Sravanthi Relay Setting Chart

7/27/2019 Sravanthi Relay Setting Chart

1/24

Greenesol Power Systems Pvt. Ltd.,

Doc No: P-1113-G60-1-RS Rev:00 Page 1 of 24

Revision

Rev Descriptions Date Approved

0 R0-Issued for approval 11.07.11

PROJECT225 MW KASHIPUR GAS COMBINED CYCLE POWERPROJECT AT KASHIPUR.

OWNER M/s. SRAVANTHI ENERGY PVT LTD.

OWNER

CONSULTANTM/S.TATA CONSULTING ENGINEERS LIMITED, BANGALORE.

EPC

CONTRACTOR

M/s. SRAVANTHI INFRATECH PVT

LTD (EPC DEVISION)

EPC

CONSULTANT

M/s. TOSHIBA TERMAL AND HYDRO POWER SYSTEM

COMPANY TOSHIBA INDIA PVT LTD.Prepared by 11.07.11

STG RELAY SETTINGSSRIRANGAN

Checked by 11.07.11 GREENESOL POWER SYSTEMS PVT. LTD.,# 995, SERVICE ROAD,RPC LAYOUT, VIJAYANAGAR,

BENGALURU 560 040.

ARK

Approved by 11.07.11

DJY

CAD File Date: Size Scale Drawing No: P-1113-G60-1-RS

Office: GPSPL NA

Job Number: P-1113


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Input Details

Generator data:

Rated Generator output: 100 MVA (80 MW)

Rated voltage between phases: 11.5 kVPower Factor: 0.8Rated speed: 3000 rpmFrequency: 50 Hz

Current at full load = 100x 106/ 3 x 11.5 x 103= 5020.58 AI2Capability : 10%I2

2t Constant: = 15Direct axis synchronous reactance Xd(UNSAT) : 2.077 p.uDirect axis synchronous reactance Xd(UNSAT) :2.7468 OhmsDirect axis transient reactance Xd(SAT) : 0.163 p.uDirect axis transient reactance Xd(SAT) :0.2155 Ohms [(kV

2/ MVA) * p.u)]Direct axis sub transient reactance Xd(SAT): 0.103 p.u

Direct axis sub transient reactance Xd(SAT):0.1362 ohms [(kV2

/ MVA) * p.u)]Fault current: 80KALine-1 length: 18km ACSR DRAKE conductor (To be confirmed by consultant)Line-2 length: 4km ACSR DRAKE conductor (To be confirmed by consultant)

Neutral grounding Transformer (NGT)Ratio: 11KV/220V

CT / PT DetailsGenerator 11.5 kV side, CT ratio: 5500/1 A

GROUND CTRATIO:50/1A

Generator PT ratio: 11.5kV/3/ 1103 V


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Generator Protection

Protection functions Generator Protection system GPR-1 G60 are:Note: Similar protection functions are enabled in GPR-2 relay also.

1. Generator Differential Protection - 872. Generator Unbalance Protection 463. Loss of Excitation Protection 404. Under Frequency 81U5. Over Frequency 81O6. Over Voltage 597. Under Voltage 27

8. Over Excitation / Over Fluxing Protection 249. Phase Instantaneous O/C Protection 50P10. Phase IDMT O/C Protection 51P11. Neutral IDMT O/C Protection 51N12. Directional Power Protection - 3713. 100% Stator Ground Fault Protection 64TN14. Dead Machine Protection 50/2715. System Back-up O/C Protection - 51V16. Back-up Impedance protection 21G17. Pole Slipping Protection (78G)18. Reverse active power protection (32P)19. Reverse reactive power protection(32Q)

Protection functions for CDG 11 relay

1. Stand-by Earth fault Protection (51S)

Protection functions for RXNB-4 relay

1. Rotor Earthfault Protection (64F)


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Generator Differential Protection (87)

Relay Type - G60Make - GE MULTILIN

CalculationThe differential current pickup setting can be set as low as 5% of rated generator current, toprovide protection for as much of the winding as possible. Thus, to obtain maximum sensitivity,the differential pickup current is chosen as 0.05 P.U.

