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Type LGPG111Digital Integrated Generator Protection Relay
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Features
An optimum mix of generatorprotection functions
Applicable to a wide range ofgenerators
User configurable scheme logic
An alternative setting group
Wide operative frequency range
Display of measured values
Fault, event and disturbancerecording
Integral testing to aidcommissioning
Remote serial communications
Power-on diagnostics and self-monitoring
Eight optically isolated logicinputs for monitoring externalplant.
Type LGPG111Digital Integrated Generator Protection Relay
Figure 1: Relay Type LGPG111
Introduction
The LGPG111 is a multi-functionrelay which integrates a number ofcommon generator protectionfunctions and associated schemelogic into a single relay case.
Models Available
LGPG111Incorporating 14 separategenerator protection functions
(see Figure 2).
Application
The LGPG111 can be applied to awide range of generators. Each ofits protection functions can beenabled or disabled to suitindividual requirements.This approach avoids the need forapplication-specific relay versions,and simplifies the tasks of relayspecification, evaluation and projectplanning. The integrated schemelogic eliminates much panelengineering work by reducing theneed for auxiliary relays andassociated external wiring.
Contacts from external protection
and plant monitoring equipment canbe connected to any of the eightoptically-isolated inputs. This allowsexternal information to beincorporated into the relays user-configurable scheme logic.The optically-isolated inputs andrelay outputs may be labelled in thesoftware for local or remotemonitoring.These functions can be recorded inthe alarm and event recording
facilities.
The protection functions provided bythe LGPG111 relay are as shown inFigure 2.
Functions
Generator differential (87G)
The generator differential function isfor the protection of phase to phaseor three-phase stator windings faults
which normally involve high faultcurrents, so that fast fault clearanceis required. This function works on aper phase basis and has a dualslope bias characteristic as shown
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in Figure 3: the lower slopeprovides sensitivity for internalfaults, whereas the higher slopeprovides stability under through faultconditions, especially if thegenerator CTs saturate.
Stator earth fault (51N)
The stator earth fault function iscurrent operated and can betypically set to cover up to 95% ofthe stator windings. It is generallyused on resistively earthedgenerators, but can also be used torespond to current in the secondarycircuit of an earthing transformerloaded with a resistor. A time-delayed low set element and aninstantaneous high set element areprovided.
Neutral displacement (59N)
The neutral displacement function isvoltage operated and is used fordetecting stator winding earth faultson generators which are earthed viaa distribution transformer. Two timeroutput elements are provided.
Sensitive directional earthfault (67N)
When two or more generators are
connected in parallel directly to abusbar, the sensitive directionalearth fault function is used todiscriminate between internal andexternal earth faults. A dedicatedsingle-phase CT input is availablefor the operating current, which canaccept the residual current fromthree line CTs or current from adedicated core-balance CT.The polarising signal for thedirectional decision is either the
voltage signal applied to the neutralvoltage VT input or the currentsignal applied to the stator earthfault current input.
The stator earth fault, neutraldisplacement and sensitivedirectional earth fault functions allhave third harmonic rejection builtin by means of a software filter.
Voltage dependent
overcurrent (51V)The voltage dependent overcurrentfunction is used for system backupprotection and can trip thegenerator circuit breaker, if a fault
Figure 2: Protection functions provided by LGPG111
Figure 3: Generator differential bias characteristic
Figure 4: Voltage dependent overcurrent functions
Currentpick-uplevel
Currentpick-uplevel
I>
KI>
Vs Voltage
levelVoltage controlled mode Voltage restrained mode
I>
KI>
Vs2 Vs1 Voltage
level
Trip
Differentialcurrent
No TripIs1
Percentagebias K2
Percentagebias K1
Maximum mean bias currentIs2
has not been cleared by otherprotection after a certain period oftime. The voltage dependentfunction can be either voltagecontrolled or voltage restrained.
When voltage controlled, the timingcharacteristic is changed from aload to a fault characteristic whenthe voltage drops below a set level.
It is mainly used for generatorsconnected directly to the busbar.
