Category: GE

Programmer Connection, Parallel

For a parallel interface (MS-DOS programmer only)

connect the programmer to the top port connector on

the Bus Transmitter Module (IC697BEM713) as shown

in Figure 1.  Consult  Reference 2 for a description of

programming functions.

Serial Port

The 15-pin D-connector provides the connection to an

RS-485 compatible serial port as shown in Figure 3.

This port provides a serial connection to a Standard

Serial COM port, or to a Work Station Interface board

installed in the programming computer. For more in

formation on serial communications, see references 1.

2. and 3.

Programmer Connection, Ethernet TCP/IP

Connecting your programmer via an Ethernet

TCP/IP network requires installation of an Ethernet

Interface module in the PLC.  This can be either the

Ethernet Controller, IC697CMM741. or Ethernet

Interface (Type 2), IC697CMM742.  Before connecting

your programmer and PLC to the Ethernet TCP/IP

network you must set the IP address in the Ethernet

Interface.  After setting the IP address, connect the

PLC and the programmer running Windows software

to the Ethernet Interface.  For more detailed

information on the programmer connection via

Ethernet TCP/IP, refer to the TCP/IP Ethernet

Communications (Type 2) User’s Manual, and the

Windows programming manual, GFK-1295.

Monitoring and Metering

• Synchrophasors in select products with IEEE C37.118 (2011) and

IEC 61850-90-5 support

• Advanced recording capabilities deliver a 1024 event recorder,

configurable and extended waveform capture and data logger

• Fault locator and user-programmable fault reports

• Breaker condition monitoring including breaker arcing current

(I2t), breaker re-strike and breaker flashover

• Metering: current, voltage, power, power factor, frequency,

voltage & current harmonics, energy, demand, phasors, etc.

EnerVista™ Software

• Graphical Logic Designer and Logic Monitor to simplify

configuration and testing procedures via EnerVista UR Engineer

• Service and update notification toolset ensures device documents

and software are up-to-date via EnerVista Launchpad

• EnerVista Integrator providing easy integration of data in the UR

Family into new or existing monitoring and control systems

FEATURES

Protection and Control

• Fast and segregated line current differential and distance

protection functionality in a single device

• Phase segregated line current differential with adaptive restraint

and ground differential, stub bus protection

• Phase distance (five zones) with independent settings for compensation

• Single-pole tripping, breaker-and-half with independent current

source support

• Complete generator protection with 100% stator ground fault

detection with sub-harmonic injection and field ground protection

Communications

• Networking interfaces: 10 or 100MB copper or fiber optic

Ethernet, RS485, RS232, RS422, G.703, C37.94, up to three

independent ethernet ports

• Multiple protocols: IEC 61850, DNP 3.0 and Modbus® serial/TCP,

IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP, EGD

• Direct I/O: secure, high-speed exchange of data between URs for

direct transfer trip and I/O extension applications

IEC 61850 Process Bus Interface

• Robust communications with up to 8 HardFiber Bricks

• Redundant architecture for dependability and security

APPLICATIONS

• Protection, control, monitoring and supervision of power assets

across generation, transmission, distribution, substation and

industrial systems

• Utility substation and industrial plant automation

• Digital fault recording and Sequence of Event (SOE) recording

• Predictive maintenance through data analysis and trending

• Synchrophasor based monitoring and control systems with

specialized PMU devices that support multiple feeders

• Complex protection & control and wide area monitoring solutions

with complete diagnostic and automation capabilities (URPlus)

