R0 VE J108 D E212 Relay Setting Calculation HPL16 09 13

DATED

A

For Approval

REV.

DESCRIPTION

BY

APPVD.

19.08.13

DSGND.

MN

19.08.13

CHKD.

GP

DATE

APPVD.

GP

CONTRACTOR:

HPL ELECTRIC & POWER PVT. LTD.

CLIENT:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL)

PROJECT:

220/132/33kV SUBSTATION, DEHRADUN

DESIGNER:

VOLTECH ENGINEERS PVT LTD

TITLE:

RELAY SETTING CALCULATION AND COORDINATION

DOC. NO:

VE-J108-D-E212

REV:

A

CONTENT

S.No

Description

Page No

A 1 1.1 1.2 1.3 1.4 2 2.1 2.2 2.3 2.4 3 3.1 3.2 3.3 3.4 3.5 3.6 3.7 4 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.9 4.10 4.11 4.12 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

NOTES 11/0.415kV 0.415kV MSB Bus coupler 0.415kV MSB Incomer-1 0.415kV MSB Incomer-2 11/0.415kV 400KVA Transformer 33kV 33kV Capacitor bank- OC and EF 33kV Line OC and EF 33kV Bus coupler OC and EF 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 132 kV Line Distance Protection(30kM) 132 kV Line Distance Protection(22kM) 132 kV Line Distance Protection(15kM) 132/33kV 40 MVA Trafo Differential Protection 220kV 160 MVA Transformer OC and EF 220 kV Bus Coupler OC and EF 220 kV Line OC and EF 220kV Distance Protection(50kM) Main-1 220kV Distance Protection(40kM) Main-1 220kV Distance Protection(10kM) Main-1 220kV Distance Protection(50kM) Main-2 220kV Distance Protection(40kM) Main-2 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 11/0.433kV POC Coordination 11/0.433kV EOC Coordination 0.433-33kV POC Coordination 0.433-33kV EOC Coordination 132-33kV POC Coordination 132-33kV EOC Coordination 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 OLV-SC Analysis Ph-G-Maximum Short Circuit Analysis Repot-Minimum Short Circuit Analysis Repot-Maximum Relay Setting -ETAP Format

1 2 3 5 7 9 11 12 14 16 18 20 21 23 25 27 34 41 48 52 53 55 57 59 66 73 80 86 92 98 102 106 108 109 110 111 112 113 114 115 116 117 118 119 120 121 121 150

Total Pages -160

A1

Note: 1

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

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

Page 1 of 160

0.415kV FEEDERS

Page 2 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR MSB BC RELAY GE F650 BAY/FEEDER MAKE MODEL 1.1. Non Directional Overcurrent and Earth Fault Protection for 0.415kV MSB BC CT Details CT Ratio CT Primary CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current, Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

= = = =

1000/1 1000 1 5P20

A A A

= = = = = =

0.4 11.00 0.43 21.00 533.36 0.450

MVA kV kV A A 4.50%

= = = = =

533.36 A i Load / CT ratio 0.53 586.70 0.59

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.25 From ETAP 11240.00 A I fault / CT ratio 11.24 A (t *((If/IS)0.02 -1)) /0.14 (0.25*(((11.24/0.6)^0.02)-1))/0.14)

= = = = = =

TMS

Instantaneous Phase Overcurrent Setting For High set considering the 130% of through fault current t

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

= = =

t

0.1

1540.83 1.541 0.100

A A Sec

200.00 A Primary I earth fault / CT ratio (200/1000) 0.200 A Secondary

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.25 From ETAP 11340.00 A I fault / CT ratio 11.34 (t *((If/IS)0.02 -1)) /0.14 (0.25*(((11.34/0.2)^0.02)-1))/0.14)

= = =

Instantaneous Earth Overcurrent Setting For High set considering the 100% of CT Primary Current

Primary Secondary

= = = =

= = =

TMS

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP MSB BC

= = =

0.15

1000.00 1.000 0.100

A A Sec

Page 3 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR MSB BC GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP MSB BC

F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.59 IEC Normal Inv 0.11

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Phase Overcurrent- 50 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.54 Definite Time 0.10

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 51N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.20 IEC Normal Inv 0.15

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 50N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.00 Definite Time 0.10

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 4 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 0.415kV INCOMER-1 RELAY GE F650 BAY/FEEDER MAKE MODEL 1.2 Non Directional Overcurrent and Earth Fault Protection for 0.415 kV MSB Incomer-1 CT Details CT Ratio CT Primary CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current, Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

= = = =

1000/1 1000 1 5P20

A A A

= = = = = =

0.4 11.00 0.43 21.00 533.36 0.450

MVA kV kV A A 4.50%

= = = = =

533.36 A i Load / CT ratio 0.53 586.70 0.59

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.50 From ETAP 11240.00 A I fault / CT ratio 11.24 A (t *((If/IS)0.02 -1)) /0.14 (0.5*(((11.24/0.6)^0.02)-1))/0.14)

= = = = = =

TMS

Instantaneous Phase Overcurrent Setting For High set considering the 130% of through fault current t

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

= = =

t

0.2

1540.83 1.541 0.200

A A Sec

200.00 A Primary I earth fault / CT ratio (200/1000) 0.200 A Secondary

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.50 From ETAP 11340.00 A I fault / CT ratio 11.34 (t *((If/IS)0.02 -1)) /0.14 (0.5*(((11.34/0.2)^0.02)-1))/0.14)

= = =

Instantaneous Earth Overcurrent Setting For High set considering the 100% of CT Primary Current

Primary Secondary

= = = =

= = =

TMS

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 0.415kV Incomer-1

= = =

0.30

1000.00 1.000 0.200

A A Sec

Page 5 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 0.415kV INCOMER-1 GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 0.415kV Incomer-1

F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.59 IEC Normal Inv 0.22

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Phase Overcurrent- 50 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.54 Definite Time 0.20

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 51N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.20 IEC Normal Inv 0.30

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 50N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.00 Definite Time 0.20

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 6 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 0.415kV INCOMER-2 RELAY GE F650 BAY/FEEDER MAKE MODEL 1.3. Non Directional Overcurrent and Earth Fault Protection for 0.415kV Incomer-2 CT Details CT Ratio CT Primary CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current, Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

= = = =

1000/1 1000 1 5P20

A A A

= = = = = =

0.6 33.00 0.43 11.02 840.05 0.500

MVA kV kV A A 5.00%

= = = = =

840.05 A i Load / CT ratio 0.84 924.05 0.92

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.50 From ETAP 15570.00 A I fault / CT ratio 15.57 A (t *((If/IS)0.02 -1)) /0.14 (0.5*(((15.57/0.9)^0.02)-1))/0.14)

= = = = = =

TMS

Instantaneous Phase Overcurrent Setting For High set considering the 130% of through fault current t

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

= = =

t

0.2

2184.13 2.184 0.200

A A Sec

200.00 A Primary I earth fault / CT ratio (200/1000) 0.200 A Secondary

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.50 From ETAP 15840.00 A I fault / CT ratio 15.84 (t *((If/IS)0.02 -1)) /0.14 (0.5*(((15.84/0.2)^0.02)-1))/0.14)

= = =

Instantaneous Earth Overcurrent Setting For High set considering the 100% of CT Primary Current

Primary Secondary

= = = =

= = =

TMS

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 0.415kV Incomer-2

= = =

0.3

1000.00 1.000 0.200

A A Sec

Page 7 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 0.415kV INCOMER-2 GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 0.415kV Incomer-2

F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.92 IEC Normal Inv 0.21

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Phase Overcurrent- 50 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 2.18 Definite Time 0.20

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 51N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.20 IEC Normal Inv 0.33

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 50N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.00 Definite Time 0.20

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 8 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 11/0.415kV 400KVA Trafo 11kV Side RELAY GE F650 BAY/FEEDER MAKE MODEL 1.4. Non Directional Overcurrent and Earth Fault Protection for 11kV Incomer CT Details CT Ratio CT Primary CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current, Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

= = = =

100/1 100 1 5P20

A A A

= = = = = =

0.4 11.00 0.43 21.00 533.36 0.450

MVA kV kV A A 4.50%

= = = = =

21.00 A i Load / CT ratio 0.21 23.09 0.23

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.75 From ETAP 15230.00 A I fault / CT ratio 152.30 A (t *((If/IS)0.02 -1)) /0.14 (0.75*(((152.3/0.2)^0.02)-1))/0.14)

= = = = = =

TMS

Instantaneous Phase Overcurrent Setting For High set considering the 130% of through fault current t

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 11/0.415kV 400KVA Tafo-11kV Side

= = =

Primary Secondary

0.74

60.65 0.607 0.300

A A Sec

Calculated

Setting Table: F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.23 IEC Normal Inv 0.74

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Phase Overcurrent- 50 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.61 Definite Time 0.30

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 9 of 160

ERROR: undefined OFFENDING COMMAND: ‘~ STACK:

Page 10 of 160

33kV FEEDERS

Page 11 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 33kV CAPACITOR BANK RELAY MAKE GE MODEL F650 BAY/FEEDER 2.1. Directional Overcurrent and Earth Fault Protection for 33kV capacitor Bank Feeder