When voltage restrained, thecurrent pick-up level is
proportionally lowered as thevoltage falls below a set value,producing a continuous variation oftiming characteristics. This isapplicable to generators connected
87G Generator dif ferent ia l
51N Stator earth fault
59N Neutral displacement
67N Sensitive directional earth fault
51V Voltage dependent overcurrent
32R Reve rse powe r
32L Low forward power
46 Negat ive phase sequence40 F iel d f ailu re
27 Unde rvol tage
59 Over voltage
81U Under frequency
81O Overf requency
60 Voltage balance
67N 51N
59N
51V 32R32L
40 46
2759
81U81O
60
87G
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to the busbar, each via a step-uptransformer.A voltage vector compensationfeature is also available todetermine the HV phase-phasevoltage signals where a Yd1 or aYd11 step-up transformer is used.
The timing characteristic can either
be definite time or IDMT.
The effects of the voltage level onthe current pick-up level for bothfunctions are shown in Figure 4.
Reverse power (32R) and lowforward power (32L)
Reverse power protection is used todetect loss of the prime mover.Low forward power protection canbe applied to steam turbine
generators where sequentialshutdown is preferable, under lessurgent operations, to avoid over-speeding. Both are balancedconditions, therefore a single phasemeasurement is sufficient. For thisfunction, the relay calculates VIcosfor the A-phase.
In order to provide the requiredsensitivity, a special current input isused for both of these functions.A compensation angle setting is alsoavailable to compensate for phaseerror of the generators CT and VTsignals. A delayed drop-off timer isincluded in the timing logic whichacts as an integrating timer. Thisallows the relay to trip within thepre-determined time delay, underpulsating power conditions.
Negative phase sequence (46)
Negative phase sequence function
is for the detection of sustainedunbalanced load conditions.Under such circumstances doublefrequency eddy currents are inducedin the rotor of a generator and cancause rapid overheating.The function has a thermal replicacurve which simulates the effects ofpre-fault heating due to low levels ofstanding negative phase sequencecurrent I2. When the I2 value is wellabove threshold, the thermal replica
approximates to a t = K/I22
characteristic, where K is thegenerators per-unit current thermalcapacity constant in seconds.
Figure 5: Negative phase sequence tripping characteristic
tMAX
t
tmin
I2>> I2
K
Figure 6: Field failure protection characteristic
The tripping characteristic is shownin Figure 5.
When high values of K are selectedand the negative phase sequencecurrents measured are near to thethreshold, the operating time maybe too slow. In this case, amaximum time setting tMAX isavailable to provide a safe trip time.
When I2 is high, the operating timemay become too fast and cause lossof discrimination with other powersystem protection under faultconditions. To reduce this risk, the
inverse characteristic is providedwith an adjustable minimumoperating time setting tMIN.
A separate thermal capacityconstant setting Kreset is alsoprovided for use when the generator
is cooling, due to a reduction in I2.This is to cater for rotor componentswith differing cooling time constants.
An independent alarm element witha definite time output is available forpre-trip warning purposes.
Field failure (40)
Severe loss of excitation caused byfield failure can cause a high valueof reactive current to be drawn from
the power system which canendanger the generator. The fieldfailure protection provided by thisrelay is a single phase impedancemeasuring element with an offset
Xa
Xb
X
R
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mho characteristic, as shown inFigure 6. An integrating timingarrangement, identical to that for thepower functions, is also provided.This allows the relay to trip withinthe pre-determined time delay eventhough the impedance measurementmay temporarily fall outside the mho
characteristic, eg. under pole-slipping conditions.
Undervoltage (27) andovervoltage (59)
An undervoltage element and a2-stage overvoltage element areprovided. They are primarily usedfor backing up the speed controlgovernor and the automatic voltageregulator. When severe overvoltageoccurs, the high set of the
overvoltage element can be set toprovide fast operation.Both elements are three-phasedevices.
Underfrequency (81U) andoverfrequency (81O)
Two underfrequency elements andone overfrequency element areprovided. The underfrequencyelements are used to detectoverloading of the generator caused
by various system disturbances oroperating conditions.The overfrequency element is usedto back-up the speed controlgovernor if overspeeding occurs.
Voltage balance (60)
The voltage balance function isprovided to detect VT fuse failure.It compares the secondary voltagesof two sets of VTs (or from twoseparately fused circuits of a singleVT) and can be used to blockpossible incorrect tripping of thoseprotection functions whoseperformance may be affected by theapparent loss of voltage such aswhen a VT fuse ruptures.
Timer held facility
Both the overcurrent function, thelow set element of the stator earthfault function and the neutraldisplacement function are providedwith a timer held facility.The purpose is to enable fasterclearance of recurrent intermittentfaults, for example, self-sealinginsulation faults. This facility allows
the relay timer to hold its valuewhen the current drops off, providedthat the drop-off period is less thanthe tRESET timer setting.This adjustable reset facility alsoenables closer co-ordination withelectromechanical induction discrelays.
