r0 ve j108 d e212 relay setting calculation hpl16 09 13

PROJECT:

DATED 19.08.13

DSGND. MN

CHKD. GP

BY APPVD. APPVD. GP REV: A

CONTRACTOR: HPL ELECTRIC & POWER PVT. LTD.

CLIENT:POWER TRANSMISSION CORPORATION OF UTTARKHAND

LIMITED(PTCUL)

220/132/33kV SUBSTATION, DEHRADUN

DESIGNER: VOLTECH ENGINEERS PVT LTD

TITLE: RELAY SETTING CALCULATION AND COORDINATION

DOC. NO: VE-J108-D-E212

A For Approval 19.08.13

REV. DESCRIPTION DATE

S.No Page No

A 1

1 2

1.1 3

1.2 5

1.3 7

1.4 9

2 11

2.1 12

2.2 14

2.3 16

2.4 18

3 20

3.1 21

3.2 23

3.3 25

3.4 27

3.5 34

3.6 41

3.7 48

4 52

4.1 53

4.2 55

4.3 57

4.4 59

4.5 66

4.6 73

4.7 80

4.8 86

4.9 92

4.10 98

4.11 102

4.12 106

5 108

6 109

7 110

8 111

9 112

10 113

11 114

12 115

13 116

14 117

15 118

16 119

17 120

18 121

19 121

20 150

Total Pages -160

OLV-SC Analysis Ph-G-Maximum

Short Circuit Analysis Repot-Minimum

Short Circuit Analysis Repot-Maximum

Relay Setting -ETAP Format

220-132kV POC Coordination

220-132kV EOC Coordination

220-132kV SC Trip Coordination

OLV-SC Analysis Three phase-Minimum

OLV-SC Analysis Three phase-Maximum

OLV-SC Analysis Ph-G-Minimum

220kV Distance Protection(10kM) Main-2

220/132kV 160 MVA Transformer Differential Proetction

220/132kV 160 MVA Restricted Earthfault Proetction

220 kV Bus Bar protection

0.433-33kV POC Coordination

132-33kV EOC Coordination

0.433-33kV EOC Coordination

132-33kV POC Coordination

220 kV Line OC and EF






132 kV Line Distance Protection(22kM)


132/33kV 40 MVA Trafo Differential Protection

220kV

160 MVA Transformer OC and EF

220 kV Bus Coupler OC and EF

CONTENT

Description

33kV

33kV Capacitor bank- OC and EF

33kV Line OC and EF

33kV Bus coupler OC and EF

NOTES

11/0.415kV

0.415kV MSB Bus coupler

0.415kV MSB Incomer-1

0.415kV MSB Incomer-2

11/0.415kV 400KVA Transformer

11/0.433kV POC Coordination

11/0.433kV EOC Coordination

40 MVA Transformer OC and EF(LV Side)

132kV

40 MVA Transformer OC and EF(HV Side)

160MVA Transformer OC and EF(LV Side)

132kV Line OC and EF


A1

Note:

1

2 There is no NCT for REF and SBEF Protection of 40 MVA Transformer,

SBEF Protection For 160MVA Transformer is Not provided, Since the NCT is Not available

Page 1 of 160

0.415kV FEEDERS

Page 2 of 160

MAKE MODEL

1.1. Non Directional Overcurrent and Earth Fault Protection for 0.415kV MSB BC

CT Details

CT Ratio = 1000/1 A

CT Primary = 1000 A

CT Secondary = 1 A

Class = 5P20

Transformer Data:

Rated power = 0.4 MVA

Rated HV Voltage = 11.00 kV

Rated LV Voltage = 0.43 kV

Full Load current HV Side = 21.00 A

Full Load current LV Side = 533.36 A

Impedence = 0.450 4.50%

Phase Over current setting

O/C SETTING (51):

Load current I load = 533.36 A

CT secondary current, = i Load / CT ratio

= 0.53

Consider 110% of transformer Full load = 586.70 Primary

Pickup Phase fault Secondary , recommended = 0.59 Secondary

Time Multiplier Setting

Characteristics = IDMT Normal inverse

t Required operating time in seconds =

= 0.25

Minimum Fault current = 11240.00 A

I Fault current at secondary = I fault / CT ratio

11.24 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.25*(((11.24/0.6)^0.02)-1))/0.14)

= 0.1

Instantaneous Phase Overcurrent Setting

For High set considering the 130% of through fault current = 1540.83 A

= 1.541 A

t = 0.100 Sec

Earth Over current setting HV side

= 200.00 A Primary

= I earth fault / CT ratio

Setting of 20% is selected = (200/1000)

= 0.200 A Secondary


CHARACTERISTICS = IDMT Normal inverse


= 0.25

Fault current = 11340.00 A


11.34

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.25*(((11.34/0.2)^0.02)-1))/0.14)

= 0.15

Instantaneous Earth Overcurrent Setting

For High set considering the 100% of CT Primary Current = 1000.00 A

= 1.000 A

t = 0.100 Sec

From ETAP

grading time + Downstream relay

operating timeMinimum grading time interval considered

in sec

From ETAP

In solidly earthed system a setting of 10 to 20% of CT Primary

current is considered



in sec

RELAY GE F650 BAY/FEEDER MSB BC

The relay setting shall be such that it shall not operate for max.

probable load current

PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) PRPD: MN

TITLE: SETTING CALCULATION FOR MSB BC CKD: GP

VOLTECH ENGINEERS PVT. LTDDOCUMENT No.

VE-J108-D-E212

DATE 16.09.13

Page 3 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER MSB BC


TITLE: SETTING CALCULATION FOR MSB BC CKD: GP


VE-J108-D-E212

DATE 16.09.13

Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

Curve Definite Time

Time Dial Multiplier 0.10 0 900

Phase Overcurrent

Function Enabled Enabled/Disabled

Pickup Level 1.00 0.05 160

F650

GROUP-1 Non Directional Earth Overcurrent- 50N

MENU TEXT RECOMMEND SETTINGSETTING RANGE

STEP SIZE UNITMINIMUM MAXIMUM

Curve IEC Normal Inv


Phase Overcurrent



F650




Curve Definite Time


Phase Overcurrent



F650

GROUP-1 Non Directional Phase Overcurrent- 50





Phase Overcurrent



F650




Page 4 of 160

MAKE MODEL

1.2 Non Directional Overcurrent and Earth Fault Protection for 0.415 kV MSB Incomer-1

CT Details

CT Ratio = 1000/1 A

CT Primary = 1000 A

CT Secondary = 1 A

Class = 5P20

Transformer Data:






Impedence = 0.450 4.50%


O/C SETTING (51):



= 0.53






= 0.50



11.24 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.5*(((11.24/0.6)^0.02)-1))/0.14)

= 0.2



= 1.541 A

t = 0.200 Sec


= 200.00 A Primary



= 0.200 A Secondary




= 0.50



11.34

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.5*(((11.34/0.2)^0.02)-1))/0.14)

= 0.30



= 1.000 A

t = 0.200 Sec

From ETAP



in sec

From ETAP





in sec

RELAY GE F650 BAY/FEEDER 0.415kV Incomer-1




TITLE: SETTING CALCULATION FOR 0.415kV INCOMER-1 CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 5 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 0.415kV Incomer-1




VE-J108-D-E212

DATE 16.09.13

Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

Curve Definite Time


Phase Overcurrent



F650






Phase Overcurrent



F650




Curve Definite Time


Phase Overcurrent



F650






Phase Overcurrent



F650




Page 6 of 160

MAKE MODEL

1.3. Non Directional Overcurrent and Earth Fault Protection for 0.415kV Incomer-2

CT Details

CT Ratio = 1000/1 A

CT Primary = 1000 A

CT Secondary = 1 A

Class = 5P20

Transformer Data:






Impedence = 0.500 5.00%


O/C SETTING (51):



= 0.84






= 0.50



15.57 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.5*(((15.57/0.9)^0.02)-1))/0.14)

= 0.2



= 2.184 A

t = 0.200 Sec


= 200.00 A Primary



= 0.200 A Secondary




= 0.50



15.84

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.5*(((15.84/0.2)^0.02)-1))/0.14)

= 0.3



= 1.000 A

t = 0.200 Sec

From ETAP



in sec

From ETAP





in sec

RELAY GE F650 BAY/FEEDER 0.415kV Incomer-2






VE-J108-D-E212

DATE 16.09.13

Page 7 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 0.415kV Incomer-2




VE-J108-D-E212

DATE 16.09.13

Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

Curve Definite Time


Phase Overcurrent



F650






Phase Overcurrent



F650




Curve Definite Time


Phase Overcurrent



F650






Phase Overcurrent



F650




Page 8 of 160

MAKE MODEL

1.4. Non Directional Overcurrent and Earth Fault Protection for 11kV Incomer

CT Details

CT Ratio = 100/1 A

CT Primary = 100 A

CT Secondary = 1 A

Class = 5P20

Transformer Data:






Impedence = 0.450 4.50%


O/C SETTING (51):



= 0.21






= 0.75



152.30 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.75*(((152.3/0.2)^0.02)-1))/0.14)

= 0.74



= 0.607 A

t = 0.300 Sec

Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S


Curve

Enabled Enabled/Disabled

0.30 0 900

Phase Overcurrent

Function Enabled

Definite Time


Phase Overcurrent

Function

Enabled/Disabled

0.05 160

0 900

Time Dial Multiplier



F650


STEP SIZE

F650


Time Dial Multiplier 0.74

Pickup Level 0.23




in sec

From ETAP

Calculated

UNITMINIMUM MAXIMUM

RELAY GE F650 BAY/FEEDER 11/0.415kV 400KVA Tafo-11kV Side




TITLE: SETTING CALCULATION FOR 11/0.415kV 400KVA Trafo 11kV Side CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 9 of 160

ERROR: undefined

OFFENDING COMMAND: ‘~

STACK:

Page 10 of 160

33kV FEEDERS

Page 11 of 160

MAKE MODEL

2.1. Directional Overcurrent and Earth Fault Protection for 33kV capacitor Bank Feeder

CT Details

CT Ratio = 200-100/1 A

CT Primary = 200 A

CT Secondary = 1 A

Class = PS

Capacitor Bank Details

Rated kVAR = 10000 kVAR

Rated Voltage = 33 kV

Rated Current = 175 A


O/C SETTING (51):

Load current I load = 175 A Considering the CT Ratio


= 0.87




Characteristics = IDMT IEC-Standard inverse


= 0.10

Minimum Fault current = 3640 A


18.20 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.1*(((18.2/1)^0.02)-1))/0.14)

= 0.04

Maximum fault Current = 9620 A Primary

= 48.10 A Secondary

Operating time at Maximum fault Current = 0.07 Sec


= 40.00 A Primary



= 0.20 A Secondary


CHARACTERISTICS = IDMT IEC-Standard inverse


= 0.10

Fault current = 3880 A


19.40

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.1*(((19.4/0.2)^0.02)-1))/0.14)

= 0.07


= 48.25 A Secondary



VE-J108-D-E212

DATE 19.08.13


TITLE: SETTING CALCULATION FOR 33kV CAPACITOR BANK CKD: GP



in sec

From ETAP



RELAY GE F650 BAY/FEEDER 33kV Capacitor Bank





in sec

From ETAP

From ETAP

From ETAP

Page 12 of 160

MAKE MODEL


VE-J108-D-E212

DATE 19.08.13


TITLE: SETTING CALCULATION FOR 33kV CAPACITOR BANK CKD: GP

RELAY GE F650 BAY/FEEDER 33kV Capacitor Bank

Setting Table:

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

F650

GROUP-1 Directional Phase Overcurrent- 67



Phase Overcurrent

Function Enabled

MTA 45 -90 90

Enabled/Disabled

Direction Forward Forward/Reverse

0.96 0.05 160

Pol V Threshold 40.00 0


STEP SIZE UNITMINIMUM

Pickup Level

Curve


300

F650

GROUP-1 Directional Earth Overcurrent- 67N

IEC Normal Inv

MTA -45 -90 90

0.04 0 900

MAXIMUM

Phase Overcurrent

Pol V Threshold 40 0 300






Page 13 of 160

MAKE MODEL

2.2. Directional Overcurrent and Earth Fault Protection for 33kV Line Feeder

CT Details

CT Ratio = 400-200/1 A

CT Primary = 400 A

CT Secondary = 1 A

Class = PS


O/C SETTING (51):

Load current I load = 400 A Considering the CT Ratio


= 1.00






= 0.10



9.10 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.1*(((9.1/1)^0.02)-1))/0.14)

= 0.03

Maximum fault Current = 9620.00 A Primary

= 24.05 A Secondary



= 80.0 A Primary



= 0.20 A Secondary


CHARACTERISTICS =


= 0.10



9.70

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.1*(((9.7/0.2)^0.02)-1))/0.14)

= 0.06


= 24.13 A Secondary



VE-J108-D-E212

DATE 16.09.13

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) PRPD: MN

TITLE: SETTING CALCULATION FOR 33kV LINE CKD: GP

PROJECT:

RELAY GE F650 BAY/FEEDER 33kV Line

From ETAP


operating time


operating time



From ETAP

From ETAP

Minimum grading time interval considered

in sec



Minimum grading time interval considered

in sec

From ETAP

Page 14 of 160

MAKE MODEL


VE-J108-D-E212

DATE 16.09.13



PROJECT:


Setting Table:

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S0 900

Phase Overcurrent


Forward/ReverseDirection




0.05 160

F650

Pol V Threshold 40.00 0 300

Curve

F650



MINIMUM MAXIMUMSTEP SIZE UNIT

Phase Overcurrent

Function Enabled

45 -90 90

Enabled/Disabled

MTA

0.06

Pol V Threshold 40.00

Pickup Level 0.2 0.05


0 300

IEC Normal Inv


IEC Normal Inv

0.03

MTA -45

Curve

Forward

900

160

Forward/ReverseDirection Forward

-90 90

0

Pickup Level 1.00

Page 15 of 160

MAKE MODEL

2.3. Non Directional Overcurrent and Earth Fault Protection for 33kV Bus Coupler

CT Details

CT Ratio = 800-400/1 A

CT Primary = 800 A

CT Secondary = 1 A

Class = PS


O/C SETTING (51):

Load current I load = 699.8 A Considering the CT Ratio


= 0.8747988






= 0.32



4.55 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.32*(((4.55/1)^0.02)-1))/0.14)

= 0.07


= 6.01 A Secondary



= 160.00 A Primary



= 0.2 A Secondary




= 0.33



4.85

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.33*(((4.85/0.2)^0.02)-1))/0.14)

= 0.16


= 6.03 A Secondary


From ETAP

From ETAP



in sec

From ETAP





in sec

From ETAP

RELAY GE F650 BAY/FEEDER 33kV Bus Coupler




TITLE: SETTING CALCULATION FOR 33kV BUS COUPLER CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 16 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 33kV Bus Coupler




VE-J108-D-E212

DATE 16.09.13

Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S900







0

F650


Phase Overcurrent

Enabled/DisabledFunction Enabled



Enabled/Disabled

Phase Overcurrent

Function Enabled


F650



Page 17 of 160

MAKE MODEL

2.4. Non Directional Overcurrent and Earth Fault Protection for 33kV Incomer

CT Details

CT Ratio = 800-400/1 A

CT Primary = 800 A

CT Secondary = 1 A

Class = PS

Transformer Data:

Rated power = 40 MVA





Impedence = 0.138 13.80%


O/C SETTING (51):



= 0.87






= 0.52



4.55 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.52*(((4.55/1)^0.02)-1))/0.14)

= 0.12

Maximum through fault Current = 5020.00 A Primary

= 6.28 A Secondary




= 8.241 A

t = 0.250 Sec


= 160.00 A Primary



= 0.200 A Secondary




= 0.56



4.85

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.56*(((4.85/0.2)^0.02)-1))/0.14)

= 0.26


= 6.29 A Secondary




= 2.000 A

t = 0.100 Sec


VE-J108-D-E212

DATE 16.09.13


TITLE: SETTING CALCULATION FOR 33kV INCOMER CKD: GP

RELAY GE F650 BAY/FEEDER 132/33kV,40 MVA Trafo 33kV Side





in sec

From ETAP





in sec

From ETAP

From ETAP

From ETAP

Page 18 of 160

MAKE MODEL


VE-J108-D-E212

DATE 16.09.13


TITLE: SETTING CALCULATION FOR 33kV INCOMER CKD: GP


Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

0.01 A

0.01 S

0 900

F650




MAXIMUM

0.96

F650



STEP SIZE UNITMINIMUM


160

Phase Overcurrent


0.05Pickup Level

UNITMINIMUM MAXIMUM


F650

Phase Overcurrent




STEP SIZE

0.20 0.05 160


Phase Overcurrent

Function Enabled/DisabledEnabled



Curve Definite Time


Pickup Level

0.25 0 900

F650



STEP SIZE UNIT

2.00 0.05 160

MINIMUM MAXIMUM

Phase Overcurrent


Curve Definite Time


Pickup Level

Page 19 of 160

132kV FEEDERS

Page 20 of 160

MAKE MODEL

3.1. Non Directional Overcurrent and Earth Fault Protection for 132/33kV Transformer(40MVA)

CT Details

CT Ratio = 800-400/1 A

CT Primary = 400 A

CT Secondary = 1 A

Class = PS

Transformer Data:






Impedence = 0.138 13.80%


O/C SETTING (51):



= 0.44






= 0.68



7.43 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.68*(((7.43/0.5)^0.02)-1))/0.14)

= 0.27

Maximum fault Current = 28280.00 A

70.70



= 1648.17 A

= 4.12 A

t = 0.30 Sec


= 80.00 A Primary



= 0.20 A Secondary




= 0.77



9.30

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.77*(((9.3/0.2)^0.02)-1))/0.14)

= 0.44

Maximum through fault Current = 28990.00 A Primary

= 72.48 A Secondary




= 2.00 A

t = 0.35 Sec

Calculated


VE-J108-D-E212

DATE 16.09.13


TITLE: SETTING CALCULATION FOR 132/33kV TRANSFORMER(40MVA) CKD: GP






in sec

From ETAP

For High set considering the 130% of Through Fault current in

HV Side

Calculated



From ETAP



in sec

From ETAP

Page 21 of 160

MAKE MODEL


VE-J108-D-E212

DATE 16.09.13


TITLE: SETTING CALCULATION FOR 132/33kV TRANSFORMER(40MVA) CKD: GP


Setting Table:

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

0 900

F650




F650




Phase Overcurrent

Function Enabled

MTA 45 -90 90

Enabled/Disabled


F650


Pickup Level 0.48 160



0.05

MTA 45

GROUP-1 Directional Phase Overcurrent- 67 INST



Phase Overcurrent


-90 90


Phase Overcurrent

Direction Forward


Forward/Reverse

0

MTA -45



300


-90 90


Curve Definite Time




0.30 0 900

F650

GROUP-1 Directional Earth Overcurrent- 67N INST



Phase Overcurrent


MTA -45 -90 90




Curve Definite Time


Page 22 of 160

MAKE MODEL

3.2. Directional Overcurrent and Earth Fault Protection for 132kV Side of 220/132kV Transformer(160MVA)

CT Details

CT Ratio = 800-400/1 A

CT Primary = 800 A

CT Secondary = 1 A

Class = PS

Transformer Data:







O/C SETTING (51):



= 0.87






= 0.70



4.86 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.7*(((4.86/1)^0.02)-1))/0.14)

= 0.17


= 7581.59 A

= 9.48 A

t = 0.50 Sec


= 160.00 A Primary



= 0.20 A Secondary




= 0.72

Fault current = 1400.00 A A


1.75

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.72*(((1.75/0.2)^0.02)-1))/0.14)

= 0.2


1310.00


= 2.46 A

t = 0.60 Sec



in sec

From ETAP



in sec

From ETAP


HV Side

From ETAP







TITLE: SETTING CALCULATION FOR 132kV SIDE TRANSFORMER(160MVA) CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 23 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 220/132kV,160 MVA Trafo 132kV Side


TITLE: SETTING CALCULATION FOR 132kV SIDE TRANSFORMER(160MVA) CKD: GP


VE-J108-D-E212

DATE 16.09.13

Setting Table:

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

Forward/Reverse

0 300

0 900

F650


Direction

F650




F650




Phase Overcurrent


MTA 45 -90 90


900





Phase Overcurrent


MTA -45 -90 90




Curve Definite Time


0.05 160



Forward


Pickup Level 0.2

MTA -45 -90 90


Phase Overcurrent


Curve Definite Time

Time Dial Multiplier 0.50 0





MTA 45 -90 90

Enabled/Disabled

Phase Overcurrent

Function Enabled

MINIMUM MAXIMUMSTEP SIZE UNITMENU TEXT RECOMMEND SETTING

SETTING RANGE

F650


Page 24 of 160

MAKE MODEL

3.3. Directional Overcurrent and Earth Fault Protection for 132kV Line

CT Details

CT Ratio = 800-400/1 A

CT Primary = 400 A

CT Secondary = 1 A

Class = PS


O/C SETTING (51):

Load current I load = 400 A


= 1.00






= 0.65



4.85 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.65*(((4.85/1)^0.02)-1))/0.14)

= 0.15


= 80.00 A Primary



= 0.20 A Secondary




= 0.65



5.98

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.65*(((5.98/0.2)^0.02)-1))/0.14)

= 0.33


VE-J108-D-E212

DATE 16.09.13






grading time + Zone-2 operating timeMinimum grading time interval considered

in sec

From ETAP





in sec

From ETAP

Page 25 of 160

MAKE MODEL


VE-J108-D-E212

DATE 16.09.13




Setting table

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S0 900

160

F650



STEP SIZE UNITMAXIMUM


STEP SIZE UNIT

F650

Phase Overcurrent

Function Enabled

MINIMUM MAXIMUM

Enabled/Disabled


90

300


Pol V Threshold 40.00 0

MTA 45.00 -90

Function



MINIMUM

0


Phase Overcurrent

MTA -45.00 -90 90

Curve

Enabled Enabled/Disabled

Direction Forward


Forward/Reverse

IEC Normal Inv

300



Page 26 of 160

MAKE MODEL

3.4. Distance Protection for 132kV-30KM Line

System Details for 220kV lineNominal system voltage,UN = 132000V 132000 V

Current transformer ratio,Nct = 400/1A 400.0Voltage transformer ratio,Nvt = 132000/110 1200.0

Ratio of secondary to primary impedance,Nct/Nvt =

Protected OHL Type =

Current rating in Amps = Considered CT Ratio

Protected OHL length = KM

Positive seq.Resistance of OHL in Ω, per kM, Rprim =

Positive seq.Reactance of OHL in Ω, per kM, Xprim =

Positive seq.impedance of OHL in Ω, per kM, Zprim = 0.463 68.8O

Zero seq.Resistance of OHL in Ω, per kM, Rprim =

Zero seq.Reactance of OHL in Ω, per kM, Xprim =

Zero seq.impedance of OHL in Ω, per kM, Zprim = 0.743 56.9O

Adjacent Longest Line details








Adjacent Shortest Line details








PT Details:

PT Ratio = 132000/110 V

PT Primary Voltage = 132000.0 V

PT Secondary Voltage = 110.0 V

System Frequency = 50.0 HZ

Distance element Settings:

Reactance settings

Zone 1 Settings

Required Zone 1 reach is to be 85% of the Protected line

X1prim = 85% * Xprim = 11.02

X1sec = Nct/Nvt * Xprim = 3.67

Zone 2 Settings

Zone 2 element setting with a reach of 120% of Protected line reactance accounts for effect of infeed.This point must be verified

using a fault study to calculate the apparent ohms at the local terminal for a fault at the remote end of transmission line.

In our case 120% is considered for the zone-2 elements with assurance that all faults in the protected line are detectable,even

with infeed from remote terminals.

Assuming the zone-1 reach for the adjacent line protection is set at 85% of that line reactance, and it is to be verified such that

the zone-2 reach of 120%(protected line) shall not extend beyond the max.effective zone-1 reach of the adjacent line protection.

