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


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



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



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

= =


= = = = = =

TMS



= = =

t

0.2

1540.83 1.541 0.200

A A Sec


= =


= = =


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


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



RECOMMEND SETTING



STEP SIZE

UNIT


160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



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

= =


= = = = = =

TMS



= = =

t

0.2

2184.13 2.184 0.200

A A Sec


= =


= = =


Primary Secondary

= = = =

= = =

TMS


= = =

0.3

1000.00 1.000 0.200

A A Sec

Page 7 of 160


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



RECOMMEND SETTING



STEP SIZE

UNIT


160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



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

= =


= = = = = =

TMS


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



STEP SIZE

UNIT


160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



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

=


=

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


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


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


STEP SIZE

UNIT


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


= = = = =

400 A i Load / CT ratio 1.00 400.00 1.00


=

IDMT Normal inverse



Primary 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

= = = =




=

grading time + Downstream relay operating time 0.10 From ETAP

From ETAP

=


=


= =

TMS

= = = = = =


=

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



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


RECOMMEND SETTING



STEP SIZE

UNIT


1 Degree

90 Forward/Reverse

0 0.05

300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING

Enabled -45 Forward 40.00 0.2 IEC Normal Inv 0.06

SETTING RANGE MINIMUM MAXIMUM Enabled/Disabled -90

90

1 Degree


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



= = = = =

769.82294

Primary Secondary


=

t Required operating time in seconds

=

Minimum grading time interval considered in sec

grading time + Downstream relay operating time

=

0.32


= =

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

= = = =



=

IDMT Normal inverse


=



=

0.33


= =

TMS

= = = = = =




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



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


RECOMMEND SETTING



STEP SIZE

UNIT


160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



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


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

= = = =


= =


= = = = = =

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


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



RECOMMEND SETTING


SETTING RANGE MAXIMUM MINIMUM

STEP SIZE

UNIT


160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



160

0

900

0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING


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


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


= =

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

= = = =


800-400/1 A 400 A 1 A PS

= = = = =

= = =

TMS


= = =

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


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



STEP SIZE

UNIT


90

1 Degree


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


90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


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


90

1 Degree


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,

= = = = =


800-400/1 A 800 A 1 A PS

160 220.00 132.00 419.90 699.84

MVA kV kV A A


= = = = =

699.84 A i Load / CT ratio 0.87 769.82 0.96


=

IDMT Normal inverse


=



=

0.70


= =

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

= = = =



=

IDMT Normal inverse


=



=

0.72


= =

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


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


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



STEP SIZE

UNIT


90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


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


= = = =

800-400/1 A 400 A 1 A PS


= = = = =

400 A i Load / CT ratio 1.00 400.00 1.00


=

IDMT Normal inverse


Primary 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



=


=


= =

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



RECOMMEND SETTING Enabled 45.00 Forward 40.00 1.00 IEC Normal Inv 0.15


STEP SIZE

UNIT


90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


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


300 160

0

900

1V 0.01 A 0.01

S

Page 26 of 160


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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

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

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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 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


=

5.56


=

6.33


=

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

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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

Page 29 of 160


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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

Page 30 of 160


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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





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

Page 31 of 160


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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 132kV Line-30KM Recommended Setting Setting

Unit


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




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



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


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

Page 32 of 160


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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)


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

Page 33 of 160


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

132000V 400/1A 132000/110

132000 V 400.0 1200.0

0.33 ACSR PANTHER 400.0 22.0


0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743


= = = = = = =

KM

44.28 0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743


= = = = = = =

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


V V V HZ


2.69


Page 34 of 160


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=

38.11

Ω secondary


=

50.81

Ω secondary


= = = = = = =


0.54


= =

1.325


=

4.60


=

5.03


=

6.51


=

3.76

=

0.00



sec



0.400 0.400

0.80 0.80

sec

Page 35 of 160


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= =

0.48 0.15


= = = =

0.24 0.19 0.31

38.53

O

0.22

-30.29

O

= = = =

118800

=

40.01



400.000

171.48 57.16






Page 36 of 160


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= = = = = =

400.000

40.00 0.10 200% 20.00 5.00

A A


% s






= = = = = = ≈ =

132000/110


118800 118800/1200 99.000 0.90 3.00

v


V pu s

Page 37 of 160


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Unit



km











Page 38 of 160


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Unit

















0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S



DEG

Page 39 of 160


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Unit



1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled


Enabled






20.00 5.00

% S


pu s


pu pu S S S S S

S S S S S

pu pu S S

Page 40 of 160


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

132000V 400/1A 132000/110

132000 V 400.0 1200.0

0.33 ACSR PANTHER 400.0 15.0


0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743


= = = = = = =

KM

5.60 0.167 0.432 0.463

68.8

O

56.9

O

0.406 0.622 0.743


= = = = = = =

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


V V V HZ


1.84


Page 41 of 160


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=

38.11

Ω secondary


=

50.81

Ω secondary


= = = = = = =


0.40


= =

1.325


=

4.27


=

4.56


=

4.75


=

3.70

=

0.00



sec



0.400 0.400

0.80 0.80

sec

Page 42 of 160


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= =

0.48 0.15


= = = =

0.24 0.19 0.31

38.53

O

0.22

-30.29

O

= = = =

118800

=

40.01



400.000

171.48 57.16






Page 43 of 160


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= = = = = =

400.000

40.00 0.10 200% 20.00 5.00

A A


% s






= = = = = = ≈ =

132000/110


118800 118800/1200 99.000 0.90 3.00

v


V pu s

Page 44 of 160


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Unit



km











Page 45 of 160


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Unit

















0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S



DEG

Page 46 of 160


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Unit



1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled


Enabled






20.00 5.00

% S


pu s


pu pu S S S S S

S S S S S

pu pu S S

Page 47 of 160


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] )

= = =


(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,


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


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


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



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 |

= =


Restriant current in minimum tap position IRestaint

=

| IN2(-5%) + INobj |

= =


Iop, Relay operating current at +15% tap,

= =

slope1 X Irest 0.25x1.905INObj


=


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,

= = =


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



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


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,

= = = =


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

= = = =


Primary Secondary

= = = =

= = =

TMS

MVA kV kV A A

= =

= =


160 220.00 132.00 419.90 699.84

419.90 A i Load / CT ratio 0.52 461.89 0.58


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

= = = = =

=



= = =

1600.00 2.00 0.50

A A Sec

Page 53 of 160


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



RECOMMEND SETTING



STEP SIZE

UNIT

Enabled/Disabled 90

-90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


300 160

0

900

1V 0.01 A 0.01

S

STEP SIZE

UNIT


RECOMMEND SETTING



90

1 Degree


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

= = = = =



1600-800/1 A 1600 A 1 A PS

160 220 132 420 700

MVA kV kV A A


= = = = =

1600 A i Load / CT ratio 1.00 1600.00 1.00


=

IDMT Normal inverse


=


= =

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

TMS



=

0.87

= = = = = =

= = = =


=

IDMT Normal inverse

=


= =

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



Primary Secondary

=

From ETAP

From ETAP


From ETAP

From ETAP

Page 55 of 160


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


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

RECOMMEND SETTING



STEP SIZE

UNIT


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


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


For 10kM Line For 40 & 50kM Line

MVA kV kV A A


= = = = =

1600 A i Load / CT ratio 1.00 1600.00 1.00


=

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

= = =


=


= =

TMS


=

= = = = = =

Primary Secondary


From ETAP

From ETAP

Page 57 of 160


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


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


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


0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274


= = = = = = =

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


0.44

KM

78.9

O

76.8

O

0.29 1.24


V V V HZ


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


MAKE








=

38.11

Ω secondary


=

50.81

Ω secondary


= = = = = = =


1.33


= =

1.325


=

5.69


=

6.28


=

8.39


=

4.55

=

0.00



sec



0.400 0.400

0.80 0.80

sec

Page 60 of 160


MAKE





= =

0.83 0.63


= = = =

0.21 0.81 0.84

75.62

O

0.64

-3.30

O

= = = =

198000

=

40.01



800.000

142.90 57.16






Page 61 of 160


MAKE




= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A


% s






= = = = = = ≈ =

220000/110


198000 198000/2000 99.000 0.90 3.00

v


V pu s

Page 62 of 160


MAKE





Unit



km











Page 63 of 160


MAKE



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

Unit

















0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S



DEG

Page 64 of 160


MAKE



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


Unit

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


1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled


Enabled






20.00 5.00

% S


pu s


S S

S S S S S

pu pu S S

Page 65 of 160


MAKE


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


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

220000V 800/1A 220000/110

220000 V 800.0 2000.0

0.40 ACSR ZEBRA 800.0 40.0


0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274


= = = = = = =

KM

81.85 0.084 0.428 0.436

78.9

O

76.8

O

0.292 1.240 1.274


= = = = = = =

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


V V V HZ


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

Page 66 of 160


MAKE








=

38.11

Ω secondary


=

50.81

Ω secondary


= = = = = = =


1.10


= =

1.325


=

5.40


=

5.87


=

7.52


=

4.49

=

0.00



sec



0.400 0.400

0.80 0.80

sec

Page 67 of 160


MAKE





= =

0.83 0.63


= = = =

0.21 0.81 0.84

75.62

O

0.64

-3.30

O

= = = =

198000

=

40.01



800.000

142.90 57.16






Page 68 of 160


MAKE




= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A


% s






= = = = = = ≈ =

220000/110


198000 198000/2000 99.000 0.90 3.00

v


V pu s

Page 69 of 160


MAKE





Unit



km











Page 70 of 160


MAKE



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

Unit

















0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S



DEG

Page 71 of 160


MAKE





Unit



1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled


Enabled






20.00 5.00

% S


pu s


pu pu S S S S S

S S S S S

pu pu S S

Page 72 of 160


MAKE




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

220000V 800/1A 220000/110

220000 V 800.0 2000.0

0.40 TWIN ACSR ZEBRA 800.0 10.0


0.022 0.290 0.291

85.6

O

73.8

O

0.284 0.978 1.019


= = = = = = =

KM

10.00 0.022 0.290 0.291

85.6

O

73.8

O

0.284 0.978 1.019


= = = = = = =

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


V V V HZ


0.99


Page 73 of 160


MAKE








=

38.11

Ω secondary


=

50.81

Ω secondary


= = = = = = =


0.45


= =

1.325


=

4.34


=

4.37


=

4.43


=

4.28

=

0.00



sec



0.400 0.400

0.80 0.80

sec

Page 74 of 160


MAKE





= =

3.91 0.79


= = = =

0.26 0.69 0.74

69.19

O

0.84

-16.41

O

= = = =

198000

=

40.01



800.000

142.90 57.16






Page 75 of 160


MAKE




= = = = = =

800.000

80.00 0.10 200% 20.00 5.00

A A


% s






= = = = = = ≈ =

220000/110


198000 198000/2000 99.000 0.90 3.00

v


V pu s

Page 76 of 160


MAKE





Unit



km











Page 77 of 160


MAKE




Unit

















0.25 40.01 26.00 0.00 0.00

pu Ω DEG S S



DEG

Page 78 of 160


MAKE





Unit



1.00 0.70 0.15 0.09 0.04 Enabled 0.05 0.01 Enabled


Enabled






20.00 5.00

% S


pu s


pu pu S S S S S

S S S S S

pu pu S S

Page 79 of 160


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




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,


0.64 -3.30

°

Page 81 of 160





=

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


=

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


200%

0.20 60.00

s

Page 82 of 160




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




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




GROUP 1 VOLT Protection V
Phase-phase 99.00 3.00

V s

GROUP 1 BROKEN CONDUCTOR Broken conductor I2 / I1 I2 / I1 Time Delay I2 / I1 Trip