Integrating timer facility
Time integration is required for thepower function to allow forreciprocating load conditions wherethe measuring element may pick upbriefly and periodically. The samefeature is also provided for the fieldfailure function for pole-slippingconditions. Time integration allowsthe function to operate within its pre-determined operating time.
To implement timing integration, anadditional delayed drop-off timer isprovided. Once the protectionmeasurement element has pickedup, the relay will operate after theset time delay, provided that thetime interval when the elementdrops off is within the setting of thedelayed drop-off timer tDO.
Frequency tracking
The relay tracks the power systemfrequency and continuously adjustsits internal sampling clock to exactmultiples of the system frequency.This provides correct measurementsand operation of the protectionfunctions during start-up and run-down of the generator set when thegenerator unit is operated at
abnormal frequency. The operatingfrequency range is from 25Hz to70Hz for the differential functionand from 5Hz to 70Hz for the otherprotection functions.
Configuration
Scheme logicThe protection scheme logic for agenerator set normally involves alarge number of protection functionscombined together to drive a fewcommon trip outputs. Some blockingand interlocking logic may also berequired. In order to accommodatedifferent generator applications, thescheme logic is flexible andreconfigureable.
The LGPG111 scheme logic is in theform of logic arrays with anarchitecture commonly found inprogrammable logic array devices,having an internal AND-ORstructure shown in Figure 7.
The OR functions allow one or moreof the AND function outputs tocontrol each output relay, whilst theAND functions provide blocking orinterlocking for two or more inputs,or just a through connection for one
input. There are 32 inputs to thescheme logic: 19 from theprotection functions, 8 optically-isolated inputs and a selection ofinverted inputs to allow blockinglogic to be created. The schemelogic controls a total of 15 outputrelays and has 32 selectable ANDfunctions.
Figure 7: Block diagram of the scheme logic
From protection elementsand status inputs
Output matrix
Input matrix
AND
AND
AND
OR OR OR
To output relays
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20ms. Thus the duration of a recordvaries with the data type. For rawdata, the duration is 64 electricalcycles, but for magnitude and phasedata, the duration is 7.68s.The latter set-up allows longduration events such as pole-slipping to be captured. In either
case, each data entry is timestamped. This is particularly usefulfor the raw data recording, sincethe sampling interval varies with thepower system frequency, due to thefrequency tracking.
The disturbance recorder can betriggered from selected relay outputsand status inputs. A maximum oftwo records can be stored in volatilememory. A record remains in thebuffer area until it is uploaded to a
PC, after which the buffer isreleased. If the two buffers are full,no further recording can be made.
Time synchronisation
The clock for event record timetagging has a resolution of 1ms.To provide time synchronisation withother equipment in the generatorstation, the clock can besynchronised by external clockpulses (0.5, 1, 5, 10, 15, 30 or 60minute period) from an optically-isolated input.
Print functions
Several print functions are providedto allow the relay to provide hard-copy documentation, via the frontpanel parallel port. This consists ofthe system settings, protectionsettings, scheme logic settings, eventrecords and fault records.
The scheme logic print-out isformatted so that it can becompared directly with the schemelogic diagram.
Test features
A number of features are providedto enable the relay to be thoroughlytested during commissioning, routinemaintenance and fault findingoperations:
The measurement functions allow
the analogue input and itsassociated wiring to be checked.
Display the on/off states of thestatus inputs and relay outputs.
The input and output matrices allowthe desired connections to becreated. Each intersection of thematrix represents a programmableinterconnection. By designing theappropriate interconnections andthen entering the information intothe relay, through the scheme logic
settings, the required tripping logiccan be configured.
The presence of the optically-isolated inputs to the scheme allowsexternal devices such as rotor earthfault relay, temperature sensingdevices and mechanical relays to beconnected to the scheme, so that thetripping facilities, together with thealarm and remote communicationfacilities, can be utilised.
The optically-isolated inputs andrelay outputs used in a scheme maybe allocated to any functionrequired by the application.The relay has a facility to label eachof these by providing an identifier.The identifiers are used during theconfiguration of the scheme logic,by the input and output statusdisplays and by the event, fault anddisturbance recording systems.
