Reg216e

REG216/

REG216 Compact

1MRB520004-Ben

Page 1

Issued: November 1999Changed: since July 1998

Data subject to change without notice

REG216 System

REG216 Compact

•Display of event, their acknowledgment and printout•Disturbance recording•Self-documentation•Long-term stability

•Communication and coordination with sta-tion control•Two design versions available; extended version or compact version (with or without cubicle)

Features

•Modular hardware

•Selectable protection functions•Multitude of applications•Menu-assisted setting with PC•Fully numerical signal processing•Continuous self-monitoring of hardware•Cyclical testing routines

•Setting of parameters and recording of the settings by PC•Display of measured values

Application

The REG216/REG216 Compact system is intended for the protection of generators and block transformers.

The modular hardware and software design allows an extremely flexible installation. Simplicity of adaption to the size of the pri-mary system and the desired protection schemes are achieved through the combi-nation of a software library and hardware modules.

Economic solutions can thus be achieved in the full range of applications for which it is intended.

The REG216 software system offers a library of protective functions. Functions suitable for generator and transformer protection are listed in the table below.

Different degrees of redundancy can be selected. Availability and reliability of the protection can be chosen to suit the applica-tion by duplicating e.g. auxiliary supply units of the whole system.

Standard interfaces make REG216/REG216 Compact compatible with different process control systems. Data exchange with higher process control levels are possible, e.g. one-way reporting of digital states and events, measured values and protection parameters.

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REG216/ REG216

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Application (cont´d)

Protection functions:Generator differential

Power transformer differential

Definite time overcurrent (undercurrent)Overcurrent or undercurrent with peak valueevaluation

Restricted earth fault

Voltage-controlled overcurrentInverse time overcurrent

Negative phase sequence currentDefinite time overvoltage (undervoltage)

ANSIcode87 G87 T515087 N51-2751465927

Description

three-phase

three-phase for 2- and 3-winding transformers

definite time delay, for phase and earth-fault, over-and undercurrent

instantaneous operation or with definite time delay,

value evaluation wide frequency range, over- and undercurrentovercurrent operation with definite time delay*operation restrained by undervoltage

inverse current dependent time delay, for phase andearth fault

negative phase sequence current with definite time delay or inverse time delay with thermal replicadefinite time delay, over- and undervoltageApplicable also for

- stator E/F (95%) (59 G/N)- rotor E/F ( R) **

- intertum fault protection

based on the displacement principle calculation of theearth fault resistance.

in addition the units REX010 and REX011 are required

circular characteristics centered at origin of impedance planecircular characteristics for loss of excitation protection

detecting loss of synchronism of a generator as against the net-work

any characteristic angle, over and underpower for:- active power- reactive power

- reverse power protection- minimum forward power

thermal replica with operating characteristicaccording to ASA-C50.13*** for:- standard stator current (49 S)- rotor current (49 R)

evaluation of negative phase sequence of currentsinverse time delay;with terminal replica

thermal protection with precise thermal replica

evaluation of voltage inputdf/dt

voltage/frequency protection

definite time delay or inverse time delay

monitoring/comparing two groups of single- or three-phase volt-age

instantaneous operation with definite time delay

supervision of phase angle frequency and voltage level of two systems

AND, OR, flip-flop, time delay, counter

*with external hardware: stabilizing resistor, voltage-dependent resistor

**with external hardware: measuring bridge YWX111-..., coupling condensers***ASA = American Standard Association

Aside from these typical generator protection functions the entire library of the RE.316*4 platform is also available (e.g. distance protection, autoreclosure, I0 inverse, etc.). For more details see manual of REG216.

100% stator and rotor earth faultprotection

UnderimpedanceMinimum reactancePole slip protectionPower

S R21407832

Overload49

Negative phase sequence current46

Overtemperature

Frequency

Rate-of-frequency changeOverexcitationVoltage balance

Voltage peak value evaluationSynchro checkLogical functions

498181246059,2725

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Protection functions

All protection functions required for the stand-alone protection of generators, power transformers and feeders are available. The system therefore replaces several relays of a conventional protection scheme for such power system equipment. The table on page 2 gives a survey of the most significant protec-tion functions.

The desired protection functions to suit the particular application can simply be selected from a comprehensive library using the per-sonal computer. No knowledge of computer programming is required.

All setting ranges are extremely wide to make the protection functions suitable for a multi-tude of applications. The following main parameters can be set:

•Allocation of processing units•Input channel or channels•Pick-up setting•Time delay

•Definition of the operating characteristic•Tripping logic•Control signal logic

Setting a corresponding parameter enables the protection functions to be \"connected\" to particular input channels.

Digital input and output signals can also be internally combined logically:

•The tripping outputs of each protection function can be assigned to channels of the tripping auxiliary relay assembly in a man-ner corresponding to a matrix.•The pick-up and tripping signals can be assigned to the channels of the signalling auxiliary relay assembly.•Provision is available for blocking each protection function with a digital signal (e.g. digital inputs or by using the tripping signal of another protection function).•External signals applied to the digital inputs can be processed in any desired fashion.•Digital signals can be combined to per-form logical functions e.g. external en-abling or blocking signals with the output signals of an internal protection function and then used to block one of the other protection functions.

ConstructionHardware

There are two different versions available: REG216 and REG216 Compact. The REG216 equipment comprises two main assemblies which are physically separated from each other and linked by standard pre-fabricated screened cables:

•Interfaces to the primary system (CT’s, PT’s and auxiliary relays), which provide dc isolation and a barrier to electromag-netic interference.•Parallel bus and associated electronic units (e.g. analogue inputs and data processors/ for signal conditioning and processingThe complete protection scheme comprises relatively few hardware modules allowing subsequent expansion of electronic units and the interfaces. 21 units of rack space is avail-able per equipment frame.

Excellent electromagnetic compatibility has been achieved through careful attention to physical separation of the interfaces from the signal processing units

All hardware can be accommodated in one cubicle, which provides a further screen against induced interference and affords physical protection against dust, etc.REG216C is a standard compact rack ver-sion, available in 7 versions, with a limited number of I/O's but equipped with the same SW library as the REG216 system.

Other protection relays for functions which are not part of the REG216/REG216 Com-pact system may be installed in the cubicle and correspondingly interwired with REG216/REG216 Compact.

Interfaces to the primary system

The following modular assemblies provide interfacing of REG216 to the power system.

Input transformer assembly 216GW61

This assembly adjusts the signal levels and provides isolation between the primary sys-tem CT and PT circuits and the electronic cir-cuits of the protection. One type of PT and two types of CT’s are available, to meet dif-ferent accuracy and dynamic performance requirements.

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Construction (cont´d)

Space is available for up to 12 transformers, which are selected to suit the application. Up to four assemblies can be used, i.e. 48 inputs.