Enabled 0.20 60.00 Enabled

A s

GROUP 1 SUPERVISION VT Supervision VTS Time Delay VTS I2>IO>inhibit Detect 3P Threshold 3P Delta I>

5.00 0.20 Enabled 10 0.20

s A V A

Page 85 of 160





= = = = =

800/1A 800 1 800 PS

A A


= = = =


= =

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


= =

ZEBRA 50km

= = =


=

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


Zebra 81.85km 0.084 0.292 81.850 = =

km L 78.920 Ω/km L 76.750 Ω/km

0.436 1.274



=

0.436

L 78.920 Ω/km

Z0

=

1.274

L 76.750 Ω/km

0.084 0.292 5.770

+j +j

0.428 1.240

km

Page 86 of 160





=



=


0.40


Zone 1 Phase Reach Settings Required Zone 1 reach is to be 85% of the Protected line Zone 1 Reach (0.85*0) = 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


=


=

(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*81.85*0.4)*1.2 = L 79.00 Ω secondary 19.03 = Actual Zone 3 reach, Z3 L 79.00 19.03 =


L

79.00

Ω secondary


=

0

s

tZ2

=

0.40

s

tZ3

=

0.80

s

tZ4

=

0.50

s


= =

(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

= =



0.64 -3.30

°

Page 87 of 160





=




=

38.11 Ω secondary


=

50.81 Ω secondary

Where:


Primary resistive coverage for phase faults

= = = = = =


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 30.48 Phase (RPh)Ω 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

Biased Residual Current IN> Biased Negative Sequence Current I2> Power swing current minimum setting for Imax line> minimum setting for Imax line> minimum fault current level Fault current in secondary maximum setting for Imax line> Hence setting for Imax line>

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

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 40% (typical setting from manual) 30% (typical setting from manual) 2 In 1.2 x (max.power swing current) 1.2*2*1

2.40 3660.00

A

3660*1/800

4.58 0.8

3.66 3.66

A x (min.phase fault current level) A A


= = = = = =

800 80.00 0.10

A A


200%

0.20 60.00

s

Page 88 of 160







= = = = = =


=

1 1 5 25 5 5

s s s s s

11111111

0.20

11111111 s


= =

0.20 0.20

s In



= = = = = = = =

220000/110

2000.00 0.90 * Nominal 0.9x220000

198000

90

%

v

198000/2000

99 3

V s

Page 89 of 160




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


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 19.03 38.11 30.48 0.80 1.48 0.50

Ω


Ω Ω

Single 1.00 1.00 5.00 25.00 5.00 5.00 0.20 11111111

0.20 0.20


A s

s s s s s s 11111111

s 0.00

Page 90 of 160





V s

GROUP 1 BROKEN CONDUCTOR Broken conductor I2 / I1 I2 / I1 Time Delay I2 / I1 Trip


A s


5.00 0.20 Enabled 10 0.20

s A V A

Page 91 of 160





= = = = =

800/1A 800 1 800 PS

A A


= = = =


= =

220kV/√3 110V/√3 220000 V 110 V 2000.00 50HZ 7.98kA


= =

ZEBRA 10km

= = =


=

0.022 0.284 10 800

Z1

=

0.291

L 85.660 Ω/km

Z0

=

1.018

L 73.810 Ω/km

Z0/Z1

=

3.502

L -11.850 °

+j +j

0.290 0.978

km


Zebra 81.85km 0.022 0.284 10 = =

+j +j

0.290 0.978

km L 85.660 Ω/km L 73.810 Ω/km

0.291 1.018



=

0.291

L 85.660 Ω/km

Z0

=

1.018

L 73.810 Ω/km

0.022 0.284 10

+j +j

0.290 0.978

km

Page 92 of 160





=



=


0.40


Zone 1 Phase Reach Settings Required Zone 1 reach is to be 85% of the Protected line Zone 1 Reach (0.85*0) = Z1 0.99 = The Line Angle 79.00 = Therefore actual Zone 1 reach, Z1 0.99 =

L

79.00

Ω secondary

L

79.00

Ω secondary

L L

79.00

Ω secondary


=


=

(1.2*1.163)

1.40 1.40

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*1.163)+(0.5*0.291*10*0.4)*1.2 = L 79.00 Ω secondary 2.09 = Actual Zone 3 reach, Z3 L 79.00 2.09 =


L

79.00

Ω secondary


=

0

s

tZ2

=

0.40

s

tZ3

=

0.80

s

tZ4

=

0.50

s


= =

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

Z0-Z1

= =

(Z0-Z1) / 3Z1

=

(0.284+j0.978)-(0.022+j0.29) 0.262 +j 0.688 L 69.15 ° 0.74 L69.15-85.66 (0.736/(3*0.291)) L -16.51 ° 0.84

│kZ0│ L kZ0

= =



0.84 -16.51

°

Page 93 of 160





=




=

38.11 Ω secondary


=

50.81 Ω secondary

Where:


Primary resistive coverage for phase faults assuming a typical earth fault coverage

= = = = = = =


40.00

Ω

RPH (min) = 0.445*0.4 0.178 Ω RG (min) = 40*0.4 16 Ω Selection of Resistive Reaches The Zone 2 elements satisfy R2Ph ≤ (R3Ph x 80%), and R2G ≤ (R3G x 80%) R3Ph - R4Ph should be set ≤ 80% Z minimum load - ∆R Minimum Maximum Zone 1 Zone 2 Zones 3 & 4 Phase (RPh)Ω 30.48 0.18 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 = 7980.00 A Fault current in secondary = 7980*1/800 = A 9.98 maximum setting for Imax line> = 0.8 x (min.phase fault current level) = A 7.98 Hence setting for Imax line> = A 7.98


= = = = = =

800 80.00 0.10

A A


200%

0.20 60.00

s

Page 94 of 160







= = = = = =


=

1 1 5 25 5 5

s s s s s

11111111

0.20

11111111 s


= =

0.20 0.20

s In



= = = = = = = =

220000/110

2000.00 0.90 * Nominal 0.9x220000

198000

90

%

v

198000/2000

99 3

V s

Page 95 of 160




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


Unit

10.00 1.16 86.00

km Ω

0.84 -16.51 0.99 21.43 19.51 0.00 0.84 -16.51 1.40 28.58 24.39 0.40 0.84 -16.51 2.09 38.11 30.48 0.80 0.20 0.50

Ω


Ω Ω

Single 1.00 1.00 5.00 25.00 5.00 5.00 0.20 11111111


A s

s s s s s s 11111111

LOCAL BREAKER BACKUP PROTECTION CB Fail & I< Breaker Fail CB Fail 1 Timer I< Current Set

0.20 0.20

s 0.00

Page 96 of 160






V s

A s


5.00 0.20 Enabled 10 0.20

s A V A

Page 97 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220/132-160MVATRAFO DIFF PROTN GE T60 BAY/FEEDER MAKE MODEL


4.10.Differential Protection For 160MVA Transformer

Transformer Data: Rated Power, Prated Rated Voltage HV, Vnom[1] LV, Vnom[2] % Impedance Vector Group 220kV SIDE Primary-winding 1, CT Ratio (Inom,a) 132kV SIDE Primary-winding 2, CT Ratio (Inom,b) OLTC Range on 132kV side

=

160.0

MVA

= = = =

220.0 132.0 0.125 YNa0

kV kV 12.50%

=

800.0

= +

800.0 10.0

.

1.0

A

(1600-800/1A)

1.0

A Step

(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 1.25 242.0 209.0

% Max Step

8.00

Min Step

4.00

kV kV 145.20 kV 125.40 kV


= = = = = =

Prated / (√3*Vnom[1] ) (160*1000)/(1.732*220) 419.89 A Prated / (√3*Vnom[2] ) (160*1000)/(1.732*132) 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] = 800/419.89 Imargin[1], 1.91 = 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] = 220kV side M[1], = = magnitude compensation factor for winding [2], M[2] = 132kV side M[2], =

IPrimary [1] × Vnom [1] / IPrimary [2] × Vnom[2] 800x220000/800x132000

1.67 IPrimary [2] × Vnom [2] / IPrimary [2] × Vnom[2] 800x132000/800x132000

1.00

Page 98 of 160

VOLTECH ENGINEERS PVT. LTD PROJECT: POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) TITLE: SETTING CALCULATION FOR 220/132-160MVATRAFO DIFF PROTN RELAY MAKE GE MODEL T60 BAY/FEEDER a) Calculating the minimum differential pickup current required for relay to operate,


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) 0.05×419.89 = No load current of the transformer primary current, 20.99 = A No load current refered to the CT secondary, = 20.9945/800 0.03 = A No load current to the relay after applying magnitude compendation factor M[1], IS1

0.026×1.667

= =

0.0433

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

A

0.0 0.0

Differential current IdA,

= | Is1+Is2 | = |0.043+0 | 0.0433 Id A, = A Restraining current IrA, = max( | Is1|, |Is2 |) = max( |0.043|, |0 |) 0.04 IrA, = A The differential current IdA=0.0433A is found to be less than the minimum pickup selected setting of 0.1 is adequate as the relay catalogue has a setting generally recommended between 0.1 to 0.3.

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 0.52 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(145.2*125.4)/(145.2+125.4) 134.58 kv

Object current of regulated side, IN2

=

SN/(1.732 X VN2)

= = =

(160*1000)/(1.732x134.576) 686.44 A IN2 / CT2

= =

686.45/800 0.86 A



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


Differential current in maximum tap position IDiff

=

IN1 / CT1

= =

419.89/800 0.52 A

=

SN/(1.732 X Vmax)

= =

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

~

INobj

~

INobj

~

0.93

636.22

=

IN2(+15%) / CT2

= =

636.22/800 0.80 A

=

| IN2(+15%) - INobj |

= =


INobj

Page 99 of 160



Restriant current in maximum tap position IRestaint

=

| IN2(+15%) + INobj |

= =


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

=

SN/(1.732 X Vmin)

= =

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

736.67

=

IN2(-5%) / CT2

= =

736.67/800 0.92 A

Differential current in minimum tap position IDiff

=

| IN2(-5%) - INobj |

= =


Restriant current in minimum tap position IRestaint

=

| IN2(-5%) + INobj |

= =


Iop, Relay operating current at +15% tap,

= =



=


0.48

~

1.07

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,

= = =


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 7.00 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 2519.34 A = 3.15 pu =

Page 100 of 160



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


II)

4.20 7.00

= =

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,

= = = =


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

= = = =


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 2 pu 30 pu 50% 1 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 101 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220/132-160MVATRAFO REF PROTN GE T60 BAY/FEEDER MAKE MODEL


4.11Restricted Earth Fault portection For 160MVA Transformer

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) Neutral CT Ratio OLTC Range on 132kV side

= = = =

160

MVA

220 kV 132 kV 0.125 12.50% YN yn 0

Py

.