Alternative setting groupThe relay provides an alternativesetting group which consists of allthe protection and scheme logicsettings. It can be used during start-up or run-down of generators orduring changes in power systemconfiguration. This setting group canbe selected by either energising theappropriate optically-isolated inputs,or via the relay settings menu.
Ancillary Functions
Measurements
The magnitudes of all 17 analogueinputs to the relay are available fordisplay. Other derived quantities arealso available. This provides suchinformation as the three-phase,
residual and earth currents, thephase to phase voltages, differentialand bias currents, negative phasesequence current, phase A activeand reactive power plus the phaseangle and power system frequency.All measurements can be displayedin either primary or secondaryquantities, selectable by the user.Primary display quantities are basedon the settings for the CT and VTratios used by the relay.
Event and fault records
Up to 100 event records areavailable, all of them stored in non-volatile memory. The latest recordwill automatically overwrite theoldest one. Event records aregenerated whenever there is aprotection function operation,energisation of a status input,operation of an output relay or anyhardware failure.
Fault records are also stored asevents. Out of the 100 eventrecords, up to 50 fault records canbe accommodated. Fault recordsare initiated when user selectedrelay outputs operate. The recordconsists of the date and time of thefault, the state of the optically-isolated inputs, relay outputs andprotection functions, together withthe measurement values during the
fault.
Disturbance records
The internal disturbance recordercan store up to eight analoguechannels, together with all the statusinput and relay output information.The analogue channels are userselectable from the relays 17inputs.
The data in the analogue channels
can be stored as either raw data oras magnitude and phase data.The raw data is sampled at 12samples per electrical cycle,whereas the magnitude and phasedata are calculated once every
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Testing the four indicating LEDs.
Testing the relay outputs and theirassociated circuits by operatingthe relay output contacts.
Display the operation of eachprotection function as apercentage of the time-to-trip.
This allows the pick-up, progressand operation of each protectionfunction to be checked.
Testing the set-up of the schemelogic settings by manuallyentering an input pattern to thescheme, and then examining itslogical output. This test can beperformed at any time withoutinterfering with the relaysoperation.
Power-on diagnostics and selfmonitoring
Power-on diagnostic tests arecarried out by the relay when it isenergised. These tests includechecks on the timer, microprocessor,memory and the analogue inputmodule. Continuous self-monitoring,in the form of watchdog circuitry,memory checks and analogue inputmodule tests, is also performed. Inthe event of a failure, the relay willeither lock-out or attempt a recovery,depending on the type of failuredetected.
Hardware Description
The relay is housed in a 4U(178mm) high case suitable foreither rack or panel mounting.Internally, it consists of a number ofplug-in modules which areindividually tested and calibrated.The modular hardware architectureis shown in Figure 8.
The microcomputer module consistsof a powerful 16-bit microcomputerwhich controls all of the subsidiarymodules through a 64-way ribboncable called the I/O Bus.The processor performs all of themajor software functions such asinput signal processing, protectionalgorithms, scheme logic, relayoutput controls and handling of the
operator interface.The analogue input module consistsof 12 CTs, 5 VTs and 6 optically-isolated inputs. The CTs and VTs areused to isolate and condition theanalogue inputs from the maintransformers connected to thegenerator. Their output signals arethen converted into digital data forfurther processing.
In addition to the 6 optically-isolated
inputs on the analogue module, afurther 8 are provided by the statusinput module, making a total of 14optically-isolated inputs available tothe relay. Six of these have pre-defined functions, such as clocksynchronisation, setting groupselection, etc., which leaves 8 inputsto be fed into the scheme logic.
All of the optically-isolated inputsoperate from an auxiliary supplyVx(2), which is independent of themain auxiliary supply Vx(1).The ratings of Vx(1) and Vx(2) maybe different (see Technical Data).
Two relay output modules areprovided; each module contains 8
miniature relays. All relays are self-reset. However, a software functionis available which allows the user toselect outputs to be latched whenoperated.
The front panel consists of a 2 x 16character alphanumeric liquidcrystal display (LCD) and a 7 push-button keypad. It provides localaccess to all of the relays features.There are also 4 light emitting
diodes for visual indication of therelays status, a non-isolatedIEC 60870 serial port forconnection to a PC, and a parallelport for connection to a printer.
At the rear of the relay, apart fromthe normal dc supply and plantconnections, there is an isolatedIEC 60870 port and a K-Bus portfor permanent connection to aremote PC.