Input auxiliary relay assembly 216GE61

Auxiliary relay and optocoupler assembly 216GD61a

Up to 16 auxiliary relays can be accommo-dated, providing complete potential separa-tion of digital input signals.

Output auxiliary relay assembly 216GA61

This assembly is used in the compact version REG216. It provides eight tripping relays, each with two powerful, potential-free trip-ping contacts (with surge circuits), 16 auxil-iary relays and 16 optocoupler input circuits. Max. four assemblies can be provided.

Parallel bus and electronic units

Up to 16 auxiliary relays can be accommo-dated providing complete potential separation of digital output signals (two contacts per sig-nal).

Tripping auxiliary relay assembly 216GA62

Up to eight powerful, potential-free tripping contacts and circuits, which provide high-speed operation (surge circuit) with reduced consumption after operation (economy cir-cuit) are provided.

Facilities for different trip circuit supervision arrangements in conjunction with the output unit 216DB61and the input auxiliary relay assembly 216GE61 (option) are also pro-vided.

The tripping auxiliary relay assembly can be optionally fitted with a tripping logic diode matrix to enable direct coupling of external signals. REG216 can also read and process external signals via digital inputs.

The electronic units are of plug-in design and accommodated in an equipment rack with the standard dimension 19\mm). An equipment rack of this kind is divided into 21 standard divisions. The

exchange of data via the parallel bus B448C is controlled and monitored by all units avail-able.

The protection system is based on a data bus with digital signal processing for most func-tions; signal conditioning, analogue and digi-tal inputs, A/D conversion, processing and signal output.

The components of the system are:

•Static plug-in units, which exchange data via a powerful parallel bus.

•Interfaces to the process (primary system, station equipment), which are isolated from the digital processing unit.

Transformer unitGW61A / DEA61bCPUVC62aPC carde.g.LONBinaryoutputDB61Signal relaysGA61BinaryoutputAB61Tripping relaysGA62TripDB61DC / DCNG61,2,3CPUVC62aPC cardSPALONSMSSCSInput relaysGE61Fig. 1Configuration of the REG216 protection system

Numerical generator protection

Equipment rack 216MB66/216MB68 and parallel bus B448C

The main features of the parallel bus B448C are:

•Specification based on IEEE P 6 (future bus).

•Time multiplexing of addresses and data (16 bit).

•Asynchronous data transmission with handshake.

•Integrity checking of each data exchange.•Up to 32 master units having equal status, actively accessing the bus.

•Common internal 24V auxiliary supply for all electronic units; redundant 24V are possible.

Processing unit 216VC62a

•32 bit processor type 80486DX-2•Application software on Flash EPROM•Operating data on RAM

•Settings on non-volatile Flash EPROM•Potential-free RS-423 interface for PCoperation•Connection to the station control with transmission of messages•Time clock synchronizing for time-tagging of events•Non-volatile event and disturbance mem-ory (gold capacitor buffered) •Space requirement: two rack divisions

Analogue Input unit 216EA61b

•24 inputs sampled simultaneously in groups of six•Sampling frequency 600 (720) Hz for a power frequency of 50 (60) Hz•Space requirement: two rack divisions

Digital output unit 216AB61

•32 outputs for controlling the relays of the output auxiliary relay assembly•Short-circuit proof

•Front plate LED’s for indication of acti-vated relays•Space requirement: one rack division

Binary and analog output unit 216AC61

•16 binary outputs for controlling of the output auxiliary relay assembly-Short-circuit proof

-Front plate LED’s for marking activated relays

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•8 analog outputs (0 . . . 20 mA without gal-vanic separation)•Front space requirements: one rack divi-sion

Binary input unit 216EB61

•32 binary inputs used to connect ON or OFF signals to the REG216 protection sys-tem from input relay assembly•Time-tagging with a resolution of 1 ms•Front plate LED’s marking activated relays•Front space requirements: one rack divi-sion

Tripping output unit 216DB61

•8 outputs for two-pole control of auxiliary tripping relays•Monitored output amplifiers

•16 digital inputs for the signals from the input auxiliary relay assembly (two each can be used to externally enable and block tripping respectively)•Activated outputs and inputs indicated by LED’s•Front space requirements: one rack divi-sion

Auxiliary dc supply unit 216NG61, 216NG62 and 216NG63

•Versions for 36 to 312 V dc input•Outputs 24V dc, 150 W

•Short-circuit and overload-proof outputs•Parallel connection to increase rating•Parallel connection for redundancy(2 outputs)•Space requirement: 3 rack divisionsAll the REG216 protection functions operate with sampled primary system voltages and currents. The sampling rate of the analogue input units is 12 times per period at rated power system frequency with a dynamic range of 15 bits.

All further signal processing takes place digi-tally. The protection functions are therefore universally applicable, highly accurate and have excellent long-time stability.

Dc components and harmonic contents are efficiently suppressed by digital filters to avoid disturbance. The tripping logic for the

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internal protection functions (earlier a diode matrix), is software-controlled in REG216/REG216 Compact.

Setting and control

The protection system is set and controlled using a personal computer connected to it via a serial interface. Operation of the console is menu-assisted and permits:

•Setting of parameters and recording of the settings

•Display of measured values

•Display of events, their acknowledgment and printout

•Disturbance recording (option)

Windows HMI (Option)

A new Windows-based setting tool RE.16 WIN-HMI is available since the Firmware version V5.2.This Software runs only under the following operating systems: •WINDOWS 95•WINDOWS 98•WINDOWS NT

The perfect tool for engineering, testing, commissioning and maintenance personnel can be used for ON-LINE or OFF-LINE pro-gramming.

For each protection function a visible tripping characteristic is displayed depending on the setting values, e.g. the underimpedance func-tion shown below.

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There is a library with all protection functions necessary for generator and transformer pro-tection. Easy activation of a protective func-tion bay “drag&drop” technology.

Self-monitoring and testing facilities

The self-monitoring and testing routine

philosophy can be divided into following sec-tions:

•Self-monitoring

•Parameter viewing facilities

•Injection testing with separate test equip-ment.

Self-monitoring

The self-monitoring and testing routine philo-sophy is quite different from conventional testing techniques. Whilst the previous prac-tice in protection was to maintain availability through comprehensive periodic testing. REG216/REG216 Compact does this contin-uously by taking full advantage of digital and data bus technology.

The self-monitoring functions have two ele-ments:

•Continuous self-monitoring by hardware•Cyclically executed testing routines, mainly by software.

Testing

Viewing protection measurements

One feature is the provision to view various operating measurements. This together with the self-monitoring functions replaces the periodic injection testing necessary with con-ventional protection equipment. The follow-ing data can be viewed:

a)The system values as measured by all pro-tection functions. The corresponding func-tions do not have to have picked up for this purpose.