Zone-2 setting limit = Protected line reactance +

0.85 * adjacent shortest line reactance

= 5.67

Zone-2 setting with 120% reach = 5.18

Since 120%, 5.18 is lower than zone-2 limit. 5.67, so the zone-2 setting of 120% will not overreach beyond zone-1 setting

of adjacent line protection. Therefore we consider 120% of protected line reactance

Hence set X2 prim = 15.55

Hence set X2 sec = 5.18

11.00

0.167

0.432


VE-J108-D-E212

DATE

PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL)

16.09.13

PRPD:

0.622

MN

TITLE: SETTING CALCULATION FOR 132kV LINE PROTN(30KM) CKD: GP

RELAY GE D60 BAY/FEEDER

0.167

0.432

0.33

ACSR PANTHER

400.0

30.0

132kV Line-30KM

0.167

0.432

0.406

0.622

0.406

0.622

22.80

0.406

Page 27 of 160

MAKE MODEL


VE-J108-D-E212

DATE


16.09.13

PRPD: MN


RELAY GE D60 BAY/FEEDER 132kV Line-30KM

Zone 3 Settings

For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line)

X3prim, reach = 21.46

X3sec = Nct/Nvt * X3prim*IN/A = 7.15

Zone 4 Settings

For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance.



Resistance settings

For resistance setting of OHL, consideration of AC resistance is most important. Also tower footing resistance shall be

accounted in the calculation.

Resistive Reach Calculations

Minimum Load impedence to the relay = Vn (phase - neutral) / In

= (110/√3/1)

= 63.51 Ω

= 38.11 Ω secondary


Ra = (28710 x L) / If^1.4

Where:

If = Minimum expected phase-phase fault current (A);

L = Maximum phase conductor separation (m);

Ra =

fault current = 3.89 kA

Conductor spaces = 2.7 mtrs

= 0.73 Ω

(RARC is = 1.325 Ω

RTFT Tower Foot Resistance = 10 Ω

Zone-1 setting(same way as done above for X reach)R1 sec = R1sec + 0.5RARC+ RTFT = 4.98




Time setting

Zone-1 setting = 0.00 sec

Zone-2 setting

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections

including circuit breaker trip time

Adjoining line protection operating time = 0.040

Breaker opening time = 0.080

Local relay reset = 0.030

Grading margin = 0.250

Required zone-2 time delay = 0.40

set zone-2 at = 0.40 sec

Zone-3 setting

zone-3 time delay shall be such that zone-2 time delay plus grading margin

zone-2 time delay = 0.400




Typically,phase fault distance zones would avoid the minimum load impedence by a margin of ≥ 40%,earth fault zones would use a ≥ 20% margin.

This allows maximum resistive reaches

for Phase faults


for Earth faults

Arc resistance, calculated from the van Warrington

formula (W).

Primary resistive coverage for phase faults

Page 28 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Zone-4 setting

zone-4 might be used to provide back up protection for the local bus bar. zone-4 time delay shall be such that LBB time delay

plus grading margin

LBB time delay = 0.200




Earth Impedance matching factor for Zone-1,2,3 & 4RE/RL = 1/3 (R0/R1 -1) = 0.48XE/XL = 1/3 (X0/X1 -1) = 0.15

R0-R1 = 0.24

X0-X1 = 0.19

Z0-Z1 = 0.31 38.53 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.22 -30.29 O

Where

R1 is +ve seq. resistance of protected line

R0 is zero seq. resistance of protected line

X1 is +ve seq. reactance of protected line

X0 is zero seq. reactance of protected line

Load impedance valueRload prim = Umin/√3*ILmax

Where

Umin = minimum operating voltage, 0.9*UN = 118800ILmax = max load current = 400.000

Hence Rload prim = 171.48

Rload sec = 57.16

The above is calculated for ph to earth and for ph to ph it is same value because current is multiplied by √3

PHI load , maximum load angle

As load current ideally is in phase with the voltage, the difference is indicated with the power factor cosØ. The largest angle

of the load impedance is therefore given by the worst, smallest powerfactor. We considered the worst power factor under

full load condition is 0.9.

Øload- max = cos -1

(power factor min)

Øload- max = cos-1

(0.9)

Øload- max = 26.00 O

Power Swing Detection:

The power swing detect element provides both power swing blocking and out-of-step tripping functions.

Power swing Shape, = QUAD

Power swing Mode, = Two step

Power swing Supervision, = 0.600 pu (typical setting from manual)

Power swing Forward Reach(inner) = 7.15 ΩΩΩΩ

(considered zone-3 reactance boundary)

Power swing Forward RCA = 68.8 O

Power swing Forward Reach(outer) = 8.58 ΩΩΩΩ

(120% of inner Reach)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach

Power swing Reverse Reach(inner) = 4.31 ΩΩΩΩ

Power swing Reverse Reach(outer) = 5.17 ΩΩΩΩ

(120% of Reverse inner Reach)

Power swing inner Right blinder = 6.33 ΩΩΩΩ

(considered zone-3 resistive boundary)

Power swing outer Right blinder = 7.59 ΩΩΩΩ

(120% of inner Right blinder)

Power swing inner Left blinder = 6.33 ΩΩΩΩ


Power swing outer Left blinder = 7.59 ΩΩΩΩ

(120% of inner Left blinder)

VT Fuse fail

Function enabled

The setting shall be applied 30% lower

than calculated above= 40.01

Page 29 of 160

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VE-J108-D-E212

DATE


16.09.13

PRPD: MN



Broken Conductor Protection

Full load current = 400.000 A

Considered I2 = 40.00 A (10% of fullload current)

I2 / I1 = 0.10

Allow for tolerences and load varations = 200%

I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:

This autoreclose can be single pole tripping for single phase faults and three phase tripping for multi-phase faults.

1 pole:

In this mode, the recloser starts the AR-1P DEAD TIME for the first shot if the fault is single phase.

If the fault is three phase or three pole trip occurred on the breaker during single initiation, the scheme goes to lockout with out reclosing.

AR Mode, = 1 pole

AR Max Number of Shots, = 1.00

AR Close Time Breaker 1, = 0.20 s

AR Block Time Upon Man Cls. = 10.00 s

AR Reset Time, = 25.00 s

AR Breaker1 Fail Option, = Lockout

AR Incomplete Sequence Time, = 2.00 s

AR 1-P Dead Time, 1.00 s

AR Breaker Sequence, = 1.00

Local Breaker Backup Protection

In general, a breaker failure scheme determines that a breaker signaled to trip has not cleared a fault with in a definite time,

so further tripping action must be performed.

BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1

BF1 USE AMP SUPV, = Yes

BF1 USE SEAL-IN, = Yes

BF1 PH AMP SUPV, = 0.20 pu

BF1 N AMP SUPV, = 0.20 pu

BF1 USE TIMER1, = Yes

BF1 TIMER1 PICKUP DELAY, = 0.20 S

BF1 TRIP DROPOUT = 0.00 S

Setting Recommendation for UV

PT Ratio =

=Under

voltage =

= v 90% OF Rated Voltage

Select Under voltage setting, 27 =

= V

≈ pu

Time delay setting , 27 = s

132000/110

1200.00

0.90*Nominal Volt

118800

118800/1200

99.000

0.90

3.00

Page 30 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA

PHS DIST Z1 COMP LIMIT

PHS DIST Z1 DIR RCA

PHS DIST Z1 DIR COMP LIMIT

PHS DIST Z1 QUAD RGT BLD

PHS DIST Z1 QUAD RGT BLD RCA

PHS DIST Z1 QUAD LFT BLD

PHS DIST Z1 QUAD LFT BLD RCA

PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY

Menu text Recommended Setting

PHASE DISTANCE ELEMENTSSetting Unit

Line setting

30.00 km

Forward

Quadrilateral

3.67 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.98 Ω

68.82 DEG

4.98 Ω

68.82 DEG

0.00 S

0.34 pu

Forward

Quadrilateral

5.18 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

5.56 Ω

68.82 DEG

5.56 Ω

68.82 DEG

0.40 S

Forward

Quadrilateral

7.15 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

6.33 Ω

68.82 DEG

6.33 Ω

68.82 DEG

0.80 S

Reverse

Quadrilateral

0.73 Ω

68.82 DEG

90.00 DEG

68.82

90.00 DEG

6.33 Ω

68.82 DEG

6.33 Ω

68.82 DEG

0.50 S

Page 31 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA

GND DIST Z1 COMP LIMIT

GND DIST Z1 DIR RCA

GND DIST Z1 DIR COMP LIMIT

GND DIST Z1 QUAD RGT BLD

GND DIST Z1 QUAD RGT BLD RCA

GND DIST Z1 QUAD LFT BLD

GND DIST Z1 QUAD LFT BLD RCA

GND DIST Z1 DELAY

GND DIST Z1 Z0/Z1 MAG

GND DIST Z1 Z0/Z1 ANG

GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT

LOAD ENCROACHMENT MIN VOLT

LOAD ENCROACHMENT REACH

LOAD ENCROACHMENT ANGLE

LOAD ENCROACHMENT PKP DELAY

LOAD ENCROACHMENT RST DELAY



Line setting

Forward

Quadrilateral

3.67 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.98 Ω

68.82 DEG

4.98 Ω

68.82 DEG

0.00 S

0.22

-30.29 DEG

Forward

Quadrilateral

5.18 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

5.56 Ω

68.82 DEG

5.56 Ω

68.82 DEG

0.40 S

0.22 Ω

-30.29 DEG

Forward

Quadrilateral

7.15 Ω

68.82 DEG

6.33 Ω

68.82 DEG

6.33 Ω

68.82 DEG

0.80 S

0.22 Ω

-30.29 DEG

Reverse

Quadrilateral

0.73 Ω

68.82 DEG

6.33 Ω

68.82 DEG

6.33 Ω

68.82 DEG

0.50 S

0.22 Ω

-30.29 DEG

0.25 pu

40.01 Ω

26.00 DEG

0.00 S

0.00 S

Page 32 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV

POWER SWING FWD REACH

POWER SWING QUAD FWD REACH OUT

POWER SWING FWD RCA

POWER SWING REV REACH

POWER SWING QUAD REV REACH OUT

POWER SWING OUTER RGT BLD

POWER SWING OUTER LFT BLD

POWER SWING INNER RGT BLD

POWER SWING INNER LFT BLD

POWER SWING PICKUP DELAY1

POWER SWING RESET DELAY1




POWER SWING SEAL IN DELAY

POWER SWING TRIP MODE

PHASE IOC LINE PICKUP

LINE UV PICKUP

LINE END OPEN PICKUP DELAY

LINE END OPEN RESET DELAY

LINE OV PICKUP DELAY

AR COORDINATION BYPASS

AR COORDINATION PICKUP DELAY

AR COORDINATION RESET DELAY

LINE PICKUP DISTANCE TRIP

FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1

AR BLK TIME UPON MAN CLS

AR RESET TIME

AR BKR1 FAIL OPTION

AR INCOMPLETE SEQ TIME

AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN

BF1 PH AMP SUPV PICKUP

BF1 N AMP SUPV PICKUP

BF1 USE TIMER1

BF1 TIMER1 PICKUP DELAY

BF1 TRIP DROPOUT

TAP LEVEL IN PERCENTAGE OF I2/I1

TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY



Quadrilateral

Two Step

0.60 pu

7.15 Ω

8.58

68.82 DEG

4.31 Ω

5.17 Ω

7.59 Ω

7.59 Ω

6.33 Ω

6.33 Ω

0.03 S

0.05 S

0.02 S

0.01 S

0.02 S

0.40 S

Delayed S

LINE PICKUP (SOTF)

1.00 pu

0.70 pu

0.15 S

0.09 S

0.04 S

Enabled

0.05 S

0.01 S

Enabled

FUSE FAILURE

Enabled

AUTO RECLOSE

Enabled

1 pole

1.00

0.20 S

10.00 S

25.00 S

Lockout

2.00 S

1.00 S

1.00

BREAKER FAILURE 1

Enabled

3-Pole

SRC1

Yes

Yes

0.20 pu

0.20 pu

Yes

0.20 S

0.00 S

BROKEN CONDUCTOR (F650 RELAY)

20.00 %

0.90 pu

3.00 s

5.00 S

UNDERVOLTAGE

Enabled

Phase to Phase

Page 33 of 160

MAKE MODEL






























PT Details:

PT Ratio = 132000/110 V





Reactance settings

Zone 1 Settings


X1prim = 85% * Xprim = 8.08


Zone 2 Settings









= 4.22






8.60

0.167

0.432


VE-J108-D-E212

DATE


16.09.13

PRPD:

0.622

MN



0.167

0.432

0.33

ACSR PANTHER

400.0

22.0

132kV Line-22KM

0.167

0.432

0.406

0.622

0.406

0.622

44.28

0.406

Page 34 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Zone 3 Settings




Zone 4 Settings




Resistance settings





= (110/√3/1)

= 63.51 Ω



Ra = (28710 x L) / If^1.4

Where:



Ra =



= 0.54 Ω

(RARC is = 1.325 Ω






Time setting


Zone-2 setting









Zone-3 setting








for Phase faults


for Earth faults


formula (W).


Page 35 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Zone-4 setting


plus grading margin






R0-R1 = 0.24

X0-X1 = 0.19

Z0-Z1 = 0.31 38.53 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.22 -30.29 O

Where






Where



Rload sec = 57.16







(power factor min)

Øload- max = cos-1

(0.9)
























VT Fuse fail

Function enabled



Page 36 of 160

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VE-J108-D-E212

DATE


16.09.13

PRPD: MN






I2 / I1 = 0.10


I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:


1 pole:



AR Mode, = 1 pole












BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1









PT Ratio =

=Under

voltage =



= V

≈ pu


132000/110

1200.00

0.90*Nominal Volt

118800

118800/1200

99.000

0.90

3.00

Page 37 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA


PHS DIST Z1 DIR RCA






PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY



Line setting

22.00 km

Forward

Quadrilateral

2.69 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.60 Ω

68.82 DEG

4.60 Ω

68.82 DEG

0.00 S

0.34 pu

Forward

Quadrilateral

3.80 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

5.03 Ω

68.82 DEG

5.03 Ω

68.82 DEG

0.40 S

Forward

Quadrilateral

7.63 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

6.51 Ω

68.82 DEG

6.51 Ω

68.82 DEG

0.80 S

Reverse

Quadrilateral

0.54 Ω

68.82 DEG

90.00 DEG

68.82

90.00 DEG

6.51 Ω

68.82 DEG

6.51 Ω

68.82 DEG

0.50 S

Page 38 of 160

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VE-J108-D-E212

DATE


16.09.13

PRPD: MN



GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA


GND DIST Z1 DIR RCA






GND DIST Z1 DELAY



GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT








Line setting

Forward

Quadrilateral

2.69 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.60 Ω

68.82 DEG

4.60 Ω

68.82 DEG

0.00 S

0.22

-30.29 DEG

Forward

Quadrilateral

3.80 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

5.03 Ω

68.82 DEG

5.03 Ω

68.82 DEG

0.40 S

0.22 Ω

-30.29 DEG

Forward

Quadrilateral

7.63 Ω

68.82 DEG

6.51 Ω

68.82 DEG

6.51 Ω

68.82 DEG

0.80 S

0.22 Ω

-30.29 DEG

Reverse

Quadrilateral

0.54 Ω

68.82 DEG

6.51 Ω

68.82 DEG

6.51 Ω

68.82 DEG

0.50 S

0.22 Ω

-30.29 DEG

0.25 pu

40.01 Ω

26.00 DEG

0.00 S

0.00 S

Page 39 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV



POWER SWING FWD RCA















LINE UV PICKUP








FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1


AR RESET TIME

AR BKR1 FAIL OPTION


AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN



BF1 USE TIMER1


BF1 TRIP DROPOUT


TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY



Quadrilateral

Two Step

0.60 pu

7.63 Ω

9.15

68.82 DEG

4.35 Ω

5.22 Ω

7.81 Ω

7.81 Ω

6.51 Ω

6.51 Ω

0.03 S

0.05 S

0.02 S

0.01 S

0.02 S

0.40 S

Delayed S

LINE PICKUP (SOTF)

1.00 pu

0.70 pu

0.15 S

0.09 S

0.04 S

Enabled

0.05 S

0.01 S

Enabled

FUSE FAILURE

Enabled

AUTO RECLOSE

Enabled

1 pole

1.00

0.20 S

10.00 S

25.00 S

Lockout

2.00 S

1.00 S

1.00

BREAKER FAILURE 1

Enabled

3-Pole

SRC1

Yes

Yes

0.20 pu

0.20 pu

Yes

0.20 S

0.00 S


20.00 %

0.90 pu

3.00 s

5.00 S

UNDERVOLTAGE

Enabled

Phase to Phase

Page 40 of 160

MAKE MODEL






























PT Details:

PT Ratio = 132000/110 V





Reactance settings

Zone 1 Settings


X1prim = 85% * Xprim = 5.51


Zone 2 Settings









= 2.85






5.60

0.167

0.432


VE-J108-D-E212

DATE


16.09.13

PRPD:

0.622

MN



0.167

0.432

0.33

ACSR PANTHER

400.0

15.0

132kV Line-15KM

0.167

0.432

0.406

0.622

0.406

0.622

5.60

0.406

Page 41 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Zone 3 Settings




Zone 4 Settings




Resistance settings





= (110/√3/1)

= 63.51 Ω



Ra = (28710 x L) / If^1.4

Where:



Ra =



= 0.40 Ω

(RARC is = 1.325 Ω






Time setting


Zone-2 setting









Zone-3 setting








for Phase faults


for Earth faults


formula (W).


Page 42 of 160

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VE-J108-D-E212

DATE


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PRPD: MN



Zone-4 setting


plus grading margin






R0-R1 = 0.24

X0-X1 = 0.19

Z0-Z1 = 0.31 38.53 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.22 -30.29 O

Where






Where



Rload sec = 57.16







(power factor min)

Øload- max = cos-1

(0.9)
























VT Fuse fail

Function enabled



Page 43 of 160

MAKE MODEL


VE-J108-D-E212

DATE


16.09.13

PRPD: MN






I2 / I1 = 0.10


I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:


1 pole:



AR Mode, = 1 pole












BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1









PT Ratio =

=Under

voltage =



= V

≈ pu


132000/110

1200.00

0.90*Nominal Volt

118800

118800/1200

99.000

0.90

3.00

Page 44 of 160

MAKE MODEL


VE-J108-D-E212

DATE


16.09.13

PRPD: MN



Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA


PHS DIST Z1 DIR RCA






PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY



Line setting

15.00 km

Forward

Quadrilateral

1.84 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.27 Ω

68.82 DEG

4.27 Ω

68.82 DEG

0.00 S

0.34 pu

Forward

Quadrilateral

2.59 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.56 Ω

68.82 DEG

4.56 Ω

68.82 DEG

0.40 S

Forward

Quadrilateral

3.08 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.75 Ω

68.82 DEG

4.75 Ω

68.82 DEG

0.80 S

Reverse

Quadrilateral

0.37 Ω

68.82 DEG

90.00 DEG

68.82

90.00 DEG

4.75 Ω

68.82 DEG

4.75 Ω

68.82 DEG

0.50 S

Page 45 of 160

MAKE MODEL


VE-J108-D-E212

DATE


16.09.13

PRPD: MN



GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA


GND DIST Z1 DIR RCA






GND DIST Z1 DELAY



GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT








Line setting

Forward

Quadrilateral

1.84 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.27 Ω

68.82 DEG

4.27 Ω

68.82 DEG

0.00 S

0.22

-30.29 DEG

Forward

Quadrilateral

2.59 Ω

68.82 DEG

90.00 DEG

68.82 DEG

90.00 DEG

4.56 Ω

68.82 DEG

4.56 Ω

68.82 DEG

0.40 S

0.22 Ω

-30.29 DEG

Forward

Quadrilateral

3.08 Ω

68.82 DEG

4.75 Ω

68.82 DEG

4.75 Ω

68.82 DEG

0.80 S

0.22 Ω

-30.29 DEG

Reverse

Quadrilateral

0.37 Ω

68.82 DEG

4.75 Ω

68.82 DEG

4.75 Ω

68.82 DEG

0.50 S

0.22 Ω

-30.29 DEG

0.25 pu

40.01 Ω

26.00 DEG

0.00 S

0.00 S

Page 46 of 160

MAKE MODEL


VE-J108-D-E212

DATE


16.09.13

PRPD: MN



POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV



POWER SWING FWD RCA















LINE UV PICKUP








FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1


AR RESET TIME

AR BKR1 FAIL OPTION


AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN



BF1 USE TIMER1


BF1 TRIP DROPOUT


TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY



Quadrilateral

Two Step

0.60 pu

3.08 Ω

3.69

68.82 DEG

1.91 Ω

2.29 Ω

5.70 Ω

5.70 Ω

4.75 Ω

4.75 Ω

0.03 S

0.05 S

0.02 S

0.01 S

0.02 S

0.40 S

Delayed S

LINE PICKUP (SOTF)

1.00 pu

0.70 pu

0.15 S

0.09 S

0.04 S

Enabled

0.05 S

0.01 S

Enabled

FUSE FAILURE

Enabled

AUTO RECLOSE

Enabled

1 pole

1.00

0.20 S

10.00 S

25.00 S

Lockout

2.00 S

1.00 S

1.00

BREAKER FAILURE 1

Enabled

3-Pole

SRC1

Yes

Yes

0.20 pu

0.20 pu

Yes

0.20 S

0.00 S


20.00 %

0.90 pu

3.00 s

5.00 S

UNDERVOLTAGE

Enabled

Phase to Phase

Page 47 of 160

MAKE MODEL

3.7. 40MVA.TRAFO DIFF. SETTING CALCULATION

Transformer Data:

Rated Power, Prated = 40.0 MVA

Rated Voltage

HV, Vnom[1] = 132.0 kV

LV, Vnom[2] = 33.0 kV

% Impedance = 0.138 13.80% .

Vector Group = YN yn 0

= 400.0 1.0 A

= 800.0 1.0 A

OLTC Range on 132kV side + 15.0 %

to

- 5.0 %

Step Size 1.25 Max Step 12.00 Min Step 4.00

Voltage at Min Tap Position = 151.8 kV

Voltage at Max Tap Position = 125.4 kV

Highest voltage tolerence, Vmax = 37.95 kV

Lowest voltage tolerence,Vmin = 31.35 kV

The reference winding is determined as follows,

Rated current on winding 1- Irated = Prated / (√3*Vnom[1] )

= (40*1000)/(1.732*132)

Irated [1], = 174.95 A


=

Irated [2], = A

With this rated currents the CT margin for Winding1& winding 2 as follows,

CT margin for windings 1, Imargin[1] = CT primary[1] / Irated[1]

=

Imargin[1], =


=

Imargin[2], =

Since Imargin[2] < Imargin[1], the reference winding Wref is winding 2.

Calculation of magnitude compensation factor (M),

magnitude compensation factor for winding [1], M[1]= IPrimary [1] × Vnom [1] / IPrimary [2] × Vnom[2]

= 400x132000/800x33000

132kV side M[1], = 2.00


= 800x33000/800x33000

33kV side M[2], = 1.00

SETTING CALCULATION FOR 132/33-40MVATRAFO DIFF PROTN CKD:

RELAY GE T60 BAY/FEEDER


VE-J108-D-E212

DATE 16.09.13

132/33-40 MVA Trafo


TITLE: GP

33kV SIDE Primary-winding 2, CT Ratio

(Inom,b)

Note: In the entire calculation primary and secondary windings are referred as winding "1" & "2" respectively.

The unit for calculation of the differential and restraint currents and base for the differentialrestraint setting is

the CT primary associated with the reference winding.

699.82

2.29

1.14

(800-400/1A)

(800-400/1A)

(40*1000)/(1.732*33)

400/174.95

800/699.82


(Inom,a)

Page 48 of 160

MAKE MODEL




VE-J108-D-E212

DATE 16.09.13

132/33-40 MVA Trafo


TITLE: GP

a) Calculating the minimum differential pickup current required for relay to operate,

Criteria:

No load current of the transformer primary current,=

= A

No load current refered to the CT secondary, =

= A

=

IS1 = A

No load current of the transf. winding2,(secondary side)=

IS2 =

Differential current IdA, =

=

Id A, = A

Restraining current IrA, = max( | Is1|, |Is2 |)

= max( |0.044|, |0 |)

IrA, = A

b) Selection of Break point 1 and slope 1:

Recommened Settings,

The Break point 1 setting is based on the pu value of the full load transformer current

HV side (Winding -1) = 0.44 pu

LV side (Winding -2) = 0.87 pu

Hence we choose Break point-1 = 2 pu

Slope -1 = 25%

Nominal Voltage, Vnom = 2 ( Vmax X Vmin) / (Vmax + Vmin)

= 2(37.95*31.35)/(37.95+31.35)

= 34.34 kv

Object current of regulated side, IN2 = SN/(1.732 X VN2)

= (40*1000)/(1.732x34.336)

= 672.61 A

= IN2 / CT2

= 672.62/800

= 0.84 A ~ INobj

= IN1 / CT1

= 174.95/400

= 0.44 A ~ INobj

= SN/(1.732 X Vmax)

= (40*1000)/(1.732x37.95)

= 608.56

= IN2(+15%) / CT2

= 608.56/800

= 0.76 A ~ 0.90 INobj

= | IN2(+15%) - INobj |

= I0.905INobj-INobjl

= 0.10 INobj

Differential / Restraint Current in the Tap Changer Extreme Position:

Corresponds on the CT2 secondary side

to IN2


to IN1

The differential current IdA=0.0440A is found to be less than the minimum pickup selected setting of 0.1 is

adequate as the relay catalogue has a setting generally recommended between 0.1 to 0.3.

