symmetrical Components
• Fault Types
• Fault Current Calculations Example

Who Should Attend
Distribution Engineers and Technicians, and Operations personnel desiring a practical background into the protection of this part of the system.

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4 Hours
(4 PDHs)

Distributed Electric Resource (DER) is increasing its penetration into the distribution system. This technical session provides a background into DER operation and associated control and protection considerations for conventional and inverter-based power sources. We will review types of DER/DG and the modes in which they can operate in parallel with the distribution system. Key aspects of IEEE 1547 and a sample DER interconnection screening process are highlighted. Details of on-site standby power system conversion to operate in parallel with the distribution system are shown. Protection methodology at the point-of-common coupling (PCC) and point-of-interconnection (PI) is explored for all types of DER. A treatment of distribution system protection and control considerations and applications with DER is discussed.

• Define Distributed Electrical Resource (DER)
• Explore Types of DERs
• Why DER?
• Utility and Facility Drivers for DER
• Mission Critical Power and Conversion to DER
• Rates and DER Operational Sequences
• Industry Concerns
• IEEE 1547: Industry DER Guide
• Sample Utility DER Interconnection Guide
• Interconnection Protection: “The Five Food Groups”
  • Anti-islanding
  • Powerflow
  • Fault detection
  • Abnormal operating conditions
  • Reconnection
• Interconnection Transformer Impacts
• Generator Types and Impacts
  • Synchronous
  • Induction
  • Asynchronous (Inverter Based)
• Example Protection Applications
• Distribution Protection Coordination Issues
  • Directionalization
  • Reclosing coordination
• Smart Grid / Microgrid and DER
• Impact of IEEE 1547-2018
  • Fault ride-through
  • Reactive support and voltage control
• System Control with DER
  • LTC, Regulator and Capacitor Control Issues

Who Should Attend
Electrical distribution generalists, system planners and DER P&C practitioners.

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8 Hours
(8 PDHs)

On-line load tapchangers are a key component for controlling voltage at transmission and distribution levels. They are also a key element of IVVC, VVO and CVR application. Schemes and applications for operation, alarming, runback, reliability centered maintenance, paralleling and coordination with capacitors are addressed.

• Review of LTC, Regulator, and Capacitor Control Functions
  • Basics of Voltage Regulation
  • Regulation Blocking
  • Tap Position Feedback
  • Line Drop Compensation
  • Reverse Power Conditions and Options
  • Voltage Reduction
  • Paralleling of Transformers
• Control Hardware and Hands-On
  • HMI, buttons, switches, LEDs
  • Menu items, entering settings and navigation
  • Communications options
  • External interfaces and connections
  • Accessories- Adapter kits, panels, etc.
• Settings Programming
  • Use of TapTalk Software for Communicating with controls
  • Configuration for connected apparatus
  • Control Setpoints
  • Real time monitoring
  • Advanced Smart Grid Functions
  • TapPlot Software

Who Should Attend
T&D Engineers, Technicians and Operations personnel responsible for implementing Smart Grid applications, including those with interests in IVVC, VVO, CVR and DER/DG Integration.

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1 Hour
(1 PDHs)

LTC Transformer Paralleling

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4 Hours
(4 PDHs)

• Volt-VAr Control (VVC), Volt-VAr Optimization (VVO), and Conservation Voltage Reduction (CVR) Issues and Answers
• Allowable voltage ranges
• Equipment and devices used in Volt-var control
  • LTC, voltage regulator and capacitor controls
• Volt-var Control Technologies and tradeoffs
• Cost-Benefit Analysis of VVO
• Verification, Assessment and Monitoring Requirements for CVR

Who Should Attend
Distribution Engineers and Technicians, and Operations personnel desiring a practical background into the protection of this part of the system.