Sec

=

800

1

A

(1600-800/1A)

= = +

800 600 10

1 1

A A

(800-400/1A) 600/1A

%

5

%

to Step Size

Max Step

1.25 Voltage at Min Tap Position Voltage at Max Tap Position Highest voltage tolerence, Vmax Lowest voltage tolerence,Vmin

= = = =

242.00 209.00 145.20 125.40

8.00

Min Step

4.00

kV kV kV kV


= = =


= = =


(160*1000)/(1.732*220) 419.89 A

(160*1000)/(1.732*132) 699.82 A

Setting Calculation Base kV Base MVA Base Impedence Zb= kV2 /MVA Zt=Zb*Zp.u If= kV/(√3*Zt)

= = = = =

132.00 160.00

220.00 160.00

108.90 302.50 13.61 37.81 5598.71 3359.23

For a winding fault point at 5% Distance from the transformer neutral, the phase to ground primary fault current is calculated as Ifault

= = =

0.05 x Igf(max) (0.05X3359.23)

167.97

Increase in phase current (Iph) due to the fault are negligible, meaning that

3Io= 0

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

(0-(167.97/800) 0.21

Note that phase CT primary is used as a unit for calculating the RGF setting . Hence, magnitude scaling is applied to the measured ground current The new restraint calculation algorithm provides very secure behavior of the element on external faults and CT saturation, and high sensitivity on internal faults. The setting of the slope should be selected based on two criteria: Reliable detection of the internal fault curents corresponding to the point of the selected distance from the grounded neutral

Page 102 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220/132-160MVATRAFO REF PROTN MAKE GE MODEL T60 BAY/FEEDER


Security on external faults with or without CT saturation Let us consider the case of an internal fault that occurs on in the winding at 5% distance from the transformer neutral. The primary fault current of 167.97 A IG = 0.21 pu Based on 100% transformer load currents of 419.89 A On the Wye winding, the phase unit currents are IA = IB=IC

=

0.52

pu

0.52

pu ; I2 = I0= 0 pu

and the symmetrical components are I1

=

The ground differential current is IGD

= = =

| IG + IN |

0.21 0.21

pu + 0 pu pu

The restraint current used by the relay algorithm is defined as the maximum from the |R1, |R2 , |R0 quantities, based on the following symmentrical components calculations: IGR max( |R1, |R2, |R0) = The value of |R1 is calculating using the positive-sequence current: |I_1 < 1.5 pu, then IR1

= |I_1| / 8 = 0.066 The value of |R2 is calculating using the negative-sequence current: IR2 = 3 x |I_2| = 0.000 The value of |R0 is calculating using the zero-sequence current: | IG - IN | IR0 = = 0.210 pu + 0 pu = 0.210 pu

The ground restraint current is IGR

max( |R1, |R2, |R0) = max(0.066pu,0pu,0.21pu) = 0.210 pu = The RGF element would therefore calculate a ground differential / restraint ratio of: IGD / IGR X 100% 0.21pu/0.21pux100% = 100 % The slope should be set at some level below 100% If no CT Saturation is involved, the RGF protection detects no differential current during ground fault that are external to the zone. However, RGF slope setting should be also selected to maintain the security on external faults with CT saturation.

External Solid phase A to ground fault with no CT Saturation. Fault Current at secondary side, IA

=

(3359.23/800)

IB=IC=0

4.20 = IN = 4.20 pu L 00 IG = 4.20 pu L 1800 The symmetrical components derived from the phase unit current are I1= I2 = I0 = 1.40 The ground differential current will be | IG + IN | IGD = = = The |R1, |R2, and |R0 current are : |R1 =

4.20 pu L 00 + 0.00 pu

4.20 pu L 1800

|I_1| / 8

0.17

Page 103 of 160



POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220/132-160MVATRAFO REF PROTN MAKE GE MODEL T60 BAY/FEEDER |R2

= =

3 x |I_2|

= = =

| IG - IN |

= = =

max( |R1, |R2, |R0) max(0pu,0.175pu,8.4pu) 8.40 pu

|R0

4.20

4.20 8.40

pu L 1800 pu

4.20

pu L 00

The ground restraint current is IGR

The RGF element would therefore calculate calculate a ground differential / restraint ratio of: IGD / IGR X 100% 0pu/8.4pux100% = 0.00 % and the protection element is effectively in non operating stage.

External phase A to ground fault where the ground CT Saturates, producing only 5% of the total fault current on its secondary winding. = Fault Current at secondary side, IA = IN 4.20 pu L 00 IG = 0.21 pu L 1800 The symmetrical components derived from the phase unit current are I1= I2 = I0 = 1.40 pu IGDbe The ground differential current will

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

IB=IC=0

= = =

| IG + IN |

=

|I_1| / 8

= = = = =

3 x |I_2| | IG - IN |

= = =

max( |R1, |R2, |R0) max(3.99pu,0.175pu,4.2pu) 4.20 pu

4.20 3.99

pu L 00 + pu

0.21

pu L 1800

pu L 1800 pu

4.20

pu L 00

pu

0.18 |R2 |R0

IGR

The restraint current is

4.20 0.00 4.20

The RGF element would therefore calculate calculate a ground differential / restraint ratio of: IGD / IGR X 100%

3.99pu/4.2pux100% = % 95 = This is well above the restraint characteristics in the operating region if no special treatment to the restraint is provided. CT Saturation and switch off conditions, the ground restraint IGR is set to decay slowly. Since the CTs do not immediately saturate at the same instant the fault occurs, the restraint current will be equal to the intial fault current value of 8.40pu(as in the no saturation case).The restraint will drop to 50% of its original value after 15.5 cycles, so that if the worst case of saturation occurs after a cycle, the restraint current will be approximately 7.98 pu, IGD / IGR X 100% 3.99pu/7.98pux100% = % 50 The slope would have to be above 50%(assuming very severe saturation leading to only 5% current from the saturated ground CT) and below 100% (assuming detection of faults on the winding at 5% distance from the neutral point) slope

=

70

%

Page 104 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220/132-160MVATRAFO REF PROTN MAKE GE MODEL T60 BAY/FEEDER


Setting Table: Menu Text Restricted Earth fault Protection Restd GND FT1 Function Restd GND FT1 Source Restd GND FT1 Pick Up Restd GND FT1 Slope Restd GND FT1 Pick Up Delay Restd GND FT1 Reset Delay Restd GND FT1 Block Restd GND FT1 Target Restd GND FT1 Events

Setting Range Recomm.Setting Enabled SRC1 0.21 pu 70 pu 0s 0s Off Self Reset Enabled

Min

Max

Enabled/Disabled SRC1,SRC2,SRC3,SRC4 0pu 30 pu 0% 100% 0 600 0 600 Self reset/Latched/Disabled Enabled/Disabled

Page 105 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220kV BUSBAR PROTECTION GE MAKE MODEL B90 BAY/FEEDER

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

4.12.220kV BUSBAR PROTECTION Input Parameters CT Details: CT Ratio CT Py (A) (A) 220kV Line-1 1600/1 1600 220kV Line-2 1600/1 1600 220kV Line-3 1600/1 1600 220kV Line-4 1600/1 1600 Trafo-1 1600/1 1600 Trafo-2 1600/1 1600 Transfer Bus Coupler 1600/1 1600 Bus Coupler 1600/1 1600

Feeders

Relay details: Type Burden ktf Setting calculation Base CT ratio selection Base CT ratio shall be selected based on highest CT ratio connected to the protected bus

CT Sec CT class (A) 1.00 PS 1.00 PS 1.00 PS 1.00 PS 1.00 PS 1.00 PS 1.00 PS 1.00 PS

= = = =

=

B90 0.2/12 0.20 5.00

Rct in ohms 8.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00

Lead Res Cable (Ω/m) Length (m) 1.24 168.00 1.27 171.00 1.00 135.00 1.02 138.00 0.64 86.00 0.53 72.00 0.56 75.00 0.38 51.00

VA Ω

1600.00 A

Basic fault data of the connected circuit CT sec (A) Ifault (kA) Circuit 220kV Line-1 2.29 3.66 220kV Line-2 2.61 4.18 220kV Line-3 7.98 4.99 220kV Line-4 7.98 4.99 Trafo-1 0.88 1.40 1.40 Trafo-2 0.88 0.00 Transfer Bus Coupler 0.00 9.24 5.78 Bus Coupler Tne Maximum Secondary current transformed Without Saturation Vsat/Rs Imax = Where, Vsat = Saturation Voltage of CT Rs = Total Burden Resistance The Total burden Resistance Rs depends on the fault current and the connection of the CTs. For Single line to ground fault and the CTs connection in Wye, the Burden Resistance is calculated as, Rs 2Rlead+RCT+RRelay = Where, Rlead = Lead Resistance RCT = CT Resistance RRelay = Relay Input Resistance Rs Imax Limits of linear operations of the CTs Imax Circuit Rs(Ω) (A sec) 220kV Line-1 10.69 18.30 220kV Line-2 10.73 20.90 220kV Line-3 10.20 39.90 220kV Line-4 10.25 39.90 Trafo-1 9.47 7.00 Trafo-2 9.27 7.00 Transfer Bus Coupler 9.31 0.00 Bus Coupler 8.96 46.20

= =

9.27 7.00

Imax(PU) 18.30 20.90 39.90 39.90 7.00 7.00 0.00 46.20

A

Imax(PU) 3.66 4.18 7.98 7.98 1.40 1.40 0.00 9.24

Page 106 of 160


POWER TRANSMISSION CORPORATION OF UTTARKHAND LIMITED(PTCUL) SETTING CALCULATION FOR 220kV BUSBAR PROTECTION MAKE GE MODEL B90 BAY/FEEDER

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

CT Saturation voltage calculation Knowing the Ktf value, The Saturation voltage needed to ensure stability for through faults will be The over dimensioning factor can be as low as Ktf = 5 , particularly for voltages lower than 132 kV. CT Knee point voltage, vkp

Basic CT data Circuit 220kV Line-1 220kV Line-2 220kV Line-3 220kV Line-4 Trafo-1 Trafo-2 Transfer Bus Coupler Bus Coupler

