generator protection 1
TRANSCRIPT
Generator protection
Presented by
Bipasha Jash (PEE)
NTPC
Classification of Generator Protection
Stator Protection
Generator Abnormal Operating conditions System back up protections Rotor protection GT protections UT protections
Over view of type of fault Vs protection
FAULT/ABNORMAL CONDITION
EFFECT PROTECTION
Thermal over loading
Over heating of stator winding/insulation failure
Thermo couples/Over current relays
External fault Unbalanced loading stress Over load/negative phase sequence relay
Stator fault Ph to Ph/Ph to E Inter turn
Winding burn outWelding of core lamination
Differential prot100% E/F prot/95% E/FInter turn prot
Rotor fault Damage to shaft/bearing 2 stage rotor E/F protection
Motoring LFPR/Rev power
O/V,O/F,U.F Insulation failure,Heating of core failure of blades
O/V relay Volt/Hz relayU/F relay
Loss of field Induction gen operationAbsorb MVAR from system/damage to rotor wdg
Loss of field
Generator Connection Methods
The protection scheme depends on the type of generator connection A) Unit scheme: In this scheme no switchgear is provided between the generator and generator transformer, which are treated as a unit; a unit transformer is tapped off the interconnection for supply of power to auxiliary plant.B) Generator circuit breaker scheme:In this scheme a generator circuit breaker is provided between the generator and generator transformer.
TRIP LOGIC OF GENERATOR PROTECTION
TWO INDEPENDENT CHANNELS WITH INDEPENDENT CT/VT INPUTS/DC SUPPLY/TRIP RELAY
CLASS A TRIPALL ELECTRICAL TRIPSTRIP TURBINE, GENERATOR, GT, UT
CLASS-B TRIPMECHANICAL TRIPSAVOID OVER SPEEDING OF TURBINE DUE TO STEAM ENTRAPPED IN TURBINE. TURBINE TRIP SIGNAL IS GIVEN FIRST AND THE ACTIVE POWER, SENSED BY THE LOW FORWARD RELAY (32G) GIVES THE TRIP SIGNAL TO THE UNIT BREAKER & FIELD BREAKER AFTER A TIME DELAY
Class CTRIPS ONLY HV CB IN CASE OF GCB SCHEME
Typical Generator protection scheme
GENERATOR PROTECTIONSNTPC PRACTICES
DIFFERENTIAL PROTECTIONUNIT TYPE PROTECTION
INSTANTANEOUS IN OPERATION.
COVERS THE STATOR WDG FOR PHASE TO PHASE FAULTS.
SINGLE PHASE TO EARTH FAULTS ARE NOT COVERED IN HIGH IMP EARTHING SYSTEMS (EARTH CURRENT IS LOW)
DUPLICATED DIFF USED FOR GCB SCHEME
TYPICAL SETTING: HIGH IMP TYPE: 5% BIASED 10%
STATOR EARTH FAULT PROTECTION
E/F CURRENT IS LIMITTED TO 10ATHIS MINIMIZES THE DAMAGEFIRST FAULT LESS CRITICALNEEDS CLEARANCE AS
IT MAY DEVELOP INTO A PH TO PH FAULT SECOND FAULT WILL RESULT IN VERY HIGH CURRENT
FIRE MAY RESULT FROM EARTH FAULT.TWO TYPES:
100 % E/F95 % E/F
95 % STATOR E/FRESULTS IN VOLTAGE SHIFT OF GEN NEUTRAL W.R.T. GROUNDDETECTED BY OVER VOLTAGE RELAY CONNECTED ACROSS GROUNDING RESISTORPROTECTS APPROX 95% OF STATOR WDGTYP SETTING:
5V TIME DELAY OF MORE THAN 1 SEC(GEN IDMT RELAY WITH PMS 5.4 AND TMS 1 IS USED)
100% Stator E/F Protection
THIRD HARMONIC PRINCIPLE
A RELAY WHICH RESPONDS TO THE REDUCTION OF THE 3RD HARMONIC COMPONENT A STATOR PHASE-TO-GROUND FAULT OCCURS AT OR NEAR THE GENERATOR NEUTRAL, THERE WILL BE AN INCREASE IN THIRD HARMONIC VOLTAGE AT THE GENERATOR TERMINALS, WHICH WILL CAUSE RELAY OPERATION.