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Numerical generator protection

b) Analogue inputs. The amplitudes, fre-quency and phase relationships of all the analogue inputs can be viewed without jeopardizing the operation of the protec-tion functions.c)Digital input and output signals. The status of each signal can be viewed.Apart from the self-monitoring routines, the fact that the measurement data can be viewed all the way from the input transformers to the digital signals also confirms the correct func-tioning of the digital processors and the data bus.

Using software HMI „Test functions“

The desired protective function may be se-lected from the list of available active func-tions. The test operation is based on simu-lated numerical values. One or more channels may be selected for testing the tripping or sig-

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nalling outputs. The test function is mainly used for commissioning purposes when the system is out of service.

Redundancy

Hardware and software redundancy is ad-apted to the functional requirements. Two independent groups of protection functions are accommodated in either two separate hardware racks (REG216) or in only one rack (REG216C), but with two completely inde-pendent hardware groups.

Injection testing

A 100% test of system can be carried out by injecting test voltages and currents using, for example, a test set type XS92a or FREJA. Provision is made for injection testing with a test set at the terminals of the input trans-former assembly 216GW61/216GW62. The terminals enable primary system PT circuits to be interrupted and CT’s to be short-cir-cuited.

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Technical data

Table 1:Input circuit

Rated current INRated voltage UNRated frequency fNThermal ratings:

continuousfor 10 sfor 1 s

surge (half-cycle)Burden of the current inputsBurden of the voltage inputsInput signals

acdc

1A,2Aor5A

100 V/110 V or 200 V/220 V50/60 Hz4 x IN30 x IN100 x IN

250 x IN (peak)<0.2 VA/input at IN<0.4 VA/input at UN24 V to 220 V24 V to 250 V

Table 2:Generator differential (87G)

Features:

-Three-phase function

-Current-adaptive characteristic

-High stability for external faults and current transformer saturationSettings:

g-setting (basic sensitivity)v-setting (slope)Max. trip time

- for I∆ > 2 IN- for I∆ ≤=2=IN

Accuracy of pick-up value of g

0.1 to 0.5 IN in steps of 0.05 IN0.25; 0.5≤=30 ms≤ 50 ms± 5% IN (at fN)

Table 3:Transformer differential (87T)

Features:

- For two- and three-winding transformers- Three-phase function

- Current-adaptive characteristic

- High stability for external faults and current transformer saturation

- No auxiliary transformers necessary because of vector group and CT ratio compensation- Inrush restraint using 2nd harmonicSettings:g-settingv-settingb-setting

Max. trip time (protected transformer loaded)

- for I∆ > 2 IN- for I∆=≤ 2 IN

0.1 to 0.5 IN in steps of 0.05 IN0.25, 0.5

1.25 to 2.5 in steps of 0.25≤ 30 ms≤ 50 ms

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Accuracy of pick-up valueReset conditions

Differential protection definitions:

± 5% IN (at fN)I∆ < 0.8 g-setting

I∆ = I1+ I2 + I3 IH=

0

α== arg (I1'; - I2')2-winding:3-winding:

I1' = I1, I2' = I2I1' = MAX (I1, Ì2, Ì3) I2' = I1 + I2 + I3 - I1'I′⋅I′⋅cosα12

forcosα ≥0

for cos α <0

Fig. 2Differential protection characteristic

Table 4:Definite time overcurrent (51)

(optionally used as restricted earth fault relay by additional external hardware)Features:

- Maximum or minimum function (over- and undercurrent)- Single- or three-phase measurement

- Highest or lowest phase value evaluation for three-phase functionSettings:CurrentDelay

Accuracy of pick-up valueReset ratio

Max. trip time with no delay

0.02 to 20 IN in steps of 0.01 IN0.02 to 60 s in steps of 0,01 s± 5% (at fN)

> 94% (for max. function)< 106% (for min. function)≤ 60 ms

Table 5:Instantaneous overcurrent (50)

Features:

- Maximum or minimum function (over- and undercurrent)- Single- or three-phase measurements- Wide frequency range (0.04 to 1.2 fN)- Peak value evaluationSettings:CurrentDelay

Accuracy of pick-up value (at 0.08 to 1.1 fN)Reset ratio

Max. trip time with no delay (at fN)

0.1 to 20 IN in steps of 0.1 IN0 to 60 s in steps of 0.01 s±5%

>90% (for max. function)<110% (for min. function)≤ 30 ms

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Technical data (cont´d)

Table 6:Voltage-controlled overcurrent (51-27)

Features:

- Maximum current value memorized after start- Reset of function after voltage return or after trip- Single- or three-phase measurement for current- Positive-sequence voltage evaluationSettings:CurrentVoltageDelayHold time

Accuracy of pick-up valueReset ratioStarting time

0.5 to 20 IN in steps of 0.1 IN0.4 to 1.1 UN in steps of 0.01 UN0.5 to 60 s in steps of 0.01 s0.1 to 10 s in steps of 0.02 s± 5% (at fN)> 93%≤ 80 ms

Table 7:Inverse time-overcurrent function (51)

Single or three-phase measurement with detection of the highest phase currentStable response to transients

Inverse time characteristic

(acc. to B.S. 142 with extended setting range)

normal inversevery inverse

extremely inverselong time earth faultor RXIDG characteristicSettings:

Number of phasesBase current IBPick-up currentMin. time settingk1 setting

Accuracy classes for the operating time

according to BritishStandard 142RXIDG characteristicReset ratio

1 or 3

0.04...2.5IN in steps of 0.01IN1...4IB in steps of 0.01IB0...10s in steps of 0.1s0.01...200s in steps of 0.01sE 5.0

±4% (1 - I/80 IB)95%

t=k1 / ((I/IB)C-1)c = 0.02c = 1c = 2c = 1

t = 5.8 - 1.35 · In (I/IB)

Table 8:Negative phase sequence current (46)

Features:

- Protection against unbalanced load- Definite time delay

- Three-phase measurementSettings:

Negative phase-sequence current (I2)Delay

Accuracy of pick-up valueReset ratioStarting time

0.02 to 0.5 IN in steps of 0.01 IN0.5 to 60 s in steps of 0.01 s

± 2% IN (at fN, I ≤ IN with measuring transformers)> 94%≤ 80 ms

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Table 9:Definite time overvoltage (27, 59)

Features:

- Maximum or minimum function

- Single- or three-phase measurement

- Highest or lowest phase value evaluation for three-phase function- Also applicable as

- Stator earth fault (95%)(59G/N)- Rotor earth fault* (R)- Interturn faultSettings:VoltageDelay

Accuracy of pick-up valueReset ratioMin. trip time

0.01 to 2.0 UN in steps of 0.002 UN0.02 to 60 s in steps of 0.01 s± 3% (at fN, U > 0.1 UN)> 96% (for max. function)< 104% (for min. function)≤ 60 ms

*requires ext. hardware: measuring bridge YWX111-... and coupling condensers.