The percentage differential element has a dual slope characteristic.The through current is adjusted to compensate for CT ratio error mismatch and CT response viaa dual slope characteristic typically as shown below.

Slope 1, set at 15% starting from 0.04 (Restrain Current) as shown below.The STATOR DIFF BREAK 1 setting should greater than the maximum overload expected for the

machine, so it is set at 1.25 PU

Slope 2, set at 80 %.The STATOR DIFF BREAK 2 setting is set at 3 PU.

0.5 2.0 3.02.51.0 1.5

0.5

2.

0

3.0

4.0

5.0

6.0

1.0

I Restraint (Multiples of CT)

IOperate

(MultiplesofCT)

Slope 115 %

Slope 2

80 %

Operating

Region

Restraint

Region

Minimum Pickup = 0.5

Fig-1


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Protection Setting

SlNo

ProtectionFunction

Setting Available in the Relay RecommendedSetting

Remarks

1 Stator Differential

PickupSlope 1Break 1

0.05 to 1 p.u in 0.001 p.u steps.1 - 100% in 1% steps.1 to 1.5 p.u in 0.01 p.u steps.

0.0515%1.25

Slope 2

Break 2

1-100%IN 1%STEPS

1.5 to 30 p.u 0.01 p.u steps

80%

3.00 p.u

Generator Unbalance Protection (46)

Calculation

System Details:

Asymmetrical short circuit performance is given by I22t = 10

Continuous negative sequence capability = 8%CT Ratio = 5500/1

The generator nominal currentInom(p.u) = (Inomprimary) / CT Primary

=5020.4/5500

= 0.912 P.URecommended settings:Stage 1Pickup = 100% x I2 capability

= 1.0 x 8%= 8 %of FLC= 8%

The minimum operate time of Stage 1 = 0.2secondsThe maximum operating time = 600 seconds

Stage 2 is typically set lower than Stage 1 with a time delay to prevent nuisance alarms forexternal faults that are normally cleared by system protection.Stage 2 pickup = 5.6% (70% of I2capability) with time delay of 10 sec.


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Protection Setting

Sl

No

Protection Function Setting Available in the Relay Recommended

Setting

Remarks

1 GEN UNBAL INOMStage 1 PickupStage 1 K-ValueStage 1 TminStage 1 TmaxStage 1 K-ResetStage 2 PickupStage 2 PickupDelay

0.000 to 1.250 p.u in steps of 0.0010.00 to 100.00% in steps of 0.010.00 to 100.00 in steps of 0.010.000 to 50.000 s in steps of 0.0010.0 to 1000.0 s in steps of 0.10.0 to 1000.0 s in steps of 0.10.05 to 30.00 p.u in steps of 0.010.0 to 1000.0 s in steps of 0.1

0.9128%100.2 s600.0 s240.0 s5.6%10 s

Stage 1for86BTrip

Stage 2for 86CTrip

Loss of Excitation Protection (40)

This protection is applicable when the unit is running in Generator Mode.

CalculationXd = 2.077 puXd = 0.163 pu

MVA =100

CTR/PTR = (5500 / 1) x (110/11500) = 52.6

Zbase(sec) = (base kV

2

/ base MVA) x (CT ratio / VT ratio)= (11.5 kV2 / 100 MVA) x (5500/ 104.5) = 69.63

Xd (sec) =Xdx Zb

= 0.163 69.63 = 11.34

Xd(sec) = Xdx Zb

= 2.07769.63 =144.62

CENTER 1 = (Zbase(sec) + Xd(sec) ) / 2 = (69.63+ 11.34) /2 = 40.48RADIUS 1 = Zbase (sec)/2 = (69.63 ) /2 = 34.81 PICKUP DELAY 1 = 0.06 seconds

The stage 1 element should be time delayed to allow for blocking by the VT fuse failure element(50mS)

CENTER 2 = (Xd(sec)+ Xd(sec)) / 2 = (144.62 +11.34 ) /2= 77.98RADIUS 2 = Xd(sec)/ 2= (144.62)/2 = 72.31