Ratio 1600/1 1600/1 1600/1 1600/1 1600/1 1600/1 1600/1 1600/1

= = =

Vsat 195.62 224.35 407.01 408.78 66.32 64.87 0.00 413.76

ktf . If. (2Rct + RL + Rp) (5*1.4*(2*1.24488+8+0.2) 74.83 V

RCTSEC 8 8 8 8 8 8 8 8

The B90 relay requires the breakpoints to be entered as 'pu' values. CT ratio 1600A is selected for the pu quantities. With a given Ibase current, the limits of linear operation have been recalculated to pu values as follows Low Slope Break point Imax(pu) = Imax(sec)/ Ibase * CT ratio (with no remanence) = (7/1600)*1600) = 7.00 pu with 80% remanence, Imax(pu) can be calculated is as follows = 1.4 pu High slope Break point Imax(pu) = Imax(sec)/ Ibase * CT ratio (with no remanence) = (46.2/1600)*1600) = 39.90 pu with 80% remanence, Imax(pu) can be calculated is as follows = 7.98 pu Low slope break point Considering CTs that could be connected LOW BPNT for minimum of all feeders High slope break point Considering CTs that could be connected HIGH BPNT for minimum of all feeders Pickup For pickup setting 10% considered for busbar protection

=

1.40

pu

=

7.98

pu

=

0.1

pu

Setting 0.1 25 1.40 80.00 7.98 4.62

pu % pu % pu pu

Setting Table: Menu text pickup Low slope Low slope break point High slope High slope break point High set

Range 0.050 to 6.000 pu 15-100% 1-30PU 50-100% 1-30PU 0.10 to 99,99PU

Unit

Page 107 of 160

Amps X 100 0.433kV Bus-1 (Nom. kV=0.433, Plot Ref. kV=0.433) .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

10K 1K

500

500

300

300

100

100

50

50

30

30

10

10

5

5

3

11kV - P OC1 MSB IC-1 - P OC1

1

MSB BC - P OC1

.5

3

1

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K

Amps X 100 0.433kV Bus-1 (Nom. kV=0.433, Plot Ref. kV=0.433) 1.968

5

10

30

50

100

300

500

1K

3K

5K

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

10K

39.36K

ETAP Star 11.1.0C

11-0.433kV POC Project: Location: Contract: Engineer: Filename:

220/132/33kV Sub station Dehradun HPL Marimuthu.N C:\ETAP 1110\HPL\HPL.OTI

Date: SN: Rev: Fault: Circuit:

16-09-2013 VOLTECHENG Base Phase 11/0.433kV

Page 108 of 160

Seconds

Seconds

1K


1

3

5

10

30

50

100

300

500

1K

3K

5K

10K 1K

500

500

300

300

100

100

50

50

30

30

10

10

5

5

MSB IC-1 - G OC1

3

3

MSB BC - G OC1 1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K


30

50

100

300

500

1K

3K

5K

10K

Amps (Plot Ref. kV=3.3)

30K

50K

ETAP Star 11.1.0C

11-0.433kV EOC Project: Location: Contract: Engineer: Filename:


131.2K


16-09-2013 VOLTECHENG Base Ground 11/0.433kV

Page 109 of 160

Seconds

Seconds

1K


1

3

5

10

30

50

100

300

500

1K

3K

5K

1K

10K 1K

500

500

300

300

100

100

50

50

30

30

10

10

MSB IC-2 - P OC1

5

5

3

3

1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K


3

5

10

30

50

100

300

500

1K

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

3K

5K

ETAP Star 11.1.0C

33-0.433kV POC Project: Location: Contract: Engineer: Filename:



13.12K

16-09-2013 VOLTECHENG Base Phase 33/0.433kV

Page 110 of 160

Seconds

Seconds

33kV Fuse


1

3

5

10

30

50

100

300

500

1K

3K

5K

1K

500

500

300

300

100

100

50

50

30

30

10

10

MSB IC-2 - G OC1

5

5

3

3

1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K


30

50

100

300

500

1K

3K

5K

10K


30K

50K

ETAP Star 11.1.0C

33-0.433kV EOC Project: Location: Contract: Engineer: Filename:


131.2K


16-09-2013 VOLTECHENG Base Ground 33/0.433kV

Page 111 of 160

Seconds

Seconds

10K 1K

Amps X 100 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33) .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

1K

10K 1K

500

500

300

300

100

100

50

50

30

30

10

10

5

40 MVA 33 KV SIDE TR-2 - P OC1

3

5

3

33KV BUS COUPLER - P OC1 1

33KV Capacitor Bank - P OC1 - 67

1

.5

33 KV LINE - P - 51 OC1

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K

Amps X 100 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33) 12.5

30

50

100

300

500

1K

3K

5K

10K

30K

50K

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

100K

ETAP Star 11.1.0C

132-33kV POC Project: Location: Contract: Engineer: Filename:



250K

16-09-2013 VOLTECHENG Base Phase 132/33kV

Page 112 of 160

Seconds

Seconds

40 MVA 132 KV SIDE TR-2 - P OC1 - 67

Amps X 10 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33) .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

1K

10K 1K

500

500

300

300

100

100

50

50

30

30

40 MVA 132 KV SIDE TR-2 - N OC1 - 67 40 MVA 33 KV SIDE TR-2 - N OC1

5

10

5

33KV BUS COUPLER - N OC1

3

3

33KV Capacitor Bank - N OC1 33 KV LINE - N - 51 OC1

1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

300K

500K

.01 10K

Amps X 10 33KV BUS 2 (Nom. kV=33, Plot Ref. kV=33) 50

100

300

500

1K

3K

5K

10K

30K

50K

100K


ETAP Star 11.1.0C

132-33kV EOC Project: Location: Contract: Engineer: Filename:


1000K


16-09-2013 VOLTECHENG Base Ground 132/33kV

Page 113 of 160

Seconds

Seconds

10

Amps X 100 220KV Bus1 (Nom. kV=220, Plot Ref. kV=220) .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

10K 1K

1K

500

500

300

300

100

100

50

50

220 KV LINE - P - 51 OC1

30

30

BUS COUPLER - P OC1 160 MVA TR-2 220KV SIDE - P OC1 - 67

5

10

5

132KV LINE-4 - P - 51 OC1 - 67

3

3

40 MVA 132 KV SIDE TR-2 - P OC1 - 67

1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K

Amps X 100 220KV Bus1 (Nom. kV=220, Plot Ref. kV=220) 83.33

300

500

1K

3K

5K

10K

30K

50K

100K

300K

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

500K

1667K

ETAP Star 11.1.0C

220-132kV POC Project: Location: Contract: Engineer: Filename:



16-09-2013 VOLTECHENG Base Phase 220/132kV

Page 114 of 160

Seconds

Seconds

10

Amps X 10 220KV Bus1 (Nom. kV=220, Plot Ref. kV=220) .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

10K 1K

1K

500

500

300

300

100

100

50

50

BUS COUPLER - N OC1

30

30

220 KV LINE - N - 51 OC1 10

160 MVA TR-2 220KV SIDE - N OC1 - 67

5

3

5

3

132KV LINE-4 - N - 51 OC1 - 67 40 MVA 132 KV SIDE TR-2 - N OC1 - 67

1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .5

1

3

5

10

30

50

100

300

500

1K

3K

5K

.01 10K

Amps X 10 220KV Bus1 (Nom. kV=220, Plot Ref. kV=220) 333.3

1K

3K

5K

10K

30K

50K

100K

300K

500K

1000K


3000K

ETAP Star 11.1.0C

220-132kV EOC Project: Location: Contract: Engineer: Filename:


6667K


16-09-2013 VOLTECHENG Base Ground 220/132kV

Page 115 of 160

Seconds

Seconds

10

Per Unit .005 1K

.01

.03

.05

.1

.3

.5

1

3

10

Normalized (shifted) TCC Line-to-Ground (Sym) fault: Adj Bus: Connector: SQOP File: Data Rev: Configuration: Date:

500

300

30

50

100 1K

10.985kA @ 220kV Bus9 Bus9 - 50KM Line Untitled Base Normal 16-09-2013

500

300

100

100

50

50

30

30

160 MVA TR-2 132KV SIDE - P OC1 - 67

10

1.372 kA @ 132 kV t1: 2.04 s

5

5

220 KV LINE-4 - P - 51 OC1

3

10

3

1.221 kA @ 220 kV t1: 3.3 s 1

1

.5

.5

.3

.3

.1

.1

.05

.05

.03

.03

.01 .005

.01

.03

.05

.1

.3

.5

1

3

5

10

30

Per Unit

50

ETAP Star 11.1.0C

220-132kV Trip Coord Project: Location: Contract: Engineer: Filename:


.01 100


16-09-2013 VOLTECHENG Base Phase(Normalized) 220/132

Page 116 of 160

Seconds

Seconds

5

One-Line Diagram - OLV1 (Star Sequence-of-Operation) 220kV IC Line-1 3722.87 MVAsc Bus6

220kV IC Line-2 3722.87 MVAsc Bus7

220kV OG Line-1 3722.87 MVAsc Bus8

10KM Line

Bus9

10KM Line-2

220 KV LINE-1

40KM Line

220 KV LINE

±

50KM Line

220 KV LINE-3

±

220 KV LINE-4

±

R

R

CB1 Open 220KV Bus1

220kV OG Line-2 3722.87 MVAsc

±

R

0 0 kV

CB2

U24 2972.199 MVAsc

R

CB3 Open

U9 2972.199 MVAsc

U10 2972.199 MVAsc

0 0 kV

CB4

Bus11

3.66 220KV Bus2

7.98

U8 2972.199 MVAsc

Bus12

Bus13

Bus15 13

CB5

CB6

Open

7.98 kA 85.9

3.66

CB7

Open ±

160 MVA TR-1 220KV SIDE

kA 81.5

±

R

22KM Line

22KM Line.

15KM Line

30KM Line

R

±

BUS COUPLER

R


160/160/53.33 MVA

160/160/53.33 MVA

T11

132KV LINE-1

132KV LINE-2

132KV LINE-3

132KV LINE-4

T2 ±

±

±

R ±

±

R

R

R

± ±

R


R


CB8

R

CB21

CB9

132KV BUS

CB15 40 MVA 132 KV SIDE TR-2 11kV Bus.