Table 10:Instantaneous overvoltage protection function (59, 27) with peak value

evaluation

Features:

- Evaluation of instantaneous values, therefore extremely fast and frequency-independent on a wide scale- Storing of the highest instantaneous value after start- No suppression of d. c. components- No suppression of harmonics- 1- or 3phase

- Maximum value detection for multi-phase functions- Variable lower limiting frequency fminSettings:VoltageDelayLimiting fminReset ratio

Min. trip time at no delay (at fN)

0.01 to 2.0 UN in steps of 0.01 UN0.00 to 60 s in steps of 0.01 s25 to 50 Hz in steps of 1 Hz> 90% (for max. function)< 110% (for min. function)< 30 ms (for max. function)

±5%Accuracy of pick-up value (at 0.08 to 1.1 fN) ABB Power Automation

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Technical data (cont´d)Table 11:Underimpedance (21)

Features:

- Detection of two- and three-phase short circuits (back-up protection)- Single- or three-phase measurement

- Circular characteristic centered at origin of R-X diagram

- Lowest phase value evaluation for three-phase measurement

Fig. 3Settings:

Underimpedance protection function characteristics

0.025 to 2.5 UN/lN in steps of 0.001 UN/lN0.2 to 60 s in steps of 0.01 s< 107%< 80 ms (at fN)

ImpedanceDelayReset ratioStarting time

Table 12:Minimum reactance (40)

Features:

- Detection of loss-of-excitation failure of synchronous machines- Single- or three-phase measurement

- Out-of-step detection with additional time delay or count logic- Circular characteristic

- Tripping possible inside or outside the circle

Fig. 4Settings:

Minimum reactance protection function characteristics

-5 to 0 UN/lN in steps of 0.01 UN/lN-2.5 to + 2.5 UN/lN in steps of 0.01 UN/lN0.2 to 60 s in steps of 0.01 s-180° to +180° in steps of 5°

Reactance XAReactance XBDelayAngle

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Accuracy of pick-up valuesReset ratio

± 5% of highest absolute value of XA, XB (at fN)(related to origin of circle),105% for min. function. 95% for max. function.≤ 80 ms

Starting time

Table 13:Power (32)

Features:Applicable for

- Active power protection- Reverse power protection- Reactive power protection

- Maximum and minimum function

- Single- or two- or three-phase measurement

- Adjustable compensation angle for input transformer errorsSettings:Power

Minimum setting:AngleDelay

Compensation angleNominal power PNReset ratioAccuracy

-0.1 to 1.2 PN in steps of 0.005 PN- 0.005 PN (with measuring CT)- 0.02 PN (with protection CT)-180° to +180° in steps of 5°0.05 to 60s in steps of 0.01 s-5° to +5° in steps of 0.l°

0.5 to 2.5 UN · IN in steps of 0.001 UN . IN30% to 170% in steps of 1%

± 0.5% PN (at fN, I < IN) with measuring CTs

Table 14:Stator overload (49S)

Features:

- Single- or three-phase measurement

- Operating characteristics according to ASA-C50.13 - Highest phase value for three-phase measurement- Wide time multiplier setting.

Fig. 5Settings:

Stator overload protection function characteristics

0.5 to 2.5 IN in steps of 0.01 IN1 to 50 s in steps of 0.1 s1.0 to 1.6 IB in steps of 0.01 IB

Base current (IB)Time multiplier k1Pick-up current (Istart)

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Technical data (cont´d)

tmintgtmaxtreset

Accuracy of current measurementStarting time

1 to 120 s in steps of 0.1 s10 to 2000 s in steps of 10 s100 to 2000 s in steps of 10 s10 to 2000 s in steps of 10 s

± 5% (at fN), ± 2% (at fN) with measuring transformer≤ 80 ms

Table 15:Rotor overload (49R)

Features:

Same as stator overload function, but three-phase measurementSettings:

Same as for stator overload function

Table 16:Inverse time negative phase sequence current (46)

Features:

- Protection against unbalanced load- Inverse time delay

- Three-phase measurement

Fig. 6

Inverse time negative phase

sequence current protection function characteristics

0.5 to 2.5 IN in steps of 0.01 IN5 to 30 s in steps of 0.1 s0.02 to 0.20 in steps of 0.011 to 120 s in steps of 0.1 s500 to 2000 s in steps of 1 s5 to 2000 s in steps of 1 s

+2% (at fN) with measuring transformers≤ 80 ms

Settings:Base current (IB)Time multiplier k1Factor k2 (pick-up)tmintmaxtreset

Accuracy of NPS current (I2) measurementStarting time

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Table 17:Overtemperature (49)

Features:

- Thermal replica for system of first order or general thermal system response- Single- or three-phase current measurement

- Highest phase value for three-phase measurementSettings:Base current IBWarning stageTripping stageThermal time constant

Accuracy of current measurementAccuracy of the thermal image

0.5...2.5IN in steps of 0.01IN50...200% ϑN in steps of 1% ϑN50...200% ϑN in steps of 1% ϑN0.0...500min in steps of 0.1min± 2% (at fN) with measuring transformers±5%

Table 18:Frequency (81)

Features:

- Maximum or minimum function (over-, underfrequency)- Minimum voltage blockingSettings:FrequencyDelay

Minimum voltageAccuracy of pick-up valueReset ratioStarting time

40 to 65 Hz in steps of 0.01 Hz0.1 to 60 s in steps of 0.01 s0.2 to 0.8 UN in steps of 0.1 UN± 30 mHz (at UN and fN)< 106%< 135 ms

Table 19:df/dt (81)

Features:

- combinde pick-up with frequency criterion possible- blocking by undervoltageSettings:df/dtFrequencyDelay

Minimum voltageAccuracy of df/dtAccuracy of frequencyReset ratio df/dt

-10 to +10 Hz/s in steps of 0.1 Hz/s40 to 65 Hz in steps of 0.01 Hz0.1 to 60 s in steps of 0.01 s0.2 to 0.8 UN in steps of 0.1 UN± 0.1 Hz/s

± 30 mHz (at UN and fN)95% for max. function105% for min. function

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Technical data (cont´d)

Table 20:Overexcitation (24)

Features:

- U/f measurement

- Minimum voltage blockingSettings:Pick-up valueDelay

Frequency rangeAccuracyReset ratioStarting time

0.2 to 2 UN/fN in steps of 0.01 UN/fN0.1 to 60 s in steps of 0.01 s0.5 to 1.2 fN± 3% (at fN)

> 97% (max.), < 103% (min.)≤ 120 ms

Table 21:Overexcitation function with inverse time delay (24)

Features:

-Single-phase measurement-inverse time delay

-According to IEEE Guide C37.91-1985 setting made by help of table settings Settings:Table settingsStart value U/ftmintmaxReset timeReference voltageAccuracy of pick-up valueFrequency rangeReset ratioStarting time