DOCUMENT No. VE-J108-D-E212 DATE 19.08.13 PRPD: MN CKD: GP 33kV Capacitor Bank

CT Details CT Ratio CT Primary CT Secondary Class

= = = =

Capacitor Bank Details Rated kVAR Rated Voltage Rated Current

= = =

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

200-100/1 A 200 A 1 A PS

10000 33 175

kVAR kV A

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

175 A i Load / CT ratio 0.87 192.46 0.96

Considering the CT Ratio

Time Multiplier Setting Characteristics

=

IDMT IEC-Standard inverse

Primary Secondary

t Required operating time in seconds Minimum grading time interval considered in sec

=

Minimum Fault current I Fault current at secondary

= =

TMS

= = = = = =

3640 A I fault / CT ratio 18.20 A (t *((If/IS)0.02 -1)) /0.14 (0.1*(((18.2/1)^0.02)-1))/0.14) 0.04 Primary 9620 A Secondary 48.10 A 0.07 Sec

= = = =

40.00 A Primary I earth fault / CT ratio (40/200) A Secondary 0.20

=

IDMT IEC-Standard inverse

Maximum fault Current Operating time at Maximum fault Current Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

Time Multiplier Setting CHARACTERISTICS

=

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

= = = = = =

Maximum fault Current Operating time at Maximum fault Current

=

grading time + Downstream relay operating time 0.10 From ETAP

From ETAP

grading time + Downstream relay operating time 0.10 3880 A I fault / CT ratio 19.40 (t *((If/IS)0.02 -1)) /0.14 (0.1*(((19.4/0.2)^0.02)-1))/0.14) 0.07 Primary 9650 A Secondary 48.25 A 0.08 Sec

From ETAP

From ETAP

Page 12 of 160

DOCUMENT No. VE-J108-D-E212 DATE 19.08.13 PRPD: MN CKD: GP 33kV Capacitor Bank

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 33kV CAPACITOR BANK GE MODEL F650 BAY/FEEDER

F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 0.96 IEC Normal Inv 0.04

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

1 Degree

90 Forward/Reverse

0 0.05

300 160

1V 0.01 A

0

900

0.01 S

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40 0.2 IEC Normal Inv 0.07

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 13 of 160

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 33kV Line

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 33kV LINE RELAY MAKE GE MODEL F650 BAY/FEEDER 2.2. Directional Overcurrent and Earth Fault Protection for 33kV Line Feeder CT Details CT Ratio CT Primary CT Secondary Class

= = = =

400-200/1 A 400 A 1 A PS

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

400 A i Load / CT ratio 1.00 400.00 1.00

Time Multiplier Setting Characteristics

=

IDMT Normal inverse

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

Considering the CT Ratio

Primary Secondary

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

= = = = = =

3640 A I fault / CT ratio 9.10 A (t *((If/IS)0.02 -1)) /0.14 (0.1*(((9.1/1)^0.02)-1))/0.14) 0.03 Primary 9620.00 A Secondary 24.05 A 0.07 Sec

= = = =

80.0 A Primary I earth fault / CT ratio (80/400) A Secondary 0.20

Maximum fault Current Operating time at Maximum fault Current Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

Time Multiplier Setting CHARACTERISTICS

=

grading time + Downstream relay operating time 0.10 From ETAP

From ETAP

=

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

= = = = = =

Maximum fault Current Operating time at Maximum fault Current

=

grading time + Downstream relay operating time 0.10 3880 A I fault / CT ratio 9.70 (t *((If/IS)0.02 -1)) /0.14 (0.1*(((9.7/0.2)^0.02)-1))/0.14) 0.06 Primary 9650.00 A Secondary 24.13 A 0.08 Sec

From ETAP

From ETAP

Page 14 of 160

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 33kV Line

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 33kV LINE GE MODEL F650 BAY/FEEDER

F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 1.00 IEC Normal Inv 0.03

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

1 Degree

90 Forward/Reverse

0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 0.2 IEC Normal Inv 0.06

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 15 of 160

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 33kV Bus Coupler

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 33kV BUS COUPLER RELAY GE F650 BAY/FEEDER MAKE MODEL 2.3. Non Directional Overcurrent and Earth Fault Protection for 33kV Bus Coupler CT Details CT Ratio CT Primary CT Secondary Class

= = = =

800-400/1 A 800 A 1 A PS

699.8 A i Load / CT ratio 0.8747988

Considering the CT Ratio

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

769.82294

Primary Secondary

Time Multiplier Setting Characteristics

=

t Required operating time in seconds

=

Minimum grading time interval considered in sec

grading time + Downstream relay operating time

=

0.32

Fault current I Fault current at secondary

= =

TMS

= = = = = =

3640 A I fault / CT ratio 4.55 A 0.02 (t *((If/IS) -1)) /0.14 (0.32*(((4.55/1)^0.02)-1))/0.14) 0.07 Primary 4810 A Secondary 6.01 A 0.27 Sec

= = = =

160.00 A Primary I earth fault / CT ratio (160/800) 0.2 A Secondary

Time Multiplier Setting CHARACTERISTICS

=

IDMT Normal inverse

t Required operating time in seconds

=

Minimum grading time interval considered in sec

grading time + Downstream relay operating time

=

0.33

Fault current I Fault current at secondary

= =

TMS

= = = = = =

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

Maximum fault Current Operating time at Maximum fault Current Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

Maximum fault Current Operating time at Maximum fault Current

0.96

IDMT Normal inverse

3880 A I fault / CT ratio 4.85 (t *((If/IS)0.02 -1)) /0.14 (0.33*(((4.85/0.2)^0.02)-1))/0.14) 0.16 Primary 4820 A Secondary 6.03 A 0.31 Sec

From ETAP

From ETAP

From ETAP

From ETAP

Page 16 of 160

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 33kV Bus Coupler

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 33kV BUS COUPLER GE MODEL F650 BAY/FEEDER

F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.96 IEC Normal Inv 0.07

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 51N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.2 IEC Normal Inv 0.1

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 17 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 33kV INCOMER RELAY MAKE GE MODEL F650 BAY/FEEDER 2.4. Non Directional Overcurrent and Earth Fault Protection for 33kV Incomer CT Details CT Ratio CT Primary CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

= = = = = = = = = =

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

Operating time at Maximum fault Current Instantaneous Phase Overcurrent Setting For High set considering the 130% of through fault current t

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

IDMT Normal inverse grading time + Downstream relay operating time 0.52 From ETAP 3640.00 A I fault / CT ratio 4.55 A (t *((If/IS)0.02 -1)) /0.14 (0.52*(((4.55/1)^0.02)-1))/0.14)

= = =

Operating time at Maximum fault Current Instantaneous Earth Overcurrent Setting For High set considering the 200% of CT Primary Current t

Primary Secondary

0.12

5020.00 6.28 0.43

A A Sec

6592.69

A A Sec

8.241 0.250

Primary Secondary

From ETAP

= = = =

160.00 A Primary I earth fault / CT ratio (160/800) 0.200 A Secondary

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.56 From ETAP 3880.00 A I fault / CT ratio 4.85 (t *((If/IS)0.02 -1)) /0.14 (0.56*(((4.85/0.2)^0.02)-1))/0.14)

= = = = = =

Maximum fault Current

MVA kV kV A A 13.80%

= =

= = =

TMS

40 132.00 33.00 174.96 699.84 0.138

699.84 A i Load / CT ratio 0.87 769.82 0.96

= = = = = =

Maximum through fault Current

800-400/1 A 800 A 1 A PS

= = = = =

= = =

TMS

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33kV,40 MVA Trafo 33kV Side

= = =

0.26

5030.00 6.29 0.515

A A Sec

1600.00

A A Sec

2.000 0.100

Primary Secondary

From ETAP

Page 18 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 33kV INCOMER GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33kV,40 MVA Trafo 33kV Side

F650 GROUP-1 Non Directional Phase Overcurrent- 51 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.96 IEC Normal Inv 0.12

SETTING RANGE MAXIMUM MINIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Phase Overcurrent- 50 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 8.24 Definite Time 0.25

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 51N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.20 IEC Normal Inv 0.26

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Non Directional Earth Overcurrent- 50N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 2.00 Definite Time 0.10

SETTING RANGE MAXIMUM MINIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 19 of 160

132kV FEEDERS

Page 20 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 132/33kV TRANSFORMER(40MVA) RELAY MAKE GE MODEL F650 BAY/FEEDER 3.1. Non Directional Overcurrent and Earth Fault Protection for 132/33kV Transformer(40MVA) CT Details CT Ratio CT Primary CT Secondary Class

= = = =

Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Impedence Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

= = = = = =

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec Minimum Fault current I Fault current at secondary

Operating time at Maximum fault Current Instantaneous Phase Overcurrent Setting For High set considering the 130% of Through Fault current in HV Side

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

IDMT Normal inverse grading time + Downstream relay operating time 0.68 From ETAP 2970.00 A I fault / CT ratio 7.43 A (t *((If/IS)0.02 -1)) /0.14 (0.68*(((7.43/0.5)^0.02)-1))/0.14) 0.27 From ETAP 28280.00 A 70.70 0.37 Sec