±

T9

40 MVA

40 MVA

CB13

Open

0 0 kV

Open 2.97

kA 85.2

15.2 3 kA -87. 2

R

T6

CB12

Open

15.23

±

R

CB11

0 Open 0 kV

2.97

CB14 40 MVA 132 KV SIDE TR-1

11kV CB10

T5

400 kVA

± ±

40 MVA 33 KV SIDE TR-1

3.64

Open

CB22

CB17 40 MVA 33 KV SIDE TR-2 3.64

kA 87.7

MSB IC-1

R

0 0 kV

CB16 33KV BUS 1

R

±

R

33KV BUS 2

3.64

0 0 kV 3.64

33kV Fuse

CB18 R

CB20

kA 87.7

CB19 T7 630 kVA

± ±

33 KV LINE

±

33KV BUS COUPLER Bus Ref A

R

R

3.64

0 0 kV 3.64

kA 87.7

33KV Capacitor Bank ±

0 0 kV

Bus Ref B

R

MSB IC-2

3.64 3.64

CAP1 10000 kvar

0 0 kV kA 87.7

R

MSB BC

11.24

0.433kV Bus-1

CB23 15.57

0 0 kV

±

CB24 Open 11.2 4 kA -57. 2

0.433kV Bus-2

15.5 7 kA -58. 1

Page 117 of 160

page 1

09:56:06

Sep 16, 2013

Project File: HPL



Bus8

10KM Line 220 KV LINE-1

40KM Line

220 KV LINE

220 KV LINE-4

±

R

±

R

0 0 kV

CB2

2.19 CB6

5.84

18.15 kA 84.8 CB7

±


Bus11

3.66 220KV Bus2 23.9 9

23.9

2.19

BUS COUPLER

R

Bus13

Bus15 13

22KM Line

22KM Line.

15KM Line

30KM Line


160/160/53.33 MVA

T11

U10 2972.199 MVAsc

9 kA -84. 8

R

±

U9 2972.199 MVAsc

Bus12

±

R

U8 2972.199 MVAsc

0 0 kV

CB4

7.98

CB5

U24 2972.199 MVAsc

R

CB3 Open

7.98

50KM Line

220 KV LINE-3

±

R

CB1


10KM Line-2

±

220KV Bus1


160/160/53.33 MVA

T2

132KV LINE-1

132KV LINE-2

±

±

R ±

132KV LINE-3 ±

132KV LINE-4 ±

R

R

R

± ±

R


R


CB8

R

CB21

CB9

132KV BUS

4.26

4.26


T9

40 MVA

40 MVA

CB13 6.01

0 0 kV

3.89 27.8

8 kA -79. 1

26.6 8 kA -87. 8

R

T6

CB12 4.8

26.68

±

R

CB11 4.8

0 0 kV


±

11kV CB10

T5

400 kVA ±

±


9.61

4.81

CB22


kA 87.5

4.81

MSB IC-1

R

0 0 kV

CB16 33KV BUS 1

R

±

R

4.81

CB18 R

±

33KV BUS COUPLER Bus Ref A

R

R

9.61

0 0 kV 9.61

kA 87.5

kA 87.5

T7 630 kVA

±

33 KV LINE

9.61

33kV Fuse

CB20

CB19 ±

0 0 kV

33KV BUS 2

33KV Capacitor Bank ±

0 0 kV

Bus Ref B

R

9.61 9.61

CAP1 10000 kvar

0 0 kV kA 87.5

R

MSB BC

11.37

0.433kV Bus-1

MSB IC-2

CB23 16.07

0 0 kV

±

CB24

Open 11.3 7 kA -56. 8

0.433kV Bus-2

16.0 7 kA -57

Page 118 of 160

page 1

10:05:38

Sep 16, 2013

Project File: HPL




10KM Line

Bus9

10KM Line-2

220 KV LINE-1

40KM Line

220 KV LINE

±

50KM Line

220 KV LINE-3

±

220 KV LINE-4

±

R

R

CB1 Open 220KV Bus1


CB2

±

kV

61 132.

R

CB3 Open

4.3

3.24

Open

CB7

Open ±


Bus11

1.08 220KV Bus2 6.95 kA

CB6

V 88 k 119.

CB4

6.95 CB5

U24 2972.199 MVAsc

R

BUS COUPLER

R

Bus15 13

22KM Line

22KM Line.

15KM Line

30KM Line


160/160/53.33 MVA

T11

Bus13

U10 2972.199 MVAsc

kA

R

±

U9 2972.199 MVAsc

Bus12

±

R

U8 2972.199 MVAsc

160/160/53.33 MVA

T2

132KV LINE-1

132KV LINE-2

±

132KV LINE-4

±

R ±

132KV LINE-3

±

±

R

R

R

± ±

R


R


CB8 132KV BUS

CB10

2.09


V 11 k


±

T9

40 MVA

40 MVA

CB12

Open

CB13

Open

6 kV 67.3

Open kA

0 kA

R

T6

CB11

Open

4.04

±

R

11kV

R

CB21

CB9

T5

400 kVA ±

±

40 MVA 33V KV SIDE TR-1

3.97

Open

CB22


kA

MSB IC-1

R

6 k 18.3

CB16 33KV BUS 1

R

±

R

33KV BUS 2

3.97 R

T7 630 kVA

± ±

Bus Ref A

R

R

33KV BUS COUPLER 3.97

6 kV 18.3 3.97

kA

kA

CB20

CB19 ±

33 KV LINE

3.97

33kV Fuse

CB18

6 kV 18.3

33KV Capacitor Bank 6 18.3

Bus Ref B

kV

±

R

3.97 3.97

kV 0.25 kA

R

MSB BC

11.34

MSB IC-2

CB23 15.84

0.25

kV

±

CAP1 10000 kvar

0.433kV Bus-1 11.3 4 kA

CB24 Open

0.433kV Bus-2

15.8 4 kA

Page 119 of 160

page 1

10:09:48

Sep 16, 2013

Project File: HPL



Bus8

10KM Line 220 KV LINE-1

40KM Line

220 KV LINE

220 KV LINE-4

±

R

±

kV

28 127.

CB2

R

5.19 CB6

CB5

Bus11

1.73 220KV Bus2

6.9

16.62 CB7

kA

±


V 28 k 127.

CB4

5.73 23.5 1

U24 2972.199 MVAsc

R

CB3 Open

5.73

50KM Line

220 KV LINE-3

±

R

CB1


10KM Line-2

±

220KV Bus1


23.5

5.19

BUS COUPLER

R

Bus15 13.83

22KM Line

22KM Line.

15KM Line

30KM Line


160/160/53.33 MVA

T11

Bus13

U10 2972.199 MVAsc

1 kA

R

±

U9 2972.199 MVAsc

Bus12

±

R

U8 2972.199 MVAsc

160/160/53.33 MVA

T2

132KV LINE-1

132KV LINE-2

±

±

R ±

132KV LINE-3

±

132KV LINE-4 ±

R

R

R

± ±

R


R


CB8 132KV BUS

7.81

CB10

7.81


T9

40 MVA

40 MVA

CB13 4.36

1 kV 74.5

2.61 5 kA

0 kA

R

T6

CB12 3.33

28.6

±

R

CB11 3.33

V 11 k


±

11kV

R

CB21

CB9

T5

400 kVA ±

±

40 MVA 33V KV SIDE TR-1

9.64

4.82

CB22


kA

4.82

MSB IC-1

R

2 k 19.0

CB16 33KV BUS 1

R

±

R

33KV BUS 2

4.82

CB18 R

±

Bus Ref A

R

R

33KV BUS COUPLER 9.64

2 kV 19.0 9.64

kA

kA

T7 630 kVA

±

33 KV LINE

9.64

33kV Fuse

CB20

CB19 ±

2 kV 19.0

33KV Capacitor Bank 2 19.0

Bus Ref B

kV

±

R

9.64 9.64

kV 0.25 kA

R

MSB BC

11.42

MSB IC-2

CB23 16.18

0.25

kV

±

CAP1 10000 kvar

0.433kV Bus-1 11.4 2 kA

CB24 Open

0.433kV Bus-2

16.1 8 kA

Page 120 of 160

page 1

10:07:37

Sep 16, 2013

Project File: HPL

Project:

ETAP

220/132/33kV Sub station

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

1

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Electrical Transient Analyzer Program Short-Circuit Analysis IEC 60909 Standard 3-Phase, LG, LL, & LLG Fault Currents

Swing

V-Control

Load

Total

8

0

11

19

XFMR2

XFMR3

Reactor

Line/Cable

Impedance

Tie PD

Total

4

2

0

0

8

4

18

Synchronous Generator

Power Grid

Synchronous Motor

Induction Machines

Lumped Load

Total

Number of Machines:

0

8

0

0

0

8

System Frequency:

50.00 Hz

Unit System:

Metric

Project Filename:

HPL

Output Filename:

C:\ETAP 1110\HPL\Untitled.ST2

Number of Buses:

Number of Branches:

Page 121 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

2

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Adjustments Apply Tolerance

Individual

Adjustments

/Global

Transformer Impedance:

Yes

Individual

Reactor Impedance:

Yes

Individual

Overload Heater Resistance:

No

Transmission Line Length:

Yes

Cable Length:

No

Percent

Individual

Apply

Individual

Adjustments

/Global

Transmission Line Resistance:

Yes

Global

0

Cable Resistance:

Yes

Global

0

Temperature Correction

Degree C

Page 122 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

3

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Bus Input Data

Bus ID

Type

Initial Voltage

Nom. kV

0.433kV Bus-1

Load

0.433

0.433kV Bus-2

Load

11kV Bus.

Load

33KV BUS 1

Load

33.000

Base kV

Sub-sys

%Mag.

Ang.

0.433

1

100.00

-60.00

0.433

0.433

1

100.00

-30.00

11.000

11.000

1

100.00

-30.00

33.000

1

100.00

0.00

33KV BUS 2

Load

33.000

33.000

1

100.00

0.00

132KV BUS

Load

132.000

132.000

1

100.00

0.00

220KV Bus1

Load

220.000

220.000

1

100.00

0.00

220KV Bus2

Load

220.000

220.000

1

100.00

0.00

Bus6

SWNG

220.000

220.000

1

100.00

0.00

Bus7

SWNG

220.000

220.000

1

100.00

0.00

Bus8

SWNG

220.000

220.000

1

100.00

0.00

Bus9

SWNG

220.000

220.000

1

100.00

0.00

Bus11

SWNG

132.000

132.000

1

100.00

0.00

Bus12

SWNG

132.000

132.000

1

100.00

0.00

Bus13

SWNG

132.000

132.000

1

100.00

0.00

Bus15

SWNG

132.000

132.000

1

100.00

0.00

Bus Ref A

Load

33.000

33.000

1

100.00

0.00

Bus Ref B

Load

33.000

33.000

1

100.00

0.00

T11~3

Load

11.000

11.000

0

100.00

0.00

19 Buses Total All voltages reported by ETAP are in % of bus Nominal kV. Base kV values of buses are calculated and used internally by ETAP .

Page 123 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

4

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

2-Winding Transformer Input Data

Transformer

Rating

ID

MVA

Prim. kV

Z Variation

Sec. kV

%Z

X/R

Adjusted

% Tap Setting

+ 5%

- 5%

% Tol.

Prim.

Sec.

Phase Shift

%Z

Type

Angle

T5

0.400

11.000

0.433

4.50

1.50

0

0

0

0

0

4.5000

Dyn

T6

40.000

132.000

33.000

13.80

27.30

0

0

0

0

0

13.8000

YNyn

30.000 0.000

T7

0.630

33.000

0.433

5.00

1.50

0

0

0

0

0

5.0000

Dyn

30.000

T9

40.000

132.000

33.000

13.80

45.00

0

0

0

0

0

13.8000

YNyn

0.000

2-Winding Transformer Grounding Input Data Grounding Transformer

Rating

ID

MVA

Conn.