U/f values: (1.05; 1.10 to 1.50) UN/fN1.05 to 1.20 UN/fN in steps of 0.01 UN/fN0.01 to 2 min in steps of 0.01 min5 to 100 min in steps of 0.1 min0.2 to 100 min in steps of 0.1 min0.8 to 1.2 UN in steps of 0.01 UN± 3% UN/fN (at fN)0.5 to 1.2 fN100%> 120 ms

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Table 22:Voltage balance function (60)

Features:

-Comparing of the voltage amplitudes of two groups of voltage inputs (line 1, line 2)-1- or 3-phase voltage measurement

-Signalling of the group having the lower voltage

-Evaluation of the voltage differences per phase for the 3-phase function and logic OR connection for the tripping decision

- Variable tripping and reset delay-Suppression of d. c. components-Suppression of harmonics

Fig. 7Settings:

Tripping characteristic Voltage comparison (shown for the phases R and the setting value volt. diff. = 0.2 . UN)

0.1 to 0.5 UN in steps of 0.05 UN0.00 to 1.0 s in steps of 0.01 s0.1 to 2.0 s in steps of 0.01 s1 or 3≤ 50 ms

phase R voltage amplitude voltage channel 1 (line 1)phase R voltage amplitude voltage channel 2 (line 2)

Voltage differenceTrip delayReset delayNumbers of phases

Maximum tripping time without delayU1R:U2R:

For 3-phase function: the characteristic is valid accordingly for the phases S and T

Table 23:Dead machine protection (51, 27)

Features:

-Quick separation from network at accidental energization of generator (e.g. at standstill or on turning gear)

-Instant overcurrent measurement

-Voltage-controlled overcurrent function e.g. blocked at voltage values > 0.85 UN

This function does not exist in the library, it must be combined from the voltage current and time function Settings:VoltageReset delayCurrentDelay

0.01 to 2 UN in steps of 0.002 UN0 to 60 s in steps of 0.01 s0.02 to 20 IN in steps of 0.02 IN0.02 to 60 s in steps of 0.01 s

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Technical data (cont´d)

Table 24:100% Stator earth fault protection (S)

Features:

-Protection of the entire stator winding, including star points, even at standstill. Works also for most of theoperating conditions.

- Also suitable when 2 earthings (groundings) are in the protection zone-Continuous supervision of the insulation level of the stator

-Based on the earth (ground) voltage displacement principle and calculation of the earth (ground) fault resistance

-Alarm and tripping values are entered, resp. measured and displayed in kΩ-Type of earthings (groundings):

-star point earthing with resistors (requires REX011)

-star point earthing with grounding transformer (requires REX011-1)-earthing transformers on generator terminals (requires REX011-2)Settings:Alarm stageDelayTripping stageDelayRES

Number of star pointsRES-2. starpointReset ratioAccuracyStarting time

Functional requirements:- max. earthing current- stator earthing capacity- stator earthing resistance RPS- stator earthing resistance RES

(All values are based on the starpoint side)

The actual earthing resistances RES + RPS have to be calculated in accordance with the User’s Guide:The 100% stator earth fault protection function always requires an injection unit type REX010, an injection transformer block type REX011 and a 95% stator earth fault protection function.

I0 < 20A (recommended I0 = 5A)0.5 µF to 6 µF130Ω to 500Ω

700Ω to 5 kΩ (≥4.5 x RPS)100Ω to 20 kΩ0.2 s to 60 s100Ω to 20 kΩ0.2 s to 60 s700Ω to 5 kΩ2

900Ω to 30 kΩ

110% for setting values of ≤ 10 kΩ120% for setting values of > 10 kΩ0.1 kΩ to 10 kΩ: < ± 10%

0 to 100 Ω, 10 kΩ to 20 kΩ: < ± 20%1.5 s

Table 25:Rotor earth fault protection (R)

Features:

-Continuous supervision of the insulation level and calculation of the earthing (grounding) resistance-Alarm and tripping values are entered resp. measured and displayed in kΩSettings:Alarm stageDelayTripping stageDelayRER

Coupling capacityReset ratio

100Ω to 25 kΩ0.2 s to 60 s100Ω to 25 kΩ0.2 s to 60 s900Ω to 5 kΩ2 µF to 10 µF110%

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AccuracyStarting time

Functional requirements:- total rotor earthing capacity- rotor earthing resistance RPR- rotor earthing resistance RER- coupling capacity- time constant

0.1 kΩ to 10 kΩ < ±10%

0 to 100 Ω, 10 kΩ to 25 kΩ < ±20%1.5 s

200 nF to 1µF100 Ω to 500 Ω900 Ω to 5 kΩ4 µF to 10 µ F

T = RER, x C = 3 to 10 ms

The actual earthing resistance RER + RPR have to be calculated in accordance with the User’s Guide. The 100% rotor earth fault protection function always requires an injection unit type REX010 and an injec-tion transformer block type REX011 which are connected to the plant via coupling capacities.

Table 26:Pole slip protection (78)

Features:

-Recording the pole wheel movements from 0.2 Hz to 8 Hz

-Differentiation of the pendulum center inside or outside of the generator-transformer block zone by two independent tripping stages

-Adjustable warning angle for pole wheel movements-Number of slips adjustable before tripping

Fig. 8Settings:

Characteristic of the function

0 to 5.0 UN/lN-5.0 to 0 UN/lN0 to 5.0 UN/lN60° to 270°0° to 180°0° to 180°0 to 200 to 200.5 s to 25 s

ZA (system impedance)ZB (generator impedance)ZC (impedance step 1)Phi

warning angletripping anglen1n2t-reset

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Technical data (cont´d)Table 27:Synchrocheck (25)

Features:

-Supervision of synchronism.

Single-phase measurement. The differences of the amplitudes, phase angles and frequencies of two voltage-vectors are checked-Voltage supervision:

Single- or three-phase voltage measurement. Evaluation of instantaneous values and therefore a large frequency range. Detection of maximum and minimum values in case of three-phase input-Phase-selection of the voltage-inputs

-External switch over to another voltage input is possible (for double busbar systems)-External selection of the modeSettings:Max. voltage diff.Max. phase diff.Max. frequency diff.Min. voltageMax. voltageSupervision timeReset time

0.05 to 0.4 UN in steps of 0.05 UN5 to 80 deg in steps of 5.0 deg0.05 to 0.4 Hz in steps of 0.05 Hz0.6 to 1 UN in steps of 0.05 UN0.1 to 1 UN in steps of 0.05 UN0.05 to 5 s in steps of 0.05 s0 to 1 s in steps of 0.05 s