Object current in maximum tap position,

IN2(+15%)


to IN2

Differential current in maximum tap

position IDiff

Stability of relay when the transformer is operating under no load (Secondary side breaker is open) and the transformer is drawn

the magnetising current(up to 5% of rated current)

The minimum differential pickup should be above the no load current of the transformer when the secondary side of the breaker is

open

0.05×174.95

8.7475/400

8.75

0.022

0.022×2

0.044

No load current to the relay after applying magnitude compendation factor M[1],

0.0

0.0

| Is1+Is2 |

|0.044+0 |

0.0440

0.0440

Page 49 of 160

MAKE MODEL




VE-J108-D-E212

DATE 16.09.13

132/33-40 MVA Trafo


TITLE: GP

= | IN2(+15%) + INobj |

= I0.905INobj+INobjl

= 1.90 INobj

= SN/(1.732 X Vmin)

= (40*1000)/(1.732x31.35)

= 736.67

= IN2(-5%) / CT2

= 736.67/800

= 0.92 A ~ 1.10 INobj

= | IN2(-5%) - INobj |


= 0.10 INobj

= | IN2(-5%) + INobj |


= 2.10 INobj

Iop, Relay operating current at +15% tap, = slope1 X Irest

= 0.25x1.905INObj

= 0.48 INObj

whereas the Idiff , 0.1 INObj is less than 0.47 INObj . Hence the relay is Stable.

Iop, Relay operating current at -5% tap, = slope1 X Irest

= 0.25x2.095INObj

= 0.52 INObj


From the above calculation it is derived that , under rated condition and at Tap Changer Extreme positions,

Operating current are not in the Tripping Area .

C) Selection of Break point 2 and slope 2:

break point 2

The setting for Break point -2 depend very much on the capability of CTs to correctly transform Primary into

secondary currents during external faults. Break point -2 should be set below the fault current that is most likely to saturate

some CTs due to an AC Component alone

External Fault current = 12.72 pu

Break point- 2 = 8 pu

Slope-2 = 98% (as per relay catalogue)

2nd HARMONICS:

INRUSH INHIBIT LEVEL, = 20%

INRUSH INHIBIT FUNCTION

(now a days all modern transformers produce low 2nd harmonic ratios)

INRUSH INHIBIT MODE PER PHASE

5TH HARMONICS:This

setting is

OVEREXCITN INHIBIT LEVEL, = 30%

Instantaneous differential protection:

The pickup thersold should be set greater than the maximum spurious differential current that could be encountered

under non-internal fault conditions ( typically maganetizing inrush current or an external fault with extremely severe CT saturation.

I) Magnetizing inrush current = 6 x Full load current

= 1049.70 A

= 2.62 pu

Object current in minimum tap position,

IN2(-5%)

Differential current in minimum tap

position IDiff

Restriant current in minimum tap position

IRestaint

The percentage of harmonics present in the inrush current, for the relay to recognise the inrush current is set as 20%

as per manufacturer recommended,

ADAPTIVE 2nd Harmonic

Restriant current in maximum tap position

IRestaint


to IN2

Page 50 of 160

MAKE MODEL




VE-J108-D-E212

DATE 16.09.13

132/33-40 MVA Trafo


TITLE: GP

II) External fault condition:

HV Side Fault Current = 3.18 pu

LV Side Fault Current = 6.36 pu

8 pu

VOLTS PER HERTZ (OVER FLUX):

According to experience we set the definite time curve with the following settings,

Stage-1

Volts/Hz 1 Pickup, = 1.1 pu

Volts/Hz 1 Curve, = Definite Time

Volts /Hz 1 TD Multiplier, = 10.0 S

Volts/Hz 1 T-Reset, = 0.0 S

Stage-2





Setting Table:

0.1 pu

0.25

2 pu

8 pu

0.98

0.2

5th

0.3

8 pu

1.1 pu

10 s

0 s

1.2 pu

1 s

0 s

VOLTS/HZ 1

VOLTS/HZ 2

VOLTS/HZ 2 CURVE

VOLTS/HZ 2 TD MULTIPLIER

VOLTS/HZ 2 T-RESET

VOLTS/HZ 1 PICKUP

VOLTS/HZ 1 CURVE

VOLTS/HZ 1 TD MULTIPLIER

VOLTS/HZ 1 T-RESET

VOLTS/HZ 2 PICKUP

2nd Harmonic INRUSH INHIBIT MODE

2nd Harmonic INHIBIT FUNCTION

OVEREXCITN INHIBIT FUNCTION

OVEREXCITN INHIBIT LEVEL

INST DIFFERENTIAL PICKUP

4 pu

2 pu

50%

Definite Time

Menu Text

PERCENT DIFFERENTIAL PICKUP

PERCENT DIFFERENTIAL SLOPE1

PERCENT DIFFERENTIAL BREAK1

PERCENT DIFFERENTIAL BREAK2

PERCENT DIFFERENTIAL SLOPE2

Definite Time, IDMT

5%

5%

Setting Range

PER PHASE

Adaptive

Definite Time

40%

30 pu

4 pu

600 S

1000 S

Adaptive, Traditional,Disabled

600 S

0.8 pu

0 S

0.8 pu

1 pu

1

2 pu

30 pu

2 pu

perphase,2-out-of-3,Avg.

disabled,5th

1%

1

0.4

Definite Time, IDMT

0 S 1000 S

1%

0.05 pu

15%

1 pu

2nd Harmonic INRUSH INHIBIT LEVEL

For safety margin we choosen instantaneous

differential protection setting

The per-unit V/HZ value is calculated using the maximum of the three-phase voltage inputs or the auxiliary

voltage channel Vx input, if the source is not configured with Phase voltages.

The volts-per-Hertz protection, to protect transformers during potentially damaging over voltage and under

frequency disturbances.

PERCENT DIFFERENTIALRecomm.Setting

Min Max

Page 51 of 160

220kV FEEDERS

Page 52 of 160

MAKE MODEL

4.1. Directional Overcurrent and Earth Fault Protection for 160MVA Transformer(220kV Side)

CT Details

CT Ratio = 800-400/1 A

CT Primary = 800 A

CT Secondary = 1 A

Class = PS

Transformer Data:







O/C SETTING (51):



= 0.52






= 0.62



4.58 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.62*(((4.58/0.6)^0.02)-1))/0.14)

= 0.19


= 35.20 A Secondary



= 4548.95 A

= 5.69 A

t = 0.35 Sec


= 160 A Primary



= 0.20 A Secondary




= 0.74



1.78

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.74*(((1.78/0.2)^0.02)-1))/0.14)

= 0.24

Maximum fault Current = 25980.00 A

32.48




= 2.00 A

t = 0.50 Sec



in sec

From ETAP



in sec

From ETAP


HV Side

Calculated



From ETAP

From ETAP





TITLE: SETTING CALCULATION FOR 160MVA TRANSFORMER 220kV SIDE CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 53 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 220/132kV,160 MVA Trafo 220kV Side


TITLE: SETTING CALCULATION FOR 160MVA TRANSFORMER 220kV SIDE CKD: GP


VE-J108-D-E212

DATE 16.09.13

Setting Table:

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

1 Degree

1 V

0.01 A

0.01 S

Forward/Reverse

0 300

0 900

F650




F650




Phase Overcurrent


160

MTA 45 -90 90


0 900



F650




Phase Overcurrent


MTA -45 -90 90




Curve Definite Time


0.05 160



Direction Forward


Pickup Level 0.2

MTA -45 -90 90


Phase Overcurrent


Curve Definite Time




-90 90

Enabled/Disabled


Direction

UNIT

Phase Overcurrent

Function Enabled

Forward Forward/Reverse

MTA 45


F650

MINIMUM MAXIMUMSTEP SIZE


Page 54 of 160

MAKE MODEL

4.2. Non Directional Overcurrent and Earth Fault Protection for 220kV Buscoupler

CT Details

CT Ratio = 1600-800/1 A

CT Primary = 1600 A

CT Secondary = 1 A

Class = PS

Transformer Data:


Rated HV Voltage = 220 kV

Rated LV Voltage = 132 kV

Full Load current HV Side = 420 A

Full Load current LV Side = 700 A


O/C SETTING (51):



= 1.00






= 0.87

Fault current (220kV Line-3+220kV Line-4) = 7980 A


4.99 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.87*(((4.99/1)^0.02)-1))/0.14)

= 0.20


= 11.34 A Secondary



= 320.00 A Primary



= 0.20 A Secondary




= 0.56



4.34

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.56*(((4.34/0.2)^0.02)-1))/0.14)

= 0.3


= 10.91 A Secondary


From ETAP

grading time Minimum grading time interval considered

in sec

From ETAP





in sec

From ETAP

RELAY GE F650 BAY/FEEDER 220kV Bus Coupler



PRPD: MN


From ETAP


VE-J108-D-E212

DATE 16.09.13


Page 55 of 160

MAKE MODELRELAY GE F650 BAY/FEEDER 220kV Bus Coupler

PRPD: MN



VE-J108-D-E212

DATE 16.09.13


Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

Phase Overcurrent

MENU TEXT RECOMMEND SETTING

0 900

SETTING RANGESTEP SIZE

0.05 160





Pickup Level 0.2

UNITMINIMUM MAXIMUM

160


F650

Phase Overcurrent




F650




Page 56 of 160

MAKE MODEL

4.3. Non Directional Overcurrent and Earth Fault Protection for 220kV Line

CT Details

CT Ratio = 1600-800/1 A

CT Primary = 1600 A For 10kM Line

800 A For 40 & 50kM Line

CT Secondary = 1 A

Class = PS

Transformer Data:


Rated HV Voltage = 220 kV

Rated LV Voltage = 132 kV

Full Load current HV Side = 420 A

Full Load current LV Side = 700 A


O/C SETTING (51):



= 1.00






= 0.82



4.99 A

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.82*(((4.99/1)^0.02)-1))/0.14)

= 0.2


= 17.60 A Secondary



= 320 A Primary



= 0.20 A Secondary




= 0.68



4.34375

TMS = (t *((If/IS)0.02

-1)) /0.14

= (0.68*(((4.34/0.2)^0.02)-1))/0.14)

= 0.31


= 16.79 A Secondary


From ETAP


operating timeMinimum grading time interval

considered in sec

From ETAP

In solidly earthed system a setting of 10 to 20% of CT

Primary current is considered


operating timeMinimum grading time interval

considered in sec

From ETAP

RELAY GE D60 BAY/FEEDER 220kV Line

The relay setting shall be such that it shall not operate for

max. probable load current

PRPD: MN


From ETAP


VE-J108-D-E212

DATE 16.09.13


Page 57 of 160

MAKE MODELRELAY GE D60 BAY/FEEDER 220kV Line

PRPD: MN



VE-J108-D-E212

DATE 16.09.13


Setting Table:

0.01 A

0.01 S

0.01 A

0.01 S

Phase Overcurrent

MENU TEXTRECOMMEND

SETTING

0 900

SETTING RANGESTEP SIZE

0.05 160





Pickup Level 0.2

UNITMINIMUM MAXIMUM

160


F650

Phase Overcurrent




D60


MENU TEXTRECOMMEND

SETTING

SETTING RANGE


Page 58 of 160

MAKE MODEL

4.4. Distance Protection -220kV Line(50kM)





























PT Details:

PT Ratio = 220000/110 V





Reactance settings

Zone 1 Settings


X1prim = 85% * Xprim = 18.19


Zone 2 Settings







Zone-2 setting limit = (Protected line reactance +

0.85 * adjacent shortest line reactance)

= 12.05






PRPD: MN

CKD: GP

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL)

220kV Line(50Km)

TITLE: SETTING CALCULATION FOR DISTANCE PROTECTION

PROJECT:


VE-J108-D-E212

DATE 16.09.13

50.0

104.97


ACSR ZEBRA

1.240

0.08

0.43

0.29

1.24

23.97

800.0

0.084

0.428

0.292

1.240

0.084

0.428

0.292

0.40

Page 59 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13


Zone 3 Settings




Zone 4 Settings




Resistance settings





= (110/√3/1)

= 63.51 Ω



Ra = (28710 x L) / If^1.4

Where:



Ra =



= 1.33 Ω

(RARC is = 1.325 Ω






Time setting


Zone-2 setting









Zone-3 setting








for Phase faults


for Earth faults



formula (W).

Page 60 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13


Zone-4 setting


plus grading margin






R0-R1 = 0.21

X0-X1 = 0.81

Z0-Z1 = 0.84 75.62 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.64 -3.30 O

Where






Where



Rload sec = 57.16







(power factor min)

Øload- max = cos-1

(0.9)
























VT Fuse fail

Function enabled

= 40.01The setting shall be applied 30% lower

than calculated above

Page 61 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13





I2 / I1 = 0.10


I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:


1 pole:



AR Mode, = 1 pole












BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1









PT Ratio =

=Under

voltage =



= V

≈ pu


0.90

3.00

220000/110

0.90*Nominal Volt

198000/2000

2000.00

198000

99.000

Page 62 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13


Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA


PHS DIST Z1 DIR RCA






PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY

90.00

5.69

78.92

5.69

78.92

0.00

0.34

Quadrilateral

17.55

78.92

90.00

0.80

Reverse

Quadrilateral

S

DEG

Ω

DEG

Ω

DEG

S

Ω

DEG

DEG

DEG

DEG

Ω

DEG

Ω

DEG

S

Ω

DEG

DEG

pu

Ω

DEG

DEG

DEG

DEG

Ω

DEG

DEG

DEG

DEG

Ω

DEG

Ω

UnitLine setting

50.00

Setting

Recommended SettingMenu text

PHASE DISTANCE ELEMENTS

km

DEG

S

Forward

Quadrilateral

7.28

78.92

90.00

78.92

90.00

6.28 Ω

DEG

Ω

DEG

Forward

Quadrilateral

10.27

78.92

90.00

78.92

78.92

6.28

78.92

0.40

Forward

78.92

90.00

8.39

78.92

8.39

78.92

1.46

78.92

90.00

78.92

90.00

8.39

78.92

8.39

78.92

0.50

Page 63 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13


GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA


GND DIST Z1 DIR RCA






GND DIST Z1 DELAY



GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT






DEG

S

S

DEG

5.69

78.92

78.92

DEG

Ω

DEG

pu

Ω

S

5.69

78.92

0.00

0.64

Ω

Ω

90.00

Ω

90.00

6.28

78.92

6.28

8.39

78.92

8.39

78.92

0.80

DEG

Ω

DEG

Quadrilateral

17.55

DEG

S

78.92

Ω

DEG

Ω

DEG

Ω

Ω

DEG

S

Ω

DEG

DEG

DEG

DEG

DEG

Ω

DEG

S

DEG

Ω

DEG

DEG

Ω

DEG

Ω

DEG

Ω

DEG

DEG

0.25

40.01

26.00

0.00

0.00

0.64

-3.30

Quadrilateral

1.46

78.92

8.39

78.92

Forward

8.39

78.92

0.50

Line setting

Quadrilateral

7.28

78.92

90.00

78.92

0.64

-3.30

Forward

Unit

-3.30

Forward

Quadrilateral

10.27

78.92

90.00

0.64

-3.30

Reverse


PHASE DISTANCE ELEMENTSSetting

78.92

0.40

Page 64 of 160

MAKE MODEL

PRPD: MN

CKD: GP


220kV Line(50Km)


PROJECT:


VE-J108-D-E212

DATE 16.09.13


POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV



POWER SWING FWD RCA















LINE UV PICKUP








FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1


AR RESET TIME

AR BKR1 FAIL OPTION


AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN



BF1 USE TIMER1


BF1 TRIP DROPOUT


TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY

%

S

pu

s

S

pu

pu

S

S

S

S

S

pu

pu

S

S

S

S

S

S

S

S

Ω

Ω

DEG

Ω

Ω

Ω

Ω

0.90

3.00

0.20

0.00

20.00

5.00

Enabled

Phase to Phase

UNDERVOLTAGE


S

S

SRC1

Yes

Yes

0.20

0.20

Yes

25.00

Lockout

2.00

1.00

Enabled

3-Pole

1.00

BREAKER FAILURE 1

S

Enabled

Enabled

1 pole

1.00

0.20

10.00

Enabled

AUTO RECLOSE

FUSE FAILURE

0.40

Delayed

1.00

0.70

0.15

0.09

LINE PICKUP (SOTF)

S

S

8.39

0.03

0.05

0.02

0.01

0.02

78.92

10.23

12.27

10.06

10.06

8.39

Quadrilateral

Two Step

0.60

17.55

Unit

21.05

pu

Ω

0.04

Enabled

0.05

0.01

PHASE DISTANCE ELEMENTSSetting


Page 65 of 160

MAKE MODEL






























PT Details:

PT Ratio = 220000/110 V





Reactance settings

Zone 1 Settings


X1prim = 85% * Xprim = 14.55


Zone 2 Settings









= 7.69


Since 120%, 8.22 is Higher than zone-2 limit. 7.69, so the zone-2 setting of 120% will overreach beyond zone-1 setting

of adjacent line protection. Therefore we consider 100% of protected line reactance + 50% of Adjacent Shortest Line



1.240

5.77

GP

ACSR ZEBRA

1.240

81.85

0.084

0.428

800.0


0.084

0.292

40.0

0.428

16.09.13

PROJECT:

220kV Line(40kM)

0.40


TITLE:


VE-J108-D-E212

DATE

CKD:SETTING CALCULATION FOR DISTANCE PROTECTION

0.292

0.08

0.43

0.29

1.24

Page 66 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE


Zone 3 Settings




Zone 4 Settings




Resistance settings





= (110/√3/1)

= 63.51 Ω



Ra = (28710 x L) / If^1.4

Where:



Ra =



= 1.10 Ω

(RARC is = 1.325 Ω






Time setting


Zone-2 setting









Zone-3 setting







for Phase faults



for Earth faults


formula (W).


Page 67 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE


Zone-4 setting


plus grading margin






R0-R1 = 0.21

X0-X1 = 0.81

Z0-Z1 = 0.84 75.62 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.64 -3.30 O

Where






Where



Rload sec = 57.16







(power factor min)

Øload- max = cos-1

(0.9)
























VT Fuse fail

Function enabled



Page 68 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE





I2 / I1 = 0.10


I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:


1 pole:



AR Mode, = 1 pole












BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1









PT Ratio =

=Under

voltage =



= V

≈ pu


220000/110

2000.00

0.90*Nominal Volt

198000

198000/2000

99.000

0.90

3.00

Page 69 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE


Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA


PHS DIST Z1 DIR RCA






PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY

40.00 km

Quadrilateral

5.82

78.92 DEG

78.92 DEG

Forward

78.92 DEG

Recommended Setting

90.00 DEG

Ω

0.34 pu

Forward

0.00 S

90.00

Quadrilateral

7.34 Ω

78.92 DEG

78.92 DEG

78.92 DEG

5.87 Ω

78.92 DEG

Forward

1.16 Ω

90.00 DEG

16.63 Ω

0.80 S

90.00 DEG

78.92 DEG

0.50 S

7.52 Ω

Menu text


Line setting

5.40 Ω

90.00 DEG

5.40 Ω

78.92

DEG

78.92 DEG

5.87 Ω

78.92 DEG

90.00 DEG

DEG

0.40 S

90.00 DEG

78.92 DEG

7.52 Ω

Quadrilateral

7.52 Ω

78.92 DEG

78.92 DEG

Reverse

Quadrilateral

78.92

90.00 DEG

7.52 Ω

78.92 DEG

Page 70 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE


GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA


GND DIST Z1 DIR RCA






GND DIST Z1 DELAY



GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT






Recommended Setting

DEG

Menu text


Quadrilateral

Line setting

Forward

5.40 Ω

78.92 DEG

90.00 DEG

5.82 Ω

78.92

78.92 DEG

Quadrilateral

78.92 DEG

7.34 Ω

78.92 DEG

90.00 DEG

-3.30 DEG

78.92 DEG

5.87

0.64 Ω

78.92 DEG

Forward

Quadrilateral

Quadrilateral

78.92 DEG

16.63 Ω

78.92 DEG

7.52 Ω

78.92 DEG

1.16 Ω

78.92 DEG

7.52 Ω

78.92 DEG

40.01 Ω

26.00 DEG

0.00

5.40 Ω

-3.30 DEG

78.92 DEG

90.00 DEG

Forward

0.00 S

0.64

90.00 DEG

78.92 DEG

0.40 S

5.87 Ω

Ω

7.52 Ω

-3.30 DEG

Reverse

0.80 S

0.64 Ω

7.52 Ω

-3.30 DEG

0.50 S

0.64 Ω

0.25 pu

S

0.00 S

Page 71 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(40kM)


TITLE:


VE-J108-D-E212

DATE


POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV



POWER SWING FWD RCA















LINE UV PICKUP








FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1


AR RESET TIME

AR BKR1 FAIL OPTION


AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN



BF1 USE TIMER1


BF1 TRIP DROPOUT


TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY

Ω

Quadrilateral

Two Step

7.52 Ω

9.48 Ω

11.37 Ω

7.52

Ω

pu

S

Ω

0.03 S

0.05 S

0.02 S

S

1.00

FUSE FAILURE

0.20 S

Delayed S

LINE PICKUP (SOTF)

1.00

0.09

Enabled

AUTO RECLOSE

Enabled

1 pole

10.00 S

S

1.00

BREAKER FAILURE 1

Lockout

25.00 S

Menu text


Recommended Setting

78.92 DEG

0.60 pu

16.63

pu

0.15 S

0.40 S

19.95

9.02 Ω

9.02

0.01

0.04 S

Enabled

0.05 S

0.02 S

0.70

Yes

Yes

0.01 S

Enabled

2.00 S

1.00


20.00 %

Enabled

3-Pole

SRC1

0.20 pu

0.20 pu

Yes

0.20 S

0.00 S

0.90 pu

3.00 s

5.00 S

UNDERVOLTAGE

Enabled

Phase to Phase

Page 72 of 160

MAKE MODEL






























PT Details:

PT Ratio = 220000/110 V





Reactance settings

Zone 1 Settings


X1prim = 85% * Xprim = 2.47


Zone 2 Settings









= 2.15






0.978

10.00

GP

TWIN ACSR ZEBRA

0.978

10.00

0.022

0.290

800.0


0.022

0.284

10.0

0.290

16.09.13

PROJECT:

220kV Line(10kM)

0.40


TITLE:


VE-J108-D-E212

DATE


0.284

0.02

0.29

0.284

0.978

Page 73 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE


Zone 3 Settings




Zone 4 Settings




Resistance settings





= (110/√3/1)

= 63.51 Ω



Ra = (28710 x L) / If^1.4

Where:



Ra =



= 0.45 Ω

(RARC is = 1.325 Ω






Time setting


Zone-2 setting









Zone-3 setting







for Phase faults



for Earth faults


formula (W).