KEY BENEFITS

• Modular construction: common hardware, reduced stock of spare

parts, plug & play modules for maintenance cost savings and

simplification

• Proven flexibility and customization capabilities make UR/URPlus

devices suitable to retrofit almost any kind of legacy P&C scheme

• Large HMI and annunciator panels provide local monitoring &

control capabilities, and backup the substation HMI

• Phasor Measurement Unit (synchrophasor) according to IIEEE®

C37.118 (2011) and IEC® 61850-90-5 directly streamed from your

protective device

• Three ethernet ports enable purpose specific LAN support that

eliminates latency effect of heavy traffic protocols on mission

critical communication services

• Embedded IEEE 1588 time synchronization protocol support

eliminates dedicated IRIG-B wiring requirements for P&C devices

• Complete IEC 61850 Process Bus solution provides resource

optimization and minimizes total P&C life cycle costs

• Increase network availability by reducing failover time to zero

through IEC 62439-3 “PRP” support

• CyberSentry™ provides high-end cyber security aligned to

industry standards and services (NERC® CIP, based, AAA, Radius,

RBAC, Syslog)

• Enhanced CT/VT module diagnostics verify analog signal integrity

using an advanced algorithm, ensuring reliability

• Reduces system event analysis effort with the support of

embedded high-end and extended recording functionality

After the multiplexer samples analog channels via the sample and hold (S/H) mechanism, samples from all four channels are summed up digitally, using the same equation to get a digital value Sd. The “Mean Square” of the difference between the channels is summed up in the hardware and an equivalent, computed digitally over one protection pass is supplied to the comparator. If the summed squared difference Σ(Sa – Sd)2 is greater than the adaptable per signal level error boundary, then “invalid data” is declared and protection functions using the measured data are momentarily blocked. In addition, if the error keeps repeating, a major self-test diagnostics error message is displayed on the UR. As a result of such failure, the relay’s self-test alarm contact operates and the relay is taken out of service. The relay can be rebooted and if no more failures are detected, it continues to be functional unless a new failure is detected and the relay is again taken out of service. The above analog data integrity check is performed on both analog banks (that is, four currents or four voltages) within each CT/VT input module.

In addition, these modules with enhanced diagnostics include power supply voltage rail monitoring to further monitor hardware health. This is achieved by continuous check of the power supply voltage Vdc against safe operate reference voltage Vref, which ensures that all electronic components of the CT/VT module operate in the safe operating conditions.

Internal CT secondary monitoring

The CT/VT input modules with enhanced diagnostics are monitoring internal CT circuitry integrity. This is done to eliminate relay erroneous operation in case of CT secondary winding failure. The secondary winding of CT is divided into two equal parts with a central tap in the middle. CT current values from both halves of the CT secondary windings are run through a differential amplifier to get a true current sample for the phasor calculations. It also compares between each other by simply summing two samples together. (Note that due to CT central tap, samples have different polarity.) In case that values from different halves of the same CT accumulated over one protection pass per adaptable per signal level do exceed the fixed error boundary, failure is declared and protection is blocked. CT secondary monitoring is performed at all four CT channels (A, B, C, and N) individually at each CT bank.

INTRODUCTION

The performance of a microprocessor-based relay is highly dependent on the performance of the analog channels measurement of the relay, as protection functions operate on these values. The failure of an analog measurement channel, either due to a failure in the external measurement circuit, or due to an internal failure inside a UR CT/VT module, can cause incorrect operation of protection functions. The UR CT/VT modules with Enhanced Diagnostics (module types 8L, 8M, 8N, 8R, 8S, 8V) can detect the failure of an analog channel measurement due to internal failures of the CT/VT module, alarm for failure of the module, and block tripping from any protection function associated with this module. This feature is available when using firmware 5.20 or later within the UR family and therefore field-proven since 2006.

Analog data integrity validation

The CT/VT input modules (8L, 8M, 8N, 8R, 8S, 8V) use an analog data integrity check to verify the performance of the analog measurement channels. This feature uses an additional analog hardware channel that has as its input, an analog sum of Sa = Xa – Xb + Xc + Xn, where X stands for either Voltage or Current phases A, B, C, and N analog inputs, to monitor the integrity of analog data.