Table 28:Metering functions U, I, P, Q, f

SettingVoltage UNCurrent INReal power PApparent power Q

Range0 to 1.2 UN0 to 20 IN0 to 1.2 UN0 to 20 IN0 to 1.2 UN0 to 20 IN

Accuracy0.5%2%

1% resp. 0.5%*3% resp. 2%*2% resp.0.5%*5% resp. 3%*2% resp. 0.5%*5% resp. 3%*

Minimum

0.002 UN (compensated)0.005 UN (uncompensated)0.01 IN (compensated)0.02 IN (uncompensated)0.02 PN (compensated)0.05 PN (uncompensated)0.02 PN (compensated)0.05 PN (uncompensated)

* applies for toroidal core c.t’s (0 to 2 IN)Table 29:Disturbance recorder

Max. 12 analogue channelsMax. 16 binary channels

Max. 12 analogue channels of internal measurement values

12 samples per period (sampling frequency 600 or 720Hz at a rated frequency of 50/60Hz)Available recording time for 9 analogue and 8 binary signals approximately 5sRecording initiated by any binary signal, e.g. the general trip signal.Data formatDynamic rangeResolutionSettings:

Recording periods

Pre-event Event

Post-event

40...400ms in steps of 20ms100...3000ms in steps of 50ms40...400ms in steps of 20msEVE

70 x IN, 2.2 x UN12 bits

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Table 30:Logic functions

Delay function:

- Adjustable trip delay and drop delay- Two time integration modes- Input invertible

Counting function:

- Adjustable trip counting threshold and drop delay- Input invertible

AND function

- Maximum of four inputs- All inputs invertible

- Trip with additional delay or counting functionOR-function

- Maximum of four inputs- All inputs invertible

- Trip with additional delay or counting functionFLIP-FLOP function

- Two set- and two reset inputs- All inputs invertible

- Trip with additional delay or counting function

0 to 300 s in steps of 0.01 s

1 to 100 in steps of 1

Table 31:Configuration and Settings

Locally via the comm. port on the front-plate using an IBM AT or compatible PC

User interface program in English, German, French or Spanish on a disc (31/2\"/1.44 MByte or 51/4\"/1.2 MByte)

Table 32:Remote communication

RS232C interface

Data transfer rateProtocol

Electrical/optical converter (optional)PC-Card interface

Number

PC-Cards (optional)

for interbay busfor process bus

(interbay and process bus can be used concurrently)LON bus

Data transfer rateIEC 1375 busData transfer rateEvent memory

Capacity

Time marker resolutionEngineering interface

9 pin Sub-D female9600 Bit/s

SPA or IEC 870-5-103216BM61b

2 plug-in sockets for type 3 cardsLON or IEC 1375 protocolIEC 1375 protocol

PC-Card with fibre-optical port, ST connectors1.25 MBit/s

PC-Card with redundant fibre-optical port, ST connectors1.5 Mbit/s256 events1 ms

integrated software interface for signal engineering with SigTOOL

Table 33:Contact data

Tripping:

Max. operating voltageMake and carry for 0.5 sContinuous currentMaking power

250 VAC or VDC30 AAC or A DC10 AC or A DC2500 VA

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Technical data (cont´d)

Rupture current with two contacts in series andL/R = 40 ms

at U ≤ 50 VDCat U ≤ 120 VDCat U ≤ 250 VDCSignalling stand by

No. of contacts (216GA61)No. of contacts (216GD61)Max. operating voltageMake and carry for 0.5 sContinuous currentMaking power

5 A1 A0,3 A

2 break contacts per signalling channel1 make contact per signalling channel4 signalling channels with 1 break contact250VAC or VDC10 AAC or ADC5 AAC or ADC1250 VAAC 60 WDC

Table 34:Auxiliary supply

Max. installed rating per cubicleSupply interruption bridging time

at min input voltage and full loadat rated input voltage and 70% load

400W> 10 ms> 50 ms

Table 35:General data

Temperature range

operationstorageHumiditySeismic testInsulation test

-10° C...+55°C-40°C...+85°C93%, 40°C, 4 days5g, 30s, 1..33Hz (1 octave/min)

2kV, 50Hz, 1 min

1kV across open contacts

0.5kV at the serial interface on the front-plate

>100MΩ, 500VDC5kV, 1.2/50µs1.0/2.5 kV, Cl. 3; 1MHz,400 Hz rep.freq.2/4 kV, Cl. 4

6/8 kV (10 shots), Cl. 31000 A/m 50/60 Hzpermanent field

• 0.15-80 MHz, 80% amplitude modulated10 V, cl. 3

• 80-1000 MHz, 80% amplitude modulated10 V/m, cl. 3

• 900 MHz, puls modulated10 V/m, cl. 3Cl. A

IEC 255-6 (1988)IEC 68-2-3 (1984)IEC 255-21-3 (1993)IEEE 344 (1987)IEC 255-5 (1977)

Leakage resistanceSurge voltage test

1 MHz burst disturbance test

IEC 255-5 (1977)IEC 255-5 (1977)IEC 255-22-1 (1988)ANSI/IEEE C37.90.1 (19)

EN61000-4-4 (1994), IEC 1000-4-4 (1995)EN 61000-4-2 (1994),IEC 1000-4-2 (1995)EN 61000-4-8 (1993),IEC 1000-4-8 (1993)ENV50141 (1993)ENV 50140 (1995),IEC 1000-4-3 (1995)ENV 50204 (1995)EN 50081-2 (1994),(EN55011 (1992),CISPR 11 (1990)),(EN 55022 (1995), CISPR 22 (1995))

Fast transient test

Electrostatic discharge test (ESD)

Immunity to magnetic interfer-ence at power system frequen-cies

Radio frequency interference test (RFI)

Emission

* Reduced values apply for repeat tests according to IEC publication 255-5, Clauses 6.6 and 8.6.

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Table 36:Mechanical design

Terminals

CT and PT circuits

tripping and signalling circuits

aux. dc supply and remaining aux. circuitsCubicle wiringCT and PT circuitsaux. dc supply

tripping and signalling circuitsstandard pre-made cablesCubicle design

Cubicle dimensions (w x d x h)

Total weight (with all aux. relays and units inserted)

10 mm2, Type Phoenix URTK/S4 mm2, Type Phoenix UKK5-MT KD-P/P(GKOS for 216GD61)

10 mm2, Type Phoenix UK4 (GKOS for 216GD61)directly mounted terminals1.50 mm20.5 mm20.25 mm2

ABB Type RESP (see catalogue 1MDB14004-EN)800 x 800 x 2200 mm200 to 400 kg

Ordering

In order to configure the generator protection system type REG216 the ABB-engineering group needs the information from the Ques-tionnaire 1MRB520026-Ken.