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During stable Power swing conditions the positive-sequence impedance maymomentarily enter the stage 2 characteristics. For security of the function under suchconditions, it is recommended to delay stage2 by a minimum of 0.5 seconds

FIG-2

Protection Setting

SlNo

Protection Function Setting Available in the Relay RecommendedSetting

Remarks

Center 1Radius 1UV SupervisionPickup Delay 1

Center 2Radius 2UV Supervision

Pickup Delay 2UV Supervision

0.10 to 300.00 in steps of 0.010.10 to 300.00 in steps of 0.01Disabled, Enabled0.000 to 65.535 s in steps of 0.01

0.10 to 300.00

in steps of 0.010.10 to 300.00 in steps of 0.01Disabled, Enabled

0.000 to 65.535 s in steps of 0.010.000 to 1.250 p.u in steps of 0.001

40.4834.81Enabled0.06

77.9872.31Disabled

0.50.7

BLOCK Flex logic VT FUSE FAIL

Under Frequency Protection (81U)

Rated frequency is 50 Hz

UNDERFREQUENCY 1

SlNo

Protection Function Setting Available in theRelay

RecommendedSetting

Remarks

1 Min Volt/Amp 0.10 to 1.25 p.u in stepsof 0.01

0.5 To Trip 86C


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Pickup 20.00 to 65.00 Hz in stepsof 0.01

47.5

Pickup Delay 0.000 to 65.535 s in stepsof 0.001

0.5 sec

Reset Delay 0.000 to 65.535 s in steps

of 0.001

0 sec

UNDERFREQUENCY 2

SlNo


RecommendedSetting

Remarks


0.5 To Trip 86B


47.5


3 sec

Reset Delay 0.000 to 65.535 s in stepsof 0.001

0 sec

Over Frequency Protection (81O)

Stage -1

SlNo


RecommendedSetting

Remarks


0.5 To Trip 86C


52.5


0.5 sec

Reset Delay 0.000 to 65.535 s in stepsof 0.001 0 sec

BLOCK Flex logic


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Stage-2

SlNo


RecommendedSetting

Remarks

1 Min Volt/Amp 0.10 to 1.25 p.u in steps

of 0.01

0.5 To Trip 86B


52.5


3 sec

Reset Delay 0.000 to 65.535 s in stepsof 0.001

0 sec

BLOCK Flex logic

Over Voltage Protection (59)

These settings are used as backup for failure of AVR or other regulators. The time settings shouldalso be depended on the withstand levels of the machine

Calculations:Trip stage-1 & 2 110 % of the rated Voltage

Protection Setting Stage-1

SlNo

ProtectionFunction


Remarks

Pickup 0.000 to 3.000 p.u in steps of 0.001 1.1 p.u To TRIP 86CDelayReset Delay

0.00 to 600.00 s in steps of 0.010.00 to 600.00 s in steps of 0.01

0.5 s1.00 s

Stage-2 (Flex Elements-1, 2 & 3)

SlNo

ProtectionFunction


Remarks

Pickup -90 to 90 p.u in steps of 0.001 1.1 p.u To TRIP 86B

Delay 0.00 to 65.50 s in steps of 0.001 3.00 s

Under Voltage Protection (27)

Calculations:Trip stage-1 & 2 90 % of the rated Voltage

Under Voltage stage 1

SlNo

ProtectionFunction


Remarks


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1 Mode Phase to Ground, Phase to Phase Phase to Phase To Trip 86C

Pickup 0.000 to 3.000 p.u in steps of 0.001 0.90 p.u

Curve

Delay

Definite Time, Inverse Time

0.00 to 600.00 s in steps of 0.01

Definite Time

0.50 s

Min Volt 0.000 to 3.000 p.u in steps of 0.001 0.100 p.u

Under Voltage stage 2

SlNo

ProtectionFunction


Remarks

1 Mode Phase to Ground, Phase to Phase Phase to Phase To Trip 86B

Pickup 0.000 to 3.000 p.u in steps of 0.001 0.90 p.u

Curve

Delay

Definite Time, Inverse Time

0.00 to 600.00 s in steps of 0.01

Definite Time

3.00 s

Min Volt 0.000 to 3.000 p.u in steps of 0.001 0.100 p.u

Over Excitation Protection (24)Calculations:Rated Generator Voltage: 11.5 kV, 50 HzRatio of the voltage transformer: 11500/3/110/3