DISADVANTAGES
DUE TO DESIGN VARIATIONS, CERTAIN GENERATING UNITS MAY NOT PRODUCE SUFFICIENT THIRD HARMONIC VOLTAGES THIS METHOD DOES NOT PROTECT THE M/C DURING STAND STILL CONDITIONS.
100 % Stator E/F protectionLOW FREQUENCY INJECTION PRINCIPLE
THIS SCHEME DETECTS THE GROUND FAULTS BY INJECTING A LOW FREQUENCY SIGNAL (SAY 20 HZ)AT THE NEUTRAL EARTHING TRFR OR LINE CONNECTED EARTHING TRFR AND MONITOR EITHER THE EARTH CURRENT IN THE WDG(INCREASES DURING A FAULT) OR THE STATOR EARTH RESISTANCE (REDUCES DURING FAULT)
PROVIDES PROTECTION EVEN DURING SHUT DOWN
SETTINGS TYPICAL FOR 500 MW UNIT14 mA /1 sec (current setting )
ORTrip : 10 Ohm/1 secAlarm : 20 ohm/10 sec( for Imp measuring relaySETTINGS ARE TO BE FINALISED DURING COMMISSIONING TEST IN LINE WITH INSTRUCTIONS OF RELAY CATALOGUE.
Rotor Earth Fault Protection
FIRST ROTOR E/F DOES NOT CAUSE IMMEDIATE DAMAGESECOND E/F RESULTS IN A WDG SC OF ROTOR CAUSE MAGNETIC UNBALANCE/MECH FORCES /DAMAGEMETHODS OF DETECTION
POTENTIOMETER METHODA CENTRE TAPED RESISTOR IS CONNECTED ACROSS THE MAIN FIELD WINDING THE CENTRE TAP IS CONNECTED TO EARTH THROUGH A VOLTAGE RELAYAN EARTH FAULT ON THE FIELD WINDING WILL PRODUCE VOLTAGE IN THE RELAY, MAXIMUM VOLTAGE OCCURRING FOR END FAULTSA BLIND SPOT EXISTS AT THE TAPPING POINT, TO AVOID THIS , THE TAPPING POINT IS VARIED WITH A PUSH BUTTON OR SWITCH , AND IS TESTED PERIODICALLY TO DETECT BLIND ZONESETTING IS 5% OF FIELD VOLTAGE
LOW FREQUENCY INJECTION METHOD
MODERN ROTOR EARTH FAULT PROTECTION RELAY OPERATES ON THE PRINCIPLE OF LOW FREQUENCY INJECTION INTO THE FIELD WINDING VIA CAPACITORS.
IF AN EARTH FAULT OCCURS, THE CORRESPONDING CURRENT OR RESISTANCE IS DETECTED
TYP SETTING (500 MW)
ALARM 40 K OHM TIME = 10 SEC
TRIP 5 K OHM TIME = 1 SEC
ACTUAL VALUES OF SETTING SHALL BE DECIDED AT SITE DURING COMMISSIONING TO ACCERTAIN THE HEALTHY VALUE OF THE PARTICULAR M/C.
INTER TURN PROTECTION
CURRENT BASED SYSTEMFOR GENERATORS WITH SPLIT NEUTRALS WITH ALL SIX TERMINALS BROUGHT OUT ON NEUTRAL SIDE DELAYED LOW-SET O/C RELAY WHICH SENSES THE CURRENT IN THE CONNECTION BETWEEN THE NEUTRALS OF THE STATOR WINDINGS
VOLTAGE BASED SYSTEM RELAY COMPARES THE NEUTRAL NGT SEC VOLTAGE AND GEN TERMINAL OPEN DELTA VOLTAGE
BALANCE DURING E/F OR NORMAL CONDITIONDURING INTER TURN FAULT OPEN DELTA VOLTAGE WILL BE DEVELOPED AND NGT SEC VOLTAGE WILL BE ZERO, RESULTING IN A DIFFERENTIAL VOLTAGE WHICH MAKES THE RELAY OPERATE
IDMT RELAYS WITH 5.4 PMS AND 1 TMS ARE ADOPTED.