The remote communications moduleis responsible for handling thecommunications protocol and forcontrolling the three communicationports.
Figure 8: Hardware architecture
Relay
outputs
Remote
comms
Status
input
Analogue
inputs
Front
panel
Microcomputer
Powersupply
I/O bus
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User Interface
Front panel user interface
The features of the relay can beaccessed through a user-friendlymenu system. The menu is arrangedso that related items (menu cells) aregrouped into individual sections,
each of which is identified by a title.The user navigates around the menuby using the arrow keys, first toselect a particular section title andthen to select an item within it.The front panel liquid crystal displayis limited to displaying one menucell at a time.
Remote access user interface
The menu can be accessed via theremote communications facility.
This allows all of the menu cells in asection to be displayed on thescreen of a PC. Changes to themenu cell can be made from the PCkeyboard.
Relay interconnection
Three communication ports areavailable: the front panel, non-isolated IEC 60870 port; the rear,isolated IEC 60870 port; and theK-Bus port. The IEC 60870 ports useRS232 signal levels and allow point-to-point connection. It is applicablewhen networking is not required orduring commissioning.
Alternatively, the relays can beconnected via a shielded, twistedpair called K-Bus. Up to 32 relaysmay be connected in parallel to thebus.K-Bus can be connected through aprotocol converter, type KITZ, either
directly or via a modem, to theRS232 port of a PC. K-Bus is RS485based and runs at 64kbits/s.The K-Bus connection is shown inFigure 9.
Software is available with each KITZto provide access to the relays, toread and change settings.Additional software entitledProtection Access Software andToolkit is available to give access tothe event recorder, together withother additional functions.
Each relay is directly addressablevia the bus to allow communicationwith the PC. It should be noted thatprotection tripping and blockingsignals are not routed via the K-Bus.Separate conventional wiring isused for these functions.
Figure 9: K-Bus terminals connection arrangement
SK1
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10
Figure 11: Type LGPG111 scheme logic
Relay14
Relay15
Logic 0Logic 1Logic 2Logic 3
&&&&
Logic 4Logic 5Logic 6Logic 7
&&&&
Logic 8Logic 9Logic 10Logic 11
&&&&
Logic 12Logic 13Logic 14Logic 15
&&&&
Logic 16Logic 17
Logic 18Logic 19
&&
&&
Logic 20Logic 21Logic 22Logic 23
&&&&
Logic 24Logic 25Logic 26Logic 27
&&&&
Logic 28Logic 29Logic 30Logic 31
&&&&
Input13
Input12
Input11
Input10
Input9
Input9
Input8
Input8
Input7
Input7
Input6
Input6
60VBProt(Blocking)
60VBComp
60VBProt
40FieldFailure
67NSensitiveDirEF
59N2NeutralDisp
59N1NeutralDisp
51N>>StatorEF
51N>StatorEF
46>>NPSTrip
46>NPSAlarm
59OverVoltage
27Undervoltage
81U2Underfreq
81U1Underfreq
81OOverfreq
32LLow
ForwardPower
32RReversePower
51VOverCurrent
87GGeneratorDiff
Input Matrix
Output Inhibited
EN
Note: Speed of the relay outputs are:
Relays 1, 2, 8, 9, 10 8ms pick-up, 8 ms drop-off
Relays 3, 11 2ms pick-up, 2ms drop-off
Relays 4, 5, 6, 7,
12, 13, 14, 152ms pick-up, 8ms drop-off
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Technical Data
Ratings
Inputs
AC current In 1A or 5A
AC voltage Vn 100V to 120V
Nominal dc Operative range(V) (V)
Auxiliary voltage Vx(1) 24/27 19.2 32.4(Relay power supply) 30/34 24 40.8
48/54 38.4 64.8110/125 88 150220/250 176 300
Auxiliary voltage Vx(2) 24/27 19.2 32.4(Optically isolated status input supply) 30/34 24 40.8
48/54 38.4 64.8110/125 88 150220/250 176 300
Note: Vx(2) may be different fromVx(1)
Frequency Fn 50/60Hz
Burdens
AC current
Generator differential
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CT requirements
Generator differential
Biased differential Vk 50In (Rct + 2RL + Rr) where maximumsettings at Is1=0.05In, through fault currentk1=0%, Is2=1.2In, = 10 x In andk2=150% maximum X/R = 120
Vk 30In (Rct + 2RL + Rr) where maximum
through fault current= 10 x In andmaximum X/R = 60
Note: Minimum knee point voltage = 34V
Earth fault protection functions
Sensitive directional Vk 6In (Rct + 2RL + Rr) where maximumearth fault, using three X/R = 5 andresidually connected maximum earth faultline CTs current = 1 x In
Sensitive directional Vk 6NI
n(R
ct+ 2R
L+ R
r) where maximum
earth fault, using core X/R = 5 andbalance CT maximum earth fault
current = 2 x In
Stator earth fault Vk 6NIn (Rct + 2RL + Rr)
Ancillary protection functions
Voltage dependent Vk 20In (Rct + 2RL + Rr)overcurrent, field failureand negative phasesequence
where Vk = Minimum current transformer knee-point voltage for stabilityIn = Relay rated current (1A or 5A)
Rct = Resistance of current transformer secondary winding ()
RL = Resistance of a single lead from relay to current transformer ()
Rr = Resistance of any other protection functions sharing the currenttransformer ()
N =Maximum earth fault current
Core balanced CT or earth CT rated primary current
Note: N should not be greater than 2. The core balance CT or earth CT
ratio must be selected accordingly.