Rated generator secondary voltage: 63.5Rated generator V/Hz on secondary side: 63.5/50 = 1.27 V/Hz.With max. Permissible continuous over excitation 105% (assumed)

Definite Time Element (ALARM SETTING):Minimum Pickup Level = 1.06 x 1.27 = 1.3462 PU (106 %)Independent Time Delay= 3 s

Inverse Time Element (TRIP SETTING):Select setting 110 % of rated generator V/Hz.Minimum Pickup Level = 1.1 x 1.27 V/Hz = 1.397 PU

Protection SettingVOLTS PER HERTZ 1 (Stage-1)

SlNo


Remarks

1 Pickup 0.80 to 4.00 p.u in steps of0.01

1.35 ALARM


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2CURVES

Definite Time, Inverse A,Inverse B, Inverse C,Flex Curve A, Flex Curve B

Definite time3 seconds

3TDMULTIPLIER

0.05 to 600.00 in steps of 0.01

4 T Reset 0.0 to 1000.0 s in steps of 0.1 1 second

VOLTS PER HERTZ 2 (Stage-2)

SlNo


Remarks

1 Pickup 0.80 to 4.00 p.u in steps of0.01

1.4 To TRIP 86B

2 Curves Definite Time, Inverse A,Inverse B, Inverse C,

Flex Curve A, Flex Curve B

Inverse B

3 TD Multiplier 0.05 to 600.00 in steps of 0.01 3 sec

4 T Reset 0.0 to 1000.0 s in steps of 0.1 0.1sec

Generator Phase Instantaneous O/C (IOC) Protection (50P)

The phase instantaneous overcurrent element is used as an instantaneous element with nointentional delay or as a Definite Time element. The input current is the fundamental phasor

magnitude.The setting is selected to protect for fault at or near generator terminals.

CalculationPhase Instantaneous Over CurrentMax. Fault current of Generator = 48741.74A (i.e 5020.4 / 0.103)

Therefore we have chosen the trip setting as 30% of the total fault value for protecting thegenerator windings. i.e 48741x0.3 = 14622.52A. When it is converted into secondary we get14622.52 / 5020.4 = 2.91 p.u

PROTECTION SETTING

SlNo


Remarks

Pickup 0.000 to 30.000 p.u in steps of0.001

2.91 p.u

Delay 0.00 to 600.00 s in steps of0.01

0


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Reset Delay 0.00 to 600.00 s in steps of0.01

0

Generator Phase time O/C (TOC) Protection (51P)

This protection is implemented using a Phase TOC element.The pickup of this element is set at a safe margin above the maximum load expected on themachine.

Pickup = 1.1x Generator Nominal CurrentCT Primary

= 1.1 x 5020.45500

= 1.004P.U

The equation for IEC Curve-A is as follows:

T = TDM x KI E

I Pick up - 1

Where, I= Input current, I Pickup=Relay Setting current, K = 0.14(constant), E = 0.020

(constant) and Considered operating time for a three phase fault on the HV side oftransformer as 0.50s (to be confirmed by customer).