= = =

Operating time at Maximum fault Current Instantaneous Earth Overcurrent Setting For High set considering the 200% of CT Primary Current t

A A Sec

Calculated

80.00 A Primary I earth fault / CT ratio (80/400) A Secondary 0.20

= =

IDMT Normal inverse grading time + Downstream relay operating time 0.77 From ETAP 3720.00 A I fault / CT ratio 9.30 (t *((If/IS)0.02 -1)) /0.14 (0.77*(((9.3/0.2)^0.02)-1))/0.14) 0.44 Primary Calculated 28990.00 A Secondary 72.48 A 0.488 Sec

= = = = = =

Maximum through fault Current

1648.17 4.12 0.30

Primary Secondary

= = = =

= = =

TMS

MVA kV kV A A 13.80%

= =

=

t

40 132.00 33.00 174.96 699.84 0.138

174.96 A i Load / CT ratio 0.44 192.46 0.48

= = = =

Maximum fault Current

800-400/1 A 400 A 1 A PS

= = = = =

= = =

TMS

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33kV,40 MVA Trafo 132kV Side

= = =

800.00 2.00 0.35

A A Sec

Page 21 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132/33kV TRANSFORMER(40MVA) GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33kV,40 MVA Trafo 132kV Side

Setting Table: F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 0.48 IEC Normal Inv 0.3

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Phase Overcurrent- 67 INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 4.12 Definite Time 0.30

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 0.2 IEC Normal Inv 0.44

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 2.0 Definite Time 0.35

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 22 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 132kV SIDE TRANSFORMER(160MVA) MAKE MODEL RELAY GE F650 BAY/FEEDER 3.2. Directional Overcurrent and Earth Fault Protection for 132kV Side of 220/132kV Transformer(160MVA) CT Details CT Ratio CT Primary CT Secondary Class

= = = =

Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

= = = = =

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220/132kV,160 MVA Trafo 132kV Side

800-400/1 A 800 A 1 A PS

160 220.00 132.00 419.90 699.84

MVA kV kV A A

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

699.84 A i Load / CT ratio 0.87 769.82 0.96

Time Multiplier Setting Characteristics

=

IDMT Normal inverse

t Required operating time in seconds

=

Minimum grading time interval considered in sec

grading time + Downstream relay operating time

=

0.70

Fault current I Fault current at secondary

= =

TMS

= = =

Instantaneous Phase Overcurrent Setting For High set considering the 130% of Through Fault current in HV Side t

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

= = =

Primary Secondary

3890.00 A I fault / CT ratio 4.86 A (t *((If/IS)0.02 -1)) /0.14 (0.7*(((4.86/1)^0.02)-1))/0.14) 0.17

7581.59 9.48 0.50

A A Sec

From ETAP

From ETAP

= = = =

160.00 A Primary I earth fault / CT ratio (160/800) A Secondary 0.20

Time Multiplier Setting CHARACTERISTICS

=

IDMT Normal inverse

t Required operating time in seconds

=

Minimum grading time interval considered in sec

grading time + Downstream relay operating time

=

0.72

Fault current I Fault current at secondary

= =

TMS

= = =

1400.00 A A I fault / CT ratio 1.75 (t *((If/IS)0.02 -1)) /0.14 (0.72*(((1.75/0.2)^0.02)-1))/0.14) 0.2

From ETAP

Instantaneous Earth Overcurrent Setting For High set considering the 200% of CT Primary Current t

= = =

1310.00 1965.00 2.46 0.60

A A Sec

Page 23 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV SIDE TRANSFORMER(160MVA) GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220/132kV,160 MVA Trafo 132kV Side

Setting Table: F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 0.96 IEC Normal Inv 0.17

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Phase Overcurrent- 67 INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 9.48 Definite Time 0.50

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 0.2 IEC Normal Inv 0.23

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 2.5 Definite Time 0.60

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 24 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 132kV LINE RELAY MAKE GE MODEL F650 BAY/FEEDER 3.3. Directional Overcurrent and Earth Fault Protection for 132kV Line CT Details CT Ratio CT Primary CT Secondary Class

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line

= = = =

800-400/1 A 400 A 1 A PS

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

400 A i Load / CT ratio 1.00 400.00 1.00

Time Multiplier Setting Characteristics

=

IDMT Normal inverse

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

Primary Secondary

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

= = =

1940 A I fault / CT ratio 4.85 A (t *((If/IS)0.02 -1)) /0.14 (0.65*(((4.85/1)^0.02)-1))/0.14) 0.15

= = = =

80.00 A Primary I earth fault / CT ratio (80/400) Secondary A 0.20

=

IDMT Normal inverse

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

Time Multiplier Setting CHARACTERISTICS

=

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

= = =

=

grading time + Zone-2 operating time 0.65 From ETAP

grading time + Downstream relay operating time 0.65 2390 A I fault / CT ratio 5.98 (t *((If/IS)0.02 -1)) /0.14 (0.65*(((5.98/0.2)^0.02)-1))/0.14) 0.33

From ETAP

Page 25 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting table

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line

F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING Enabled 45.00 Forward 40.00 1.00 IEC Normal Inv 0.15

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING Enabled -45.00 Forward 40.00 0.20 IEC Normal Inv 0.33

SETTING RANGE MAXIMUM MINIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 26 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM

3.4. Distance Protection for 132kV-30KM Line System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

132000V 400/1A 132000/110

132000 V 400.0 1200.0

0.33 ACSR PANTHER 400.0 30.0

Considered CT Ratio KM

0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

KM

22.80 0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Shortest Line details Protected OHL length 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 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

= = = = = = =

0.74

= = = =

132000/110 132000.0 110.0 50.0

= =

11.02

KM

11.00 0.167 0.432 0.46

68.8

O

56.9

O

0.406 0.622

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim 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. = Protected line reactance + Zone-2 setting limit 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

Page 27 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 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 = 7.15 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 2.20 = 0.73 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 3.89 2.7

0.73

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

4.98

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

5.56

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

6.33

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

3.84

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

Page 28 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

0.48 0.15

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.24 0.19 0.31

38.53

O

0.22

-30.29

O

= = = =

118800

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

400.000

171.48 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 7.15 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 68.8 O Power swing Forward Reach(outer) = 8.58 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 4.31 Ω Power swing Reverse Reach(outer) = 5.17 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 6.33 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 7.59 Ω (120% of inner Right blinder) Power swing inner Left blinder = 6.33 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 7.59 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

400.000

40.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

132000/110

1200.00 0.90*Nominal Volt

118800 118800/1200 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

30.00 Forward Quadrilateral 3.67 68.82 90.00 68.82 90.00 4.98 68.82 4.98 68.82 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 5.18 68.82 90.00 68.82 90.00 5.56 68.82 5.56 68.82 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 7.15 68.82 90.00 68.82 90.00 6.33 68.82 6.33 68.82 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 0.73 68.82 90.00 68.82 90.00 6.33 68.82 6.33 68.82 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(30KM) GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 3.67 68.82 90.00 68.82 90.00 4.98 68.82 4.98 68.82 0.00 0.22 -30.29

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 5.18 68.82 90.00 68.82 90.00 5.56 68.82 5.56 68.82 0.40 0.22 -30.29

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 7.15 68.82 6.33 68.82 6.33 68.82 0.80 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 0.73 68.82 6.33 68.82 6.33 68.82 0.50 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-30KM Recommended Setting Setting

Quadrilateral Two Step 0.60 7.15 8.58 68.82 4.31 5.17 7.59 7.59 6.33 6.33 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

pu pu S S S S S

S S S S S

pu pu S S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM

3.5. Distance Protection for 132kV-30KM Line System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

132000V 400/1A 132000/110

132000 V 400.0 1200.0

0.33 ACSR PANTHER 400.0 22.0

Considered CT Ratio KM

0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

KM

44.28 0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Shortest Line details Protected OHL length 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 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

= = = = = = =

0.74

= = = =

132000/110 132000.0 110.0 50.0

= =

8.08

KM

8.60 0.167 0.432 0.46

68.8

O

56.9

O

0.406 0.622

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim X1sec = Nct/Nvt * Xprim

2.69

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. = Protected line reactance + Zone-2 setting limit 0.85 * adjacent shortest line reactance = 4.22 = Zone-2 setting with 120% reach 3.80 Since 120%, 3.80 is lower than zone-2 limit. 4.22, 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 11.40 = Hence set X2 sec 3.80

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM

Zone 3 Settings For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line) = X3prim, reach 22.88 = 7.63 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 1.62 = 0.54 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 4.8 2.7

0.54

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

4.60

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

5.03

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

6.51

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

3.76

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

0.48 0.15

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.24 0.19 0.31

38.53

O

0.22

-30.29

O

= = = =

118800

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

400.000

171.48 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 7.63 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 68.8 O Power swing Forward Reach(outer) = 9.15 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 4.35 Ω Power swing Reverse Reach(outer) = 5.22 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 6.51 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 7.81 Ω (120% of inner Right blinder) Power swing inner Left blinder = 6.51 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 7.81 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