Prim. kV

Sec. kV

Type D/Y

T5

0.400

11.000

0.433

T6

40.000

132.000

33.000

Y/Y

T7

0.630

33.000

0.433

D/Y

T9

40.000

132.000

33.000

Y/Y

Primary Type

Secondary

kV

Amp

Ohm

Type

kV

Amp

Ohm

Solid Solid

Solid Solid

Solid

Solid

3-Winding Transformer Input Data Transformer

Rating

ID

Winding

T2

T11

Tap

Impedance

MVA

kV

%

%Z

X/R

Primary:

160.000

220.000

0

Zps =

12.50

Secondary:

Z Variation

Phase Shift

MVAb

% Tol.

+ 5%

- 5%

45.00

160.000

0

0

0

Type

Angle

160.000

132.000

0

Zpt =

45.65

45.00

160.000

0

Std Pos. Seq.

0.000

Tertiary:

53.330

11.000

0

Zst =

29.05

45.00

160.000

0

Std Pos. Seq.

-30.000

Primary:

160.000

220.000

0

Zps =

12.50

45.00

160.000

0

Secondary:

160.000

132.000

0

Zpt =

45.65

45.00

160.000

0

Std Pos. Seq.

0.000

53.330

11.000

0

Zst =

29.05

45.00

160.000

0

Std Pos. Seq.

-30.000

Tertiary:

0

0

3-Winding Transformer Grounding Input Data Transformer ID T2

Rating Winding

MVA

Conn. kV

Grounding

Type

Type

Primary:

160.000

220.000

Wye

Solid

Secondary:

160.000

132.000

Wye

Solid

53.330

11.000

Delta

Tertiary:

kV

Amp

Ohm

Page 124 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

5

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

3-Winding Transformer Grounding Input Data Transformer

Rating

ID

Winding

T11

Conn.

MVA

kV

Grounding

Type

Type

Primary:

160.000

220.000

Wye

Solid

Secondary:

160.000

132.000

Wye

Solid

53.330

11.000

Delta

Tertiary:

kV

Amp

Ohm

Impedance Input Data

Impedance ID 10KM Line 10KM Line-2

Positive Sequence Impedance R 0.223

X

Zero Sequence Impedance

Y

R0

2.9

0

2.84

X0

Y0

9.784

Unit 0

Ohm

0.223

2.9

0

2.84

9.784

0

Ohm

15KM Line

2.51145

6.48015

0

6.084

9.3315

0

Ohm

22KM Line

3.68346

9.50422

0

8.9232

13.6862

0

Ohm

22KM Line.

3.68346

9.50422

0

8.9232

13.6862

0

Ohm

30KM Line

5.0229

12.9603

0

12.168

18.663

0

Ohm

40KM Line

3.352

17.12

0

11.68

49.6

0

Ohm

50KM Line

4.19

21.4

0

14.6

62

0

Ohm

Page 125 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

6

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Branch Connections CKT/Branch ID

Connected Bus ID Type

From Bus

% Impedance, Pos. Seq., 100 MVAb To Bus

T5

2W XFMR

11kV Bus.

0.433kV Bus-1

T6

2W XFMR

132KV BUS

33KV BUS 1

T7

2W XFMR

33KV BUS 2

0.433kV Bus-2

T9

2W XFMR

132KV BUS

T2

3W Xfmr

220KV Bus2

3W Xfmr

220KV Bus2

3W Xfmr

132KV BUS

3W Xfmr 3W Xfmr

T11

R 608.80

X 913.20

Z

Y

1097.53

1.22

33.28

33.30

428.44

642.66

772.39

33KV BUS 2

0.74

33.29

33.30

132KV BUS

0.16

7.19

7.19

11kV Bus.

-3.35

-150.79

150.83

11kV Bus.

0.35

15.94

15.94

220KV Bus1

132KV BUS

0.16

7.19

7.19

220KV Bus1

T11~3

-3.35

-150.79

150.83

3W Xfmr

132KV BUS

T11~3

0.35

15.94

15.94

10KM Line

Impedance

Bus6

220KV Bus1

0.05

0.60

0.60

10KM Line-2

Impedance

Bus7

220KV Bus1

0.05

0.60

0.60

15KM Line

Impedance

Bus13

132KV BUS

1.44

3.72

3.99

22KM Line

Impedance

Bus11

132KV BUS

2.11

5.45

5.85

22KM Line.

Impedance

Bus12

132KV BUS

2.11

5.45

5.85

30KM Line

Impedance

Bus15

132KV BUS

2.88

7.44

7.98

40KM Line

Impedance

Bus8

220KV Bus2

0.69

3.54

3.60

50KM Line

Impedance

Bus9

220KV Bus2

0.87

4.42

4.51

CB6

Tie Breakr

220KV Bus1

220KV Bus2

CB18

Tie Breakr

33KV BUS 1

Bus Ref A

CB19

Tie Breakr

33KV BUS 2

33KV BUS 1

CB20

Tie Breakr

33KV BUS 2

Bus Ref B

Page 126 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

7

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Power Grid Input Data

Power Grid

Connected Bus

ID

ID

% Impedance 100 MVA Base

Rating MVASC

kV

R

X"

Grounding R/X"

Type

220kV IC Line-1

Bus6

3722.870

220.000

0.19138

2.67927

0.07

Wye - Solid

220kV IC Line-2

Bus7

3722.870

220.000

0.19138

2.67927

0.07

Wye - Solid

220kV OG Line-1

Bus8

3722.870

220.000

0.19138

2.67927

0.07

Wye - Solid

220kV OG Line-2

Bus9

3722.870

220.000

0.19138

2.67927

0.07

Wye - Solid

U8

Bus12

2972.199

132.000

0.23971

3.35596

0.07

Wye - Solid

U9

Bus13

2972.199

132.000

0.23971

3.35596

0.07

Wye - Solid

U10

Bus15

2972.199

132.000

0.23971

3.35596

0.07

Wye - Solid

U24

Bus11

2972.199

132.000

0.23971

3.35596

0.07

Wye - Solid

Total Connected Power Grids ( = 8 ): 26780.276 MVA

Page 127 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

8

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

SHORT- CIRCUIT REPORT

Fault at bus: Nominal kV Voltage c Factor

0.433kV Bus-1 = 0.433 = 0.95 (Minimum If) Contribution

From Bus ID

3-Phase Fault To Bus ID

0.433kV Bus-1

Total

11kV Bus.

%V From Bus

Positive & Zero Sequence Impedances Looking into "From Bus"

Line-To-Ground Fault

kA Symm. rms

Va

% Voltage at From Bus Vb Vc

kA Symm. rms Ia 3I0

R1

% Impedance on 100 MVA base X1 R0

X0

0.00

11.367

0.00

99.48

100.01

11.425

11.425

6.10E+002

9.33E+002

6.09E+002

9.13E+002

0.433kV Bus-1

98.49

11.367

98.98

100.00

99.51

11.425

11.425 *

6.10E+002

9.33E+002

6.09E+002

9.13E+002

# 220KV Bus2

11kV Bus.

99.98

0.058

99.99

100.00

99.98

0.033

0.000

3.04E+003

3.16E+003

# 132KV BUS

11kV Bus.

99.86

0.505

99.96

99.99

99.91

0.293

0.000

3.42E+002

3.63E+002

Bus8

220KV Bus2

99.99

0.001

100.00

100.00

99.99

0.000

0.000

1.47E+004

2.01E+004

Bus9

220KV Bus2

99.99

0.001

100.00

100.00

99.99

0.000

0.000

1.66E+004

2.31E+004

# 132KV BUS

220KV Bus2

99.86

0.004

99.96

99.99

99.91

0.001

0.000

3.26E+003

4.66E+003

Bus6

220KV Bus1

99.98

0.002

100.00

100.00

99.99

0.001

0.000

8.39E+003

9.97E+003

Bus7

9.97E+003

220KV Bus1

99.98

0.002

100.00

100.00

99.99

0.001

0.000

8.39E+003

# 132KV BUS

220KV Bus1

99.86

0.004

99.96

99.99

99.91

0.001

0.000

3.26E+003

4.66E+003

# T11~3

220KV Bus1

99.85

0.000

99.90

100.00

99.94

0.000

0.000 *

6.11E+004

8.74E+004

Bus13

132KV BUS

99.94

0.009

99.98

100.00

99.96

0.003

0.000

1.97E+003

4.37E+003

Bus11

132KV BUS

99.95

0.007

99.98

100.00

99.97

0.002

0.000

2.31E+003

5.55E+003

Bus12

132KV BUS

99.95

0.007

99.98

100.00

99.97

0.002

0.000

2.31E+003

5.55E+003

Bus15

132KV BUS

99.96

0.006

99.99

100.00

99.98

0.002

0.000

2.71E+003

6.89E+003

33KV BUS 1

132KV BUS

99.86

0.000

99.96

99.99

99.91

0.000

0.000

33KV BUS 2

132KV BUS

99.86

0.000

99.96

99.99

99.91

0.000

0.000

132KV BUS

99.85

0.000

99.90

100.00

99.94

0.000

0.000 *

6.11E+004

8.72E+004

# T11~3

220kV OG Line-1

Bus8

100.00

0.001

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.001

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.002

100.00

100.00

100.00

0.001

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.002

100.00

100.00

100.00

0.001

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

U9

Bus13

100.00

0.009

100.00

100.00

100.00

0.003

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.007

100.00

100.00

100.00

0.002

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.007

100.00

100.00

100.00

0.002

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.006

100.00

100.00

100.00

0.002

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

0.433kV Bus-2

33KV BUS 2

99.86

0.000

99.91

100.00

99.95

0.000

0.000

Page 128 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

9

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID


%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1

220KV Bus1

220KV Bus2

99.98

0.000

99.99

100.00

99.98

0.000

0.000

33KV BUS 1

Bus Ref A

99.86

0.000

99.96

99.99

99.91

0.000

0.000

33KV BUS 2

33KV BUS 1

99.86

0.000

99.96

99.99

99.91

0.000

0.000

33KV BUS 2

Bus Ref B

99.86

0.000

99.96

99.99

99.91

0.000

0.000

Initial Symmetrical Current (kA, rms) Peak Current (kA), Method C Breaking Current (kA, rms, symm) Steady State Current (kA, rms)

: : : :