0.50TDM = 0.14

8.86 0.021.004 - 1

TDM = 0.16

Protection setting


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Available Setting Recommended Setting

Function Enabled, Disable Enabled

Input Phasor, RMS Phasor

Pickup 0.00 to 30.00pu in steps of 0.001 1.004P.U

Curve IEC Curve-A

TD Multiplier 0.00 to 600.00 in steps of 0.01 0.16

Reset Instantaneous, Timed InstantaneousVoltage Restraint Disabled, Enabled Disabled

Target Self-reset, Latched, Disabled Latched

Events Disabled, Enabled Enabled

Directional PowerLow Forward Power (37)

Assuming 10% as the minimum power below which the generator should trip on turbine faults, weget: 10%of 80MW = 0.1 X 80 = 8 MW

Smin = Minimum operating Power (PW)

3 X Phase CT Primary X Phase VT Ratio X Phase VT Sec

= 8MW

3 X 5500 X 104 X 63.5

= 0.073 P.U

Smin = - 0.0734 P.U (For Low forward power SMIN< 0. Refer b diagram below)Delay = 3 secondsRCA = 180


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Available setting Sensitive Power 1 Sensitive Power 2

SensitiveDirectional PowerRCA

0 to 359 in steps of 1 180 270

Stage 1 SMIN 1.200 to 1.200 pu in stepsof 0.001 - 0.0734 p.u 0.0743 p.u

Stage 1 Delay 0.00 to 600.00 s in stepsof 0.01

3 seconds 2 seconds

Stage 2 SMIN 1.200 to 1.200 pu in stepsof 0.001

0.0743 p.u NA

Stage 2 Delay 0.00 to 600.00 s in stepsof 0.01

2 seconds NA

Block VT FUSE FAIL OP VT FUSE FAIL OP

100% Stator Ground Fault Protection (64TN)

This element has two stages, stage 1 to Trip the machine & stage 2 for Alarm. Set the pickup to0.15 for both stages to provide adequate overlap with the Auxiliary voltage element. Set stage 1to 0.375V secondary (this value may be increased for security in particularly noisy environments).Stage 2 is typically set at 0.3 V secondary. The supervision settings are expressed in per unit ofthe Nominal phase VT secondary setting. The time delay settings are 5 seconds for stage 1 and 1second for stage 2 elements respectively

This protection will be set after measurement of third harmonic voltage generated by themachine at various loads.

Calculation

Stage-1 supervision = 0.375/63.5V= 0.0059 p.u

Stage-2 supervision = 0.300/63.5V= 0.0047 p.u


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Protection Setting

Available setting Recommended setting

Stage 1 Pickup 0.000 to 0.250 p.u in stepsof 0.001

0.15 p.u

Stage 1 Pickupdelay

0.00 to 600.00 s in stepsof 0.01 s

5 seconds

Stage 1 supv 0.0010 to 0.1000 p.u insteps of 0.0001 p.u

0.0059 p.u

Stage 2 Pickup 0.000 to 0.250 p.u in stepsof 0.001

0.15 p.u

Stage 2 Pickupdelay

0.00 to 600.00 s in stepsof 0.01 s

1 seconds

Stage 2 supv 0.0010 to 0.1000 p.u insteps of 0.0001 p.u

0.0047 p.u

Dead Machine Protection (50/27)

PROTECTION SETTING

SlNo


Remarks

Accdnt Enrg ArmingMode

UV or Offline / UV & Offline UV & Offline

Accdnt Enrg OC pickup 0.00 to 3.00 p.u in steps of0.01

1.0

Accdnt Enrg UV pickup 0.00 to 3.00 p.u in steps of0.01

0.7

Accdnt Enrg Offline OFF, ON OFF

Back-up Impedance protection (21G)

Generator Trafo. Impedance @ 11.5 kV base = 11.52x 0.125

95

= 0.174Ohm

Generator Transformer Impedance x 0.8 = 0.174x 0.8

= 0.1392

Secondary Impedance = 0.1392 x CT ratio

PT ratio

= 0.1392 x 52.60


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= 7.3231 Ohm

Line Backup impedance protection setting

Line Positive sequence impedance / km = 0.3Ohm (Assumed. Exact to be given by customer).