400.000

40.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

132000/110

1200.00 0.90*Nominal Volt

118800 118800/1200 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

22.00 Forward Quadrilateral 2.69 68.82 90.00 68.82 90.00 4.60 68.82 4.60 68.82 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 3.80 68.82 90.00 68.82 90.00 5.03 68.82 5.03 68.82 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 7.63 68.82 90.00 68.82 90.00 6.51 68.82 6.51 68.82 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 0.54 68.82 90.00 68.82 90.00 6.51 68.82 6.51 68.82 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 2.69 68.82 90.00 68.82 90.00 4.60 68.82 4.60 68.82 0.00 0.22 -30.29

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 3.80 68.82 90.00 68.82 90.00 5.03 68.82 5.03 68.82 0.40 0.22 -30.29

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 7.63 68.82 6.51 68.82 6.51 68.82 0.80 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 0.54 68.82 6.51 68.82 6.51 68.82 0.50 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(22KM) GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-22KM Recommended Setting Setting

Quadrilateral Two Step 0.60 7.63 9.15 68.82 4.35 5.22 7.81 7.81 6.51 6.51 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

pu pu S S S S S

S S S S S

pu pu S S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM

3.6. Distance Protection for 132kV-30KM Line System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

132000V 400/1A 132000/110

132000 V 400.0 1200.0

0.33 ACSR PANTHER 400.0 15.0

Considered CT Ratio KM

0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

KM

5.60 0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743

Adjacent Shortest Line details Protected OHL length 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 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

= = = = = = =

0.74

= = = =

132000/110 132000.0 110.0 50.0

= =

5.51

KM

5.60 0.167 0.432 0.46

68.8

O

56.9

O

0.406 0.622

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim X1sec = Nct/Nvt * Xprim

1.84

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. = Protected line reactance + Zone-2 setting limit 0.85 * adjacent shortest line reactance = 2.85 = Zone-2 setting with 120% reach 2.59 Since 120%, 2.59 is lower than zone-2 limit. 2.85, 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 7.78 = Hence set X2 sec 2.59

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM

Zone 3 Settings For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line) = X3prim, reach 9.23 = 3.08 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 1.10 = 0.37 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 6.01 2.7

0.40

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

4.27

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

4.56

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

4.75

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

3.70

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

0.48 0.15

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.24 0.19 0.31

38.53

O

0.22

-30.29

O

= = = =

118800

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

400.000

171.48 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 3.08 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 68.8 O Power swing Forward Reach(outer) = 3.69 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 1.91 Ω Power swing Reverse Reach(outer) = 2.29 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 4.75 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 5.70 Ω (120% of inner Right blinder) Power swing inner Left blinder = 4.75 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 5.70 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

400.000

40.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

132000/110

1200.00 0.90*Nominal Volt

118800 118800/1200 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

15.00 Forward Quadrilateral 1.84 68.82 90.00 68.82 90.00 4.27 68.82 4.27 68.82 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 2.59 68.82 90.00 68.82 90.00 4.56 68.82 4.56 68.82 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 3.08 68.82 90.00 68.82 90.00 4.75 68.82 4.75 68.82 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 0.37 68.82 90.00 68.82 90.00 4.75 68.82 4.75 68.82 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 1.84 68.82 90.00 68.82 90.00 4.27 68.82 4.27 68.82 0.00 0.22 -30.29

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 2.59 68.82 90.00 68.82 90.00 4.56 68.82 4.56 68.82 0.40 0.22 -30.29

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 3.08 68.82 4.75 68.82 4.75 68.82 0.80 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 0.37 68.82 4.75 68.82 4.75 68.82 0.50 0.22 -30.29

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132kV LINE PROTN(15KM) GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132kV Line-15KM Recommended Setting Setting

Quadrilateral Two Step 0.60 3.08 3.69 68.82 1.91 2.29 5.70 5.70 4.75 4.75 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

pu pu S S S S S

S S S S S

pu pu S S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132/33-40MVATRAFO DIFF PROTN MAKE GE MODEL T60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33-40 MVA Trafo

3.7. 40MVA.TRAFO DIFF. SETTING CALCULATION

Transformer Data: Rated Power, Prated

=

Rated Voltage HV, Vnom[1] LV, Vnom[2] % Impedance Vector Group 132kV SIDE Primary-winding 1, CT Ratio (Inom,a) 33kV SIDE Primary-winding 2, CT Ratio (Inom,b) OLTC Range on 132kV side

= = = =

40.0

MVA

132.0 kV kV 33.0 0.138 13.80% YN yn 0

=

400.0

= +

800.0 15.0

.

1.0

A

(800-400/1A)

1.0

A

(800-400/1A)

%

to Step Size Voltage at Min Tap Position Voltage at Max Tap Position Highest voltage tolerence, Vmax Lowest voltage tolerence,Vmin

= = = =

5.0 1.25 151.8 125.4

37.95 31.35

% Max Step

12.00

Min Step

4.00

kV kV kV kV

The reference winding is determined as follows, Rated current on winding 1- Irated Irated [1], Rated current on winding 2- Irated Irated [2],

= = =

Prated / (√3*Vnom[1] )

= = =

Prated / (√3*Vnom[2] )

(40*1000)/(1.732*132) 174.95 A

(40*1000)/(1.732*33)

699.82

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] = 400/174.95 Imargin[1], 2.29 = CT margin for windings 2, Imargin[2] = CT primary[2] / Irated[2] = 800/699.82 Imargin[2], 1.14 = Note: In the entire calculation primary and secondary windings are referred as winding "1" & "2" respectively. Since Imargin[2] < Imargin[1], the reference winding W ref is winding 2. 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.

Calculation of magnitude compensation factor (M), = magnitude compensation factor for winding [1], M[1] = 132kV side M[1], = = magnitude compensation factor for winding [2], M[2] = 33kV side M[2], =

IPrimary [1] × Vnom [1] / IPrimary [2] × Vnom[2] 400x132000/800x33000

2.00 IPrimary [2] × Vnom [2] / IPrimary [2] × Vnom[2] 800x33000/800x33000

1.00

Page 48 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 132/33-40MVATRAFO DIFF PROTN RELAY MAKE GE MODEL T60 BAY/FEEDER a) Calculating the minimum differential pickup current required for relay to operate,

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33-40 MVA Trafo

Criteria: 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) = No load current of the transformer primary current, 0.05×174.95 8.75 = A No load current refered to the CT secondary, = 8.7475/400 0.022 = A No load current to the relay after applying magnitude compendation factor M[1], IS1

= =

0.022×2

0.044

A

0.0 0.0

= side) No load current of the transf. winding2,(secondary IS2 = Differential current IdA,

= | Is1+Is2 | = |0.044+0 | 0.0440 Id A, = A Restraining current IrA, = max( | Is1|, |Is2 |) = max( |0.044|, |0 |) 0.0440 IrA, = A 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.

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 0.44 pu HV side (Winding -1) = 0.87 pu LV side (Winding -2) = 2 Hence we choose Break point-1 = pu 25% Slope -1 =

Differential / Restraint Current in the Tap Changer Extreme Position: 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

Corresponds on the CT2 secondary side to IN2

Corresponds on the CT1 secondary side to IN1

Object current in maximum tap position, IN2(+15%)

Corresponds on the CT2 secondary side to IN2

Differential current in maximum tap position IDiff

=

IN1 / CT1

= =

174.95/400 0.44 A

=

SN/(1.732 X Vmax)

= =

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

~

INobj

~

INobj

~

0.90

608.56

=

IN2(+15%) / CT2

= =

608.56/800 0.76 A

=

| IN2(+15%) - INobj |

= =

I0.905INobj-INobjl 0.10 INobj

INobj

Page 49 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132/33-40MVATRAFO DIFF PROTN MAKE GE MODEL T60 BAY/FEEDER

Restriant current in maximum tap position IRestaint

=

| IN2(+15%) + INobj |

= =

I0.905INobj+INobjl 1.90 INobj

Object current in minimum tap position, IN2(-5%)

=

SN/(1.732 X Vmin)

= =

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

736.67

=

IN2(-5%) / CT2

= =

736.67/800 0.92 A

Differential current in minimum tap position IDiff

=

| IN2(-5%) - INobj |

= =

I1.095INobj-INobjl 0.10 INobj

Restriant current in minimum tap position IRestaint

=

| IN2(-5%) + INobj |

= =

I1.095INobj+INobjl 2.10 INobj

Iop, Relay operating current at +15% tap,

= =

slope1 X Irest 0.25x1.905INObj

Corresponds on the CT2 secondary side to IN2

=

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33-40 MVA Trafo

0.48

~

1.10

INobj

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

whereas the Idiff , 0.1 INObj is less than 0.51 INObj . Hence the relay is Stable. 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 12.72 pu = External Fault current Break point- 2 Slope-2

= =

8 98%

pu (as per relay catalogue)

2nd HARMONICS: 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, 20% = INRUSH INHIBIT LEVEL, ADAPTIVE 2nd Harmonic 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 =