Power function
For settings >3% Pn Use correctly loaded class 5P protection CT
For settings 3% Pn Use metering class CT. See table below.
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Metering CT class recommended forpower setting less than 3%Pn
Reverse/low forward Power Setting Metering CT Class(%Pn)
0.20.1
0.4
0.6
0.80.2
1.0
1.2
1.4
1.6
1.8
2.0 0.5
2.2
2.4
2.62.8
1.03.0
Thermal withstand
Continuous withstand CT input 4 x InVT input 400V
Short time withstand CT input 100A for 1s (In = 1A)400A for 1s (In = 5A)
Setting ranges
Generator differential
Basic differential current setting Is1 0.05In to 0.1In in 0.01In steps
Threshold for increase bias Is2 1In to 5In in 0.1In steps
Bias K1 (Ibias < Is2) 0% to 20% in 5% steps
Bias K2 (Ibias > Is2) 10% to 150% in 10% steps
Stator earth fault
Low set element:
Characteristic Standard inverse/Definite time
Current setting Ie> 0.005In to 0.5In in 0.005In steps
Time multiplier setting TMS 0.05 to 1.2 in 0.05 steps
IDMT Operating characteristic t =0.14
(I/Ie>)0.021x TMS
Definite time setting t> 0.1s to 10s in 0.1s steps
Reset timer setting tRESET 0s to 60s in 1s steps
High set element:
Current setting Ie>> 0.005In to 2In in 0.005In steps
Time setting t>> 0s to 5s in 0.1s steps
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Neutral displacement
Voltage setting Ve> 1V to 25V in 1V steps
Timer 1 setting t1 0.5s to 5s in 0.5s steps
Timer 2 setting t2 1s to 10s in 1s steps
Timer 2s reset timer t2RESET 0s to 60s in 1s steps
Sensitive directional earth fault
Operating current Ires> 0.005In to 0.02In in 0.005In steps
Polarising voltage Vp> 1V to 10V in 1V steps
Polarising current Ip> 0.005In to 0.02In in 0.005In steps
Relay characteristic angle RCA 95 to 95 in 1 steps
Voltage dependent overcurrent
Functions Voltage controlled/Voltagerestrained/Simple
Characteristic Standard Inverse/Definite Time
Current setting I> 0.5In to 2.4In in 0.05In steps
Time multiplier TMS 0.05 to 1.2 in 0.05 steps
IDMT Operating characteristic t = 0.14(I/I>)0.021
x TMS
Definite time setting t 0s to 10s in 0.1s steps
Reset timer setting tRESET 0s to 60s in 1s steps
Voltage settings:
Vs (for voltage controlled) 20V to 120V in 1V steps
Vs1 (for voltage restrained) 80V to 120V in 1V stepsVs2 (for voltage restrainted) 20V to 80V in 1V steps
K factor 0.25 to 1.00 in 0.05 steps
Voltage vector rotate None or Yd
Current pick-up level
Voltage Controlled Voltage Restrained
I> for V> Vs I> for V > Vs1
KI> for V Vs KI>I> KI>
VS1 VS2+ (V V
S2)for Vs1 V Vs2
KI> for V < Vs2
Reverse power
Power setting P> 0.2W to 8W in 0.05W steps(for 1A relay)
1W to 40W in 0.25W steps(for 5A relay)
Delayed pick-up timer t 0.5s to 10s in 0.5s steps
Delayed drop-off timer tDO
0s to 5s in 0.1s steps
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Low forward power
Power setting P< 0.2W to 8W in 0.05W steps(for 1A relay)
1W to 40W in 0.25W steps(for 5A relay)
Delayed pick-up timer t 0.5s to 10s in 0.5s steps
Delayed drop-off timer tDO 0s to 5s in 0.1s stepsCompensation angle comp 5 to +5 in 0.1 steps(for both reverse andlow forward power)
Note: The power settings are single phase quantities.