3-Phase 11.367 18.617 11.367

L-G 11.425 18.711 11.425 11.425

L-L 9.844 16.122 9.844 9.844


X0

L-L-G 11.427 18.714 11.427 11.427

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

Page 129 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

10

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal


From Bus ID


0.433kV Bus-2

Total

33KV BUS 2

%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1


X0

0.00

16.075

0.00

99.33

100.01

16.182

16.182

4.29E+002

6.61E+002

4.28E+002

6.43E+002

0.433kV Bus-2

98.02

16.075

98.66

100.00

99.35

16.182

16.182 *

4.29E+002

6.61E+002

4.28E+002

6.43E+002

132KV BUS

33KV BUS 2

99.82

0.105

99.89

100.00

99.93

0.061

0.000

5.51E+002

5.66E+002

132KV BUS

33KV BUS 1

99.82

0.105

99.89

100.00

99.93

0.061

0.000

5.43E+002

5.74E+002

Bus13

132KV BUS

99.92

0.011

99.95

100.00

99.98

0.007

0.000

1.22E+003

1.47E+003

Bus11

132KV BUS

99.94

0.009

99.96

100.00

99.98

0.005

0.000

1.48E+003

1.89E+003

Bus12

132KV BUS

99.94

0.009

99.96

100.00

99.98

0.005

0.000

1.48E+003

1.89E+003

Bus15

132KV BUS

99.95

0.007

99.97

100.00

99.99

0.004

0.000

1.77E+003

2.37E+003

# 220KV Bus2

132KV BUS

99.96

0.009

99.97

100.00

99.98

0.005

0.000

1.89E+003

1.54E+003

# 11kV Bus.

132KV BUS

99.80

0.000

99.87

99.94

99.99

0.000

0.000 *

3.54E+004

2.90E+004

# 220KV Bus1

132KV BUS

99.96

0.009

99.97

100.00

99.98

0.005

0.000

1.89E+003

1.54E+003

# T11~3

132KV BUS

99.80

0.000

99.87

99.94

99.99

0.000

0.000 *

3.54E+004

2.90E+004

U9

Bus13

100.00

0.011

100.00

100.00

100.00

0.007

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.009

100.00

100.00

100.00

0.005

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.009

100.00

100.00

100.00

0.005

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.007

100.00

100.00

100.00

0.004

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

Bus8

220KV Bus2

99.98

0.002

99.99

100.00

99.99

0.001

0.000

5.46E+003

4.92E+003

Bus9

220KV Bus2

99.98

0.002

99.99

100.00

99.99

0.001

0.000

6.21E+003

5.66E+003

3.54E+004

2.91E+004

# 11kV Bus.

220KV Bus2

99.80

0.000

99.87

99.94

99.99

0.000

0.000 *

0.433kV Bus-1

11kV Bus.

99.80

0.000

99.92

99.88

100.00

0.000

0.000

Bus6

220KV Bus1

99.97

0.003

99.98

100.00

99.99

0.002

0.000

3.03E+003

2.37E+003

Bus7

220KV Bus1

99.97

0.003

99.98

100.00

99.99

0.002

0.000

3.03E+003

2.37E+003

# T11~3

220KV Bus1

99.80

0.000

99.87

99.94

99.99

0.000

0.000 *

3.54E+004

2.91E+004

220kV OG Line-1

Bus8

100.00

0.002

100.00

100.00

100.00

0.001

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.002

100.00

100.00

100.00

0.001

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.003

100.00

100.00

100.00

0.002

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.003

100.00

100.00

100.00

0.002

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

98.02

0.000

98.66

100.00

99.35

0.000

0.000

33KV BUS 1

33KV BUS 2

98.02

0.105

98.66

100.00

99.35

0.061

0.000

Page 130 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

11

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID


%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1

33KV BUS 2

Bus Ref B

98.02

0.000

98.66

100.00

99.35

0.000

0.000

220KV Bus1

220KV Bus2

99.96

0.002

99.97

100.00

99.98

0.001

0.000


: : : :

3-Phase 16.075 26.364 16.075

L-G 16.182 26.539 16.182 16.182

L-L 13.922 22.832 13.922 13.922


X0

L-L-G 16.185 26.543 16.185 16.185


Page 131 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

11kV Bus. = 11.000 = 1.00 (Minimum If) Contribution

From Bus ID


11kV Bus.

Total

0.433kV Bus-1

%V From Bus 0.00



kA Symm. rms 26.699

Va


0.00

173.21

173.21

kA Symm. rms Ia 3I0 0.000

0.000

R1


7.37E-001

1.96E+001

11kV Bus.

0.00

0.000

100.00

100.00

100.00

0.000

0.000

# 220KV Bus2

11kV Bus.

98.62

3.432

100.00

100.00

100.00

0.000

0.000

3.98E+000

1.53E+002

# 132KV BUS

11kV Bus.

91.52

30.131

100.00

100.00

100.00

0.000

0.000

6.30E-001

1.74E+001

Bus8

220KV Bus2

99.40

0.060

100.00

100.00

100.00

0.000

0.000

2.26E+002

2.49E+001

Bus9

220KV Bus2

99.47

0.052

100.00

100.00

100.00

0.000

0.000

2.58E+002

3.02E+001

220KV Bus2

91.52

0.262

100.00

100.00

100.00

0.000

0.000

5.15E+001

6.74E+000

Bus6

220KV Bus1

98.87

0.114

100.00

100.00

100.00

0.000

0.000

1.19E+002

4.87E+000

Bus7

# 132KV BUS

220KV Bus1

98.87

0.114

100.00

100.00

100.00

0.000

0.000

1.19E+002

4.87E+000

# 132KV BUS

220KV Bus1

91.52

0.262

100.00

100.00

100.00

0.000

0.000

5.15E+001

6.74E+000

# T11~3

220KV Bus1

90.68

0.014

100.00

100.00

100.00

0.000

0.000

9.66E+002

1.26E+002

Bus13

132KV BUS

96.03

0.517

100.00

100.00

100.00

0.000

0.000

4.29E+001

7.78E+000

Bus11

132KV BUS

96.83

0.412

100.00

100.00

100.00

0.000

0.000

5.35E+001

1.12E+001

Bus12

132KV BUS

96.83

0.412

100.00

100.00

100.00

0.000

0.000

5.35E+001

1.12E+001

Bus15

132KV BUS

97.43

0.334

100.00

100.00

100.00

0.000

0.000

6.57E+001

1.52E+001

33KV BUS 1

132KV BUS

91.52

0.000

100.00

100.00

100.00

0.000

0.000

33KV BUS 2

132KV BUS

91.52

0.000

100.00

100.00

100.00

0.000

0.000

132KV BUS

90.68

0.023

100.00

100.00

100.00

0.000

0.000

9.69E+002

8.46E+000

# T11~3

12

X0

220kV OG Line-1

Bus8

100.00

0.060

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.052

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.114

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.114

100.00

100.00

100.00

0.000

0.000

1.91E-001

2.68E+000

1.91E-001

2.68E+000

U9

Bus13

100.00

0.517

100.00

100.00

100.00

0.000

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.412

100.00

100.00

100.00

0.000

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.412

100.00

100.00

100.00

0.000

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.334

100.00

100.00

100.00

0.000

0.000

2.40E-001

3.36E+000

2.40E-001

3.36E+000

0.433kV Bus-2

33KV BUS 2

91.52

0.000

100.00

100.00

100.00

0.000

0.000

220KV Bus2

220KV Bus1

98.62

0.029

100.00

100.00

100.00

0.000

0.000

33KV BUS 1

Bus Ref A

91.52

0.000

100.00

100.00

100.00

0.000

0.000

Page 132 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

13

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)


11kV Bus. = 11.000 = 1.00 (Minimum If) Contribution

From Bus ID


%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1

33KV BUS 2

33KV BUS 1

91.52

0.000

100.00

100.00

100.00

0.000

0.000

33KV BUS 2

Bus Ref B

91.52

0.000

100.00

100.00

100.00

0.000

0.000


: : : :

3-Phase 26.699 71.651 26.699

L-G 0.000 0.000 0.000 0.000

L-L 23.122 62.051 23.122 23.122


X0

L-L-G 23.122 62.051 23.122 23.122


Page 133 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

14

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

33KV BUS 1 = 33.000 = 1.00 (Minimum If) Contribution

From Bus ID


33KV BUS 1

Total

132KV BUS 0.433kV Bus-2

%V From Bus



kA Symm. rms

Va


0.00

9.625

0.00

99.84

33KV BUS 1

91.59

4.812

91.79

33KV BUS 2

0.00

0.000

57.70

132KV BUS

33KV BUS 2

91.59

4.813

Bus13

132KV BUS

96.06

Bus11

132KV BUS

Bus12

132KV BUS

Bus15

kA Symm. rms Ia 3I0

R1


X0

99.94

9.646

9.646

7.79E-001

1.82E+001

8.03E-001

1.80E+001

99.84

99.94

4.823

4.823

1.82E+000

3.63E+001

1.87E+000

3.61E+001

57.65

100.00

0.000

0.000

91.79

99.84

99.94

4.823

4.823

1.30E+000

3.63E+001

1.35E+000

3.61E+001

0.512

96.45

99.91

99.70

0.463

0.365

1.68E+000

7.08E+000

3.73E+000

8.71E+000

96.86

0.408

97.21

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

96.86

0.408

97.21

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

132KV BUS

97.46

0.331

97.76

99.91

99.79

0.293

0.219

3.12E+000

1.08E+001

7.22E+000

1.41E+001

# 220KV Bus2

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# 11kV Bus.

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

# 220KV Bus1

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# T11~3

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

U9

Bus13

100.00

0.512

100.00

100.00

100.00

0.463

0.365

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.331

100.00

100.00

100.00

0.293

0.219

2.40E-001

3.36E+000

2.40E-001

3.36E+000

Bus8

220KV Bus2

99.19

0.080

99.34

99.94

99.90

0.065

0.034

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

99.29

0.070

99.43

99.94

99.91

0.056

0.029

1.06E+000

7.10E+000

3.21E+000

1.55E+001

220KV Bus2

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

0.433kV Bus-1

11kV Bus.

90.82

0.000

98.11

93.86

98.89

0.000

0.000

Bus6

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

Bus7

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# T11~3

220KV Bus1

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

# 11kV Bus.

220kV OG Line-1

Bus8

100.00

0.080

100.00

100.00

100.00

0.065

0.034

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.070

100.00

100.00

100.00

0.056

0.029

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

0.00

0.000

0.00

99.84

99.94

0.000

0.000

33KV BUS 2

33KV BUS 1

0.00

4.813

0.00

99.84

99.94

4.823

4.823

33KV BUS 2

Bus Ref B

0.00

0.000

0.00

99.84

99.94

0.000

0.000

Page 134 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

15

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID

220KV Bus1


%V From Bus

220KV Bus2


kA Symm. rms

98.12

: : : :

3-Phase 9.625 25.636 9.625



0.078

Va


98.19

L-G 9.646 25.692 9.646 9.646

99.95

99.98

L-L 8.335 22.201 8.335 8.335

kA Symm. rms Ia 3I0

0.073

R1


X0

0.064

L-L-G 9.640 25.676 9.640 9.640


Page 135 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

16

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal


From Bus ID


%V From Bus 0.00



kA Symm. rms

33KV BUS 2

Total

9.625

0.433kV Bus-2

33KV BUS 2

0.00

0.000

132KV BUS

33KV BUS 2

91.59

4.813

132KV BUS

33KV BUS 1

91.59

4.812

Bus13

132KV BUS

96.06

Bus11

132KV BUS

Bus12

132KV BUS

Bus15

Va


0.00

kA Symm. rms Ia 3I0

99.84

99.94

9.646

9.646

57.70

57.65

100.00

0.000

0.000

91.79

99.84

99.94

4.823

91.79

99.84

99.94

0.512

96.45

99.91

96.86

0.408

97.21

96.86

0.408

97.21

132KV BUS

97.46

0.331

R1


X0

7.79E-001

1.82E+001

8.03E-001

1.80E+001

4.823

1.30E+000

3.63E+001

1.35E+000

3.61E+001

4.823

4.823

1.82E+000

3.63E+001

1.87E+000

3.61E+001

99.70

0.463

0.365

1.68E+000

7.08E+000

3.73E+000

8.71E+000

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

97.76

99.91

99.79

0.293

0.219

3.12E+000

1.08E+001

7.22E+000

1.41E+001

# 220KV Bus2

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# 11kV Bus.