O/V PROTECTION
TYP SETTINGS OF A 3 STAGE O/V RELAY IS AS FOLLOWS
ALARM 110 % 2 SEC TRIP 120 % 1 SEC
140 % INSTANTANEOUS
U/F O/F PROTECTION
TYPICAL SETTING:ALARM - 47.8HZ 1 SECTRIP - 47.4 HZ 2 SECSETTING NEED TO BE CO-ORDINATED WITH THE RESPECTIVE
RLDC AND THE ISLANDING SCHEME SETTINGS
Negative Sequence protectionNEGATIVE SEQUENCE PROTECTION FOR GENERATOR PROTECTS THE GENERATOR FROM EXCESSIVE HEATING IN THE ROTOR RESULTING FROM UNBALANCED STATOR CURRENTSCAUSED DUE TO
ONE POLE OPEN IN LINEONE POLE OPEN OF A CIRCUIT BREAKERCLOSE IN UNCLEARED UNBALANCED FAULTS
THE NEGATIVE SEQUENCE PROTECTION RELAYS SHALL BE SET TO THE NPS CAPABILITY OF THE MACHINE WHICH IS K = I2
2* T
TYP FOR 500 MW PERMISSIVE NEG SEQ CURRENT = 5 – 8 % OF STATOR
CURRENTPERMISSIVE I2
2* T = 5 – 10
SETTINGS ADOPTED FOR NTPCI2 = = 7.5 %
I22*T = 8.3
Loss of Field Protection
ACTS AS AN INDUCTION GENERATORINDUCED EDDY CURRENTS IN THE FIELD WINDING, ROTOR BODY, WEDGES AND RETAINING RINGS MW FLOW IN TO THE SYSTEM/MVAR FLOWS IN TO THE MACHINE.THE APPARENT IMP TRAVELS TO THE FORTH QUADRANT OF X-Y PLANE
METHODS OF DETECTION: UNDER VOLTAGE + O/C
MINIMUM IMPEDANCE WITH U/V
SOME RELAYS ARE SET IN THE ADMITTANCE PLANE MATCHING WITH THE CAPABILITY CURVE OF THE MACHINE
LOSS OF FIELD RELAY
BIG M/C WITH GOOD AVR
SMALL MACHINES
OUT OF STEP PROTECTIONMACHINE RUNS OUT OF SYNCHRONISM WITH THE NETWORKCYCLIC VARIATION OF ROTOR ANGLE CURRENT INCREASES HEAVILY FREQUENCY DEPEND ON THE RATE OF SLIP RESULT IN THE WINDING STRESS IT MAY ALSO DAMAGE THE AUXILIARIES OF THE AFFECTED UNIT DETECTED BY SENSING THE VARIATIONS IN IMPDISTINGUISH BETWEEN THE RECOVERABLE SWING AND THE IRRECOVERABLE SWING
TWO BLINDERS(IMPEDANCE) + A SUPERVISORY MHO ELEMENT, TRIP WHEN IMP IS INSIDE THE MHO AND CROSED THE BLINDERS
MINIMUM IMPEDANCE (MULTIPLE ZONE) + COUNTING NO. OF SWINGS
POLE SLIPPING CHARACTERISTIC
ACCIDENTAL BACK ENERGISATION
CAUSE OPERATION AS AN INDUCTION MOTOR
DAMAGE MACHINE AND TURBINETHE RAPID HEATING IRON PATHS NEAR THE ROTOR SURFACE DUE TO STATOR INDUCED CURRENT.
DETECTED BY OVER CURRENT + CB AUXILIARY CONTACTS
CHECKS FOR THE CURRENT WHEN THE GEN BREAKER CONTACTS ARE OPENSET BELOW THE RATED CURRENT (50 –70%)
O/C AND U/V MEASUREMENTS
Backup Impedance protection FOR UNCLEARED SYSTEM FAULT
THE BACKUP PROTECTION IS TIME DELAYED TO COORDINATE WITH THE ZONE 3 SETTING OF LINES .