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2 Hours
(2 PDHs)

Modern Intelligent Electronic Devices (IEDs) used in Electric Power System Protection and
Control Applications are incorporating high-speed wired and wireless communications. More applications are now using high-speed Ethernet communications and they are often interfaced with public shared networks such as the internet to transport the data. This brings serious vulnerability concerns from outside attackers (from within and outside the country) with malicious intent. This course covers the cyber security vulnerabilities that exits on the Electric Distribution System and how to address them using the latest cyber security technologies (IEEE 1686, IPSec, RADIUS, etc.) which can be embedded in the protection and control IEDs to provide end-to-end security. The presentation also covers NERC CIP Version 5 standard.

• Government Regulations on cyber security
• Consequences of Cyber-attack on Distribution Protection and Control IEDs
• Cyber security Standards
  • IEEE 1686
  • IEEE C37.240
  • NERC CIP Version 5
• Cyber security Requirements and technologies
  • Access Control and Authenticity of the users
    • Password Requirements
    • Role Based Access Control
    • Secure DNP Authentication
    • Password Management using Remote Authentication Dial in User Service (RADIUS)
  • Data Confidentiality
    • Data Encryption
    • IPSec
• Public Key Infrastructure and Certificates
  • Cryptographic and Key Management
    • IKE, ISAKMP, Diffie-Hellmann(DH) Key Exchange
  • Certificates
    • OpenSSL toolset
• Example of embedded implementation of IEEE 1686, RADIUS and IPSec on Distribution Capacitor bank control

Who Should Attend
Distribution Engineers that want to get a basic understanding of why Cyber Security Is important for distribution applications.

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8 Hours
(8 PDHs)

This session focuses on distribution automation controllers and applications in Smart Grid environments. Load tapchanger, regulator and line capacitor controls are all constituents of IVVC, VVO and CVR schemes. Proper control must be able to function with various levels of DMS/DA integration including autonomous operation, changing grid topology and operation adaptation, communication infrastructure and bandwidth, DER/DG integration, and cyber security considerations.

• Introduction
  • Smart Grid Industry Drivers
  • Characteristics of Smart Grid
  • Smart Grid Architecture
  • Information (Cyber) Security Challenges
  • Funding opportunities for Smart Grid Development
  • Standardization Activities Related to Smart Grid
  • Integrated Volt VAr Management Systems
  • Distributed Generation
  • Power Quality
• Introduction to IVVMS
  • Purpose & Objectives (Present + Smart Grid)
  • Expected Smart Grid Operating Requirements & Configurations
  • kW Control – Conservation Voltage Control Function Basics & Application
• Understanding IVVMS Operations
  • VAr Control – A Primary Driver & Function Cap Controls – History of Smart Grid Features & Systems Primary Effect on Voltage Profiles Sizing, Locating & Coordinating Innovative VVM Techniques & Smart Grid Backup
  • LTC Voltage Control–The Ultimate Voltage Responsibility Reverse Power Operation Reversible Radial Feed, DG Applications (Large & Small), Combo Feed/DG, Distribution Tie Transformers, Network Applications Effects on Voltage Profiles LTC Control Features & Applications Settings, Timing, Coordination Effects on Voltage Profiles
  • Voltage Control for Variation of Diverse System Configurations
• Paralleling LTC Transformers and Systems
  • Transmission Tie and Distribution Substation Transformers Smart Grid Enhancements
• Power Quality
  • Utility Definition Versus End Consumer Definition
  • Performance Based Rates
  • MAIFI, SAIFI, SAIDI and CAIDI
  • Engineering the Distribution Grid to Reduce SAIDI & MAIFI
  • Single Phase Re-Closers Versus Three Phase Reclosers
  • Fault Locators
  • Sags & Swells
  • Harmonics
• Volt/VAr Smart Grid Architectures
  • Field Apparatus Used to Implement Smart Grid
  • Types of Architectures Used to Implement Smart Grid

Who Should Attend
T&D Engineers, Technicians and Operations personnel responsible for implementing Smart Grid applications, including those with interests in IVVC, VVO, CVR and DER/DG Integration.

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