Page 50 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 132/33-40MVATRAFO DIFF PROTN MAKE GE MODEL T60 BAY/FEEDER

External fault condition: HV Side Fault Current LV Side Fault Current For safety margin we choosen instantaneous differential protection setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 132/33-40 MVA Trafo

II)

3.18 6.36

= =

8

pu pu pu

VOLTS PER HERTZ (OVER FLUX): 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. According to experience we set the definite time curve with the following settings,

Stage-1 Volts/Hz 1 Pickup, Volts/Hz 1 Curve, Volts /Hz 1 TD Multiplier, Volts/Hz 1 T-Reset,

= = = =

1.1 pu Definite Time 10.0 S 0.0 S

Volts/Hz 2 Pickup, Volts/Hz 2 Curve, Volts /Hz 2 TD Multiplier, Volts/Hz 2 T-Reset,

= = = =

1.2 pu Definite Time 1.0 S 0.0 S

Stage-2

Setting Table: Menu Text PERCENT DIFFERENTIAL PERCENT DIFFERENTIAL PICKUP PERCENT DIFFERENTIAL SLOPE1 PERCENT DIFFERENTIAL BREAK1 PERCENT DIFFERENTIAL BREAK2 PERCENT DIFFERENTIAL SLOPE2 2nd Harmonic INRUSH INHIBIT LEVEL 2nd Harmonic INRUSH INHIBIT MODE 2nd Harmonic INHIBIT FUNCTION OVEREXCITN INHIBIT FUNCTION OVEREXCITN INHIBIT LEVEL INST DIFFERENTIAL PICKUP VOLTS/HZ 1 VOLTS/HZ 1 PICKUP VOLTS/HZ 1 CURVE VOLTS/HZ 1 TD MULTIPLIER VOLTS/HZ 1 T-RESET VOLTS/HZ 2 VOLTS/HZ 2 PICKUP VOLTS/HZ 2 CURVE VOLTS/HZ 2 TD MULTIPLIER VOLTS/HZ 2 T-RESET

Setting Range Recomm.Setting 0.1 pu 0.25 2 pu 8 pu 0.98 0.2 PER PHASE Adaptive 5th 0.3 8 pu 1.1 pu Definite Time 10 s 0s 1.2 pu Definite Time 1s 0s

Min

Max

0.05 pu 1 pu 15% 1 1 pu 2 pu 30 pu 2 pu 1 50% 1% 0.4 perphase,2-out-of-3,Avg. Adaptive, Traditional,Disabled disabled,5th 1% 40% 2 pu 30 pu 0.8 pu Definite Time, IDMT 5% 0S 0.8 pu Definite Time, IDMT 5% 0S

4 pu 600 S 1000 S 4 pu 600 S 1000 S

Page 51 of 160

220kV FEEDERS

Page 52 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 160MVA TRANSFORMER 220kV SIDE RELAY MAKE GE MODEL F650 BAY/FEEDER 4.1. Directional Overcurrent and Earth Fault Protection for 160MVA Transformer(220kV Side) CT Details CT Ratio CT Primary CT Secondary Class

= = = =

Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side

= = = = =

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current, Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended Time Multiplier Setting Characteristics t Required operating time in seconds Minimum grading time interval considered in sec

IDMT Normal inverse grading time + Downstream relay operating time 0.62

TMS

= = = = = =

t

Time Multiplier Setting CHARACTERISTICS t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary

= = =

Operating time at Maximum fault Current Instantaneous Earth Overcurrent Setting For High set considering the 200% of CT Primary Current

4548.95 5.69 0.35

A A Sec

From ETAP

From ETAP

Calculated

=

IDMT Normal inverse

=

grading time + Downstream relay operating time 0.74 From ETAP 1420.00 A I fault / CT ratio 1.78 (t *((If/IS)0.02 -1)) /0.14 (0.74*(((1.78/0.2)^0.02)-1))/0.14) 0.24 From ETAP 25980.00 A 32.48 0.31 Sec

=

t

3660 A I fault / CT ratio 4.58 A (t *((If/IS)0.02 -1)) /0.14 (0.62*(((4.58/0.6)^0.02)-1))/0.14) 0.19 Primary 28160 A Secondary 35.20 A 0.30 Sec

160 A Primary I earth fault / CT ratio (160/800) A Secondary 0.20

= = = =

Maximum fault Current

Primary Secondary

= = = =

= = =

TMS

MVA kV kV A A

= =

= =

Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

160 220.00 132.00 419.90 699.84

419.90 A i Load / CT ratio 0.52 461.89 0.58

Fault current I Fault current at secondary

Operating time at Maximum fault Current Instantaneous Phase Overcurrent Setting For High set considering the 130% of Through Fault current in HV Side

800-400/1 A 800 A 1 A PS

= = = = =

=

Maximum fault Current

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220/132kV,160 MVA Trafo 220kV Side

= = =

1600.00 2.00 0.50

A A Sec

Page 53 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 160MVA TRANSFORMER 220kV SIDE GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220/132kV,160 MVA Trafo 220kV Side

F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 0.58 IEC Normal Inv 0.19

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 90

-90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Phase Overcurrent- 67 INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 45 Forward 40.00 5.69 Definite Time 0.35

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 0.2 IEC Normal Inv 0.24

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N INST MENU TEXT Phase Overcurrent Function MTA Direction Pol V Threshold Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled -45 Forward 40.00 2.0 Definite Time 0.50

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree

Forward/Reverse 0 0.05

300 160

0

900

1V 0.01 A 0.01

S

Page 54 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 220kV BUS COUPLER RELAY MAKE GE MODEL F650 BAY/FEEDER 4.2. Non Directional Overcurrent and Earth Fault Protection for 220kV Buscoupler CT Details CT Ratio CT Primary CT Secondary Class

= = = =

Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side

= = = = =

Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Bus Coupler

1600-800/1 A 1600 A 1 A PS

160 220 132 420 700

MVA kV kV A A

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

1600 A i Load / CT ratio 1.00 1600.00 1.00

Time Multiplier Setting Characteristics

=

IDMT Normal inverse

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

(220kV Line-3+220kV Line-4)

TMS

Maximum fault Current Operating time at Maximum fault Current Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected

Time Multiplier Setting CHARACTERISTICS

=

0.87

= = = = = =

= = = =

320.00 A Primary I earth fault / CT ratio (320/1600) A Secondary 0.20

=

IDMT Normal inverse

=

Fault current I Fault current at secondary

= =

TMS

= = = = = =

Operating time at Maximum fault Current

grading time

7980 A I fault / CT ratio 4.99 A (t *((If/IS)0.02 -1)) /0.14 (0.87*(((4.99/1)^0.02)-1))/0.14) 0.20 Primary 18150 A Secondary 11.34 A 0.57 Sec

t Required operating time in seconds Minimum grading time interval considered in sec

Maximum fault Current

Primary Secondary

=

From ETAP

From ETAP

grading time + Downstream relay operating time 0.56 6950 A I fault / CT ratio 4.34 (t *((If/IS)0.02 -1)) /0.14 (0.56*(((4.34/0.2)^0.02)-1))/0.14) 0.3 Primary 17460 A Secondary 10.91 A 0.43 Sec

From ETAP

From ETAP

Page 55 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY MAKE Setting Table:

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220kV BUS COUPLER GE MODEL F650 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Bus Coupler

F650 GROUP-1 Directional Phase Overcurrent- 67 MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 1.00 IEC Normal Inv 0.20

SETTING RANGE MINIMUM MAXIMUM

STEP SIZE

UNIT

Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT

F650 GROUP-1 Directional Earth Overcurrent- 67N MENU TEXT Phase Overcurrent Function Pickup Level Curve Time Dial Multiplier

RECOMMEND SETTING

Enabled 0.2 IEC Normal Inv 0.3

SETTING RANGE MAXIMUM MINIMUM Enabled/Disabled 0.05

160

0

900

0.01 A 0.01

S

Page 56 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 220kV LINE RELAY MAKE GE MODEL D60 BAY/FEEDER 4.3. Non Directional Overcurrent and Earth Fault Protection for 220kV Line CT Details CT Ratio CT Primary

= =

CT Secondary Class Transformer Data: Rated power Rated HV Voltage Rated LV Voltage Full Load current HV Side Full Load current LV Side Phase Over current setting O/C SETTING (51): The relay setting shall be such that it shall not operate for max. probable load current Load current I load CT secondary current,

= =

= = = = =

1600-800/1 A 1600 A 800 A 1 A PS

160 220 132 420 700

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line

For 10kM Line For 40 & 50kM Line

MVA kV kV A A

Consider 110% of transformer Full load Pickup Phase fault Secondary , recommended

= = = = =

1600 A i Load / CT ratio 1.00 1600.00 1.00

Time Multiplier Setting Characteristics

=

IDMT Normal inverse

=

= = = = = =

grading time + Downstream relay operating time 0.82 From ETAP 7980 A I fault / CT ratio 4.99 A (t *((If/IS)0.02 -1)) /0.14 (0.82*(((4.99/1)^0.02)-1))/0.14) 0.2 From ETAP Primary 28160 A Secondary 17.60 A 0.45 Sec