Line Voltage = 230kV

Line-1 Length = 18km

Line-2 Length = 4km

Total Line-1 Impedance (ZL1) = 0.3 x 18 = 5.4 Ohm

Total Line-2 Impedance (ZL2) = 0.3 x 4= 1.2 Ohm

Total Impedance on 230kV Base = ZL1*ZL2/ ZL1+ ZL2

= 0.981 Ohm

Impedance on 11.5 kV base = Impedance on 230kV base x 11.52

2302

= 0.9818 x 11.52

2302

= 0.002450 Ohm

Total Impedance = (Line Impedance + Transformer Impedance) x 1.1

= 0.00245+ 0.0.174x 1.1

= 0.1940 Ohm

Total Secondary Impedance = 0.1940 x CT ratio

PT ratio

= 0.1940 x 52.60

= 10.20Ohm

Generator Impedance = Xd x VL2

MVA

= j2.077 x 11.52

100

= j 2.746 Ohm

Zone 3 = (1.2 x Generator Impedance x CTR) / PTR

= (1.2 x j3.02 x 5500) / 110


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= j164.80 Ohm

Available Setting Recommended

Setting for Zone-1

Recommended Setting for

Zone-3

Function Enabled, Disabled Enabled Enabled

Function Forward, Reverse, Non-Directional Forward Reverse

Xfmr Vol

connection

Dy1, Dy3, Dy5, Dy7, Dy9,

Dy11, Yd1, Yd3, Yd5, Yd7,

Yd9, Yd11

Dy1 None

Xfmr Cur

connection

Dy1, Dy3, Dy5, Dy7, Dy9,

Dy11, Yd1, Yd3, Yd5, Yd7,

Yd9, Yd11

Dy1 None

Reach 0.02 to 500.00 Ohm in steps of

0.01

10.20 Ohm 164.80 Ohm

Delay 0.000 to 65.535s in steps of

0.001

5.00s 100ms (considering Back-

up protection for Gen. Diff)

Back-up Impedance should have time delay marginally higher than the longest time delay employed in any of

the protection system which is tripping the Generator CB.

Pole Slipping protection / Power Swing Blocking (78G)

The out of step protection is used to detect a loss of synchronism of the generator. The

impedance locus is measured as compared with blinders and MHO circle.

SGnom= 100 MVA

UGnom= 11.5 KV

IGnom= SGnom = 5020.6A3.UGnom

Generator nominal impedance in Primary value

XGnom= UGnom2

= 1.3225SGnom

Secondary impedance calculated from primary impedance, CT generator neutral end ratioand VT output ratio.


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XGsec= XGpri. CTRatio = 69.53VTRatio

Generator synchronous reactance in p.u. value

Xd = 2.077

Primary impedance calculated from nominal (generator) voltage and nominal apparentpower

Xdprim= Xd.UGnom2 = 2.745SGnom


Xdsec= Xdprim.CTratio = 144.42PTratio

Generator transient reactance in P.U. value

Xd = 0.187

Primary impedance from nominal (generator) voltage and nominal apparent power

Xdprim= Xd .UGnom2 = 0.247SGnom


Xdsec= Xdprim.CTratio =13.008PTratio

Transformer impedance in p.u. value

Uk = 12.5% = 0.125 p.u

Primary impedance calculated from nominal (generator) voltage and nominal apparentpower


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ZTprim= Uk . U2LVnom = 0.181STnom

Secondary impedance calculated from primary impedance and CT generator output ratio.

ZTsec=ZTprim.CTratio = 9.872PTratio

The protective function operates if the impedance locus crosses first the right blinder and within atime delay the left blinder.

Generator Impedance

The generator impedance is equal to the transient reactance:

Zg= j.Xdsec = 16.418i

Transformer Impedance

The transformer impedance is equal to the short circuit impedance:

Zt= j.ZTsec = 9.872i


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External system Impedance

Zsext= 3.97. exp (j.86 deg) (Assumed. Customer to give the exact value)

The impedance is based on 220KV and has to be adapted to the generator voltage,

Zs= Zsext. U2Gnom .CTR = 0.541(220KV)2 PTR

System Impedance:

Z = Zg+ Zt+ Zs = 0.0135+ 26.829i

MHO Characteristics

The forward reach is calculated with the transformer impedance as following:

Reach =150%

Fwdreach= |Reach.Zt| = 14.805

The forward angle is equal to the angle of the system impedance as following:

Fwdrca= arg(Z) = 89.97

The reverse reach is calculated with the generator impedance as following:

Reach=200%

Revreach= |Reach.Zg| = 32.836

The reverse angle is equal to the angle of the generator impedance

Revrca= arg(Zg) = 90

Blinder Calculation


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Outer Blinder

The outer blinder is calculated with the system angle as following:

out= 60

The offset between the right and left blinder is calculated according the picture above as following:

180- outtan 2

Offsetout = . |Z| = 46.46 sin (arg(Z))

With this offset the position of the right and left blinder is as following:

180

- outtan 2 |Z| |Zg|Blinderoutright = . + = 23.24

sin (arg(Z)) 2 tan(arg(Z))

Blinderoutleft = Offsetout - Blinderoutright= 23.22


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Inner Blinder

The inner Blinder is calculated with the system angle as following:

in= 120

The offset between the right and left blinder is calculated according the picture above as following:

180- intan 2

Offsetin = . |Z| = 15.50 sin (arg(Z))

With this offset the position of the right and left blinder is as following:

180- intan 2 |Z| |Z

g|

Blinderintright = . + = 7.75 sin (arg(Z)) 2 tan(arg(Z))

Blinderinleft = Offsetin Blinderinright = 7.75

PROTECTION SETTING

SlNo


Remarks

Power Swing Shape Mho, Quad Mho

Power Swing Mode Two step, Three stepTWO STEP

Power Swing Supv 0.050 to 30.00 p.u in steps of0.001

0.6

Power Swing Fwd Rch 0.1 to 500.00 Ohm in steps of0.01

14.8

Power Swing Quad FwdRch

0.1 to 500.00 Ohm in steps of0.01

-

Power Swing Quad FwdRch Mid


-

Power Swing Quad Fwd

Rch Out

0.1 to 500.00 Ohm in steps of

0.01

-

Power Swing Fwd RCA 40 to 90Deg. in steps of 1 89.97

Power Swing Rev Reach 0.1 to 500.00 Ohm in steps of0.01

32.8

Power Swing Quad RevRch Mid


-

Power Swing Quad RevRch Out


-

Power Swing Rev RCA 40 to 90Deg. in steps of 1 90


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Power Swing Outer LimitAngle

40 to 140Deg. in steps of 1 60

Power Swing MiddleLimit Angle


Power Swing Inner LimitAngle


Power Swing Outer Rgt

Bld

0.1 to 500.00 Ohm in steps of

0.01

23.24

Power Swing Outer LftBld


23.22

Power Swing Middle RgtBld


-

Power Swing Middle LftBld


-

Power Swing Inner RgtBld


7.75

Power Swing Inner LftBld


7.75

Power Swing Pickup

Delay 1

0.000 to 65.535 s in steps of

0.001

0.03

Power Swing ResetDelay 1

0.000 to 65.535 s in steps of0.001

0.05

Power Swing PickupDelay 2

0.000 to 65.535 s in steps of0.001

0.017


0.000 to 65.535 s in steps of0.001

0.009


0.000 to 65.535 s in steps of0.001

0.017

Power Swing Seal-inDelay

0.000 to 65.535 s in steps of0.001

0.4

Power Swing Trip mode Early, Delayed Early

Power Swing Blk Flex logic operand off

Power Swing target Self reset, latched, disabled Self-reset

Stand-by Earth fault relay (51S)

Relay Type - Electromagnetic relayMake - GE MULTILIN


Pickup 0.1 to 2.4 x In 0.10 x In

Curve Standard Inverse

TDM 0.05 to 2.00 0.1

Rotor Earthfault relay (64F)


24/24

Greenesol Power Systems Pvt. Ltd.,Relay Type - RXNB4Make - ABB


Stage-1 **5000 Ohm

Delay 3 secs.

Stage-2 **2000 OhmDelay 2 secs.

Note: **-To be checked and decided at site.

Documents

Sravanthi Relay Setting Chart