Negative phase sequence trip element
Trip threshold setting I2>> 0.05In to 0.5In in 0.01In steps
Thermal capacity constant (heating) K 2s to 40s in 1s steps
Thermal capacity constant (cooling)
Kreset 2s to 60s in 1s stepsOperating characteristic K
I2>>2t = 1loge
I2>>I2
2
(under no pre-heating condition)
Maximum operating time tmax 500s to 2000s in 10s steps
Minimum operating time tmin 0.25s to 40s in 0.25s steps
Negative phase sequence alarm element
Alarm threshold I2> 0.03In to 0.5In in 0.01In steps
Alarm timer setting t> 2s to 60s in 1s steps
Field failure
Mho offset Xa 2.5 to 25 in 0.5 steps(for 1A relays)0.5 to 5 in 0.1 steps(for 5A relays)
Mho diameter Xb 25 to 250 in 1 steps(for 1A relays)5 to 50 in 0.2 steps(for 5A relays)
Delayed pick-up timer t 0s to 25s in 0.1s steps
Delayed drop-off timer tDO 0s to 5s in 0.1s steps
Undervoltage
Voltage setting V< 30V to 110V in 1V steps
Timer setting t 0.1s to 10s in 0.1s steps
Overvoltage
Voltage settings V> ,V>> 105V to 185V in 1V steps
Timer settings t>, t>> 0s to 10s in 0.1s steps
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Underfrequency
Frequency settings F1< ,F2< 40Hz to 65Hz in 0.05Hz steps
Timer settings t1, t2 0.1s to 25s in 0.1s steps
Overfrequency
Frequency settings F> 40Hz to 65Hz in 0.05Hz steps
Timer settings t 0.1s to 25s in 0.1s steps
Voltage balance
Voltage setting Vs 5V to 20V in 1V steps
Digital inputs
Optically isolated inputs 14 (6 dedicated, 8 available to thescheme logic)
Contacts
Output relays 10 dual make
2 single make3 change-over
Power supply failure alarm 1 single make1 single break
Relay inoperative alarm 1 change-over
Contact rating Make: 30A and carry for 0.2sCarry: 5A continuousBreak: dc 50W resistive
25W inductive(L/R = 0.4s)
ac 1250VA
Subject to maxima of 5A and 300V
Durability
Loaded contact 10,000 operations
Unloaded contact 100,000 operations
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Communications
Language Courier
IEC 60870 port (front/rear)
Transmission mode Asynchronous
Signal levels RS232
Message format IEC 60870 FT1.2
Data rate 600 19200 bits/s
Connection Single-ended
Cable type Screened multi-core
Cable length 15m
Connector 25-way D-type female
Isolation Front (non-isolated)
Rear (1kV rms for 1 minute to case
earth and other circuits)
K-Bus portTransmission mode Synchronous
Signal levels RS485
Message format HDLC
Data rate 64 kbits/s
Connection Multidrop (32 units)
Cable type Screened twisted pair
Cable length 1000m
Connector Screw terminals
Isolation 2kV rms for 1 minute
Voltage withstand
Dielectric withstandIEC 60255-5: 1977 2.0kVrms for 1 minute between all
terminals and case earth
2.0kVrms for 1 minute betweenterminals of independent circuits,including contact circuits
1.0kVrms for 1 minute acrossopen contacts of output relays
1.0kVrms for 1 minute betweenIEC 60870 rear port and earth
High voltage impulseIEC 60255-5: 1977 Three positive and three negative
impulses of 5kV peak, 1.2/50s,0.5J between all terminals of thesame circuit (except outputcontacts), between independentcircuits and between all terminalsconnected together and case earth
Insulation resistanceIEC 60255-5: 1977 >100M
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Electrical environment
DC supply interruptionsIEC 60255-11: 1979 The relay will withstand a 10ms
interrupt in the auxiliary supply,under normal operating conditions,without de-energising
AC ripple on dc supply
IEC 60255-11: 1979 The unit will withstand 12% acripple on the dc supply
High frequency disturbanceIEC 60255-22-1: 1988 Class III 2.5kV peak between
independent circuits and betweenindependent circuits and case earth
1.0kV peak across terminals ofthe same circuit (except metalliccontacts)
Electrostatic dischargeIEC 60255-22-2: 1996 Class 2 4.0kV discharge in air with cover
in place.