Page 74 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE


Zone-4 setting


plus grading margin






R0-R1 = 0.26

X0-X1 = 0.69

Z0-Z1 = 0.74 69.19 O

Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1 = 0.84 -16.41 O

Where






Where



Rload sec = 57.16







(power factor min)

Øload- max = cos-1

(0.9)
























VT Fuse fail

Function enabled



Page 75 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE





I2 / I1 = 0.10


I2 / I1 = 20.00 %

time delay = 5.00 s

Auto Reclosure:


1 pole:



AR Mode, = 1 pole












BF1 MODE, = 3-Pole

BF1 SOURCE, = SRC1









PT Ratio =

=Under

voltage =



= V

≈ pu


220000/110

2000.00

0.90*Nominal Volt

198000

198000/2000

99.000

0.90

3.00

Page 76 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE


Settings Table

Line Length

PHASE DIST Z1 DIR

PHASE DIST SHAPE

PHS DIST Z1 REACH

PHS DIST Z1 RCA


PHS DIST Z1 DIR RCA






PHASE DIST Z1 DELAY

PHS DIST Z1 SUPV

PHASE DIST Z2 DIR

PHASE DIST SHAPE

PHS DIST Z2 REACH

PHS DIST Z2 RCA


PHS DIST Z2 DIR RCA






PHASE DIST Z2 DELAY

PHASE DIST Z3 DIR

PHASE DIST SHAPE

PHS DIST Z3 REACH

PHS DIST Z3 RCA


PHS DIST Z3 DIR RCA






PHASE DIST Z3 DELAY

PHASE DIST Z4 DIR

PHASE DIST SHAPE

PHS DIST Z4 REACH

PHS DIST Z4 RCA


PHS DIST Z4 DIR RCA






PHASE DIST Z4 DELAY

10.00 km

Quadrilateral

0.99

85.60 DEG

85.60 DEG

Forward

85.60 DEG

Recommended Setting

90.00 DEG

Ω

0.34 pu

Forward

0.00 S

90.00

Quadrilateral

1.39 Ω

85.60 DEG

85.60 DEG

4.37 Ω

85.60 DEG

0.40 S

Forward

Quadrilateral

2.09 Ω

0.80 S

85.60 DEG

85.60 DEG

85.60

Reverse

Quadrilateral

0.20 Ω

85.60 DEG

90.00 DEG

85.60 DEG

4.43 Ω

Menu text


Line setting

4.34 Ω

90.00 DEG

4.34 Ω

85.60

DEG

85.60 DEG

4.37 Ω

85.60 DEG

90.00 DEG

DEG

90.00 DEG

85.60 DEG

4.43 Ω

90.00 DEG

4.43 Ω

90.00 DEG

85.60 DEG

0.50 S

4.43 Ω

Page 77 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE


GND DIST Z1 DIR

GND DIST SHAPE

GND DIST Z1 REACH

GND DIST Z1 RCA


GND DIST Z1 DIR RCA






GND DIST Z1 DELAY



GND DIST Z2 DIR

GND DIST SHAPE

GND DIST Z2 REACH

GND DIST Z2 RCA


GND DIST Z2 DIR RCA






GND DIST Z2 DELAY



GND DIST Z3 DIR

GND DIST SHAPE

GND DIST Z3 REACH

GND DIST Z3 RCA





GND DIST Z3 DELAY



GND DIST Z4 DIR

GND DIST SHAPE

GND DIST Z4 REACH

GND DIST Z4 RCA





GND DIST Z4 DELAY



LOAD ENCROACHMENT






85.60 DEG

Forward

Quadrilateral

0.99 Ω

0.00 S

85.60 DEG

85.60 DEG

85.60 DEG

0.84

-16.41 DEG

Forward

Quadrilateral

1.39 Ω

0.40 S

90.00 DEG

4.37 Ω

85.60 DEG

85.60 DEG

0.84 Ω

-16.41 DEG

Forward

Quadrilateral

2.09 Ω

85.60 DEG

-16.41 DEG

85.60 DEG

Reverse

Quadrilateral

0.20 Ω

DEG

4.43 Ω

85.60 DEG

0.25 pu

0.00 S

Menu text


Line setting

Recommended Setting

90.00 DEG

85.60 DEG

4.34 Ω

90.00 DEG

4.34 Ω

90.00 DEG

85.60 DEG

4.37 Ω

85.60 DEG

4.43 Ω

0.80 S

0.84 Ω

4.43 Ω

85.60 DEG

4.43 Ω

0.50 S

0.84 Ω

85.60 DEG

-16.41 DEG

0.00 S

40.01 Ω

26.00

Page 78 of 160

MAKE MODEL

GP


16.09.13

PROJECT:

220kV Line(10kM)


TITLE:


VE-J108-D-E212

DATE


POWER SWING DETECT

POWER SWING SHAPE

POWER SWING MODE

POWER SWING SUPV



POWER SWING FWD RCA















LINE UV PICKUP








FUNCTION

FUNCTION

AR MODE

MAX NUMBER OF SHOTS

AR CLOSE TIME BKR1


AR RESET TIME

AR BKR1 FAIL OPTION


AR 1-P DEAD TIME

AR BKR1 SEQUENCE

FUNCTION

BR1 MODE

BF1 SOURCE

BF1 USE AMP SUPV

BF1 USE SEAL-IN



BF1 USE TIMER1


BF1 TRIP DROPOUT


TRIP TIME

PHASE UV1 FUNCTION

PHASE UV1 MODE

PHASE UV1 PICKUP

PHASE UV1 DELAY


Quadrilateral

Recommended SettingMenu text

2.51

85.60 DEG

0.60 pu

2.09

5.31 Ω

0.03 S

0.05 S

5.31 Ω

Ω

0.15 S

0.09 S

0.02 S

0.40 S

0.70 pu

Enabled

FUSE FAILURE

Enabled

0.01 S

BREAKER FAILURE 1

25.00 S

Lockout

AUTO RECLOSE

Enabled

1 pole

Two Step

Ω

1.24 Ω

1.49 Ω

0.02 S

4.43 Ω

4.43

Delayed S

LINE PICKUP (SOTF)

1.00 pu

0.01 S

0.04 S

Enabled

0.05 S

1.00

0.20 S

10.00 S

2.00 S

1.00 S

1.00

Enabled

3-Pole

SRC1

Yes

Yes

0.20 pu

0.20 pu

Yes

0.20 S

0.00 S


20.00 %

0.90 pu

3.00 s

5.00 S

UNDERVOLTAGE

Enabled

Phase to Phase

Page 79 of 160

MAKE MODEL

4.7. Distance protection MAIN-2

CT Details

CT Ratio = 800/1A

CT Primary = 800 A

CT Secondary = 1 A

CTR = 800

Class = PS

System Details

VT Ratio = 220kV/√3

= 110V/√3

VT Primary = 220000 V

VT Secondary = 110 V

PTR 2000.00

Frequency = 50HZ

Maximum fault current = 3.66kA

OHL Details

Condutor type = ZEBRA

Line Length = 50km

Line impedence

Positive sequence impedence (Z1) = 0.084 +j 0.428

Zero sequence impedence ( Z0 ) = 0.292 +j 1.240

Line Length = 50 km

Current rating in Amps = 800

Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km

Z0/Z1 = 2.921 L -2.170 °


Condutor type Zebra

Line Length 104.97km

Line impedence

Positive sequence impedence (Z1) 0.084 +j 0.428

Zero sequence impedence ( Z0 ) 0.292 +j 1.240

Line Length 104.970 km

Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km


Condutor type Zebra

Line Length 23.97km

Line impedence




Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km

RELAY Alstom P442 BAY/FEEDER 220kV Line(50KM)

PRPD: MN

TITLE: SETTING CALCULATION FOR DISTANCE PROTECTION CKD: GP



VE-J108-D-E212

DATE 16.09.13

Page 80 of 160

MAKE MODELRELAY Alstom P442 BAY/FEEDER 220kV Line(50KM)

PRPD: MN




VE-J108-D-E212

DATE 16.09.13

Relay settings

Line impedence

Ratio of secondary to primary impedence = CT ratio / VT ratio

(800/2000)

0.40

Line impedence secondary = ratio CT/VT x line impedence primary

0.4*50*0.436

Line impedence = 8.72 L 79.00

Relay line angle settings -90° to 90° in 1° steps.Therefore, select Line Angle =79° for convenience.

Therefore set Line Impedence and Line Angle = 8.72 L 79.00 Ω secondary

Zone 1 Phase Reach Settings


Zone 1 Reach = (0.85*8.72)

Z1 = 7.41 L 79.00 Ω secondary

The Line Angle = 79.00

Therefore actual Zone 1 reach, Z1 = 7.41 L 79.00 Ω secondary



Zone 2 Reach = (1.2*8.723)

10.47 L 79.00 Ω secondary

Actual Zone 2 reach, Z2 = 10.47 L 79.00


Required Zone 3 forward reach

(100% of the protected line +50%of the adjacent longest line) x 1.2

Zone 3 Reach = (1*8.723)+(0.5*0.436*104.97*0.4)*1.2

= 21.45 L 79.00 Ω secondary


Zone 4 Reverse Reach Settings

Required Zone4 reverse reach impedence,typically 20% Zone 1 reach

= 0.2*7.414


ZONE TIMER SETTING:

tZ1 = 0 s

tZ2 = 0.40 s

tZ3 = 0.80 s

tZ4 = 0.50 s

Residual Compensation for Earth Fault Element

kZ0 Res. Comp, kZ0 = (Z0-Z1) / 3Z1

kZ0 Angle, L kZ0 = L (Z0-Z1) /3Z1

Z0-Z1 = (0.292+j1.24)-(0.0838+j0.428)

= 0.2082 +j 0.812

0.84 L 75.62 °

(Z0-Z1) / 3Z1 = (0.838/(3*0.436)) L75.62-78.92

0.64 L -3.30 °

kZ0 Res. Comp, kZ0 = 0.64

kZ0 Angle, L kZ0 = -3.30 °

This feature is useful where line impedence characteristics change between sections or where hybrid circuits are used. here,the line

impedence characteristics not known for adjacent sections.Hence a common KZ0 factor can be applied to each zone.

Page 81 of 160


PRPD: MN




VE-J108-D-E212

DATE 16.09.13


= Vn (phase - neutral) / In

= (110V/√3 /1)




Ra = (28710 x L) / If^1.4

Where: If = Minimum expected phase-phase fault current (A);


Ra = Arc resistance, calculated from the van Warrington formula (W).



= 1.33 Ω

= 40.00 Ω

RPH (min) = 1.325*0.4 0.530 Ω

RG (min) = 40*0.4 16 Ω

Selection of Resistive Reaches

The Zone 2 elements satisfy R2Ph ≤ (R3Ph x 80%), and R2G ≤ (R3G x 80%)

R3Ph - R4Ph should be set ≤ 80% Z minimum load - ∆R

Minimum Maximum Zone 1 Zone 2 Zones 3 & 4

0.53 38.11 19.51 24.39

16.00 50.81 21.43 28.58

Power Swing Block

∆R and ∆X band settings are both set between 10 - 30% of R3Ph as recommended by AREVA

Minimum 10% x 30.48 = 3.05

Maximum 30% x 30.48 = 9.15

∆R = 0.16*Rload (min)

0.16*63.51*0.6 (40% of margin is considered)

= 6.10

Biased Residual Current IN> = 40% (typical setting from manual)

Biased Negative Sequence Current I2> = 30% (typical setting from manual)

Power swing current = 2 In

minimum setting for Imax line> = 1.2 x (max.power swing current)

= 1.2*2*1

minimum setting for Imax line> = 2.40

minimum fault current level = 3660.00 A

Fault current in secondary = 3660*1/800

= 4.58 A

maximum setting for Imax line> = 0.8 x (min.phase fault current level)

= 3.66 A

Hence setting for Imax line> = 3.66 A


Full load current = 800 A

= 80.00 A (10% of fullload current)

I2 / I1 = 0.10


I2 / I1 = 0.20

time delay = 60.00 s

Minimum Load impedence to the

relay

Minimum Load impedence to the relay

Earth (RG)Ω


30.48

38.11


assuming a typical earth fault coverage

Considering power swing frequency and load impedence and angle between sources,the ∆R becomes


for Phase faults


for Earth faults

Phase (RPh)Ω

(this value is well within the min&max limits above)

Page 82 of 160


PRPD: MN




VE-J108-D-E212

DATE 16.09.13

SOTF

SOTF Protection operates 120% of fault current with breaker closing command


= 1.2*3660

= 4392

= 5.5 A

Auto Reclosure:

1 pole:

Number of Shots = 1

1P Dead Time = 1 s

Healthy Window 5 s

Reclaim Time = 25 s

Discrimination Time = 5 s

A/R Inhibit Window = 5 s

Block auto-recloser =

AR Close pulse length = 0.20 s

Local Breaker Backup protection

CB Fail 1 Timer = 0.20 s

I< Current Set = 0.20 In

Setting Recommendation for Under Voltage

PT Ratio = 220000/110

= 2000.00Under

voltage =

0.90 *

Nominal

= 0.9x220000 90 %

= 198000 v

Select Under voltage setting, 27 = 198000/2000

= 99 V

Time delay setting , 27 = 3 s

11111111 11111111

In general, a breaker failure scheme determines that a breaker signaled to trip has not cleared a fault with in a definite

time, so further tripping action must be performed.

In this mode, the recloser starts the AR-1P DEAD TIME for the first shot if the fault is single phase. If the fault is three

phase or three pole trip occurred on the breaker during single initiation, the scheme goes to lockout with out reclosing.


Page 83 of 160


PRPD: MN




VE-J108-D-E212

DATE 16.09.13

Settings Table

km

Ω

Ω

ΩΩΩs

Ω

ΩΩΩs

Ω

ΩΩΩs

ΩtZ4 s

Delta R ΩDelta X ΩIN>Status

IN>(%Imax)

I2>Status

I2>(%Imax)

Imax line>Status

Imax line> A

Unblocking Time delay s

Blocking Zones

1P Trip Mode

Max number of shots

1P - Dead Time 1(HSAR) s

Healthy window s

Reclaim Time s

Discrimination Time s

A/R Inhibit Window s

Close Pulse Time s

AUTORECLOSE LOCKOUT

Block A/R 11111111 11111111

CB Fail & I<

Breaker Fail

CB Fail 1 Timer s

I< Current Set 0.00

0.20

5.00

25.00

5.00

5.00

0.40

Enabled

0.30

Enabled

3.66

30.00

0'0'0'0'0'0'0'0

Single

1.00

1.00

21.45

38.11

30.48

0.80

1.48

Enabled

10.47

28.58

24.39

0.40

0.64

-3.30

50.00

8.72

79.00

0.64

-3.30

7.41

LOCAL BREAKER BACKUP PROTECTION

0.20

0.20

tZ3

Z4

GROUP 1 AUTORECLOSE

AUTORECLOSE MODE

GROUP1 POWER SWING

0.50

6.10

6.10

KZ3/4 Angle

Z3

R3G -R4G

R3ph - R4ph

21.43

19.51

0.00

0.64

KZ2 Angle -3.30

Z2

R2G

R2ph

tZ2

KZ3/4 Res Comp

KZ1 Angle

Z1

R1G

R1ph

tZ1

KZ2 Res Comp

Line Length

Line Impedence

Line Angle

KZ1 Res Comp

Zone setting

Zone status

Menu text Settimg

GROUP1 DISTANCE ELEMENTSRecommenmded Unit

Line setting

Page 84 of 160


PRPD: MN




VE-J108-D-E212

DATE 16.09.13

V<Measur't Mode

V<1 Voltage Set V

V<1 Time delay s

Broken conductor

I2 / I1 A

I2 / I1 Time Delay s

I2 / I1 Trip

VTS Time Delay s

VTS I2>IO>inhibit A

Detect 3P

Threshold 3P V

Delta I> A

5.00

0.20

Enabled

10

0.20

60.00

Enabled

Enabled

0.20

3.00

GROUP 1 SUPERVISION

VT Supervision

GROUP 1 VOLT Protection

GROUP 1 BROKEN CONDUCTOR

Phase-phase

99.00

Page 85 of 160

MAKE MODEL


CT Details

CT Ratio = 800/1A

CT Primary = 800 A

CT Secondary = 1 A

CTR = 800

Class = PS

System Details


= 110V/√3



PTR 2000.00

Frequency = 50HZ


OHL Details


Line Length = 50km

Line impedence



Line Length = 50 km


Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km

Z0/Z1 = 2.921 L -2.170 °


Condutor type Zebra

Line Length 81.85km

Line impedence




Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km


Condutor type Zebra

Line Length 5.77km

Line impedence




Line impedences

Z1 = 0.436 L 78.920 Ω/km

Z0 = 1.274 L 76.750 Ω/km





VE-J108-D-E212

DATE 16.09.13

Page 86 of 160





VE-J108-D-E212

DATE 16.09.13

Relay settings

Line impedence


(800/2000)

0.40


0.4*50*0.436






Zone 1 Reach = (0.85*0)






Zone 2 Reach = (1.2*8.723)






Zone 3 Reach = (1*8.723)+(0.5*0.436*81.85*0.4)*1.2





= 0.2*7.414


ZONE TIMER SETTING:

tZ1 = 0 s

tZ2 = 0.40 s

tZ3 = 0.80 s

tZ4 = 0.50 s




Z0-Z1 = (0.292+j1.24)-(0.0838+j0.428)

= 0.2082 +j 0.812

0.84 L 75.62 °

(Z0-Z1) / 3Z1 = (0.838/(3*0.436)) L75.62-78.92

0.64 L -3.30 °


kZ0 Angle, L kZ0 = -3.30 °



Page 87 of 160





VE-J108-D-E212

DATE 16.09.13



= (110V/√3 /1)




Ra = (28710 x L) / If^1.4






= 1.33 Ω

= 40.00 Ω

RPH (min) = 1.325*0.4 0.530 Ω

RG (min) = 40*0.4 16 Ω





0.53 38.11 19.51 24.39

16.00 50.81 21.43 28.58

Power Swing Block


Minimum 10% x 30.48 = 3.05

Maximum 30% x 30.48 = 9.15



= 6.10





= 1.2*2*1




= 4.58 A


= 3.66 A





I2 / I1 = 0.10


I2 / I1 = 0.20


Earth (RG)Ω 38.11




for Earth faults



Phase (RPh)Ω 30.48


relay




for Phase faults

Page 88 of 160





VE-J108-D-E212

DATE 16.09.13

SOTF



= 1.2*3660

= 4392

= 5.5 A

Auto Reclosure:

1 pole:

Number of Shots = 1

1P Dead Time = 1 s

Healthy Window 5 s

Reclaim Time = 25 s









PT Ratio = 220000/110

= 2000.00Under

voltage =

0.90 *

Nominal

= 0.9x220000 90 %

= 198000 v


= 99 V


11111111 11111111






Page 89 of 160





VE-J108-D-E212

DATE 16.09.13

Settings Table

km

Ω

Ω

ΩΩΩs

Ω

ΩΩΩs

Ω

ΩΩΩs

ΩtZ4 s


IN>(%Imax)

I2>Status

I2>(%Imax)

Imax line>Status

Imax line> A


Blocking Zones

1P Trip Mode

Max number of shots


Healthy window s

Reclaim Time s



Close Pulse Time s

AUTORECLOSE LOCKOUT

Block A/R 11111111 11111111

CB Fail & I<

Breaker Fail

CB Fail 1 Timer s

I< Current Set 0.000.20

GROUP 1 AUTORECLOSE

25.00

5.00

5.00

0.20

AUTORECLOSE MODE

Enabled

3.66

30.00

0'0'0'0'0'0'0'0

Enabled

0.30

Z3 19.03

R3G -R4G 38.11

0.50

GROUP1 POWER SWING

R3ph - R4ph 30.48

Zone setting

Zone status

R1ph 19.51

tZ1 0.00

Z1 7.41

R1G 21.43

Menu text


Line setting

Settimg

Line Length 50.00

KZ1 Res Comp 0.64

KZ1 Angle -3.30

Line Impedence 8.72

Line Angle 79.00

KZ2 Angle -3.30

KZ2 Res Comp 0.64

Z2 10.47

R2G 28.58

KZ3/4 Angle -3.30

R2ph 24.39

tZ2 0.40

KZ3/4 Res Comp 0.64

6.10

6.10

Enabled

0.40

tZ3 0.80

Z4 1.48


Single

1.00

1.00

5.00

0.20

Page 90 of 160





VE-J108-D-E212

DATE 16.09.13

V<Measur't Mode

V<1 Voltage Set V

V<1 Time delay s

Broken conductor

I2 / I1 A


I2 / I1 Trip

VTS Time Delay s

VTS I2>IO>inhibit A

Detect 3P

Threshold 3P V

Delta I> A

GROUP 1 SUPERVISION

VT Supervision

5.00

Enabled

0.20

Enabled

10

0.20

3.00


Enabled

0.20

60.00


Phase-phase

99.00

Page 91 of 160

MAKE MODEL


CT Details

CT Ratio = 800/1A

CT Primary = 800 A

CT Secondary = 1 A

CTR = 800

Class = PS

System Details


= 110V/√3



PTR 2000.00

Frequency = 50HZ


OHL Details


Line Length = 10km

Line impedence



Line Length = 10 km


Line impedences

Z1 = 0.291 L 85.660 Ω/km

Z0 = 1.018 L 73.810 Ω/km

Z0/Z1 = 3.502 L -11.850 °


Condutor type Zebra

Line Length 81.85km

Line impedence



Line Length 10 km

Line impedences

Z1 = 0.291 L 85.660 Ω/km

Z0 = 1.018 L 73.810 Ω/km


Condutor type Zebra

Line Length 5.77km

Line impedence



Line Length 10 km

Line impedences

Z1 = 0.291 L 85.660 Ω/km

Z0 = 1.018 L 73.810 Ω/km





VE-J108-D-E212

DATE 16.09.13

Page 92 of 160





VE-J108-D-E212

DATE 16.09.13

Relay settings

Line impedence


(800/2000)

0.40


0.4*10*0.291






Zone 1 Reach = (0.85*0)






Zone 2 Reach = (1.2*1.163)






Zone 3 Reach = (1*1.163)+(0.5*0.291*10*0.4)*1.2





= 0.2*0.989


ZONE TIMER SETTING:

tZ1 = 0 s

tZ2 = 0.40 s

tZ3 = 0.80 s

tZ4 = 0.50 s




Z0-Z1 = (0.284+j0.978)-(0.022+j0.29)

= 0.262 +j 0.688

0.74 L 69.15 °

(Z0-Z1) / 3Z1 = (0.736/(3*0.291)) L69.15-85.66

0.84 L -16.51 °


kZ0 Angle, L kZ0 = -16.51 °



Page 93 of 160





VE-J108-D-E212

DATE 16.09.13



= (110V/√3 /1)




Ra = (28710 x L) / If^1.4






= 0.45 Ω

= 40.00 Ω

RPH (min) = 0.445*0.4 0.178 Ω

RG (min) = 40*0.4 16 Ω





0.18 38.11 19.51 24.39

16.00 50.81 21.43 28.58

Power Swing Block


Minimum 10% x 30.48 = 3.05

Maximum 30% x 30.48 = 9.15



= 6.10





= 1.2*2*1




= 9.98 A


= 7.98 A





I2 / I1 = 0.10


I2 / I1 = 0.20


Earth (RG)Ω 38.11




for Earth faults



Phase (RPh)Ω 30.48


relay




for Phase faults

Page 94 of 160





VE-J108-D-E212

DATE 16.09.13

SOTF



= 1.2*7980

= 9576

= 12.0 A

Auto Reclosure:

1 pole:

Number of Shots = 1

1P Dead Time = 1 s

Healthy Window 5 s

Reclaim Time = 25 s









PT Ratio = 220000/110

= 2000.00Under

voltage =

0.90 *

Nominal

= 0.9x220000 90 %

= 198000 v


= 99 V


11111111 11111111






Page 95 of 160





VE-J108-D-E212

DATE 16.09.13

Settings Table

km

Ω

Ω

ΩΩΩs

Ω

ΩΩΩs

Ω

ΩΩΩs

ΩtZ4 s


IN>(%Imax)

I2>Status

I2>(%Imax)

Imax line>Status

Imax line> A


Blocking Zones

1P Trip Mode

Max number of shots


Healthy window s

Reclaim Time s



Close Pulse Time s

AUTORECLOSE LOCKOUT

Block A/R 11111111 11111111

CB Fail & I<

Breaker Fail

CB Fail 1 Timer s

I< Current Set 0.00

0.20


0.20

0.20

AUTORECLOSE MODE

5.00

1.00

1.00

5.00

25.00

KZ3/4 Angle -16.51

Z4 0.20

0.50

GROUP1 POWER SWING

Z3 2.09

R3G -R4G 38.11

tZ2 0.40

KZ3/4 Res Comp 0.84

R2ph 24.39

KZ1 Res Comp 0.84

tZ1 0.00

KZ2 Res Comp 0.84

Z1 0.99

R1G 21.43

Menu text


Line setting

Settimg

Line Length 10.00

Line Impedence 1.16

KZ1 Angle -16.51

Line Angle 86.00

Zone setting

Zone status

R1ph 19.51

Z2 1.40

R2G 28.58

KZ2 Angle -16.51

Single

R3ph - R4ph 30.48

tZ3 0.80

Enabled

7.98

GROUP 1 AUTORECLOSE

Enabled

0.30

6.10

6.10

5.00

0.40

30.00

0'0'0'0'0'0'0'0

Enabled

Page 96 of 160





VE-J108-D-E212

DATE 16.09.13

V<Measur't Mode

V<1 Voltage Set V

V<1 Time delay s

Broken conductor

I2 / I1 A


I2 / I1 Trip

VTS Time Delay s

VTS I2>IO>inhibit A

Detect 3P

Threshold 3P V

Delta I> A

10

0.20

GROUP 1 SUPERVISION

VT Supervision

5.00

Enabled

0.20

60.00

Enabled

0.20

Enabled


Phase-phase

99.00

3.00


Page 97 of 160

MAKE MODEL

4.10.Differential Protection For 160MVA Transformer

Transformer Data:

Rated Power, Prated = 160.0 MVA

Rated Voltage

HV, Vnom[1] = 220.0 kV

LV, Vnom[2] = 132.0 kV

% Impedance = 0.125 12.50% .