When ordering the compact version the fol-lowing has to be stated: •Rated current•Rated voltage•Optocoupler voltage

•Quantity of different units (electronic part) and interfaces

Table 37:Subcodes

SubcodeA-A0A1A2A5B0B1B2B5U0U1U2K01L01

Explanationnone1A2A5Anone1A2A5A

none

100...130VAC200...230VAC6 CT’s (3ph1 MT (1ph2 VT (1ph

3 VT (3ph delta6 CT’s (3ph3 MT’s (3ph

3 VT’s (3ph delta

1) 216GW62 Input transformer assembly2) 216GD61 Interface unit consisting of:8 tripping relays16 signalling relays16 optocouplers3 cables 216IK61

NOTE:

The compact version in addition requires con-figuration and final testing, which is normally not included. For customizing the compact version, please contact an ABB Power Auto-mation sales representative.

Descriptionrated current

Remarks for orderingfor protection transf.

B-rated currentfor measurement transf.

U-rated voltage

K-/L-

Code A-)Code B-)Code U-)Code U-)Code A-)Code B-)Code U-)

VT,CT and MTarrangement of transformer unit

Typ 216GW62Explanation:

CT= Protection transformerVT= Voltage transformer

MT= measurement transformer

K02L02

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Ordering (cont´d)

K03L03K04L04

6 CT’s (3ph

3 VT’s (3ph delta3 VT’s (3ph delta6 CT’s (3ph1 CT (1ph1Mt (1ph1 VT (1ph

3 VT (3ph delta9 CT’s (3ph1 MT (1ph2 VT’s (1ph9 CT’s (3ph

3 VT’s (3ph delta12 CT’s (3ph9 CT’s (3ph 3 MT’s (3ph3 CT’s (3ph3 MT’s (3ph

3 VT’s (3ph delta2 VT’s (1ph1 MT (1ph6 CT’s (3ph

3 VT’s (3ph delta3 VT’s (1ph 9 CT’s (3ph3 VT’s (3ph star3 CT’s (3ph

3 VT’s (3ph delta1 VT (1ph1 MT (1ph1 VT (1ph3 VT’s (spez.6 CT’s (3ph

3 VT’s (3ph delta1 VT (1ph2 VT’s (spez.1*GW621*GD61a

Code A-)Code U-)Code U-)Code A-)Code A-)Code B-)Code U-)Code U-)Code A-)Code B-)Code U-)Code A-)Code U-)Code A-)Code A-)Code B-)Code A-)Code B-)Code U-)Code U-)Code B-)Code A-)Code U-)Code U-)Code A-)Code U-)Code A-)Code U-)Code U-)Code B-)Code U-)Code U-)Code A-)Code U-)Code U-)Code U-)Code K-Code I-Code K-/ L-Code I-/J-Code K-/ L-Code I-/J-Code K-Code I-/J- Code K-Code I-/J-The variants M2,M3, M6 and M7 con-sisting of two units GW62. The first is specified with code Kx- and the second with code Lx-

K05L05K06L06K07L07K08L08K09L09

K10L10K11L11K12L12

95% Stator earth fault protection

100% Stator- + rotor earth fault protec-tion

K13L13

95% Stator earth fault protection100% Stator earth fault protection

M-M11*rack 216MB66 consisting of 1*NG6x, 1*EA61b, 1*AB61, 1*DB61

M21*rack 216MB66 consisting of 1*NG6x, 1*EA61b, 1*AB61, 2*DB612*GW622*GD61a

M31*rack 216MB66 consisting of 1*NG6x, 1*EA61b, 1*AB61, 1*DB612*GW621*GD61a

M41*rack 216MB66 consisting of 1*NG6x, 1*EA61b, 1*AB61, 2*DB611*GW622*GD61a

M51*rack 216MB68 consisting of 1*NG6x, 1*EA61b, 1*AB61, 1*DB61 per group1*GW622*GD61a

M61*rack 216MB68 consisting of 1*NG6x, 1*EA61b, 1*AB61, 1*DB61 per group

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2*GW622*GD61a

M7

2*GW624*GD61a

Code K- / L-Code I-/J-Code K- / L-Code I-/J-

1*rack 216MB68 consisting of 1*NG6x, 1*EA61b, 1*AB61, 2*DB61 per group

The above mentioned devices are included in the code Mx. The number and types of CPU’s must be specified by code

G-G1G2G4H1H2H4I0I1I2I3S1S2S3S4T0T6V5

165...312 V DC82.....156 V DC36......75 V DC165...312 V DC82.....156 V DC36......75 V DCnone

82...312 V DC36....75 V DC20....30 V DCSPA protocolLON protocolMVB protocolnone

Lithium-battery216VC62a

(S3/S4 only valid for new CPU 216VC62a)(Interbay- or/and process bus)

(216VC62a includes gold capacitor, no battery)(T-code for new CPU not necessary)425%

1.CPU

Communication and Dist.recorder included

Communication and Dist.recorder includedReset unit

Diskette for user interface program.

1.DC/DC-con-verter supply voltage2.DC/DC-con-verter supply voltage

for variant M1-M4 an optional 2. redun-dant DC/DC-converter can be used

H-

I-

Binary input/output unit GD61aoptocoupler input voltage

S-

T-V-

W-R-P-

W5R0R1PDPEPF

216VC62anoneavailable

German 3½“ (1.44MB)English 3½“ (1.44MB)French 3½“ (1.44MB)

425%

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Ordering (cont´d)

Table 38:Accessories

PCC card interfaceType

For interbay bus:PCCLON2 SET500PCC02For process bus:500PCC02Type216BM61b

ProtocolLONIEC 1375IEC 1375

ConnectorST (bajonet)ST (bajonet)ST (bajonet)

Optical fibre*G/GG/GG/G

Gauge **62,5/12562,5/12562,5/125

ID No

HESG 448766R0001HESG 448735R0231HESG 448735R0232

RS232C interbay bus interface

ProtocolSPA

ConnectorST (bajonet)

Optical fibre*G/G

Gauge **62,5/125

Order No.

Type/ID No.HESG448267R1021

* receiver Rx / transmitter Tx, G = glass, P = plastic Operator program disk (DOS-based)Language

German/English/French

Disk 3½“ (1.44MB)

**optical fibre conductor gauge in µm

Order No.Type/ID No.HESG448753R1

* Unless expressly specified the latest version is supplied.Operator program disk (Windows-based)LanguageEnglish

Optical fibre PC connecting cableType

YX216a-1 (4 m)YX216a-1 (10 m)YX216a-1 (30 m)

Disturbance recorder evaluation programType, descriptionREVAL EnglishREVAL GermanWINEVEWINEVE

3½“-Disk3½“-DiskEnglish/GermanEnglish/German

Order No.1MRK000078-A1MRK000078-D

Basic versionFull versionType/ID No.

Order No.7433 10-AA7433 10-BA7433 10-CA

Type/ID No.HESG448522R1HESG448522R2HESG448522R3

DiskCD ROM

Order No.

Type/ID No.HESG448798R0001

* Unless expressly specified the latest version is supplied.