BASIC SECURITY

The basic security feature is present in the default offering of the 889 relay. The

889 introduces the notion of roles for different levels of authority. Roles are used as login

names with associated passwords stored on the device. The following roles are available

at present: Administrator, Operator, Factory and Observer, with a fixed permission

structure for each one. Note that the Factory role is not available for users, but strictly used

in the manufacturing process.

The 889 can still use the Setpoint access switch feature, but enabling the feature can be

done only by an Administrator. Setpoint access is controlled by a keyed switch to offer

some minimal notion of security.

CYBERSENTRY

The CyberSentry Embedded Security feature is a software option that provides advanced

security services. When the software option is purchased, the Basic Security is

automatically disabled.

CyberSentry provides security through the following features:

• An Authentication, Authorization, Accounting (AAA) Remote Authentication Dial-In

User Service (RADIUS) client that is centrally managed, enables user attribution, and

uses secure standards based strong cryptography for authentication and credential

protection.

• A Role-Based Access Control (RBAC) system that provides a permission model that

allows access to 889 device operations and configurations based on specific roles

and individual user accounts configured on the AAA server. At present the defined

roles are: Administrator, Operator and Observer.

Description of the 889 Generator Protection System

CPU

Relay functions are controlled by two processors: a Freescale MPC5125 32-bit

microprocessor that measures all analog signals and digital inputs and controls all output

relays, and a Freescale MPC8358 32-bit microprocessor that controls all the advanced

Ethernet communication protocols.

Analog Input and Waveform Capture

Magnetic transformers are used to scale-down the incoming analog signals from the

source instrument transformers. The analog signals are then passed through a 11.5 kHz

low pass analog anti-aliasing filter. All signals are then simultaneously captured by sample

and hold buffers to ensure there are no phase shifts. The signals are converted to digital

values by a 16-bit A/D converter before finally being passed on to the CPU for analysis.

The ‘raw’ samples are scaled in software, then placed into the waveform capture buffer,

thus emulating a digital fault recorder. The waveforms can be retrieved from the relay via

the EnerVista 8 Series Setup software for display and diagnostics.

Frequency

Frequency measurement is accomplished by measuring the time between zero crossings

of the composite signal of three-phase bus voltages, line voltage or three-phase currents.

The signals are passed through a low pass filter to prevent false zero crossings. Frequency

tracking utilizes the measured frequency to set the sampling rate for current and voltage

which results in better accuracy for the Discrete Fourier Transform (DFT) algorithm for offnominal

frequencies.

Overview

The relay features generator unbalance, generator differential, over excitation, loss of

excitation, 3rd harmonic neutral undervoltage, over and under frequency, synchrocheck

and other essential functions with a basic order option. Additionally available with an

advanced order option are overall differential (to protect the transformer-generator

combined), directional overcurrent elements, restricted ground fault, 100% stator ground,

out-of-step protection, rate of change of frequency, power factor, harmonic detection,

frequency out-of-band accumulation and others. An optional RTD module allows for

thermal protection and monitoring. An optional analog inputs/outputs module allows for

monitoring of generator excitation current, vibration and other parameters.

These relays contain many innovative features. To meet diverse utility standards and

industry requirements, these features have the flexibility to be programmed to meet

specific user needs. This flexibility will naturally make a piece of equipment difficult to

learn. To aid new users in getting basic protection operating quickly, setpoints are set to

typical default values and advanced features are disabled. These settings can be

reprogrammed at any time.

Programming can be accomplished with the front panel keys and display. Due to the

numerous settings, this manual method can be somewhat laborious. To simplify

programming and provide a more intuitive interface, setpoints can be entered with a PC

running the EnerVista 8 Setup software provided with the relay. Even with minimal

computer knowledge, this menu-driven software provides easy access to all front panel

functions. Actual values and setpoints can be displayed, altered, stored, and printed. If

settings are stored in a setpoint file, they can be downloaded at any time to the front panel

program port of the relay via a computer cable connected to the USB port of any personal

computer.