Vector Group = YNa0

= 800.0 1.0 A

= 800.0 1.0 A

OLTC Range on 132kV side + 10.0 % Step

to

- 5.0 %








= (160*1000)/(1.732*220)

Irated [1], = 419.89 A


=

Irated [2], = A

With this rated currents the CT margin for Winding1& winding 2 as follows,


=

Imargin[1], =


=

Imargin[2], =

Since Imargin[2] < Imargin[1], the reference winding Wref is winding 2.

Calculation of magnitude compensation factor (M),


= 800x220000/800x132000

220kV side M[1], = 1.67


= 800x132000/800x132000

132kV side M[2], = 1.00

1.14

Note: In the entire calculation primary and secondary windings are referred as winding "1" & "2" respectively.

The unit for calculation of the differential and restraint currents and base for the differentialrestraint setting is

the CT primary associated with the reference winding.


(Inom,a) (1600-800/1A)


(Inom,b) (800-400/1A)

(160*1000)/(1.732*132)

699.82

800/419.89

1.91

800/699.82

RELAY GE T60 BAY/FEEDER 220/132-160 MVA Trafo


TITLE: SETTING CALCULATION FOR 220/132-160MVATRAFO DIFF PROTN CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 98 of 160

MAKE MODELRELAY GE T60 BAY/FEEDER 220/132-160 MVA Trafo




VE-J108-D-E212

DATE 16.09.13

a) Calculating the minimum differential pickup current required for relay to operate,

Criteria:

No load current of the transformer primary current,=

= A

No load current refered to the CT secondary, =

= A

=

IS1 = A

No load current of the transf. winding2,(secondary side)=

IS2 =

Differential current IdA, =

=

Id A, = A

Restraining current IrA, = max( | Is1|, |Is2 |)

= max( |0.043|, |0 |)

IrA, = A

b) Selection of Break point 1 and slope 1:

Recommened Settings,

The Break point 1 setting is based on the pu value of the full load transformer current

HV side (Winding -1) = 0.52 pu

LV side (Winding -2) = 0.87 pu

Hence we choose Break point-1 = 2 pu

Slope -1 = 25%

Nominal Voltage, Vnom = 2 ( Vmax X Vmin) / (Vmax + Vmin)

= 2(145.2*125.4)/(145.2+125.4)

= 134.58 kv

Object current of regulated side, IN2 = SN/(1.732 X VN2)

= (160*1000)/(1.732x134.576)

= 686.44 A

= IN2 / CT2

= 686.45/800

= 0.86 A ~ INobj

= IN1 / CT1

= 419.89/800

= 0.52 A ~ INobj

= SN/(1.732 X Vmax)

= (160*1000)/(1.732x145.2)

= 636.22

= IN2(+15%) / CT2

= 636.22/800

= 0.80 A ~ 0.93 INobj

= | IN2(+15%) - INobj |


= 0.07 INobj

The differential current IdA=0.0433A is found to be less than the minimum pickup selected setting of 0.1 is

adequate as the relay catalogue has a setting generally recommended between 0.1 to 0.3.

Differential / Restraint Current in the Tap Changer Extreme Position:


to IN2


to IN1

Object current in maximum tap position,

IN2(+15%)


to IN2

Differential current in maximum tap

position IDiff

20.99

20.9945/800

0.03

No load current to the relay after applying magnitude compendation factor M[1],

0.026×1.667

0.0433

The minimum differential pickup should be above the no load current of the transformer when the secondary side of the breaker is

open

Stability of relay when the transformer is operating under no load (Secondary side breaker is open) and the transformer is drawn

the magnetising current(up to 5% of rated current)

0.05×419.89

0.0

0.0

| Is1+Is2 |

|0.043+0 |

0.0433

0.04

Page 99 of 160





VE-J108-D-E212

DATE 16.09.13

= | IN2(+15%) + INobj |


= 1.93 INobj

= SN/(1.732 X Vmin)

= (160*1000)/(1.732x125.4)

= 736.67

= IN2(-5%) / CT2

= 736.67/800

= 0.92 A ~ 1.07 INobj

= | IN2(-5%) - INobj |


= 0.07 INobj

= | IN2(-5%) + INobj |


= 2.07 INobj

Iop, Relay operating current at +15% tap, = slope1 X Irest

= 0.25x1.927INObj

= 0.48 INObj


Iop, Relay operating current at -5% tap, = slope1 X Irest

= 0.25x2.073INObj

= 0.52 INObj


From the above calculation it is derived that , under rated condition and at Tap Changer Extreme positions,

Operating current are not in the Tripping Area .

C) Selection of Break point 2 and slope 2:

Break point-2

The setting for Break point -2 depend very much on the capability of CTs to correctly transform Primary into

secondary currents during external faults. Break point -2 should be set below the fault current that is most likely to saturate

some CTs due to an AC Component alone

External Fault current = 7.00 pu

Break point- 2 = 8 pu

Slope-2 = 98% (as per relay catalogue)

2nd HARMONICS:

INRUSH INHIBIT LEVEL, = 20%

INRUSH INHIBIT FUNCTION

(now a days all modern transformers produce low 2nd harmonic ratios)

INRUSH INHIBIT MODE PER PHASE

5TH HARMONICS:This

setting is

OVEREXCITN INHIBIT LEVEL, = 30%

Instantaneous differential protection:

The pickup thersold should be set greater than the maximum spurious differential current that could be encountered

under non-internal fault conditions ( typically maganetizing inrush current or an external fault with extremely severe CT saturation.

I) Magnetizing inrush current = 6 x Full load current

= 2519.34 A

= 3.15 pu

Differential current in minimum tap

position IDiff

Restriant current in minimum tap position

IRestaint

The percentage of harmonics present in the inrush current, for the relay to recognise the inrush current is set as 20%

as per manufacturer recommended,

ADAPTIVE 2nd Harmonic

Object current in minimum tap position,

IN2(-5%)


to IN2

Restriant current in maximum tap position

IRestaint

Page 100 of 160





VE-J108-D-E212

DATE 16.09.13

II) External fault condition:

HV Side Fault Current = 4.20 pu

LV Side Fault Current = 7.00 pu

8 pu

VOLTS PER HERTZ (OVER FLUX):

According to experience we set the definite time curve with the following settings,

Stage-1





Stage-2





Setting Table:

0.1 pu

0.25

2 pu

8 pu

0.98

0.2

5th

0.3

8 pu

1.1 pu

10 s

0 s

1.2 pu

1 s

0 s

VOLTS/HZ 2 TD MULTIPLIER 5% 600 S

VOLTS/HZ 2 T-RESET 0 S 1000 S

VOLTS/HZ 2 PICKUP 0.8 pu 4 pu

VOLTS/HZ 2 CURVE Definite Time Definite Time, IDMT

VOLTS/HZ 1 T-RESET 0 S 1000 S

VOLTS/HZ 2

VOLTS/HZ 1 CURVE Definite Time Definite Time, IDMT

VOLTS/HZ 1 TD MULTIPLIER 5% 600 S

Max

0.05 pu 1 pu

PER PHASE perphase,2-out-of-3,Avg.

VOLTS/HZ 1 PICKUP 0.8 pu 4 pu

INST DIFFERENTIAL PICKUP 2 pu 30 pu

VOLTS/HZ 1

2nd Harmonic INHIBIT FUNCTION

OVEREXCITN INHIBIT FUNCTION disabled,5th

OVEREXCITN INHIBIT LEVEL 1% 40%

Adaptive Adaptive, Traditional,Disabled

2nd Harmonic INRUSH INHIBIT LEVEL 1% 0.4

2nd Harmonic INRUSH INHIBIT MODE

PERCENT DIFFERENTIAL BREAK2 2 pu 30 pu

PERCENT DIFFERENTIAL SLOPE2 50% 1

PERCENT DIFFERENTIAL PICKUP

PERCENT DIFFERENTIAL SLOPE1 15% 1

PERCENT DIFFERENTIAL BREAK1 1 pu 2 pu

PERCENT DIFFERENTIAL Min

Menu Text

For safety margin we choosen instantaneous

differential protection setting

The per-unit V/HZ value is calculated using the maximum of the three-phase voltage inputs or the auxiliary

voltage channel Vx input, if the source is not configured with Phase voltages.

The volts-per-Hertz protection, to protect transformers during potentially damaging over voltage and under

frequency disturbances.

Recomm.Setting

Setting Range

Page 101 of 160

MAKE MODEL

4.11Restricted Earth Fault portection For 160MVA Transformer

Transformer Data:

Rated Power, Prated = 160 MVA

Rated Voltage

HV, Vnom[1] = 220 kV

LV, Vnom[2] = 132 kV

% Impedance = 0.125 12.50% .

Vector Group = YN yn 0

Py Sec

= 800 1 A (1600-800/1A)

= 800 1 A (800-400/1A)

Neutral CT Ratio = 600 1 A 600/1A

OLTC Range on 132kV side + 10 %

to

- 5 %








= (160*1000)/(1.732*220)

Irated [1], = 419.89 A


= (160*1000)/(1.732*132)

Irated [2], = 699.82 A

Setting Calculation

Base kV = 132.00 220.00

Base MVA = 160.00 160.00

Base Impedence Zb=kV2 /MVA = 108.90 302.50

Zt=Zb*Zp.u = 13.61 37.81

If= kV/(√3*Zt) = 5598.71 3359.23

Ifault = 0.05 x Igf(max)

= (0.05X3359.23)

= 167.97

3Io= 0

The ground differential pickup setting can be calculated , I= | 3IO - Ig |

= (0-(167.97/800)

= 0.21

Note that phase CT primary is used as a unit for calculating the RGF setting . Hence, magnitude scaling is applied to

the measured ground current

The new restraint calculation algorithm provides very secure behavior of the element on external faults and CT saturation,

and high sensitivity on internal faults. The setting of the slope should be selected based on two criteria:

Reliable detection of the internal fault curents corresponding to the point of the selected distance from the grounded neutral


(Inom,b)

For a winding fault point at 5% Distance from the transformer neutral, the phase to ground

primary fault current is calculated as

RELAY GE T60 BAY/FEEDER 220/132-160 MVA Trafo


(Inom,a)

Increase in phase current (Iph) due to the fault are

negligible, meaning that


TITLE: SETTING CALCULATION FOR 220/132-160MVATRAFO REF PROTN CKD: GP


VE-J108-D-E212

DATE 16.09.13

Page 102 of 160





VE-J108-D-E212

DATE 16.09.13

Security on external faults with or without CT saturation

Let us consider the case of an internal fault that occurs on in the winding at 5% distance from the transformer neutral.

The primary fault current of 167.97 A

IG = 0.21 pu

Based on 100% transformer load currents of 419.89 A On the Wye winding, the phase unit currents are

IA = IB=IC = 0.52 pu

and the symmetrical components are

I1 = 0.52 pu ; I2 = I0= 0 pu

The ground differential current is

IGD = | IG + IN |

= 0.21 pu + 0 pu

= 0.21 pu

The restraint current used by the relay algorithm is defined as the maximum from the |R1, |R2 , |R0 quantities,

based on the following symmentrical components calculations:

IGR = max( |R1, |R2, |R0)

The value of |R1 is calculating using the positive-sequence current:

|I_1 < 1.5 pu, then IR1 = |I_1| / 8

= 0.066

The value of |R2 is calculating using the negative-sequence current:

IR2 = 3 x |I_2|

= 0.000

The value of |R0 is calculating using the zero-sequence current:

IR0 = | IG - IN |

= 0.210 pu + 0 pu

= 0.210 pu

The ground restraint current is

IGR = max( |R1, |R2, |R0)

= max(0.066pu,0pu,0.21pu)

= 0.210 pu

The RGF element would therefore calculate a ground differential / restraint ratio of:

IGD / IGR X 100% = 0.21pu/0.21pux100%

100 %

The slope should be set at some level below 100%

If no CT Saturation is involved, the RGF protection detects no differential current during ground fault that are external to the zone.

However, RGF slope setting should be also selected to maintain the security on external faults with CT saturation.

External Solid phase A to ground fault with no CT Saturation.

Fault Current at secondary side,

IA = (3359.23/800) IB=IC=0

= 4.20

IN = 4.20 pu L 00

IG = 4.20 pu L 1800

The symmetrical components derived from the phase unit current are

I1= I2 = I0 = 1.40

The ground differential current will be

IGD = | IG + IN |

= 4.20 pu L 00 + 4.20 pu L 180

0

= 0.00 pu

The |R1, |R2, and |R0 current are :

|R1 = |I_1| / 8

0.17

Page 103 of 160





VE-J108-D-E212

DATE 16.09.13

|R2 = 3 x |I_2|

= 4.20

|R0 = | IG - IN |

= 4.20 pu L 1800 - 4.20 pu L 0

0

= 8.40 pu

The ground restraint current is

IGR = max( |R1, |R2, |R0)

= max(0pu,0.175pu,8.4pu)

= 8.40 pu

The RGF element would therefore calculate calculate a ground differential / restraint ratio of:

IGD / IGR X 100% = 0pu/8.4pux100%

0.00 %

and the protection element is effectively in non operating stage.

External phase A to ground fault where the ground CT Saturates, producing only 5% of the total fault current

on its secondary winding.

Fault Current at secondary side, IA = IN = 4.20 pu L 00 pu

IG = 0.21 pu L 1800

The symmetrical components derived from the phase unit current are

I1= I2 = I0 = 1.40 pu

The ground differential current will beIGD = | IG + IN |

= 4.20 pu L 00 + 0.21 pu L 180

0

= 3.99 pu

The |R1, |R2, and |R0 current are :

|R1 = |I_1| / 8

0.18

|R2 = 3 x |I_2|

= 4.20

|R0 = | IG - IN |

= 0.00 pu L 1800 - 4.20 pu L 0

0

= 4.20 pu

The restraint current is IGR = max( |R1, |R2, |R0)

= max(3.99pu,0.175pu,4.2pu)

= 4.20 pu

The RGF element would therefore calculate calculate a ground differential / restraint ratio of:

IGD / IGR X 100% = 3.99pu/4.2pux100%

= 95 %

This is well above the restraint characteristics in the operating region if no special treatment to the restraint is provided.

CT Saturation and switch off conditions, the ground restraint IGR is set to decay slowly. Since the CTs do not immediately saturate

at the same instant the fault occurs, the restraint current will be equal to the intial fault current value of 8.40pu(as in the

no saturation case).The restraint will drop to 50% of its original value after 15.5 cycles, so that if the worst case of saturation

occurs after a cycle, the restraint current will be approximately 7.98 pu,

IGD / IGR X 100% = 3.99pu/7.98pux100%

50 %

The slope would have to be above 50%(assuming very severe saturation leading to only 5% current from the saturated ground CT)

and below 100% (assuming detection of faults on the winding at 5% distance from the neutral point)

slope = 70 %

IB=IC=0

Page 104 of 160





VE-J108-D-E212

DATE 16.09.13

Setting Table:

Enabled

SRC1

0.21 pu

70 pu

0 s

0 s

Off

Self Reset

Enabled

Restd GND FT1 Pick Up Delay 0 600

Restd GND FT1 Block

Restd GND FT1 Target

Restd GND FT1 Pick Up 0pu 30 pu

Restd GND FT1 Slope 0% 100%

SRC1,SRC2,SRC3,SRC4

Enabled/Disabled

Self reset/Latched/Disabled

Restd GND FT1 Function Enabled/Disabled

Restricted Earth fault Protection Min Max

Menu Text

Recomm.Setting

Setting Range

Restd GND FT1 Reset Delay 0 600

Restd GND FT1 Source

Restd GND FT1 Events

Page 105 of 160

MAKE MODEL

4.12.220kV BUSBAR PROTECTION

Input Parameters

CT Details:

1600/1 1600 1.00 PS 8.00 1.24 168.00

1600/1 1600 1.00 PS 8.00 1.27 171.00

1600/1 1600 1.00 PS 8.00 1.00 135.00

1600/1 1600 1.00 PS 8.00 1.02 138.00

1600/1 1600 1.00 PS 8.00 0.64 86.00

1600/1 1600 1.00 PS 8.00 0.53 72.00

1600/1 1600 1.00 PS 8.00 0.56 75.00

1600/1 1600 1.00 PS 8.00 0.38 51.00

Relay details:

Type = B90

Burden = 0.2/12 VA

= 0.20 Ω

ktf = 5.00

Setting calculation

Base CT ratio selection

= 1600.00 A

Basic fault data of the connected circuit

Circuit

Tne Maximum Secondary current transformed Without Saturation

Imax = Vsat/Rs

Where,

Vsat = Saturation Voltage of CT

Rs = Total Burden Resistance

Rs = 2Rlead+RCT+RRelay

Where,

Rlead = Lead Resistance

RCT = CT Resistance

RRelay = Relay Input Resistance

Rs = 9.27

Imax = 7.00 A

Limits of linear operations of the CTs

Rs(Ω)Imax

(A sec)10.69 18.30

10.73 20.90

10.20 39.90

10.25 39.90

9.47 7.00

9.27 7.00

9.31 0.00

8.96 46.20

Trafo-2

Transfer Bus Coupler

0.88

Base CT ratio shall be selected based

on highest CT ratio connected to the

protected bus


Bus Coupler

Trafo-1

220kV Line-1

Trafo-2


Bus Coupler

7.00

220kV Line-2

220kV Line-3

220kV Line-4

Trafo-1

Trafo-2

Circuit

0.00

46.20

1.40

0.00

9.24

2.29

2.61

4.99

4.99

Ifault (kA)

3.66

4.18

7.98

Trafo-1

20.90

1.40

18.30

220kV Line-1

220kV Line-2

220kV Line-3

220kV Line-4

Bus Coupler

7.98

1.40

220kV Line-2

0.88

220kV Line-3

220kV Line-4

9.24

0.00

220kV Line-1

RELAY GE

FeedersCT Ratio

(A)

CT Py

(A)

B90 BAY/FEEDER 220kV BUS BAR


TITLE: SETTING CALCULATION FOR 220kV BUSBAR PROTECTION CKD: GP


VE-J108-D-E212

DATE 16.09.13

39.90

7.00

Imax(PU)

3.66

4.18

7.98

7.98

1.40

Imax(PU)

CT Sec

(A)CT class

Rct in

ohms

Lead Res

(Ω/m)

Cable

Length (m)

39.90

0.00

5.78

The Total burden Resistance Rs depends on the fault current and the connection of the CTs. For Single line to

ground fault and the CTs connection in Wye, the Burden Resistance is calculated as,

CT sec (A)

Page 106 of 160

MAKE MODELRELAY GE B90 BAY/FEEDER 220kV BUS BAR


TITLE: SETTING CALCULATION FOR 220kV BUSBAR PROTECTION CKD: GP


VE-J108-D-E212

DATE 16.09.13

CT Saturation voltage calculation

Knowing the Ktf value, The Saturation voltage needed to ensure stability for through faults will be

The over dimensioning factor can be as low as Ktf = 5 , particularly for voltages lower than 132 kV.

CT Knee point voltage, vkp = ktf . If. (2Rct + RL + Rp)

= (5*1.4*(2*1.24488+8+0.2)

= 74.83 V

Basic CT data

Ratio Vsat RCTSEC

1600/1 195.62 8

1600/1 224.35 8

1600/1 407.01 8

1600/1 408.78 8

1600/1 66.32 8

1600/1 64.87 8

1600/1 0.00 8

1600/1 413.76 8

The B90 relay requires the breakpoints to be entered as 'pu' values.

Low Slope Break point

Imax(pu) = Imax(sec)/ Ibase * CT ratio

= (7/1600)*1600)

= 7.00 pu

= 1.4 pu

High slope Break point

Imax(pu) = Imax(sec)/ Ibase * CT ratio

= (46.2/1600)*1600)

= 39.90 pu

= 7.98 pu

Low slope break point

= 1.40 pu

High slope break point

= 7.98 pu

Pickup

= 0.1 pu

Setting Table:

Setting Unit

0.1 pu

25 %

1.40 pu

80.00 %

7.98 pu

4.62 pu

1-30PU

0.10 to 99,99PU

Circuit

220kV Line-1

220kV Line-2

220kV Line-3

220kV Line-4

Trafo-1

(with no remanence)

Trafo-2


Bus Coupler

CT ratio 1600A is selected for the pu quantities. With a given Ibase current, the limits of linear operation have

been recalculated to pu values as follows

Range

0.050 to 6.000 pu

15-100%

1-30PU

50-100%

Menu text

pickup

Low slope

Low slope break point

High slope

High slope break point

High set

with 80% remanence, Imax(pu) can be calculated is as follows

(with no remanence)

For pickup setting 10% considered for

busbar protection

Considering CTs that could be

connected LOW BPNT for minimum of

all feeders

Considering CTs that could be

connected HIGH BPNT for minimum of

all feeders

with 80% remanence, Imax(pu) can be calculated is as follows

Page 107 of 160

MSB IC-1 - P

OC1

11kV - P

OC1

MSB BC - P

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K

Amps X 100 0.433kV Bus-1 (Nom. kV=0.433, Plot Ref. kV=0.433)

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


39.36K1.968 10 100 1K 10K5 30 50 300 500 3K 5K

Amps 11kV Bus. (Nom. kV=11, Plot Ref. kV=11)

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

11-0.433kV POC

Project: 220/132/33kV Sub station

Location: Dehradun

Contract: HPL

Engineer: Marimuthu.N

Filename: C:\ETAP 1110\HPL\HPL.OTI

Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Phase

Circuit: 11/0.433kV

Page 108 of 160

MSB IC-1 - G

OC1

MSB BC - G

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


131.2K6.561 100 1K 10K30 50 300 500 3K 5K 30K 50K

Amps (Plot Ref. kV=3.3)

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

11-0.433kV EOC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Ground

Circuit: 11/0.433kV

Page 109 of 160

33kV Fuse

MSB IC-2 - P

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


13.12K.6561 10 100 1K3 5 30 50 300 500 3K 5K

Amps 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33)

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Se

co

nd

s

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Se

co

nd

s

ETAP Star 11.1.0C

33-0.433kV POC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Phase

Circuit: 33/0.433kV

Page 110 of 160

MSB IC-2 - G

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


131.2K6.561 100 1K 10K30 50 300 500 3K 5K 30K 50K


1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Se

co

nd

s

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Se

co

nd

s

ETAP Star 11.1.0C

33-0.433kV EOC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Ground

Circuit: 33/0.433kV

Page 111 of 160

40 MVA 33 KV SIDE TR-2 - P

OC1


OC1 - 67

33 KV LINE - P - 51

OC1

33KV Capacitor Bank - P

OC1 - 67

33KV BUS COUPLER - P

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K

Amps X 100 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33)

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


250K12.5 100 1K 10K 100K30 50 300 500 3K 5K 30K 50K

Amps 132KV BUS (Nom. kV=132, Plot Ref. kV=132)

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

132-33kV POC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Phase

Circuit: 132/33kV

Page 112 of 160

40 MVA 33 KV SIDE TR-2 - N

OC1


OC1 - 67

33 KV LINE - N - 51

OC1

33KV Capacitor Bank - N

OC1

33KV BUS COUPLER - N

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


1000K50 100 1K 10K 100K300 500 3K 5K 30K 50K 300K 500K


1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

132-33kV EOC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Ground

Circuit: 132/33kV

Page 113 of 160

220 KV LINE - P - 51

OC1


OC1 - 67

BUS COUPLER - P

OC1

132KV LINE-4 - P - 51

OC1 - 67

160 MVA TR-2 220KV SIDE - P

OC1 - 67

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K

Amps X 100 220KV Bus1 (Nom. kV=220, Plot Ref. kV=220)

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


1667K83.33 1K 10K 100K300 500 3K 5K 30K 50K 300K 500K

Amps 132KV BUS (Nom. kV=132, Plot Ref. kV=132)

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

220-132kV POC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Phase

Circuit: 220/132kV

Page 114 of 160

220 KV LINE - N - 51

OC1


OC1 - 67

132KV LINE-4 - N - 51

OC1 - 67

160 MVA TR-2 220KV SIDE - N

OC1 - 67

BUS COUPLER - N

OC1

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


6667K333.3 1K 10K 100K 1000K3K 5K 30K 50K 300K 500K 3000K


1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

220-132kV EOC


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Ground

Circuit: 220/132kV

Page 115 of 160

160 MVA TR-2 132KV SIDE - P

OC1 - 67

1.372 kA @ 132 kV

t1: 2.04 s

220 KV LINE-4 - P - 51

OC1

1.221 kA @ 220 kV

t1: 3.3 s

Normalized (shifted) TCC

Line-to-Ground (Sym) fault: 10.985kA @ 220kV

Adj Bus: Bus9

Connector: Bus9 - 50KM Line

SQOP File: Untitled

Data Rev: Base

Configuration: Normal

Date: 16-09-2013

100.005 .01 .1 1 10.03 .05 .3 .5 3 5 30 50

Per Unit

100.005 .01 .1 1 10.03 .05 .3 .5 3 5 30 50

Per Unit

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 11.1.0C

220-132kV Trip Coord


Location: Dehradun

Contract: HPL



Date: 16-09-2013

SN: VOLTECHENG

Rev: Base

Fault: Phase(Normalized)

Circuit: 220/132

Page 116 of 160

One-Line Diagram - OLV1 (Star Sequence-of-Operation)

page 1 09:56:06 Sep 16, 2013 Project File: HPL

11kV Bus.