4.0kV contact discharge with coverremoved.
Fast transient disturbanceIEC 60255-22-4: 1992 Class III 2.0kV, 5kHz applied directly to
auxiliary supply2.0kV, 5kHz applied directly toall inputs
Class IV 4.0kV, 2.5kHz applied directly toauxiliary supply
4.0kV, 2.5kHz applied directly toall inputs
Radio frequency interference
Radiated immunityIEC 60255-22-3: 1989 Class III field strength 10V/m
Extended frequency range 20MHzto 1000MHz
Conducted immunityIEC 60801-6: 1994 10V rms, 0.15MHz to 80MHz
Radiated emissionsEN55022: 1994 Class A
Conducted emissionsEN55022: 1994 Class A
EMC compliance89/336/EEC Compliance with the EuropeanEN50081-2: 1994 Commission Directive on EMC isEN50082-2: 1995 claimed via the Technical
Construction File route.Generic Standards were used toestablish conformity
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Product safety73/23/EEC Compliance with the European
Commission Low Voltage Directive.
EN 61010-1: 1993/A2: 1995 Compliance is demonstrated byEN 60950: 1992/A11: 1997 reference to generic safety
standards.
Atmospheric environment
TemperatureIEC 60255-6: 1988 Storage and transit
-25C to +70C
Operating25C to +55C
HumidityIEC 60068-2-3: 1969 56 days at 93% relative humidity
at 40C.
Enclosure protectionIEC 60529: 1989 IP50 (dust protected)
Mechanical environment
VibrationIEC 60255-21-1: 1988 Vibration response Class 2
Vibration endurance Class 2
Shock and bumpIEC 60255-21-2: 1988 Shock response Class 2
Shock withstand Class 2
Bump Class 1
SeismicIEC 60255-21-3: 1993 Class 2
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Case
The relay is housed in a multi-module Midos case as shown inFigure 12.
Additional Information
LGPG111 Service Manual R5942
Courier Communications leaflet R4113
Figure 12: Case outlines
432
438
Removablecover
Hinged frontpanel
465483
178 101.6
Front
252
10
Push buttonprojection 10mm max.
10
450 min.
465.1 1.6
7 max.
31.750.4
12.70.4
Tolerance betweenany two holeswithin a distance
of 1mm 0.4
10.67
Fixing hole detail
U ScaleU = 44.45
Allow a minimum of50mm for terminal blockand wiringSide
Rack mounting
Panel mounting
483mm Rack detailsDimensions to IEC 297
432
438
Removablecover
Hinged frontpanel
443
201
Front
252
10
Push buttonprojection
10mm max.
10
440
Allow a minimum of 50mm forterminal block and wiring
Side
Panel cut-out detail
37
178
400
200
191180.5
Fixing holes5.4
All dimensions in mm
Mounting screws are not provided
Terminal screws:M4 x 8 brass Cheese Head withLockwashers are provided
37
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Unit type: L G P G 1 1 1 0 1
Case mounting
Flush panel PRack R
Vx(1) auxiliary voltage
24 27V dc 1
30 34V dc 2
48 54V dc 3
110 125V dc 4
220 250V dc 5
Vx(2) auxiliary voltage
24 27V dc 130 34V dc 2
48 54V dc 3
110 125V dc 4
220 250V dc 5
VT and CT rating
100/120V 1A L
100/120V 5A M
Language
English E
French F
German G
Spanish S
Information Requiredwith Order
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St Leonards Works, Stafford, ST17 4LX England
Tel: 44 (0) 1785 223251 Fax: 44 (0) 1785 212232 Email: [email protected] Internet: www.alstom.com
1999 ALSTOM T&D Protection & Control Ltd
ALSTOM T&D Protec tion & Control Ltd