= = = =

320 A Primary I earth fault / CT ratio (320/1600) 0.20 A Secondary

=

IDMT Normal inverse

t Required operating time in seconds Minimum grading time interval considered in sec Fault current I Fault current at secondary TMS

Maximum fault Current Operating time at Maximum fault Current Earth Over current setting HV side In solidly earthed system a setting of 10 to 20% of CT Primary current is considered Setting of 20% is selected Time Multiplier Setting CHARACTERISTICS

= = =

t Required operating time in seconds Minimum grading time interval considered in sec

=

Fault current I Fault current at secondary

= =

TMS

Maximum fault Current Operating time at Maximum fault Current

=

= = = = = =

Primary Secondary

grading time + Downstream relay operating time 0.68 6950 A I fault / CT ratio 4.34375 (t *((If/IS)0.02 -1)) /0.14 (0.68*(((4.34/0.2)^0.02)-1))/0.14) 0.31 Primary 26870 A Secondary 16.79 A 0.47 Sec

From ETAP

From ETAP

Page 57 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220kV LINE MAKE GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line

Setting Table: D60 GROUP-1 Non Directional Phase Overcurrent- 51 RECOMMEND SETTING RANGE MENU TEXT SETTING MINIMUM MAXIMUM Phase Overcurrent Function Enabled Enabled/Disabled 160 Pickup Level 1.00 0.05 Curve IEC Normal Inv Time Dial Multiplier 0.19 0 900

F650 GROUP-1 Non Directional Earth Overcurrent- 51N RECOMMEND SETTING RANGE MENU TEXT SETTING MINIMUM MAXIMUM Phase Overcurrent Function Enabled Enabled/Disabled 0.2 Pickup Level 0.05 160 Curve IEC Normal Inv Time Dial Multiplier 0.31 0 900

STEP SIZE

UNIT

0.01 A 0.01

S

STEP SIZE

UNIT

0.01 A 0.01

S

Page 58 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km)

4.4. Distance Protection -220kV Line(50kM) System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

220000V 800/1A 220000/110

220000 V 800.0 2000.0

0.40 ACSR ZEBRA 800.0 50.0

Considered CT Ratio KM

0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

104.97 0.084 0.428 0.436 78.9 0.292 1.240 1.274 76.8

= = = = = = =

23.97 0.08 0.43

1.27

= = = =

220000/110 220000.0 110.0 50.0

= =

18.19

KM

O

O

Adjacent Shortest Line details Protected OHL length 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 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

0.44

KM

78.9

O

76.8

O

0.29 1.24

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim X1sec = Nct/Nvt * Xprim

7.28

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. = (Protected line reactance + Zone-2 setting limit 0.85 * adjacent shortest line reactance) = 12.05 = Zone-2 setting with 120% reach 10.272 Since 120%, 10.272 is lower than zone-2 limit. 12.048, 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 25.68 = Hence set X2 sec 10.27

Page 59 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

MAKE

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km)

Zone 3 Settings For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line) = X3prim, reach 43.86 = 17.55 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 3.64 = 1.46 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 3.66 4.5

1.33

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

5.69

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

6.28

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

8.39

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

4.55

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km)

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

0.83 0.63

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.21 0.81 0.84

75.62

O

0.64

-3.30

O

= = = =

198000

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

800.000

142.90 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 17.55 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 78.9 O Power swing Forward Reach(outer) = 21.05 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 10.23 Ω Power swing Reverse Reach(outer) = 12.27 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 8.39 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 10.06 Ω (120% of inner Right blinder) Power swing inner Left blinder = 8.39 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 10.06 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km)

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

220000/110

2000.00 0.90*Nominal Volt

198000 198000/2000 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km)

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

50.00 Forward Quadrilateral 7.28 78.92 90.00 78.92 90.00 5.69 78.92 5.69 78.92 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 10.27 78.92 90.00 78.92 90.00 6.28 78.92 6.28 78.92 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 17.55 78.92 90.00 78.92 90.00 8.39 78.92 8.39 78.92 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 1.46 78.92 90.00 78.92 90.00 8.39 78.92 8.39 78.92 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km) Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 7.28 78.92 90.00 78.92 90.00 5.69 78.92 5.69 78.92 0.00 0.64 -3.30

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 10.27 78.92 90.00 78.92 90.00 6.28 78.92 6.28 78.92 0.40 0.64 -3.30

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 17.55 78.92 8.39 78.92 8.39 78.92 0.80 0.64 -3.30

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 1.46 78.92 8.39 78.92 8.39 78.92 0.50 0.64 -3.30

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50Km) Recommended Setting Setting

Quadrilateral Two Step 0.60 17.55 21.05 78.92 10.23 12.27 10.06 10.06 8.39 8.39 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S pu pu S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

S S

S S S S S

pu pu S S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM)

4.5. Distance Protection -220kV Line(40kM) System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

220000V 800/1A 220000/110

220000 V 800.0 2000.0

0.40 ACSR ZEBRA 800.0 40.0

Considered CT Ratio KM

0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

KM

81.85 0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274

Adjacent Shortest Line details Protected OHL length 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 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

= = = = = = =

1.27

= = = =

220000/110 220000.0 110.0 50.0

= =

14.55

KM

5.77 0.08 0.43 0.44

78.9

O

76.8

O

0.29 1.24

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim X1sec = Nct/Nvt * Xprim

5.82

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. = Protected line reactance + Zone-2 setting limit 0.85 * adjacent shortest line reactance = 7.69 = Zone-2 setting with 120% reach 8.22 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 = Hence set X2 prim 18.35 = Hence set X2 sec 7.34

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM)

Zone 3 Settings For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line) = X3prim, reach 41.56 = 16.63 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 2.91 = 1.16 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 4.18 4.5

1.10

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

5.40

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

5.87

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

7.52

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

4.49

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM)

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

0.83 0.63

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.21 0.81 0.84

75.62

O

0.64

-3.30

O

= = = =

198000

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

800.000

142.90 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 16.63 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 78.9 O Power swing Forward Reach(outer) = 19.95 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 9.48 Ω Power swing Reverse Reach(outer) = 11.37 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 7.52 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 9.02 Ω (120% of inner Right blinder) Power swing inner Left blinder = 7.52 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 9.02 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM)

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

220000/110

2000.00 0.90*Nominal Volt

198000 198000/2000 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM)

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

40.00 Forward Quadrilateral 5.82 78.92 90.00 78.92 90.00 5.40 78.92 5.40 78.92 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 7.34 78.92 90.00 78.92 90.00 5.87 78.92 5.87 78.92 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 16.63 78.92 90.00 78.92 90.00 7.52 78.92 7.52 78.92 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 1.16 78.92 90.00 78.92 90.00 7.52 78.92 7.52 78.92 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM) Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 5.82 78.92 90.00 78.92 90.00 5.40 78.92 5.40 78.92 0.00 0.64 -3.30

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 7.34 78.92 90.00 78.92 90.00 5.87 78.92 5.87 78.92 0.40 0.64 -3.30

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 16.63 78.92 7.52 78.92 7.52 78.92 0.80 0.64 -3.30

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 1.16 78.92 7.52 78.92 7.52 78.92 0.50 0.64 -3.30

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(40kM) Recommended Setting Setting

Quadrilateral Two Step 0.60 16.63 19.95 78.92 9.48 11.37 9.02 9.02 7.52 7.52 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

pu pu S S S S S

S S S S S

pu pu S S

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM)

4.6. Distance Protection -220kV Line(10kM) System Details for 220kV line Nominal system voltage,UN Current transformer ratio,Nct Voltage transformer ratio,Nvt Ratio of secondary to primary impedance,Nct/Nvt Protected OHL Type Current rating in Amps Protected OHL length 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 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

= = = = = = = = = = = = =

220000V 800/1A 220000/110

220000 V 800.0 2000.0

0.40 TWIN ACSR ZEBRA 800.0 10.0

Considered CT Ratio KM

0.022 0.290 0.291

85.6

O

73.8

O

0.284 0.978 1.019

Adjacent Longest Line details Protected OHL length 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 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

= = = = = = =

KM

10.00 0.022 0.290 0.291

85.6

O

73.8

O

0.284 0.978 1.019

Adjacent Shortest Line details Protected OHL length 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 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

= = = = = = =

1.02

= = = =

220000/110 220000.0 110.0 50.0

= =

2.47

KM

10.00 0.02 0.29 0.29

85.6

O

73.8

O

0.284 0.978

PT Details: PT Ratio PT Primary Voltage PT Secondary Voltage System Frequency

V V V HZ

Distance element Settings: Reactance settings Zone 1 Settings Required Zone 1 reach is to be 85% of the Protected line X1prim = 85% * Xprim X1sec = Nct/Nvt * Xprim

0.99

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. = Protected line reactance + Zone-2 setting limit 0.85 * adjacent shortest line reactance = 2.15 = Zone-2 setting with 120% reach 1.39 Since 120%, 1.39 is lower than zone-2 limit. 2.15, 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 3.48 = Hence set X2 sec 1.39