0 kV 0

15.23 kA -87.2

±

±

220KV Bus2

0 kV 0

3.66 kA -81.5

±

220KV Bus1

0 kV 0

7.98 kA -85.9

±

±

132KV BUS

0 kV 0

2.97 kA -85.2

±

Bus11

±

Bus15

±

Bus13

±

Bus12

±

±

33KV BUS 1

0 kV 0

3.64 kA -87.7

±

Bus Ref A 0 kV 0

3.64 kA -87.7

±

33KV BUS 2 0 kV 0

3.64 kA -87.7

±

0.433kV Bus-2

0 kV 0

15.57 kA -58.1

±

0.433kV Bus-1

0 kV 0

11.24 kA -57.2

±

±

Bus Ref B

0 kV 0

3.64 kA -87.7

±

±

±

±

Bus6

±

Bus7

±

Bus8

±

Bus9

220kV OG Line-2

3722.87 MVAsc

50KM Line

R

220 KV LINE-4

CB4

220kV OG Line-1

3722.87 MVAsc

40KM Line

R

220 KV LINE-3

CB3

Open

220kV IC Line-2

3722.87 MVAsc

10KM Line-2

R

220 KV LINE

220kV IC Line-1

3722.87 MVAsc

10KM Line

R

220 KV LINE-1

CB1

Open

R160 MVA TR-2 132KV SIDE

CB9

2.97

CB15

R

40 MVA 132 KV SIDE TR-2

T9

40 MVA

R


CB17

3.64

CAP1

10000 kvar

R

33KV Capacitor Bank

CB20

T5 400 kVA

R MSB IC-1

CB22

11.24

R MSB BC

CB24Open

15.57

CB23

R MSB IC-2

T7

630 kVA

33kV Fuse

R

33KV BUS COUPLER

CB19

3.64

R33 KV LINE

CB18

CB16

Open

R 40 MVA 33 KV SIDE TR-1

T6

40 MVA

R


CB14

U8

2972.199 MVAsc

22KM Line.

R

132KV LINE-2

CB11

Open

U9

2972.199 MVAsc

15KM Line

R

132KV LINE-3

CB12

Open

U10

2972.199 MVAsc

13

30KM Line

R

132KV LINE-4

CB13

Open

U24

2972.199 MVAsc

22KM Line

R

132KV LINE-1

CB10

Open

CB8


T11160/160/53.33 MVA


CB5

Open

CB6 Open

R BUS COUPLER

CB7

R

160 MVA TR-2 220KV SIDE

T2160/160/53.33 MVA

R 11kV

CB21

15.23

220 KV LINE-1 220 KV LINE 220 KV LINE-3 220 KV LINE-4


BUS COUPLER160 MVA TR-2 220KV SIDE

160 MVA TR-1 132KV SIDE 160 MVA TR-2 132KV SIDE



33 KV LINE



33KV Capacitor Bank

132KV LINE-1 132KV LINE-2 132KV LINE-3 132KV LINE-4

33KV BUS COUPLER

MSB IC-1

11kV

MSB BC

MSB IC-2

CB2

220kV IC Line-1

3722.87 MVAsc

220kV IC Line-2

3722.87 MVAsc

220kV OG Line-1

3722.87 MVAsc

220kV OG Line-2

3722.87 MVAsc

U8

2972.199 MVAsc

U9

2972.199 MVAsc

U10

2972.199 MVAsc

U24

2972.199 MVAsc

10KM Line 10KM Line-2 40KM Line 50KM Line

22KM Line 22KM Line. 15KM Line 30KM Line

T6

40 MVA

T9

40 MVA

T5 400 kVA

T7

630 kVA

T2160/160/53.33 MVA

T11160/160/53.33 MVA

Bus6 Bus7 Bus8 Bus9

Bus11 Bus12 Bus13

CAP1

10000 kvar

0.433kV Bus-1 0.433kV Bus-2

11kV Bus.

33KV BUS 133KV BUS 2

132KV BUS

220KV Bus1

Bus Ref A Bus Ref B

220KV Bus2Bus15

7.98 3.66

3.64 3.64

0 kV 0

15.23 kA -87.2

0 kV 0

15.57 kA -58.1

0 kV 0

11.24 kA -57.2

0 kV 0

2.97 kA -85.2

0 kV 0

3.64 kA -87.7

0 kV 0

3.64 kA -87.7

0 kV 0

3.64 kA -87.7

0 kV 0

3.66 kA -81.5

0 kV 0

7.98 kA -85.9

CB1

Open

CB2 CB3

Open

CB4

CB5

Open

CB7

CB8 CB9CB11

Open

CB12

Open

CB13

Open

CB14

CB16

Open

7.98 3.66

CB19

3.64

2.97

CB15

CB17

3.64

CB10

Open

CB6 Open

CB18

3.64

0 kV 0

3.64 kA -87.7

CB20

3.64

13

CB21

33kV Fuse

CB22

11.24

CB23

CB24Open

15.57

15.23

Page 117 of 160



11kV Bus.

0 kV 0

26.68 kA -87.8

±

±

220KV Bus2

0 kV 0

23.99 kA -84.8

±

220KV Bus1

0 kV 0

23.99 kA -84.8

±

±

132KV BUS0 k

V 0

27.88 kA -79.1

±

Bus11

±

Bus15

±

Bus13

±

Bus12

±

±

33KV BUS 1

0 kV 0

9.61 kA -87.5

±

Bus Ref A 0 kV 0

9.61 kA -87.5

±

33KV BUS 2 0 kV 0

9.61 kA -87.5

±

0.433kV Bus-2

0 kV 0

16.07 kA -57

±

0.433kV Bus-1

0 kV 0

11.37 kA -56.8

±

±

Bus Ref B0 k

V 0

9.61 kA -87.5

±

±

±

±

Bus6

±

Bus7

±

Bus8

±

Bus9

220kV OG Line-2

3722.87 MVAsc

50KM Line

R

220 KV LINE-4

CB4

220kV OG Line-1

3722.87 MVAsc

40KM Line

R

220 KV LINE-3

CB3

Open

220kV IC Line-2

3722.87 MVAsc

10KM Line-2

R

220 KV LINE

220kV IC Line-1

3722.87 MVAsc

10KM Line

R

220 KV LINE-1


CB9

4.26

CB15

R


T9

40 MVA

R


CB17

4.81

CAP1

10000 kvar

R

33KV Capacitor Bank

CB20

T5 400 kVA

R MSB IC-1

CB22

11.37

R MSB BC

CB24Open

16.07

CB23

R MSB IC-2

T7

630 kVA

33kV Fuse

R

33KV BUS COUPLER

R33 KV LINE

CB18


T6

40 MVA

R


CB14

U8

2972.199 MVAsc

22KM Line.

R

132KV LINE-2

U9

2972.199 MVAsc

15KM Line

R

132KV LINE-3

U10

2972.199 MVAsc

13

30KM Line

R

132KV LINE-4

U24

2972.199 MVAsc

22KM Line

R

132KV LINE-1

4.26

CB8


T11160/160/53.33 MVA


R BUS COUPLER

2.19

CB7

R


T2160/160/53.33 MVA

R 11kV

CB21

26.68



BUS COUPLER 160 MVA TR-2 220KV SIDE




33 KV LINE



33KV Capacitor Bank


33KV BUS COUPLER

MSB IC-1

11kV

MSB BC

MSB IC-2

CB2CB1

CB5

2.19

CB10 CB11 CB12 CB13

CB16

4.81

CB6

CB19

4.81

220kV IC Line-1

3722.87 MVAsc

220kV IC Line-2

3722.87 MVAsc

220kV OG Line-1

3722.87 MVAsc

220kV OG Line-2

3722.87 MVAsc

U8

2972.199 MVAsc

U9

2972.199 MVAsc

U10

2972.199 MVAsc

U24

2972.199 MVAsc



T6

40 MVA

T9

40 MVA

T5 400 kVA

T7

630 kVA

T2160/160/53.33 MVAT11

160/160/53.33 MVA

Bus6 Bus7 Bus8 Bus9

Bus11 Bus12 Bus13

CAP1

10000 kvar

0.433kV Bus-1 0.433kV Bus-2

11kV Bus.

33KV BUS 1 33KV BUS 2

132KV BUS

220KV Bus1

Bus Ref A Bus Ref B

220KV Bus2 Bus157.98 7.98

6.014.8 4.8 3.89

3.66

4.81

18.155.84

9.61 9.61

0 kV 0

26.68 kA -87.8

0 kV 0

16.07 kA -57

0 kV 0

11.37 kA -56.8

0 kV 0

27.88 kA -79.1

0 kV 0

9.61 kA -87.5

0 kV 0

9.61 kA -87.5

0 kV 0

9.61 kA -87.5

0 kV 0

23.99 kA -84.8

0 kV 0

23.99 kA -84.8

CB1 CB2 CB3

Open

CB4

CB5 CB7

CB8 CB9 CB11 CB12 CB13

CB14

CB16

7.987.98 3.66

4.81

CB19

4.814.81

4.26 4.26 4.8 6.01 3.89

2.19 2.19

CB15

CB17

4.81

CB10

4.8

CB6

5.84 18.15

CB18

9.610 k

V 0

9.61 kA -87.5

CB20

9.61

13

CB21

33kV Fuse

CB22

11.37

CB23

CB24Open

16.07

26.68

Page 118 of 160



11kV Bus.

11 kV

0 kA

±

±

220KV Bus2

119.88

kV

4.3 kA

±

220KV Bus1

132.61

kV

6.95 kA

±

±

132KV BUS67.

36 kV

4.04 kA

±

Bus11

±

Bus15

±

Bus13

±

Bus12

±

±

33KV BUS 1

18.36

kV

3.97 kA

±

Bus Ref A 18.36

kV

3.97 kA

±

33KV BUS 2 18.36

kV

3.97 kA

±

0.433kV Bus-2

0.25 k

V

15.84 kA

±

0.433kV Bus-1

0.25 k

V

11.34 kA

±

±

Bus Ref B18.

36 kV

3.97 kA

±

±

±

±

Bus6

±

Bus7

±

Bus8

±

Bus9

220kV OG Line-2

3722.87 MVAsc

50KM Line

R

220 KV LINE-4

CB4

220kV OG Line-1

3722.87 MVAsc

40KM Line

R

220 KV LINE-3

CB3

Open

220kV IC Line-2

3722.87 MVAsc

10KM Line-2

R

220 KV LINE

220kV IC Line-1

3722.87 MVAsc

10KM Line

R

220 KV LINE-1


CB9

2.09

CB15

R


T9

40 MVA

R


CB17

3.97

CAP1

10000 kvar

R

33KV Capacitor Bank

CB20

T5 400 kVA

R MSB IC-1

CB22

11.34

R MSB BC

CB24Open

15.84

CB23

R MSB IC-2

T7

630 kVA

33kV Fuse

R

33KV BUS COUPLER

R33 KV LINE

CB18


T6

40 MVA

R


CB14

U8

2972.199 MVAsc

22KM Line.

R

132KV LINE-2

U9

2972.199 MVAsc

15KM Line

R

132KV LINE-3

U10

2972.199 MVAsc

13

30KM Line

R

132KV LINE-4

U24

2972.199 MVAsc

22KM Line

R

132KV LINE-1

CB8


T11160/160/53.33 MVA


R BUS COUPLER

3.24

CB7

R


T2160/160/53.33 MVA

R 11kV

CB21

CB19

3.97







33 KV LINE



33KV Capacitor Bank


33KV BUS COUPLER

MSB IC-1

11kV

MSB BC

MSB IC-2

CB6 Open

CB1

Open

CB2

CB5

Open

CB10

Open

CB11

Open

CB12

Open

CB13

Open

CB16

Open

220kV IC Line-1

3722.87 MVAsc

220kV IC Line-2

3722.87 MVAsc

220kV OG Line-1

3722.87 MVAsc

220kV OG Line-2

3722.87 MVAsc

U8

2972.199 MVAsc

U9

2972.199 MVAsc

U10

2972.199 MVAsc

U24

2972.199 MVAsc



T6

40 MVA

T9

40 MVA

T5 400 kVA

T7

630 kVA

T2160/160/53.33 MVAT11

160/160/53.33 MVA

Bus6 Bus7 Bus8 Bus9

Bus11 Bus12 Bus13

CAP1

10000 kvar

0.433kV Bus-1 0.433kV Bus-2

11kV Bus.


132KV BUS

220KV Bus1 220KV Bus2 Bus15

Bus Ref A Bus Ref B

6.95 1.08

3.97 3.97

11 kV

0 kA

0.25 k

V

15.84 kA

0.25 k

V

11.34 kA

67.36

kV

4.04 kA

18.36

kV

3.97 kA

18.36

kV

3.97 kA

18.36

kV

3.97 kA

119.88

kV

4.3 kA

132.61

kV

6.95 kA

CB1

Open

CB2 CB3

Open

CB4

CB5

Open

CB7

CB8 CB9 CB11

Open

CB12

Open

CB13

Open

CB14

CB16

Open

6.95 1.08

CB19

3.97

2.09

3.24

CB15

CB17

3.97

CB10

Open

CB6 Open

CB18

3.9718.

36 kV

3.97 kA

CB20

3.97

13

CB21

33kV Fuse

CB22

11.34

CB23

CB24Open

15.84

Page 119 of 160



11kV Bus.

11 kV

0 kA

±

±

220KV Bus2

127.28

kV

23.51 kA

±

220KV Bus1

127.28

kV

23.51 kA

±

±

132KV BUS74.

51 kV

28.65 kA

±

Bus11

±

Bus15

±

Bus13

±

Bus12

±

±

33KV BUS 1

19.02

kV

9.64 kA

±

Bus Ref A 19.02

kV

9.64 kA

±

33KV BUS 2 19.02

kV

9.64 kA

±

0.433kV Bus-2

0.25 k

V

16.18 kA

±

0.433kV Bus-1

0.25 k

V

11.42 kA

±

±

Bus Ref B19.

02 kV

9.64 kA

±

±

±

±

Bus6

±

Bus7

±

Bus8

±

Bus9

220kV OG Line-2

3722.87 MVAsc

50KM Line

R

220 KV LINE-4

CB4

220kV OG Line-1

3722.87 MVAsc

40KM Line

R

220 KV LINE-3

CB3

Open

220kV IC Line-2

3722.87 MVAsc

10KM Line-2

R

220 KV LINE

220kV IC Line-1

3722.87 MVAsc

10KM Line

R

220 KV LINE-1


CB9

7.81

CB15

R


T9

40 MVA

R


CB17

4.82

CAP1

10000 kvar

R

33KV Capacitor Bank

CB20

T5 400 kVA

R MSB IC-1

CB22

11.42

R MSB BC

CB24Open

16.18

CB23

R MSB IC-2

T7

630 kVA

33kV Fuse

R

33KV BUS COUPLER

R33 KV LINE

CB18


T6

40 MVA

R


CB14

U8

2972.199 MVAsc

22KM Line.

R

132KV LINE-2

U9

2972.199 MVAsc

15KM Line

R

132KV LINE-3

U10

2972.199 MVAsc

13.83

30KM Line

R

132KV LINE-4

U24

2972.199 MVAsc

22KM Line

R

132KV LINE-1

7.81

CB8


T11160/160/53.33 MVA


R BUS COUPLER

5.19

CB7

R


T2160/160/53.33 MVA

R 11kV

CB21

CB2CB1

CB5

5.19

CB10 CB11 CB12 CB13

CB16

4.82

CB6

CB19

4.82







33 KV LINE



33KV Capacitor Bank


33KV BUS COUPLER

MSB IC-1

11kV

MSB BC

MSB IC-2

220kV IC Line-1

3722.87 MVAsc

220kV IC Line-2

3722.87 MVAsc

220kV OG Line-1

3722.87 MVAsc

220kV OG Line-2

3722.87 MVAsc

U8

2972.199 MVAsc

U9

2972.199 MVAsc

U10

2972.199 MVAsc

U24

2972.199 MVAsc



T6

40 MVA

T9

40 MVA

T5 400 kVA

T7

630 kVA

T2160/160/53.33 MVAT11

160/160/53.33 MVA

Bus6 Bus7 Bus8 Bus9

Bus11 Bus12 Bus13

CAP1

10000 kvar

0.433kV Bus-1 0.433kV Bus-2

11kV Bus.


132KV BUS

220KV Bus1 220KV Bus2 Bus15

Bus Ref A Bus Ref B

5.73 5.73

4.363.33 3.33 2.61

1.73

4.82

16.626.9

9.64 9.64

11 kV

0 kA

0.25 k

V

16.18 kA

0.25 k

V

11.42 kA

74.51

kV

28.65 kA

19.02

kV

9.64 kA

19.02

kV

9.64 kA

19.02

kV

9.64 kA

127.28

kV

23.51 kA

127.28

kV

23.51 kA

CB1 CB2 CB3

Open

CB4

CB5 CB7

CB8 CB9 CB11 CB12 CB13

CB14

CB16

5.735.73 1.73

4.82

CB19

4.824.82

7.81 7.81 3.33 4.36 2.61

5.19 5.19

CB15

CB17

4.82

CB10

3.33

CB6

6.9 16.62

CB18

9.6419.

02 kV

9.64 kA

CB20

9.64

13.83

CB21

33kV Fuse

CB22

11.42

CB23

CB24Open

16.18

Page 120 of 160

Location: Dehradun

Engineer: Marimuthu.NStudy Case: HPL

11.1.0C

Page: 1

SN: VOLTECHENG

Filename: HPL

Project: 220/132/33kV Sub station ETAP

Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Electrical Transient Analyzer Program

Short-Circuit Analysis

IEC 60909 Standard

3-Phase, LG, LL, & LLG Fault Currents

Number of Buses:

Number of Branches:

Number of Machines:

Total

18

Tie PD

Total

8

4

Impedance

Lumped

Load

0

8

Total

Induction

Machines

0

Line/Cable

0

19

Load

Synchronous

Motor

0

Reactor

0

11

V-Control

8

Power

Grid

XFMR3

2

0

Swing

Synchronous

Generator

0

XFMR2

4

8

Unit System:

Project Filename:

Output Filename:

System Frequency: 50.00 Hz

Metric

HPL

C:\ETAP 1110\HPL\Untitled.ST2

Page 121 of 160

Location: Dehradun


11.1.0C

Page: 2

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Adjustments

Transformer Impedance:

Reactor Impedance:

Tolerance

Overload Heater Resistance:

Transmission Line Length:

Cable Length:

Temperature Correction

Transmission Line Resistance:

Cable Resistance:

Percent

Degree C

0

0

Individual

/Global

Individual

/Global

Global

Global

Individual

Individual

Individual

Apply

Adjustments

Apply

Adjustments

Yes

Yes

No

Yes

No

Yes

Yes

Page 122 of 160

Location: Dehradun


11.1.0C

Page: 3

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Bus Input Data

ID Type

Bus Initial Voltage

%Mag. Ang.Sub-sysBase kVNom. kV

0.433 0.433Load0.433kV Bus-1 1 100.00 -60.00

0.433 0.433Load0.433kV Bus-2 1 100.00 -30.00

11.000 11.000Load11kV Bus. 1 100.00 -30.00

33.000 33.000Load33KV BUS 1 1 100.00 0.00

33.000 33.000Load33KV BUS 2 1 100.00 0.00

132.000 132.000Load132KV BUS 1 100.00 0.00

220.000 220.000Load220KV Bus1 1 100.00 0.00

220.000 220.000Load220KV Bus2 1 100.00 0.00

220.000 220.000SWNGBus6 1 100.00 0.00

220.000 220.000SWNGBus7 1 100.00 0.00

220.000 220.000SWNGBus8 1 100.00 0.00

220.000 220.000SWNGBus9 1 100.00 0.00

132.000 132.000SWNGBus11 1 100.00 0.00

132.000 132.000SWNGBus12 1 100.00 0.00

132.000 132.000SWNGBus13 1 100.00 0.00

132.000 132.000SWNGBus15 1 100.00 0.00

33.000 33.000LoadBus Ref A 1 100.00 0.00

33.000 33.000LoadBus Ref B 1 100.00 0.00

11.000 11.000LoadT11~3 0 100.00 0.00

19 Buses Total

All voltages reported by ETAP are in % of bus Nominal kV.

Base kV values of buses are calculated and used internally by ETAP .

Page 123 of 160

Location: Dehradun


11.1.0C

Page: 4

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

2-Winding Transformer Input Data

Phase Shift

ID MVA Prim. kV Sec. kV % Z X/R Prim. Sec.

Transformer % Tap Setting

% Tol.

Rating Z Variation

+ 5% - 5% Type Angle% Z

Adjusted

T5 0.400 11.000 0.433 4.50 1.50 0 0 0 0 Dyn 30.000 0 4.5000

T6 40.000 132.000 33.000 13.80 27.30 0 0 0 0 YNyn 0.000 0 13.8000

T7 0.630 33.000 0.433 5.00 1.50 0 0 0 0 Dyn 30.000 0 5.0000

T9 40.000 132.000 33.000 13.80 45.00 0 0 0 0 YNyn 0.000 0 13.8000

2-Winding Transformer Grounding Input Data

ID MVA Prim. kV Sec. kV

Transformer

Type

Rating Primary

Grounding

Conn.

Type

Secondary

Amp OhmkVkV OhmAmpType

T5 D/Y 0.433 11.000 0.400 Solid

Y/Y 33.000 132.000 40.000T6 Solid Solid

D/Y 0.433 33.000 0.630T7 Solid

Y/Y 33.000 132.000 40.000T9 Solid Solid

3-Winding Transformer Input Data

ID MVA kV % Z X/R% MVAbWinding

Transformer Rating Tap Impedance

% Tol. - 5%

Z Variation

+ 5%

Phase Shift

Type Angle

T2

45.65

53.330

132.000

11.000

Zpt =

Zst =

45.00 0

0

Primary:

Secondary:

Tertiary:

160.000

160.000

160.000

160.000 220.000 0 160.000 45.00 12.50Zps =

45.00 29.05

0 0

Std Pos. Seq.

Std Pos. Seq.

0.000

-30.000

0

0

0

45.65

T11

53.330

132.000

11.000

Zpt =

Zst =

45.00 0

0

Primary:

Secondary:

Tertiary:

160.000

160.000

160.000

160.000 220.000 0 160.000 45.00 12.50Zps =

45.00 29.05

0 0

Std Pos. Seq.

Std Pos. Seq.

0.000

-30.000

0

0

0


ID MVA kVWinding

Transformer Rating

Type Type kV

GroundingConn.

OhmAmp

T2 WyePrimary: 160.000 220.000 Solid

WyeSecondary: 160.000 132.000 Solid

Tertiary: 53.330 11.000 Delta

Page 124 of 160

Location: Dehradun


11.1.0C

Page: 5

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal


ID MVA kVWinding

Transformer Rating

Type Type kV

GroundingConn.