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Variant M1 (single system)

Standard configuration:- 1*216NG6x- 1*216VC62a- 1*216EA61b- 1*216AB61- 1*216DB61

- 12 Input transformers- 8 Tripping relays - 16 Signalling relays - 16 Binary inputs Code G

(1*GW62)(1*GD61a)( „ )( „ )Code K

Code IOption:- additional CPU type 216VC62a - 2. DC/DC-converter (for redundant power supply)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M1K*A*B*U*G*H*I*V5W*S*R* P*3ABB Power Automation

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Ordering (cont´d)Variant M2 (single system)

Standard configuration:- 1*216NG6x- 1*216VC62a - 1*216EA61b- 1*216AB61- 2*216DB61

- 24 Input transformers- 16 Tripping relays - 32 Signalling relays - 32 Binary inputs Code G

(2*GW62)(2*GD61a)( „ )( „ )Code K / L

Code IOption:- additional CPU type 216VC62a - 2. DC/DC-converter (for redundant power supply)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M2K*L*A*B*U*G*H*I*V5W*S*R*P*3ABB Power Automation

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Variant M3 (single System)

Standard configuration:- 1*216NG6x- 1*216VC62a - 1*216EA61b- 1*216AB61- 1*216DB61

- 24 Input transformers- 8 Tripping relays - 16 Signalling relays - 16 Binary inputs Code G

(2*GW62)(1*GD61a)( „ )( „ )Code K / L

Code IOption:- additional CPU type 216VC62a - 2. DC/DC-converter (for redundant power supply)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M3K*L*A*B*U*G*H*I*V5W*S*R*P*3ABB Power Automation

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Ordering (cont´d)Variant M4 (single System)

Standard configuration:- 1*216NG6x- 1*216VC62a- 1*216EA61b- 1*216AB61- 2*216DB61

- 12 Input transformers- 16 Tripping relays - 32 Signalling relays - 32 Binary inputs Code G

(1*GW62)(2*GD61a)( „ )( „ )Code K

Code IOption:- additional CPU type 216VC62a - 2. DC/DC-converter (for redundant power supply)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M4K*A*B*U*G*H*I*V5W*S*R* P*3ABB Power Automation

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Variant M5 (redundant System)

Standard configuration:- 1*216NG6x (per group)- 1*216VC62a (per group)- 1*216EA61b (per group)- 1*216AB61 (per group)- 1*216DB61 (per group)- 12 Input transformers- 8 Tripping relays - 16 Signalling relays - 16 Binary inputs Option:- noneCode G

(1*GW62)(1*GD61a)( „ ) ( „ ) Code K / L(per group)(per group)(per group)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M5K*A*B*U*G*H0 I*V5W5S*R* P*3ABB Power Automation

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Ordering (cont´d)Variant M6 (redundant system)

Standard configuration:- 1*216NG6x (per group)- 1*216VC62a (per group)- 1*216EA61b (per group)- 1*216AB61 (per group)- 1*216DB61 (per group)- 24 Input transformers- 8 Tripping relays- 16 Signalling relays- 16 Binary inputsOption:- noneCode G

(2*GW62)(1*GD61a)( „ )( „ )Code K / L(per group)(per group)(per group)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M6K*L*A*B*U*G*H0 I*V5W5S*R*P*3ABB Power Automation

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Variant M7 (redundant System)

Standard configuration:- 1*216NG6x (per group)- 1*216VC62a (per group)- 1*216EA61b (per group)- 1*216AB61 (per group)- 2*216DB61 (per group)- 24 Input transformers- 16 Tripping relays- 32 Signalling relays- 32 Binary inputsOption:- none Code G

(2*GW62)(2*GD61a)( „ )( „ )Code K / L(per group)(per group)(per group)Ordering example for Racks with CPU-type 216VC62aHESG 324510 M1Code: M7K*L*A*B*U*G*H0 I*V5W5S*R*P*3Accessories (optional)ABB Power Automation

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Accessories (optional)

This may also be obtained elsewhere, how-ever correct operation of the overall system is crucial.

Printer to be connected to the PC.

EPSON type FX800 must possess a parallel Centronics interface.

Personal computer

event that the software functions increase (graphic display, etc.). Following require-ments should be met:

MByte RAM

Disk drive 3.5\1 CD-ROM drive

1 Hard disk minimum 500 MB1 serial interface (RS 232 C)2nd serial interface as option

A monochrome screen controller able to show block graphics (800 x 600 points or bet-ter)

•duplicating the whole system

Additional benefits considered are wide set-ting ranges, excellent long-term stability and few setting steps. The numerical system should offer a library of the available protec-tive functions. These functions will then be selected by the user by the simple assignment of parameters.

All protection functions should operate from sampled primary system voltages and cur-rents. The sampling rate of the analogue input units should be 12 times per period at rated power system frequency with a dynamic range of 15 bit.

The man-machine-communication should be performed easily using only a few push-but-ton commands on a personal computer (PC) via a serial RS 232 interface. No prior knowl-edge of programming should be necessary. For all functions the user is guided with the aid of screen menus and windows. All differ-ent languages for texts could be supplied. Any text change is accommodated easily.All the hardware components should be pack-aged in a single cabinet. This cubicle can also accommodate other protection relays with external functions, for example, 100% stator earth fault protection, Buchholz relay or some thermal sensors.

Various PC’s having a RS232 and working with the operating systems, Windows 95 or Windows NT 4.0 can be used. This PC type can also be used in the future in the probable

Sample

specification

Numerical protection equipment used for generator and block-transformer protection. It will be a stand-alone system but closely involved in the process. Parameters, signals, measured values as well as remote parameter regulation commands, will be exchanged via appropriate interfaces and a serial communi-cations channel to central process control equipment.

The system will be supported by a software library of diverse protection functions. A menu-driven HMI (human machine interface) will allow users to activate functions which are provided in the protection function library.The entire protective system will consist of a relatively small number of hardware compo-nents. This applies not only to the electronic units, but also to the process interfaces, such as current and voltage inputs as well as the numbers of signal and tripping relays.This flexibility resulting from the modular hardware will enable the equipment configu-ration to be easily adapted for installations of different sizes and the desired scope of pro-tection.

The system will permit various degrees of redundancy. The user can specify the desiredconfiguration

•duplicating power supply unit

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References

Relay mounting systemsOperating Instructions

REG 216 Numerical Generator Protection SystemQuestionnaire REG 216Reference List

1 MDB14004-EN1 MDU02005-EN1MRB520026-Ken1MRB520011-Ren

ABB Power Automation

Numerical generator protection

ABB Power Automation AG

Haselstrasse 16/122

CH-01 Baden/SwitzerlandTel. +41 56 205 77 44Fax +41 56 205 55 77Homepage:www.abb.ch/chpauPrinted in Switzerland (9911-1500-0)

REG216/ REG216

Compact

1MRB520004-Ben

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