DETECTED BYOVER CURRENT DISTANCEDISTANCE PREFFERED AS THE LINE IS PROVIDED WITH DISTANCE RELAYS
SETTING SHOULD BE MADE TO COVER THE GT IMP AND THE LONGEST LINE IMPSETTING SHOULD TAKE CARE OF THE INFEED FROM OTHER GENERATORS CONNECTED TO THE SAME BUS ALSOTIME SETTING 1.5 –2 SEC
LOW FORWARD AND REVERSE POWER INTERLOCK
To protect the machine from motoring action
Trip under class B after a short time delay in case the turbine is already tripped ( typ set at 2 sec)
Trip under class A, after a long time delay if turbine is not tripped (typically set at 10 sec)
Power setting typ 0.5 % of rated power
GEN TRANSFORMER PROTECTION
DIFFERENTIALBIASED DIFFERENTIAL
10 % BIAS SETTING (TO COVER TAP RANGE AND CT MISMATCH, IF ANY)
TIME INSTANTANEOUS
BACK UP EARTH FAULTDEF TIME OR IDMT RELAY20 % WITH 2 SEC TIME DELAY
TO BE COORDINATED WITH DISTANCE PROT ZONE 3
UT PROTECTIONDIFFERENTIAL
BIASED DIFF USEDBIASED SETTING 10%
BACK UP OVER CURRENT 2-3 TIMES THE FULL LOAD CURRENT DELAY 0.9 SECTAKE CARE OF ANY LARGE MOTOR STARTING CASE
RESTRICTED E/FHIGH IMP DIFFSET TO 5%-7% IN HIGH IMP EARTHING
COMMONLY USED GEN/GEN TRFR RELAYSPROTECTION
ALSTOM ABB SIEMENS REMARK
HIGH IMP DIFF
CAG 34MICOM P343
RADHAREG 216
7UM 62In case of duplicated diff, one low imp & one high imp preferredFor trfr biased relay preferred
BIASED DIFF
MBCHMICOM P 633
RADSBRET 316
7 UT
POWER RELAYS
RXPE PPX 7 UM SERIES Directional power relays
LOSS OF FIELD
RAGPC(DIR O/C+U/V)
YCGF 7UM SERIES Impedance / admittance
100% E/F PVMMMICOM P343PG871
GIX REG 216
7UE227UM SERIES
Low frequency injection type preferred over 3 rd harmonic principle
95% E/F VDG 7UM SERIES Open delta of gen sec VT
BACK UP IMP
YCG15 RAKZB 7UM 516 Minimum impedance
PROTECTION
ALSTOM ABB SIEMENS Remarks
OVER FLUXING
GTTM RATUBRALK
7RW IDMT
POLE SLIPPING
ZTO+YTGM15
RXZF+RXPE 7UM 516 IMPEDANCEIMP+ DIR O/CIMP+NO OF POWER SWINGS
ACC. BACK ENERG
CTIG RAGUA 7UM SERIES O/C +CB AUX CONTACTCURRENT ELEMENT+U/V
INTERTURN
VDG 7UM SERIES comp of open delta 0n gen term+ngt sec voltage
NEG PH SEQ
CTN RARIB 7UM SERIES MEASUREMENT OF
I2REF CAG/FAG RADHD 7UM SERIES HIGH IMP
PREFFERED
ROTOR E/F
VDG 7UR 227 UM SERIES
Type of fault Protection Channel Recommendation
Short circuit 87 G187G287 GT
121&2
Stator Earth Fault 64G164G2
12
Inter turn 95G 1 &2
unbalance 46G 1&2
Over load 51G Alarm <
Loss of excitation 40G140G2
12 >100 MW
Out of step 98G 1&2
Motoring 32 G1/2 / 37 G1/G2 1 / 2
O/V,O/FU/F
59/9981G1/81G1
1 /21/2
System back up 21G 1 & 2
Accidental energisation
50GDM 1 &2
Rotor E/F 64F 1 &2
Stator protections
Generator Transformer/Unit Transformer Protections
Fault Device no Channel
Recommendation
Short ckt(GT)
87T87 HV51 GT
122
Earth Fault(GT)
51 NGT64GT(3 Ph GT)64T
111/2
Short circuit(UT)
87 UT51UT
1/21/2
Earth Fault UT 51 NUT64 UT
12
THANK YOU