OhmAmp

T11 WyePrimary: 160.000 220.000 Solid

WyeSecondary: 160.000 132.000 Solid

Tertiary: 53.330 11.000 Delta

Impedance Input Data

ID R X Y UnitR0 X0 Y0

Impedance Positive Sequence Impedance Zero Sequence Impedance

10KM Line Ohm 2.84 9.784 0 0.223 2.9 0

Ohm10KM Line-2 2.84 9.784 0 0.223 2.9 0

Ohm15KM Line 6.084 9.3315 0 2.51145 6.48015 0

Ohm22KM Line 8.9232 13.6862 0 3.68346 9.50422 0

Ohm22KM Line. 8.9232 13.6862 0 3.68346 9.50422 0

Ohm30KM Line 12.168 18.663 0 5.0229 12.9603 0

Ohm40KM Line 11.68 49.6 0 3.352 17.12 0

Ohm50KM Line 14.6 62 0 4.19 21.4 0

Page 125 of 160

Location: Dehradun


11.1.0C

Page: 6

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Branch Connections

ID From Bus To Bus R X ZType

CKT/Branch % Impedance, Pos. Seq., 100 MVAbConnected Bus ID

Y

T5 11kV Bus. 608.80 913.20 1097.530.433kV Bus-12W XFMR

T6 132KV BUS 1.22 33.28 33.3033KV BUS 12W XFMR

T7 33KV BUS 2 428.44 642.66 772.390.433kV Bus-22W XFMR

T9 132KV BUS 0.74 33.29 33.3033KV BUS 22W XFMR

T2 220KV Bus2 0.16 7.19 7.19132KV BUS3W Xfmr

220KV Bus2 -3.35 -150.79 150.8311kV Bus.3W Xfmr

132KV BUS 0.35 15.94 15.9411kV Bus.3W Xfmr

T11 220KV Bus1 0.16 7.19 7.19132KV BUS3W Xfmr

220KV Bus1 -3.35 -150.79 150.83T11~33W Xfmr

132KV BUS 0.35 15.94 15.94T11~33W Xfmr

10KM Line Bus6 0.05 0.60 0.60220KV Bus1Impedance

10KM Line-2 Bus7 0.05 0.60 0.60220KV Bus1Impedance

15KM Line Bus13 1.44 3.72 3.99132KV BUSImpedance


22KM Line. Bus12 2.11 5.45 5.85132KV BUSImpedance




CB6 220KV Bus1 220KV Bus2Tie Breakr

CB18 33KV BUS 1 Bus Ref ATie Breakr

CB19 33KV BUS 2 33KV BUS 1Tie Breakr

CB20 33KV BUS 2 Bus Ref BTie Breakr

Page 126 of 160

Location: Dehradun


11.1.0C

Page: 7

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Power Grid Input Data

kV R X"

Rating

R/X"

100 MVA Base

% Impedance

MVASCID ID

Power Grid Connected Bus Grounding

Type

0.07220kV IC Line-1 220.000Bus6 3722.870 0.19138 2.67927 Wye - Solid

0.07220kV IC Line-2 220.000Bus7 3722.870 0.19138 2.67927 Wye - Solid

0.07220kV OG Line-1 220.000Bus8 3722.870 0.19138 2.67927 Wye - Solid

0.07220kV OG Line-2 220.000Bus9 3722.870 0.19138 2.67927 Wye - Solid

0.07U8 132.000Bus12 2972.199 0.23971 3.35596 Wye - Solid

0.07U9 132.000Bus13 2972.199 0.23971 3.35596 Wye - Solid

0.07U10 132.000Bus15 2972.199 0.23971 3.35596 Wye - Solid

0.07U24 132.000Bus11 2972.199 0.23971 3.35596 Wye - Solid

Total Connected Power Grids ( = 8 ): 26780.276 MVA

Page 127 of 160

Location: Dehradun


11.1.0C

Page: 8

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

SHORT- CIRCUIT REPORT

Fault at bus:

Looking into "From Bus"

ID Symm. rmsFrom BusID Va

From Bus To Bus % V kA % Voltage at From Bus

Contribution 3-Phase Fault

Vb Vc Ia 3I0 R1 X1 R0 X0

kA Symm. rms % Impedance on 100 MVA base

Line-To-Ground FaultPositive & Zero Sequence Impedances

Nominal kV

Voltage c Factor

0.433kV Bus-1

=

0.95 (Minimum If) =

0.433

0.433kV Bus-1 Total 0.00 11.367 0.00 99.48 100.01 11.425 11.425 6.09E+002 9.13E+0026.10E+002 9.33E+002

11kV Bus. 0.433kV Bus-1 98.49 11.367 98.98 100.00 99.51 11.425 11.425 6.09E+002 9.13E+0026.10E+002 9.33E+002*

220KV Bus2 11kV Bus. 99.98 0.058 99.99 100.00 99.98 0.033 0.000 3.04E+003 3.16E+003#

132KV BUS 11kV Bus. 99.86 0.505 99.96 99.99 99.91 0.293 0.000 3.42E+002 3.63E+002#

Bus8 220KV Bus2 99.99 0.001 100.00 100.00 99.99 0.000 0.000 1.47E+004 2.01E+004

Bus9 220KV Bus2 99.99 0.001 100.00 100.00 99.99 0.000 0.000 1.66E+004 2.31E+004

132KV BUS 220KV Bus2 99.86 0.004 99.96 99.99 99.91 0.001 0.000 3.26E+003 4.66E+003#

Bus6 220KV Bus1 99.98 0.002 100.00 100.00 99.99 0.001 0.000 8.39E+003 9.97E+003

Bus7 220KV Bus1 99.98 0.002 100.00 100.00 99.99 0.001 0.000 8.39E+003 9.97E+003

132KV BUS 220KV Bus1 99.86 0.004 99.96 99.99 99.91 0.001 0.000 3.26E+003 4.66E+003#

T11~3 220KV Bus1 99.85 0.000 99.90 100.00 99.94 0.000 0.000 6.11E+004 8.74E+004# *

Bus13 132KV BUS 99.94 0.009 99.98 100.00 99.96 0.003 0.000 1.97E+003 4.37E+003

Bus11 132KV BUS 99.95 0.007 99.98 100.00 99.97 0.002 0.000 2.31E+003 5.55E+003

Bus12 132KV BUS 99.95 0.007 99.98 100.00 99.97 0.002 0.000 2.31E+003 5.55E+003

Bus15 132KV BUS 99.96 0.006 99.99 100.00 99.98 0.002 0.000 2.71E+003 6.89E+003

33KV BUS 1 132KV BUS 99.86 0.000 99.96 99.99 99.91 0.000 0.000

33KV BUS 2 132KV BUS 99.86 0.000 99.96 99.99 99.91 0.000 0.000

T11~3 132KV BUS 99.85 0.000 99.90 100.00 99.94 0.000 0.000 6.11E+004 8.72E+004# *

220kV OG Line-1 Bus8 100.00 0.001 100.00 100.00 100.00 0.000 0.000 1.91E-001 2.68E+0001.91E-001 2.68E+000


220kV IC Line-1 Bus6 100.00 0.002 100.00 100.00 100.00 0.001 0.000 1.91E-001 2.68E+0001.91E-001 2.68E+000


U9 Bus13 100.00 0.009 100.00 100.00 100.00 0.003 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.007 100.00 100.00 100.00 0.002 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.007 100.00 100.00 100.00 0.002 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.006 100.00 100.00 100.00 0.002 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

0.433kV Bus-2 33KV BUS 2 99.86 0.000 99.91 100.00 99.95 0.000 0.000

Page 128 of 160

Location: Dehradun


11.1.0C

Page: 9

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

0.433kV Bus-1

=

0.95 (Minimum If) =

0.433

220KV Bus1 220KV Bus2 99.98 0.000 99.99 100.00 99.98 0.000 0.000

33KV BUS 1 Bus Ref A 99.86 0.000 99.96 99.99 99.91 0.000 0.000

33KV BUS 2 33KV BUS 1 99.86 0.000 99.96 99.99 99.91 0.000 0.000

33KV BUS 2 Bus Ref B 99.86 0.000 99.96 99.99 99.91 0.000 0.000

Initial Symmetrical Current (kA, rms)

# Indicates a fault current contribution from a three-winding transformer

* Indicates a zero sequence fault current contribution (3I0) from a grounded Delta- Y transformer

:

3-Phase L-G L-L L-L-G

11.367

Peak Current (kA), Method C

Breaking Current (kA, rms, symm)

Steady State Current (kA, rms)

:

:

:

18.617

11.367

11.425

18.711

11.425

11.425

9.844

16.122

9.844

9.844

11.427

18.714

11.427

11.427

Page 129 of 160

Location: Dehradun


11.1.0C

Page: 10

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

0.433kV Bus-2

=

0.95 (Minimum If) =

0.433

0.433kV Bus-2 Total 0.00 16.075 0.00 99.33 100.01 16.182 16.182 4.28E+002 6.43E+0024.29E+002 6.61E+002

33KV BUS 2 0.433kV Bus-2 98.02 16.075 98.66 100.00 99.35 16.182 16.182 4.28E+002 6.43E+0024.29E+002 6.61E+002*

132KV BUS 33KV BUS 2 99.82 0.105 99.89 100.00 99.93 0.061 0.000 5.51E+002 5.66E+002

132KV BUS 33KV BUS 1 99.82 0.105 99.89 100.00 99.93 0.061 0.000 5.43E+002 5.74E+002

Bus13 132KV BUS 99.92 0.011 99.95 100.00 99.98 0.007 0.000 1.22E+003 1.47E+003

Bus11 132KV BUS 99.94 0.009 99.96 100.00 99.98 0.005 0.000 1.48E+003 1.89E+003

Bus12 132KV BUS 99.94 0.009 99.96 100.00 99.98 0.005 0.000 1.48E+003 1.89E+003

Bus15 132KV BUS 99.95 0.007 99.97 100.00 99.99 0.004 0.000 1.77E+003 2.37E+003

220KV Bus2 132KV BUS 99.96 0.009 99.97 100.00 99.98 0.005 0.000 1.89E+003 1.54E+003#

11kV Bus. 132KV BUS 99.80 0.000 99.87 99.94 99.99 0.000 0.000 3.54E+004 2.90E+004# *

220KV Bus1 132KV BUS 99.96 0.009 99.97 100.00 99.98 0.005 0.000 1.89E+003 1.54E+003#

T11~3 132KV BUS 99.80 0.000 99.87 99.94 99.99 0.000 0.000 3.54E+004 2.90E+004# *

U9 Bus13 100.00 0.011 100.00 100.00 100.00 0.007 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.009 100.00 100.00 100.00 0.005 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.009 100.00 100.00 100.00 0.005 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.007 100.00 100.00 100.00 0.004 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

Bus8 220KV Bus2 99.98 0.002 99.99 100.00 99.99 0.001 0.000 5.46E+003 4.92E+003

Bus9 220KV Bus2 99.98 0.002 99.99 100.00 99.99 0.001 0.000 6.21E+003 5.66E+003

11kV Bus. 220KV Bus2 99.80 0.000 99.87 99.94 99.99 0.000 0.000 3.54E+004 2.91E+004# *

0.433kV Bus-1 11kV Bus. 99.80 0.000 99.92 99.88 100.00 0.000 0.000

Bus6 220KV Bus1 99.97 0.003 99.98 100.00 99.99 0.002 0.000 3.03E+003 2.37E+003

Bus7 220KV Bus1 99.97 0.003 99.98 100.00 99.99 0.002 0.000 3.03E+003 2.37E+003

T11~3 220KV Bus1 99.80 0.000 99.87 99.94 99.99 0.000 0.000 3.54E+004 2.91E+004# *





33KV BUS 1 Bus Ref A 98.02 0.000 98.66 100.00 99.35 0.000 0.000

33KV BUS 1 33KV BUS 2 98.02 0.105 98.66 100.00 99.35 0.061 0.000

Page 130 of 160

Location: Dehradun


11.1.0C

Page: 11

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

0.433kV Bus-2

=

0.95 (Minimum If) =

0.433

33KV BUS 2 Bus Ref B 98.02 0.000 98.66 100.00 99.35 0.000 0.000

220KV Bus1 220KV Bus2 99.96 0.002 99.97 100.00 99.98 0.001 0.000




:


16.075




:

:

:

26.364

16.075

16.182

26.539

16.182

16.182

13.922

22.832

13.922

13.922

16.185

26.543

16.185

16.185

Page 131 of 160

Location: Dehradun


11.1.0C

Page: 12

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

11kV Bus.

=

1.00 (Minimum If) =

11.000

11kV Bus. Total 0.00 26.699 0.00 173.21 173.21 0.000 0.000 7.37E-001 1.96E+001

0.433kV Bus-1 11kV Bus. 0.00 0.000 100.00 100.00 100.00 0.000 0.000

220KV Bus2 11kV Bus. 98.62 3.432 100.00 100.00 100.00 0.000 0.000 3.98E+000 1.53E+002#

132KV BUS 11kV Bus. 91.52 30.131 100.00 100.00 100.00 0.000 0.000 6.30E-001 1.74E+001#

Bus8 220KV Bus2 99.40 0.060 100.00 100.00 100.00 0.000 0.000 2.26E+002 2.49E+001

Bus9 220KV Bus2 99.47 0.052 100.00 100.00 100.00 0.000 0.000 2.58E+002 3.02E+001

132KV BUS 220KV Bus2 91.52 0.262 100.00 100.00 100.00 0.000 0.000 5.15E+001 6.74E+000#

Bus6 220KV Bus1 98.87 0.114 100.00 100.00 100.00 0.000 0.000 1.19E+002 4.87E+000

Bus7 220KV Bus1 98.87 0.114 100.00 100.00 100.00 0.000 0.000 1.19E+002 4.87E+000

132KV BUS 220KV Bus1 91.52 0.262 100.00 100.00 100.00 0.000 0.000 5.15E+001 6.74E+000#

T11~3 220KV Bus1 90.68 0.014 100.00 100.00 100.00 0.000 0.000 9.66E+002 1.26E+002#

Bus13 132KV BUS 96.03 0.517 100.00 100.00 100.00 0.000 0.000 4.29E+001 7.78E+000

Bus11 132KV BUS 96.83 0.412 100.00 100.00 100.00 0.000 0.000 5.35E+001 1.12E+001

Bus12 132KV BUS 96.83 0.412 100.00 100.00 100.00 0.000 0.000 5.35E+001 1.12E+001

Bus15 132KV BUS 97.43 0.334 100.00 100.00 100.00 0.000 0.000 6.57E+001 1.52E+001

33KV BUS 1 132KV BUS 91.52 0.000 100.00 100.00 100.00 0.000 0.000

33KV BUS 2 132KV BUS 91.52 0.000 100.00 100.00 100.00 0.000 0.000

T11~3 132KV BUS 90.68 0.023 100.00 100.00 100.00 0.000 0.000 9.69E+002 8.46E+000#





U9 Bus13 100.00 0.517 100.00 100.00 100.00 0.000 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.412 100.00 100.00 100.00 0.000 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.412 100.00 100.00 100.00 0.000 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.334 100.00 100.00 100.00 0.000 0.000 2.40E-001 3.36E+0002.40E-001 3.36E+000

0.433kV Bus-2 33KV BUS 2 91.52 0.000 100.00 100.00 100.00 0.000 0.000

220KV Bus2 220KV Bus1 98.62 0.029 100.00 100.00 100.00 0.000 0.000

33KV BUS 1 Bus Ref A 91.52 0.000 100.00 100.00 100.00 0.000 0.000

Page 132 of 160

Location: Dehradun


11.1.0C

Page: 13

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

11kV Bus.

=

1.00 (Minimum If) =

11.000

33KV BUS 2 33KV BUS 1 91.52 0.000 100.00 100.00 100.00 0.000 0.000

33KV BUS 2 Bus Ref B 91.52 0.000 100.00 100.00 100.00 0.000 0.000




:


26.699




:

:

:

71.651

26.699

0.000

0.000

0.000

0.000

23.122

62.051

23.122

23.122

23.122

62.051

23.122

23.122

Page 133 of 160

Location: Dehradun


11.1.0C

Page: 14

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

33KV BUS 1

=

1.00 (Minimum If) =

33.000

33KV BUS 1 Total 0.00 9.625 0.00 99.84 99.94 9.646 9.646 8.03E-001 1.80E+0017.79E-001 1.82E+001

132KV BUS 33KV BUS 1 91.59 4.812 91.79 99.84 99.94 4.823 4.823 1.87E+000 3.61E+0011.82E+000 3.63E+001

0.433kV Bus-2 33KV BUS 2 0.00 0.000 57.70 57.65 100.00 0.000 0.000

132KV BUS 33KV BUS 2 91.59 4.813 91.79 99.84 99.94 4.823 4.823 1.35E+000 3.61E+0011.30E+000 3.63E+001

Bus13 132KV BUS 96.06 0.512 96.45 99.91 99.70 0.463 0.365 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 97.46 0.331 97.76 99.91 99.79 0.293 0.219 7.22E+000 1.41E+0013.12E+000 1.08E+001

220KV Bus2 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

11kV Bus. 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

220KV Bus1 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

T11~3 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

U9 Bus13 100.00 0.512 100.00 100.00 100.00 0.463 0.365 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.331 100.00 100.00 100.00 0.293 0.219 2.40E-001 3.36E+0002.40E-001 3.36E+000

Bus8 220KV Bus2 99.19 0.080 99.34 99.94 99.90 0.065 0.034 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 99.29 0.070 99.43 99.94 99.91 0.056 0.029 3.21E+000 1.55E+0011.06E+000 7.10E+000

11kV Bus. 220KV Bus2 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *

0.433kV Bus-1 11kV Bus. 90.82 0.000 98.11 93.86 98.89 0.000 0.000

Bus6 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

T11~3 220KV Bus1 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *





33KV BUS 1 Bus Ref A 0.00 0.000 0.00 99.84 99.94 0.000 0.000

33KV BUS 2 33KV BUS 1 0.00 4.813 0.00 99.84 99.94 4.823 4.823

33KV BUS 2 Bus Ref B 0.00 0.000 0.00 99.84 99.94 0.000 0.000

Page 134 of 160

Location: Dehradun


11.1.0C

Page: 15

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

33KV BUS 1

=

1.00 (Minimum If) =

33.000

220KV Bus1 220KV Bus2 98.12 0.078 98.19 99.95 99.98 0.073 0.064




:


9.625




:

:

:

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

Page 135 of 160

Location: Dehradun


11.1.0C

Page: 16

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

33KV BUS 2

=

1.00 (Minimum If) =

33.000

33KV BUS 2 Total 0.00 9.625 0.00 99.84 99.94 9.646 9.646 8.03E-001 1.80E+0017.79E-001 1.82E+001

0.433kV Bus-2 33KV BUS 2 0.00 0.000 57.70 57.65 100.00 0.000 0.000

132KV BUS 33KV BUS 2 91.59 4.813 91.79 99.84 99.94 4.823 4.823 1.35E+000 3.61E+0011.30E+000 3.63E+001

132KV BUS 33KV BUS 1 91.59 4.812 91.79 99.84 99.94 4.823 4.823 1.87E+000 3.61E+0011.82E+000 3.63E+001

Bus13 132KV BUS 96.06 0.512 96.45 99.91 99.70 0.463 0.365 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 97.46 0.331 97.76 99.91 99.79 0.293 0.219 7.22E+000 1.41E+0013.12E+000 1.08E+001

220KV Bus2 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

11kV Bus. 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

220KV Bus1 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

T11~3 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

U9 Bus13 100.00 0.512 100.00 100.00 100.00 0.463 0.365 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.331 100.00 100.00 100.00 0.293 0.219 2.40E-001 3.36E+0002.40E-001 3.36E+000

Bus8 220KV Bus2 99.19 0.080 99.34 99.94 99.90 0.065 0.034 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 99.29 0.070 99.43 99.94 99.91 0.056 0.029 3.21E+000 1.55E+0011.06E+000 7.10E+000

11kV Bus. 220KV Bus2 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *

0.433kV Bus-1 11kV Bus. 90.82 0.000 98.11 93.86 98.89 0.000 0.000

Bus6 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

T11~3 220KV Bus1 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *





33KV BUS 1 Bus Ref A 0.00 0.000 0.00 99.84 99.94 0.000 0.000

33KV BUS 1 33KV BUS 2 0.00 4.812 0.00 99.84 99.94 4.823 4.823

33KV BUS 2 Bus Ref B 0.00 0.000 0.00 99.84 99.94 0.000 0.000

Page 136 of 160

Location: Dehradun


11.1.0C

Page: 17

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

33KV BUS 2

=

1.00 (Minimum If) =

33.000

220KV Bus1 220KV Bus2 98.12 0.078 98.19 99.95 99.98 0.073 0.064




:


9.625




:

:

:

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

Page 137 of 160

Location: Dehradun


11.1.0C

Page: 18

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

132KV BUS

=

1.00 (Minimum If) =

132.000

132KV BUS Total 0.00 28.281 0.00 97.87 99.69 28.986 28.986 3.13E-001 1.40E+0002.90E-001 1.52E+000

Bus13 132KV BUS 54.85 6.015 58.82 98.32 97.00 5.561 4.387 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 64.15 4.796 67.71 98.33 97.51 4.383 3.346 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 64.15 4.796 67.71 98.33 97.51 4.383 3.346 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 70.99 3.892 74.11 98.43 97.95 3.527 2.629 7.22E+000 1.41E+0013.12E+000 1.08E+001

33KV BUS 1 132KV BUS 0.00 0.000 0.00 97.87 99.69 0.000 0.000

33KV BUS 2 132KV BUS 0.00 0.000 0.00 97.87 99.69 0.000 0.000

220KV Bus2 132KV BUS 77.53 4.716 77.76 99.28 99.92 4.406 3.551 5.35E-001 1.17E+0013.60E-001 9.27E+000#

11kV Bus. 132KV BUS 9.16 0.251 55.31 53.95 100.00 1.293 4.393 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

220KV Bus1 132KV BUS 77.53 4.716 77.76 99.28 99.92 4.406 3.551 5.35E-001 1.17E+0013.60E-001 9.27E+000#

T11~3 132KV BUS 9.16 0.251 55.31 53.95 100.00 1.293 4.393 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

U9 Bus13 100.00 6.015 100.00 100.00 100.00 5.561 4.387 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 4.796 100.00 100.00 100.00 4.383 3.346 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 4.796 100.00 100.00 100.00 4.383 3.346 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 3.892 100.00 100.00 100.00 3.527 2.629 2.40E-001 3.36E+0002.40E-001 3.36E+000

0.433kV Bus-2 33KV BUS 2 0.00 0.000 57.56 56.51 100.00 0.000 0.000

Bus8 220KV Bus2 90.37 0.941 92.01 99.03 99.11 0.781 0.413 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 91.57 0.823 93.07 99.11 99.21 0.677 0.345 3.21E+000 1.55E+0011.06E+000 7.10E+000

11kV Bus. 220KV Bus2 9.16 0.151 55.31 53.95 100.00 0.307 0.613 1.98E-001 8.89E+0003.76E+000 3.90E+001# *

0.433kV Bus-1 11kV Bus. 9.16 0.000 87.96 25.43 87.10 0.000 0.000

Bus6 220KV Bus1 81.63 1.798 83.54 99.04 98.62 1.610 1.144 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 81.63 1.798 83.54 99.04 98.62 1.610 1.144 7.78E-001 4.70E+0002.37E-001 3.28E+000

T11~3 220KV Bus1 9.16 0.151 55.31 53.95 100.00 0.307 0.613 1.98E-001 8.89E+0003.76E+000 3.90E+001# *





33KV BUS 1 Bus Ref A 0.00 0.000 0.00 97.87 99.69 0.000 0.000

33KV BUS 2 33KV BUS 1 0.00 0.000 0.00 97.87 99.69 0.000 0.000

33KV BUS 2 Bus Ref B 0.00 0.000 0.00 97.87 99.69 0.000 0.000

Page 138 of 160

Location: Dehradun


11.1.0C

Page: 19

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

132KV BUS

=

1.00 (Minimum If) =

132.000

220KV Bus1 220KV Bus2 77.53 0.920 77.76 99.28 99.92 0.883 0.765




:


28.281




:

:

:

63.930

28.281

28.986

65.523

28.986

28.986

24.492

55.365

24.492

24.492

28.911

65.355

28.911

28.911

Page 139 of 160

Location: Dehradun


11.1.0C

Page: 20

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

220KV Bus1

=

1.00 (Minimum If) =

220.000

220KV Bus1 Total 0.00 28.161 0.00 101.61 103.16 26.866 26.866 1.32E-001 1.06E+0009.12E-002 9.27E-001