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Zone 3 Settings For Zone3 setting , it is customery to select 1.2 (Protected line + 50% Adjacent Longest line) = X3prim, reach 5.22 = 2.09 X3sec = Nct/Nvt * X3prim*IN/A

Zone 4 Settings For Zone4 setting, reverse reach impedence is typically 20% Zone 1 reach Impedance. = X4prim, reach 0.49 = 0.20 X4sec = Nct/Nvt * X4prim*IN/A

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) Ω = 63.51 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

=

38.11

Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81

Ω secondary

Ra Where: If L Ra fault current Conductor spaces Primary resistive coverage for phase faults

= = = = = = =

(28710 x L) / If^1.4 Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). 7.98 4.5

0.45

(RARC is RTFT Tower Foot Resistance

= =

1.325

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

=

4.34

Zone-2 setting(same way as done above for X reach) R2 sec = R2sec + 0.5RARC+ RTFT

=

4.37

Zone-3 setting(same way as done above for X reach) R3 sec = R3sec + 0.5RARC+ RTFT

=

4.43

Zone-4 setting(same way as done above for X reach) R4 sec = R4sec + 0.5RARC+ RTFT

=

4.28

=

0.00

Time setting Zone-1 setting Zone-2 setting

kA mtrs Ω Ω 10 Ω

sec

zone-2 time delay should be set to discreminative with the primary line protection of the next line sections including circuit breaker trip time = 0.040 Adjoining line protection operating time = 0.080 Breaker opening time = 0.030 Local relay reset = 0.250 Grading margin = 0.40 Required zone-2 time delay = 0.40 sec set zone-2 at

Zone-3 setting zone-3 time delay shall be such that zone-2 time delay plus grading margin = zone-2 time delay = Grading margin = Required zone-3 time delay = set zone-3 at

0.400 0.400

0.80 0.80

sec

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM)

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 = 0.200 LBB time delay = 0.250 Grading margin = 0.45 Required zone-4 time delay = 0.50 sec set zone-4 at

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

= =

3.91 0.79

R0-R1 X0-X1 Z0-Z1 Z0/Z1 MAG & ANGLE= (Z0-Z1)/3Z1

= = = =

0.26 0.69 0.74

69.19

O

0.84

-16.41

O

= = = =

198000

=

40.01

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 value Rload prim = Umin/√3*ILmax Where Umin = minimum operating voltage, 0.9*UN ILmax = max load current Hence Rload prim Rload sec The setting shall be applied 30% lower than calculated above

800.000

142.90 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) O Øload- max = 26.00

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 Power swing Forward Reach(inner) = 2.09 Ω (considered zone-3 reactance boundary) Power swing Forward RCA = 85.6 O Power swing Forward Reach(outer) = 2.51 Ω (120% of inner Reach)

(typical setting from manual)

Power swing Reverse Reach(inner) is considered as 50% zone-3 Reactance Reach + zone-4 Reactance Reach Power swing Reverse Reach(inner) = 1.24 Ω Power swing Reverse Reach(outer) = 1.49 Ω (120% of Reverse inner Reach) Power swing inner Right blinder = 4.43 Ω (considered zone-3 resistive boundary) Power swing outer Right blinder = 5.31 Ω (120% of inner Right blinder) Power swing inner Left blinder = 4.43 Ω (considered zone-3 resistive boundary) Power swing outer Left blinder = 5.31 Ω (120% of inner Left blinder)

VT Fuse fail Function enabled

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM)

Broken Conductor Protection Full load current Considered I2 I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A

(10% of fullload current)

% 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

Select Under voltage setting, 27

Time delay setting , 27

= = = = = = ≈ =

220000/110

2000.00 0.90*Nominal Volt

198000 198000/2000 99.000 0.90 3.00

v

90% OF Rated Voltage

V pu s

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DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM)

Settings Table Menu text PHASE DISTANCE ELEMENTS Line setting

Recommended Setting Setting

Unit

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

10.00 Forward Quadrilateral 0.99 85.60 90.00 85.60 90.00 4.34 85.60 4.34 85.60 0.00 0.34

km

Ω DEG DEG DEG DEG Ω DEG Ω DEG S pu

PHASE DIST Z2 DIR PHASE DIST SHAPE PHS DIST Z2 REACH PHS DIST Z2 RCA PHS DIST Z2 COMP LIMIT PHS DIST Z2 DIR RCA PHS DIST Z2 DIR COMP LIMIT PHS DIST Z2 QUAD RGT BLD PHS DIST Z2 QUAD RGT BLD RCA PHS DIST Z2 QUAD LFT BLD PHS DIST Z2 QUAD LFT BLD RCA PHASE DIST Z2 DELAY

Forward Quadrilateral 1.39 85.60 90.00 85.60 90.00 4.37 85.60 4.37 85.60 0.40

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z3 DIR PHASE DIST SHAPE PHS DIST Z3 REACH PHS DIST Z3 RCA PHS DIST Z3 COMP LIMIT PHS DIST Z3 DIR RCA PHS DIST Z3 DIR COMP LIMIT PHS DIST Z3 QUAD RGT BLD PHS DIST Z3 QUAD RGT BLD RCA PHS DIST Z3 QUAD LFT BLD PHS DIST Z3 QUAD LFT BLD RCA PHASE DIST Z3 DELAY

Forward Quadrilateral 2.09 85.60 90.00 85.60 90.00 4.43 85.60 4.43 85.60 0.80

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

PHASE DIST Z4 DIR PHASE DIST SHAPE PHS DIST Z4 REACH PHS DIST Z4 RCA PHS DIST Z4 COMP LIMIT PHS DIST Z4 DIR RCA PHS DIST Z4 DIR COMP LIMIT PHS DIST Z4 QUAD RGT BLD PHS DIST Z4 QUAD RGT BLD RCA PHS DIST Z4 QUAD LFT BLD PHS DIST Z4 QUAD LFT BLD RCA PHASE DIST Z4 DELAY

Reverse Quadrilateral 0.20 85.60 90.00 85.60 90.00 4.43 85.60 4.43 85.60 0.50

Ω DEG DEG DEG Ω DEG Ω DEG S

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POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION GE MODEL D60 BAY/FEEDER

Menu text PHASE DISTANCE ELEMENTS Line setting

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM) Recommended Setting Setting

Unit

Ω DEG DEG DEG DEG Ω DEG Ω DEG S

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z1 DIR SHAPE Z1 REACH Z1 RCA Z1 COMP LIMIT Z1 DIR RCA Z1 DIR COMP LIMIT Z1 QUAD RGT BLD Z1 QUAD RGT BLD RCA Z1 QUAD LFT BLD Z1 QUAD LFT BLD RCA Z1 DELAY Z1 Z0/Z1 MAG Z1 Z0/Z1 ANG

Forward Quadrilateral 0.99 85.60 90.00 85.60 90.00 4.34 85.60 4.34 85.60 0.00 0.84 -16.41

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z2 DIR SHAPE Z2 REACH Z2 RCA Z2 COMP LIMIT Z2 DIR RCA Z2 DIR COMP LIMIT Z2 QUAD RGT BLD Z2 QUAD RGT BLD RCA Z2 QUAD LFT BLD Z2 QUAD LFT BLD RCA Z2 DELAY Z2 Z0/Z1 MAG Z2 Z0/Z1 ANG

Forward Quadrilateral 1.39 85.60 90.00 85.60 90.00 4.37 85.60 4.37 85.60 0.40 0.84 -16.41

Ω DEG DEG DEG DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z3 DIR SHAPE Z3 REACH Z3 RCA Z3 QUAD RGT BLD Z3 QUAD RGT BLD RCA Z3 QUAD LFT BLD Z3 QUAD LFT BLD RCA Z3 DELAY Z3 Z0/Z1 MAG Z3 Z0/Z1 ANG

Forward Quadrilateral 2.09 85.60 4.43 85.60 4.43 85.60 0.80 0.84 -16.41

Ω DEG Ω DEG Ω DEG S Ω DEG

GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST GND DIST

Z4 DIR SHAPE Z4 REACH Z4 RCA Z4 QUAD RGT BLD Z4 QUAD RGT BLD RCA Z4 QUAD LFT BLD Z4 QUAD LFT BLD RCA Z4 DELAY Z4 Z0/Z1 MAG Z4 Z0/Z1 ANG

Reverse Quadrilateral 0.20 85.60 4.43 85.60 4.43 85.60 0.50 0.84 -16.41

Ω DEG Ω DEG Ω DEG S Ω DEG

0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S

LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT LOAD ENCROACHMENT

MIN VOLT REACH ANGLE PKP DELAY RST DELAY

DEG

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Menu text PHASE DISTANCE ELEMENTS 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 PICKUP DELAY2 POWER SWING PICKUP DELAY3 POWER SWING PICKUP DELAY4 POWER SWING SEAL IN DELAY POWER SWING TRIP MODE LINE PICKUP (SOTF)

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(10kM) Recommended Setting Setting

Quadrilateral Two Step 0.60 2.09 2.51 85.60 1.24 1.49 5.31 5.31 4.43 4.43 0.03 0.05 0.02 0.01 0.02 0.40 Delayed

Unit

pu Ω DEG Ω Ω Ω Ω Ω Ω S S S S S S S

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 FUSE FAILURE

1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled

FUNCTION AUTO RECLOSE

Enabled

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 BREAKER FAILURE 1

Enabled 1 pole 1.00 0.20 10.00 25.00 Lockout 2.00 1.00 1.00

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 BROKEN CONDUCTOR (F650 RELAY)

Enabled 3-Pole SRC1 Yes Yes 0.20 0.20 Yes 0.20 0.00

TAP LEVEL IN PERCENTAGE OF I2/I1 TRIP TIME UNDERVOLTAGE

20.00 5.00

% S

Enabled Phase to Phase 0.90 3.00

pu s

PHASE UV1 FUNCTION PHASE UV1 MODE PHASE UV1 PICKUP PHASE UV1 DELAY

pu pu S S S S S

S S S S S

pu pu S S

Page 79 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

4.7. Distance protection MAIN-2 CT Details CT Ratio CT Primary CT Secondary CTR Class

= = = = =

800/1A 800 1 800 PS

A A

System Details VT Ratio

= = = =

VT Primary VT Secondary PTR Frequency Maximum fault current

= =

220kV/√3 110V/√3 220000 V 110 V 2000.00 50HZ 3.66kA

OHL Details Condutor type Line Length Line impedence Positive sequence impedence (Z1) Zero sequence impedence ( Z0 ) Line Length

= =

ZEBRA 50km

= = =

Current rating in Amps Line impedences

=

0.084 0.292 50 800

Z1

=

0.436

L 78.920 Ω/km

Z0

=

1.274

L 76.750 Ω/km

Z0/Z1

=

2.921

L

-2.170 °

+j +j

0.428 1.240

+j +j

0.428 1.240

km

Adjacent Longest Line details Condutor type Line Length Line impedence Positive sequence impedence (Z1) Zero sequence impedence ( Z0 ) Line Length Line impedences Z1 Z0

Zebra 104.97km 0.084 0.292 104.970 = =

km L 78.920 Ω/km L 76.750 Ω/km

0.436 1.274

Adjacent Shortest Line details Zebra 23.97km

Condutor type Line Length Line impedence Positive sequence impedence (Z1) Zero sequence impedence ( Z0 ) Line Length Line impedences Z1

=

0.436

L 78.920 Ω/km

Z0

=

1.274

L 76.750 Ω/km

0.084 0.292 23.970

+j +j

0.428 1.240

km

Page 80 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

Relay settings Line impedence Ratio of secondary to primary impedence

=

CT ratio / VT ratio (800/2000)

Line impedence secondary

=

ratio CT/VT x line impedence primary 0.4*50*0.436

0.40

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 Required Zone 1 reach is to be 85% of the Protected line Zone 1 Reach (0.85*8.72) = Z1 7.41 = The Line Angle 79.00 = Therefore actual Zone 1 reach, Z1 7.41 =

L

79.00

Ω secondary

L

79.00

Ω secondary

L L

79.00

Ω secondary

Zone 2 Phase Reach Settings Required Zone 2 reach is to be 120% of the Protected line Zone 2 Reach

=

Actual Zone 2 reach, Z2

=

(1.2*8.723)

10.47 10.47

79.00

Zone 3 Phase Reach Settings 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 = L 79.00 Ω secondary 21.45 = Actual Zone 3 reach, Z3 L 79.00 21.45 =

Zone 4 Reverse Reach Settings Required Zone4 reverse reach impedence,typically 20% Zone 1 reach 0.2*7.414 = Z4 1.48 =

L

79.00

Ω secondary

ZONE TIMER SETTING: tZ1

=

0

s

tZ2

=

0.40

s

tZ3

=

0.80

s

tZ4

=

0.50

s

Residual Compensation for Earth Fault Element 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. │kZ0│ L kZ0

= =

(Z0-Z1) / 3Z1 L (Z0-Z1) /3Z1

Z0-Z1

= =

(Z0-Z1) / 3Z1

=

(0.292+j1.24)-(0.0838+j0.428) 0.2082 +j 0.812 L 75.62 ° 0.84 L75.62-78.92 (0.838/(3*0.436)) L -3.30 ° 0.64

│kZ0│ L kZ0

= =

kZ0 Res. Comp, kZ0 Angle,

kZ0 Res. Comp, kZ0 Angle,

0.64 -3.30

°

Page 81 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

Resistive Reach Calculations Minimum Load impedence to the relay

=

Vn (phase - neutral) / In

= (110V/√3 /1) = 63.51 Ω secondary Typically,phase fault distance zones would avoid the minimum load impedence by a margin of ≥ 40%,earth fault zones would use a ≥ 20% margin. Minimum Load impedence to the relay

This allows maximum resistive reaches for Phase faults

=

38.11 Ω secondary

This allows maximum resistive reaches for Earth faults

=

50.81 Ω secondary

Where:

Ra = (28710 x L) / If^1.4 If L Ra fault current Conductor spaces

Primary resistive coverage for phase faults

= = = = = =

Minimum expected phase-phase fault current (A); Maximum phase conductor separation (m); Arc resistance, calculated from the van Warrington formula (W). kA 3.660 mtrs 4.500 Ω 1.33

assuming a typical earth fault coverage

=

40.00

RPH (min) RG (min)

= =

1.325*0.4 40*0.4

Ω 0.530 Ω 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 Phase (RPh)Ω 30.48 0.53 38.11 19.51 24.39 38.11 Earth (RG)Ω 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 Considering power swing frequency and load impedence and angle between sources,the ∆R becomes ∆R = 0.16*Rload (min) 0.16*63.51*0.6 (40% of margin is considered) (this value is well within the min&max limits above) = 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 = A 4.58 maximum setting for Imax line> = 0.8 x (min.phase fault current level) = A 3.66 A Hence setting for Imax line> = 3.66

Broken Conductor Protection Full load current I2 / I1 Allow for tolerences and load varations I2 / I1 time delay

= = = = = =

800 80.00 0.10

A A

(10% of fullload current)

200%

0.20 60.00

s

Page 82 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

SOTF SOTF Protection operates 120% of fault current with breaker closing command Fault current = A 3660 = 1.2*3660 = 4392 = A 5.5

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.

Number of Shots 1P Dead Time Healthy Window Reclaim Time Discrimination Time A/R Inhibit Window Block auto-recloser

= = = = = =

AR Close pulse length

=

1 1 5 25 5 5

s s s s s

11111111

0.20

11111111 s

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. CB Fail 1 Timer I< Current Set

= =

0.20 0.20

s In

Setting Recommendation for Under Voltage PT Ratio Under voltage

Select Under voltage setting, 27 Time delay setting , 27

= = = = = = = =

220000/110

2000.00 0.90 * Nominal 0.9x220000

198000

90

%

v

198000/2000

99 3

V s

Page 83 of 160

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

Settings Table Menu text GROUP1 DISTANCE ELEMENTS Line setting Line Length Line Impedence Line Angle Zone setting Zone status KZ1 Res Comp KZ1 Angle Z1 R1G R1ph tZ1 KZ2 Res Comp KZ2 Angle Z2 R2G R2ph tZ2 KZ3/4 Res Comp KZ3/4 Angle Z3 R3G -R4G R3ph - R4ph tZ3 Z4 tZ4 GROUP1 POWER SWING Delta R Delta X IN>Status IN>(%Imax) I2>Status I2>(%Imax) Imax line>Status Imax line> Unblocking Time delay Blocking Zones GROUP 1 AUTORECLOSE AUTORECLOSE MODE 1P Trip Mode Max number of shots 1P - Dead Time 1(HSAR) Healthy window Reclaim Time Discrimination Time A/R Inhibit Window Close Pulse Time AUTORECLOSE LOCKOUT Block A/R LOCAL BREAKER BACKUP PROTECTION CB Fail & I< Breaker Fail CB Fail 1 Timer I< Current Set

Settimg Recommenmded

Unit

50.00 8.72 79.00

km Ω

0.64 -3.30 7.41 21.43 19.51 0.00 0.64 -3.30 10.47 28.58 24.39 0.40 0.64 -3.30 21.45 38.11 30.48 0.80 1.48 0.50

Ω

6.10 6.10 Enabled 0.40 Enabled 0.30 Enabled 3.66 30.00 0'0'0'0'0'0'0'0

Ω Ω

Single 1.00 1.00 5.00 25.00 5.00 5.00 0.20 11111111

0.20 0.20

Ω Ω Ω s Ω Ω Ω Ω s Ω Ω Ω Ω s Ω s

A s

s s s s s s 11111111

s 0.00

Page 84 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: TITLE: RELAY

POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR DISTANCE PROTECTION MAKE Alstom MODEL P442 BAY/FEEDER

DOCUMENT No. VE-J108-D-E212 DATE 16.09.13 PRPD: MN CKD: GP 220kV Line(50KM)

GROUP 1 VOLT Protection V