Bus6 220KV Bus1 18.28 7.984 27.65 98.50 96.22 7.080 6.016 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 18.28 7.984 27.65 98.50 96.22 7.080 6.016 7.78E-001 4.70E+0002.37E-001 3.28E+000

132KV BUS 220KV Bus1 63.27 2.309 66.18 98.96 99.76 2.212 2.231 1.23E+000 1.28E+0011.24E+000 1.13E+001#

T11~3 220KV Bus1 70.74 0.123 84.45 88.18 100.00 0.996 3.222 1.98E-001 8.89E+0002.32E+001 2.12E+002# *

Bus8 220KV Bus2 57.40 4.180 65.58 96.82 97.29 3.382 2.174 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 62.76 3.656 70.20 97.00 97.54 2.929 1.812 3.21E+000 1.55E+0011.06E+000 7.10E+000

132KV BUS 220KV Bus2 63.27 2.309 66.18 98.96 99.76 2.212 2.231 1.23E+000 1.28E+0011.24E+000 1.13E+001#

11kV Bus. 220KV Bus2 70.74 0.123 84.45 88.18 100.00 0.996 3.222 1.98E-001 8.89E+0002.32E+001 2.12E+002# *



Bus13 132KV BUS 82.71 2.248 85.25 99.48 98.81 1.921 1.481 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 86.22 1.793 88.40 99.49 99.00 1.514 1.129 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 86.22 1.793 88.40 99.49 99.00 1.514 1.129 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 88.83 1.455 90.68 99.53 99.16 1.219 0.887 7.22E+000 1.41E+0013.12E+000 1.08E+001

33KV BUS 1 132KV BUS 63.27 0.000 66.18 98.96 99.76 0.000 0.000

33KV BUS 2 132KV BUS 63.27 0.000 66.18 98.96 99.76 0.000 0.000

11kV Bus. 132KV BUS 70.74 0.205 84.45 88.18 100.00 0.620 1.483 2.10E-001 9.46E+0002.02E+001 7.71E+001# *

T11~3 132KV BUS 70.74 0.205 84.45 88.18 100.00 0.620 1.483 2.10E-001 9.46E+0002.02E+001 7.71E+001# *



0.433kV Bus-1 11kV Bus. 70.74 0.000 93.96 81.27 97.33 0.000 0.000

U9 Bus13 100.00 2.248 100.00 100.00 100.00 1.921 1.481 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 1.793 100.00 100.00 100.00 1.514 1.129 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 1.793 100.00 100.00 100.00 1.514 1.129 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 1.455 100.00 100.00 100.00 1.219 0.887 2.40E-001 3.36E+0002.40E-001 3.36E+000

0.433kV Bus-2 33KV BUS 2 63.27 0.000 81.30 84.70 100.00 0.000 0.000

220KV Bus2 220KV Bus1 0.00 10.020 0.00 101.61 103.16 9.507 9.409

33KV BUS 1 Bus Ref A 63.27 0.000 66.18 98.96 99.76 0.000 0.000

Page 140 of 160

Location: Dehradun


11.1.0C

Page: 21

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

220KV Bus1

=

1.00 (Minimum If) =

220.000

33KV BUS 2 33KV BUS 1 63.27 0.000 66.18 98.96 99.76 0.000 0.000

33KV BUS 2 Bus Ref B 63.27 0.000 66.18 98.96 99.76 0.000 0.000




:


28.161




:

:

:

69.772

28.161

26.866

66.563

26.866

26.866

24.388

60.425

24.388

24.388

27.770

68.803

27.770

27.770

Page 141 of 160

Location: Dehradun


11.1.0C

Page: 22

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

220KV Bus2

=

1.00 (Minimum If) =

220.000

220KV Bus2 Total 0.00 28.161 0.00 101.61 103.16 26.866 26.866 1.32E-001 1.06E+0009.12E-002 9.27E-001

Bus8 220KV Bus2 57.40 4.180 65.58 96.82 97.29 3.382 2.174 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 62.76 3.656 70.20 97.00 97.54 2.929 1.812 3.21E+000 1.55E+0011.06E+000 7.10E+000

132KV BUS 220KV Bus2 63.27 2.309 66.18 98.96 99.76 2.212 2.231 1.23E+000 1.28E+0011.24E+000 1.13E+001#

11kV Bus. 220KV Bus2 70.74 0.123 84.45 88.18 100.00 0.996 3.222 1.98E-001 8.89E+0002.32E+001 2.12E+002# *

Bus6 220KV Bus1 18.28 7.984 27.65 98.50 96.22 7.080 6.016 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 18.28 7.984 27.65 98.50 96.22 7.080 6.016 7.78E-001 4.70E+0002.37E-001 3.28E+000

132KV BUS 220KV Bus1 63.27 2.309 66.18 98.96 99.76 2.212 2.231 1.23E+000 1.28E+0011.24E+000 1.13E+001#

T11~3 220KV Bus1 70.74 0.123 84.45 88.18 100.00 0.996 3.222 1.98E-001 8.89E+0002.32E+001 2.12E+002# *



Bus13 132KV BUS 82.71 2.248 85.25 99.48 98.81 1.921 1.481 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 86.22 1.793 88.40 99.49 99.00 1.514 1.129 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 86.22 1.793 88.40 99.49 99.00 1.514 1.129 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 88.83 1.455 90.68 99.53 99.16 1.219 0.887 7.22E+000 1.41E+0013.12E+000 1.08E+001

33KV BUS 1 132KV BUS 63.27 0.000 66.18 98.96 99.76 0.000 0.000

33KV BUS 2 132KV BUS 63.27 0.000 66.18 98.96 99.76 0.000 0.000

11kV Bus. 132KV BUS 70.74 0.205 84.45 88.18 100.00 0.620 1.483 2.10E-001 9.46E+0002.02E+001 7.71E+001# *

T11~3 132KV BUS 70.74 0.205 84.45 88.18 100.00 0.620 1.483 2.10E-001 9.46E+0002.02E+001 7.71E+001# *

0.433kV Bus-1 11kV Bus. 70.74 0.000 93.96 81.27 97.33 0.000 0.000



U9 Bus13 100.00 2.248 100.00 100.00 100.00 1.921 1.481 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 1.793 100.00 100.00 100.00 1.514 1.129 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 1.793 100.00 100.00 100.00 1.514 1.129 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 1.455 100.00 100.00 100.00 1.219 0.887 2.40E-001 3.36E+0002.40E-001 3.36E+000

0.433kV Bus-2 33KV BUS 2 63.27 0.000 81.30 84.70 100.00 0.000 0.000

220KV Bus1 220KV Bus2 0.00 18.153 0.00 101.61 103.16 17.363 17.457

33KV BUS 1 Bus Ref A 63.27 0.000 66.18 98.96 99.76 0.000 0.000

Page 142 of 160

Location: Dehradun


11.1.0C

Page: 23

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

220KV Bus2

=

1.00 (Minimum If) =

220.000

33KV BUS 2 33KV BUS 1 63.27 0.000 66.18 98.96 99.76 0.000 0.000

33KV BUS 2 Bus Ref B 63.27 0.000 66.18 98.96 99.76 0.000 0.000




:


28.161




:

:

:

69.772

28.161

26.866

66.563

26.866

26.866

24.388

60.425

24.388

24.388

27.770

68.803

27.770

27.770

Page 143 of 160

Location: Dehradun


11.1.0C

Page: 24

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

Bus Ref A

=

1.00 (Minimum If) =

33.000

Bus Ref A Total 0.00 9.625 0.00 99.84 99.94 9.646 9.646 8.03E-001 1.80E+0017.79E-001 1.82E+001

132KV BUS 33KV BUS 1 91.59 4.812 91.79 99.84 99.94 4.823 4.823 1.87E+000 3.61E+0011.82E+000 3.63E+001

0.433kV Bus-2 33KV BUS 2 0.00 0.000 57.70 57.65 100.00 0.000 0.000

132KV BUS 33KV BUS 2 91.59 4.813 91.79 99.84 99.94 4.823 4.823 1.35E+000 3.61E+0011.30E+000 3.63E+001

Bus13 132KV BUS 96.06 0.512 96.45 99.91 99.70 0.463 0.365 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 97.46 0.331 97.76 99.91 99.79 0.293 0.219 7.22E+000 1.41E+0013.12E+000 1.08E+001

220KV Bus2 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

11kV Bus. 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

220KV Bus1 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

T11~3 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

U9 Bus13 100.00 0.512 100.00 100.00 100.00 0.463 0.365 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.331 100.00 100.00 100.00 0.293 0.219 2.40E-001 3.36E+0002.40E-001 3.36E+000

Bus8 220KV Bus2 99.19 0.080 99.34 99.94 99.90 0.065 0.034 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 99.29 0.070 99.43 99.94 99.91 0.056 0.029 3.21E+000 1.55E+0011.06E+000 7.10E+000

11kV Bus. 220KV Bus2 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *

0.433kV Bus-1 11kV Bus. 90.82 0.000 98.11 93.86 98.89 0.000 0.000

Bus6 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

T11~3 220KV Bus1 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *





33KV BUS 1 Bus Ref A 0.00 9.625 0.00 99.84 99.94 9.646 9.646

33KV BUS 2 33KV BUS 1 0.00 4.813 0.00 99.84 99.94 4.823 4.823

33KV BUS 2 Bus Ref B 0.00 0.000 0.00 99.84 99.94 0.000 0.000

Page 144 of 160

Location: Dehradun


11.1.0C

Page: 25

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

Bus Ref A

=

1.00 (Minimum If) =

33.000

220KV Bus1 220KV Bus2 98.12 0.078 98.19 99.95 99.98 0.073 0.064




:


9.625




:

:

:

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

Page 145 of 160

Location: Dehradun


11.1.0C

Page: 26

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Fault at bus:








Nominal kV

Voltage c Factor

Bus Ref B

=

1.00 (Minimum If) =

33.000

Bus Ref B Total 0.00 9.625 0.00 99.84 99.94 9.646 9.646 8.03E-001 1.80E+0017.79E-001 1.82E+001

0.433kV Bus-2 33KV BUS 2 0.00 0.000 57.70 57.65 100.00 0.000 0.000

132KV BUS 33KV BUS 2 91.59 4.813 91.79 99.84 99.94 4.823 4.823 1.35E+000 3.61E+0011.30E+000 3.63E+001

132KV BUS 33KV BUS 1 91.59 4.812 91.79 99.84 99.94 4.823 4.823 1.87E+000 3.61E+0011.82E+000 3.63E+001

Bus13 132KV BUS 96.06 0.512 96.45 99.91 99.70 0.463 0.365 3.73E+000 8.71E+0001.68E+000 7.08E+000

Bus11 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus12 132KV BUS 96.86 0.408 97.21 99.91 99.75 0.365 0.278 5.36E+000 1.12E+0012.35E+000 8.81E+000

Bus15 132KV BUS 97.46 0.331 97.76 99.91 99.79 0.293 0.219 7.22E+000 1.41E+0013.12E+000 1.08E+001

220KV Bus2 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

11kV Bus. 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

220KV Bus1 132KV BUS 98.12 0.401 98.19 99.95 99.98 0.367 0.295 5.35E-001 1.17E+0013.60E-001 9.27E+000#

T11~3 132KV BUS 90.82 0.021 95.03 95.84 100.00 0.108 0.365 2.10E-001 9.46E+0006.75E+000 1.74E+002# *

U9 Bus13 100.00 0.512 100.00 100.00 100.00 0.463 0.365 2.40E-001 3.36E+0002.40E-001 3.36E+000

U24 Bus11 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U8 Bus12 100.00 0.408 100.00 100.00 100.00 0.365 0.278 2.40E-001 3.36E+0002.40E-001 3.36E+000

U10 Bus15 100.00 0.331 100.00 100.00 100.00 0.293 0.219 2.40E-001 3.36E+0002.40E-001 3.36E+000

Bus8 220KV Bus2 99.19 0.080 99.34 99.94 99.90 0.065 0.034 2.60E+000 1.29E+0018.84E-001 6.22E+000

Bus9 220KV Bus2 99.29 0.070 99.43 99.94 99.91 0.056 0.029 3.21E+000 1.55E+0011.06E+000 7.10E+000

11kV Bus. 220KV Bus2 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *

0.433kV Bus-1 11kV Bus. 90.82 0.000 98.11 93.86 98.89 0.000 0.000

Bus6 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

Bus7 220KV Bus1 98.47 0.153 98.66 99.95 99.86 0.134 0.095 7.78E-001 4.70E+0002.37E-001 3.28E+000

T11~3 220KV Bus1 90.82 0.013 95.03 95.84 100.00 0.026 0.051 1.98E-001 8.89E+0003.76E+000 3.90E+001# *





33KV BUS 1 Bus Ref A 0.00 0.000 0.00 99.84 99.94 0.000 0.000

33KV BUS 1 33KV BUS 2 0.00 4.812 0.00 99.84 99.94 4.823 4.823

33KV BUS 2 Bus Ref B 0.00 9.625 0.00 99.84 99.94 9.646 9.646

Page 146 of 160

Location: Dehradun


11.1.0C

Page: 27

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

(Cont.)

Fault at bus:








Nominal kV

Voltage c Factor

Bus Ref B

=

1.00 (Minimum If) =

33.000

220KV Bus1 220KV Bus2 98.12 0.078 98.19 99.95 99.98 0.073 0.064




:


9.625




:

:

:

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

Page 147 of 160

Location: Dehradun


11.1.0C

Page: 28

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Short-Circuit Summary Report

3-Phase, LG, LL, LLG Fault Currents

ID kV

Bus

I"k ip Ik I"k I"k Ikip ip I"kIb Ib Ib

3-Phase Fault Line-to-Ground Fault Line-to-Line Fault *Line-to-Line-to-Ground

Ik ip Ik

0.433kV Bus-1 0.433 11.367 18.617 11.367 11.425 18.711 11.425 11.425 9.844 16.122 9.844 9.844 18.714 11.427 11.427 11.427

0.433kV Bus-2 0.433 16.075 26.364 16.075 16.182 26.539 16.182 16.182 13.922 22.832 13.922 13.922 26.543 16.185 16.185 16.185

11kV Bus. 11.000 26.699 71.651 26.699 0.000 0.000 0.000 0.000 23.122 62.051 23.122 23.122 62.051 23.122 23.122 23.122

33KV BUS 1 33.000 9.625 25.636 9.625 9.646 25.692 9.646 9.646 8.335 22.201 8.335 8.335 25.676 9.640 9.640 9.640

33KV BUS 2 33.000 9.625 25.636 9.625 9.646 25.692 9.646 9.646 8.335 22.201 8.335 8.335 25.676 9.640 9.640 9.640

132KV BUS 132.000 28.281 63.930 28.281 28.986 65.523 28.986 28.986 24.492 55.365 24.492 24.492 65.355 28.911 28.911 28.911

220KV Bus1 220.000 28.161 69.772 28.161 26.866 66.563 26.866 26.866 24.388 60.425 24.388 24.388 68.803 27.770 27.770 27.770

220KV Bus2 220.000 28.161 69.772 28.161 26.866 66.563 26.866 26.866 24.388 60.425 24.388 24.388 68.803 27.770 27.770 27.770

Bus Ref A 33.000 9.625 25.636 9.625 9.646 25.692 9.646 9.646 8.335 22.201 8.335 8.335 25.676 9.640 9.640 9.640

Bus Ref B 33.000 9.625 25.636 9.625 9.646 25.692 9.646 9.646 8.335 22.201 8.335 8.335 25.676 9.640 9.640 9.640

All fault currents are in rms kA. Current ip is calculated using Method C.

* LLG fault current is the larger of the two faulted line currents .

Page 148 of 160

Location: Dehradun


11.1.0C

Page: 29

SN: VOLTECHENG

Filename: HPL


Contract: HPL

Date: 16-09-2013

Revision: Base

Config.: Normal

Sequence Impedance Summary Report

ID kV

Bus

Resistance Reactance Impedance

Positive Seq. Imp. (ohm) Negative Seq. Imp. (ohm)


Zero Seq. Imp. (ohm)


Fault Zf (ohm)


0.433kV Bus-1 0.433 0.01143 0.01749 0.02089 0.01141 0.01712 0.02058 0.01143 0.01749 0.02089 0.00000 0.00000 0.00000

0.433kV Bus-2 0.433 0.00805 0.01239 0.01477 0.00803 0.01205 0.01448 0.00805 0.01239 0.01477 0.00000 0.00000 0.00000

11kV Bus. 11.000 0.00892 0.23770 0.23787 0.00892 0.23770 0.23787 0.00000 0.00000 0.00000

33KV BUS 1 33.000 0.08485 1.97772 1.97954 0.08746 1.96469 1.96664 0.08485 1.97772 1.97954 0.00000 0.00000 0.00000

33KV BUS 2 33.000 0.08485 1.97772 1.97954 0.08746 1.96469 1.96664 0.08485 1.97772 1.97954 0.00000 0.00000 0.00000

132KV BUS 132.000 0.50447 2.64711 2.69475 0.54616 2.43871 2.49913 0.50447 2.64711 2.69475 0.00000 0.00000 0.00000

220KV Bus1 220.000 0.44146 4.48871 4.51036 0.64068 5.12409 5.16399 0.44146 4.48871 4.51036 0.00000 0.00000 0.00000

220KV Bus2 220.000 0.44146 4.48871 4.51036 0.64068 5.12409 5.16399 0.44146 4.48871 4.51036 0.00000 0.00000 0.00000

Bus Ref A 33.000 0.08485 1.97772 1.97954 0.08746 1.96469 1.96664 0.08485 1.97772 1.97954 0.00000 0.00000 0.00000

Bus Ref B 33.000 0.08485 1.97772 1.97954 0.08746 1.96469 1.96664 0.08485 1.97772 1.97954 0.00000 0.00000 0.00000

Page 149 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 1

Date: 16-09-2013

Revision: Base

Overcurrent Relay Settings

11.1.0C

OCR: 11kV

MFR: AREVA

Model: P127

Tag #:

GND:

If (kA)Base kVCT

100/1

100/1Phase: 11.000

11.000

OC Level: OC1

Setting Range

Phase TOC IEC - Standard Inverse

Pickup (Tap) 0.1 - 25 xCT Sec 0.230

Time Dial 0.740

Phase INST Pickup 0.5 - 40 xCT Sec 1.000

Time Delay 0 - 150 0.300

OCR: 132KV LINE-1

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

29.03

29.03

29.03

400/1Phase: 132.000

132.000

132.000

LG, Asym. (Calc.)

3 ph, Asym. (Calc.)

LG, Asym. (Calc.)

LG, Asym. (Calc.) 29.03

OC Level: OC1

Setting Range Setting

Phase TOC IEC - Curve A

Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.150 Direction ReversePhase 67

MTA 45.00

Polarization Voltage

Neutral TOC IEC - Curve A Direction ReverseNeutral 67

Pickup (Tap) 0.05 - 160 Sec - 1A 0.200 MTA 45.00

Time Dial 0.300 Polarization Voltage

OCR: 132KV LINE-2

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 1.000


MTA 45.00




Time Dial 0.330 Polarization VoltagePage 150 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 2

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: 132KV LINE-3

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 1.000


MTA 45.00





OCR: 132KV LINE-4

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 1.000


MTA 45.00





Page 151 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 3

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: 160 MVA TR-1 132KV SIDE

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 5A 0.960

Time Dial 0.170 Direction ForwardPhase 67

Phase INST Pickup 0.05 - 160 Sec - 1A 9.480 MTA 45.00

Time Delay 0 - 900 0.500 Polarization Voltage

Neutral TOC IEC - Curve A Direction ForwardNeutral 67



Neutral INST Pickup 0.05 - 160 Sec - 1A 2.500

Time Delay 0 - 900 0.600


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

33.57

33.57

33.57

800/1Phase: 220.000

220.000

220.000

LG, Asym. (Calc.)

3 ph, Asym. (Calc.)

LG, Asym. (Calc.)


OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.580








Time Delay 0 - 900 0.500

Page 152 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 4

Date: 16-09-2013

Revision: Base


11.1.0C


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.960



Time Delay 0 - 900 0.100 Polarization Dual





Time Delay 0 - 900 0.600


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 220.000

220.000

220.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.580








Time Delay 0 - 900 0.500

Page 153 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 5

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: 220 KV LINE

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

1600/1

1600/1

33.57

33.57

33.57

1600/1Phase: 220.000

220.000

220.000

LG, Asym. (Calc.)

3 ph, Asym. (Calc.)

LG, Asym. (Calc.)


OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.200

Neutral TOC IEC - Curve A

Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.300

OCR: 220 KV LINE-1

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

1600/1

1600/1

33.57

33.57

33.57

1600/1Phase: 220.000

220.000

220.000

LG, Asym. (Calc.)

3 ph, Asym. (Calc.)

LG, Asym. (Calc.)


OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.200


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.250

OCR: 220 KV LINE-3

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 220.000

220.000

220.000

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.200


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.250

Page 154 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 6

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: 220 KV LINE-4

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 220.000

220.000

220.000

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.200


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.250

OCR: 33 KV LINE

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 33.000

33.000

33.000

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.030


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.060

OCR: 33KV BUS COUPLER

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 33.000

33.000

33.000

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 0.960

Time Dial 0.070


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.100

Page 155 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 7

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: 33KV Capacitor Bank

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

200/1

200/1

7.24

7.24

7.24

200/1Phase: 33.000

33.000

33.000

LG, Asym. (Calc.)

3 ph, Asym. (Calc.)

LG, Asym. (Calc.)


OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.960


MTA 0.00



Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.070

OCR: 40 MVA 132 KV SIDE TR-1

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.480








Time Delay 0 - 900 0.350

Page 156 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 8

Date: 16-09-2013

Revision: Base


11.1.0C


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

400/1

400/1

400/1Phase: 132.000

132.000

132.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.480








Time Delay 0 - 900 0.350


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 33.000

33.000

33.000

OC Level: OC1



Pickup (Tap) 0.05 - 160 Sec - 1A 0.960

Time Dial 0.120

Phase INST Pickup 0.05 - 160 Sec - 1A 8.000

Time Delay 0 - 900 0.250





Time Delay 0 - 900 0.300

Page 157 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 9

Date: 16-09-2013

Revision: Base


11.1.0C


MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

800/1

800/1

800/1Phase: 33.000

33.000

33.000

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 0.960

Time Dial 0.120

Phase INST Pickup 0.05 - 160 Sec - 1A 8.000

Time Delay 0 - 900 0.250


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.250


Time Delay 0 - 900 0.300

OCR: BUS COUPLER

MFR: GE Multilin

Model: F650

Tag #:

GND:

Sen. GND:

If (kA)Base kVCT

1600/1

1600/1

22.10

22.10

22.10

1600/1Phase: 220.000

220.000

220.000

LG, Sym. (Calc.)

3 ph, Sym. (Calc.)

LG, Sym. (Calc.)

LG, Sym. (Calc.) 22.10

OC Level: OC1

Setting Range


Pickup (Tap) 0.05 - 160 Sec - 1A 1.000

Time Dial 0.200


Pickup (Tap) 0.05 - 160 Sec - 1A 0.200

Time Dial 0.300

Page 158 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 10

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: MSB BC

MFR: AREVA

Model: P127

Tag #:

GND:

If (kA)Base kVCT

1000/1

1000/1Phase: 0.433

0.433

OC Level: OC1

Setting Range



Time Dial 0.100


Time Delay 0 - 150 0.100

Ground TOC IEC - Standard Inverse


Time Dial 0.150

Ground INST Pickup 0.002 - 1 xCT Sec 1.000

Time Delay 0 - 150 0.100

OCR: MSB IC-1

MFR: AREVA

Model: P127

Tag #:

GND:

If (kA)Base kVCT

1000/1

1000/1Phase: 0.433

0.433

OC Level: OC1

Setting Range



Time Dial 0.200


Time Delay 0 - 150 0.200



Time Dial 0.300


Time Delay 0 - 150 0.200

Page 159 of 160


Location: Dehradun

Contract: HPL


Filename: HPL

Page: 11

Date: 16-09-2013

Revision: Base


11.1.0C

OCR: MSB IC-2

MFR: AREVA

Model: P127

Tag #:

GND:

If (kA)Base kVCT

1000/1

1000/1Phase: 0.433

0.433

OC Level: OC1

Setting Range



Time Dial 0.200


Time Delay 0 - 150 0.200



Time Dial 0.300


Time Delay 0 - 150 0.200

Page 160 of 160

r0 ve j108 d e212 relay setting calculation hpl16 09 13

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