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

# 220KV Bus1

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# T11~3

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

U9

Bus13

100.00

0.512

100.00

100.00

100.00

0.463

0.365

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.331

100.00

100.00

100.00

0.293

0.219

2.40E-001

3.36E+000

2.40E-001

3.36E+000

Bus8

220KV Bus2

99.19

0.080

99.34

99.94

99.90

0.065

0.034

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

99.29

0.070

99.43

99.94

99.91

0.056

0.029

1.06E+000

7.10E+000

3.21E+000

1.55E+001

220KV Bus2

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

0.433kV Bus-1

11kV Bus.

90.82

0.000

98.11

93.86

98.89

0.000

0.000

Bus6

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

Bus7

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# T11~3

220KV Bus1

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

# 11kV Bus.

220kV OG Line-1

Bus8

100.00

0.080

100.00

100.00

100.00

0.065

0.034

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.070

100.00

100.00

100.00

0.056

0.029

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

0.00

0.000

0.00

99.84

99.94

0.000

0.000

33KV BUS 1

33KV BUS 2

0.00

4.812

0.00

99.84

99.94

4.823

4.823

33KV BUS 2

Bus Ref B

0.00

0.000

0.00

99.84

99.94

0.000

0.000

Page 136 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

17

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID

220KV Bus1


%V From Bus

220KV Bus2


kA Symm. rms

98.12

: : : :

3-Phase 9.625 25.636 9.625



0.078

Va


98.19

L-G 9.646 25.692 9.646 9.646

99.95

99.98

L-L 8.335 22.201 8.335 8.335

kA Symm. rms Ia 3I0

0.073

R1


X0

0.064

L-L-G 9.640 25.676 9.640 9.640


Page 137 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

18

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

132KV BUS = 132.000 = 1.00 (Minimum If) Contribution

From Bus ID


132KV BUS

Total

Bus13 Bus11

%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1


X0

0.00

28.281

0.00

97.87

99.69

28.986

28.986

2.90E-001

1.52E+000

3.13E-001

1.40E+000

132KV BUS

54.85

6.015

58.82

98.32

97.00

5.561

4.387

1.68E+000

7.08E+000

3.73E+000

8.71E+000

132KV BUS

64.15

4.796

67.71

98.33

97.51

4.383

3.346

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus12

132KV BUS

64.15

4.796

67.71

98.33

97.51

4.383

3.346

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus15

132KV BUS

70.99

3.892

74.11

98.43

97.95

3.527

2.629

3.12E+000

1.08E+001

7.22E+000

1.41E+001

33KV BUS 1

132KV BUS

0.00

0.000

0.00

97.87

99.69

0.000

0.000

9.27E+000

5.35E-001

1.17E+001

33KV BUS 2

132KV BUS

0.00

0.000

0.00

97.87

99.69

0.000

0.000

# 220KV Bus2

132KV BUS

77.53

4.716

77.76

99.28

99.92

4.406

3.551

3.60E-001

# 11kV Bus.

132KV BUS

9.16

0.251

55.31

53.95

100.00

1.293

4.393 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

# 220KV Bus1

132KV BUS

77.53

4.716

77.76

99.28

99.92

4.406

3.551

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# T11~3

132KV BUS

9.16

0.251

55.31

53.95

100.00

1.293

4.393 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

U9

Bus13

100.00

6.015

100.00

100.00

100.00

5.561

4.387

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

4.796

100.00

100.00

100.00

4.383

3.346

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

4.796

100.00

100.00

100.00

4.383

3.346

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

3.892

100.00

100.00

100.00

3.527

2.629

2.40E-001

3.36E+000

2.40E-001

3.36E+000

0.433kV Bus-2

33KV BUS 2

0.00

0.000

57.56

56.51

100.00

0.000

0.000

Bus8

220KV Bus2

90.37

0.941

92.01

99.03

99.11

0.781

0.413

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

91.57

0.823

93.07

99.11

99.21

0.677

0.345

1.06E+000

7.10E+000

3.21E+000

1.55E+001

220KV Bus2

9.16

0.151

55.31

53.95

100.00

0.307

0.613 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

0.433kV Bus-1

11kV Bus.

9.16

0.000

87.96

25.43

87.10

0.000

0.000

Bus6

220KV Bus1

81.63

1.798

83.54

99.04

98.62

1.610

1.144

2.37E-001

3.28E+000

7.78E-001

4.70E+000

Bus7

220KV Bus1

81.63

1.798

83.54

99.04

98.62

1.610

1.144

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# T11~3

220KV Bus1

9.16

0.151

55.31

53.95

100.00

0.307

0.613 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

# 11kV Bus.

220kV OG Line-1

Bus8

100.00

0.941

100.00

100.00

100.00

0.781

0.413

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.823

100.00

100.00

100.00

0.677

0.345

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

1.798

100.00

100.00

100.00

1.610

1.144

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

1.798

100.00

100.00

100.00

1.610

1.144

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

0.00

0.000

0.00

97.87

99.69

0.000

0.000

33KV BUS 2

33KV BUS 1

0.00

0.000

0.00

97.87

99.69

0.000

0.000

33KV BUS 2

Bus Ref B

0.00

0.000

0.00

97.87

99.69

0.000

0.000

Page 138 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

19

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)


132KV BUS = 132.000 = 1.00 (Minimum If) Contribution

From Bus ID

220KV Bus1


%V From Bus

220KV Bus2


kA Symm. rms

77.53

: : : :

3-Phase 28.281 63.930 28.281



0.920

Va


77.76

L-G 28.986 65.523 28.986 28.986

99.28

99.92

L-L 24.492 55.365 24.492 24.492

kA Symm. rms Ia 3I0

0.883

R1


X0

0.765

L-L-G 28.911 65.355 28.911 28.911


Page 139 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

20

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

220KV Bus1 = 220.000 = 1.00 (Minimum If) Contribution

From Bus ID


220KV Bus1

Total

Bus6 Bus7

%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1


X0

0.00

28.161

0.00

101.61

103.16

26.866

26.866

9.12E-002

9.27E-001

1.32E-001

1.06E+000

220KV Bus1

18.28

7.984

27.65

98.50

96.22

7.080

6.016

2.37E-001

3.28E+000

7.78E-001

4.70E+000

220KV Bus1

18.28

7.984

27.65

98.50

96.22

7.080

6.016

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# 132KV BUS

220KV Bus1

63.27

2.309

66.18

98.96

99.76

2.212

2.231

1.24E+000

1.13E+001

1.23E+000

1.28E+001

# T11~3

220KV Bus1

70.74

0.123

84.45

88.18

100.00

0.996

3.222 *

2.32E+001

2.12E+002

1.98E-001

8.89E+000

Bus8

220KV Bus2

57.40

4.180

65.58

96.82

97.29

3.382

2.174

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

62.76

3.656

70.20

97.00

97.54

2.929

1.812

1.06E+000

7.10E+000

3.21E+000

1.55E+001

# 132KV BUS

220KV Bus2

63.27

2.309

66.18

98.96

99.76

2.212

2.231

1.24E+000

1.13E+001

1.23E+000

1.28E+001

# 11kV Bus.

220KV Bus2

70.74

0.123

84.45

88.18

100.00

0.996

3.222 *

2.32E+001

2.12E+002

1.98E-001

8.89E+000

Bus6

100.00

7.984

100.00

100.00

100.00

7.080

6.016

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

7.984

100.00

100.00

100.00

7.080

6.016

1.91E-001

2.68E+000

1.91E-001

2.68E+000

Bus13

132KV BUS

82.71

2.248

85.25

99.48

98.81

1.921

1.481

1.68E+000

7.08E+000

3.73E+000

8.71E+000

Bus11

132KV BUS

86.22

1.793

88.40

99.49

99.00

1.514

1.129

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus12

132KV BUS

86.22

1.793

88.40

99.49

99.00

1.514

1.129

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus15

132KV BUS

88.83

1.455

90.68

99.53

99.16

1.219

0.887

3.12E+000

1.08E+001

7.22E+000

1.41E+001

220kV IC Line-1

33KV BUS 1

132KV BUS

63.27

0.000

66.18

98.96

99.76

0.000

0.000

33KV BUS 2

132KV BUS

63.27

0.000

66.18

98.96

99.76

0.000

0.000

# 11kV Bus.

132KV BUS

70.74

0.205

84.45

88.18

100.00

0.620

1.483 *

2.02E+001

7.71E+001

2.10E-001

9.46E+000

# T11~3

132KV BUS

70.74

0.205

84.45

88.18

100.00

0.620

1.483 *

2.02E+001

7.71E+001

2.10E-001

9.46E+000

Bus8

100.00

4.180

100.00

100.00

100.00

3.382

2.174

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

3.656

100.00

100.00

100.00

2.929

1.812

1.91E-001

2.68E+000

1.91E-001

2.68E+000

0.433kV Bus-1

11kV Bus.

70.74

0.000

93.96

81.27

97.33

0.000

0.000

U9

Bus13

100.00

2.248

100.00

100.00

100.00

1.921

1.481

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

1.793

100.00

100.00

100.00

1.514

1.129

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

1.793

100.00

100.00

100.00

1.514

1.129

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

1.455

100.00

100.00

100.00

1.219

0.887

2.40E-001

3.36E+000

2.40E-001

3.36E+000

0.433kV Bus-2

33KV BUS 2

63.27

0.000

81.30

84.70

100.00

0.000

0.000

220KV Bus2

220KV Bus1

0.00

10.020

0.00

101.61

103.16

9.507

9.409

33KV BUS 1

Bus Ref A

63.27

0.000

66.18

98.96

99.76

0.000

0.000

220kV OG Line-1

Page 140 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

21

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID


%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1

33KV BUS 2

33KV BUS 1

63.27

0.000

66.18

98.96

99.76

0.000

0.000

33KV BUS 2

Bus Ref B

63.27

0.000

66.18

98.96

99.76

0.000

0.000


: : : :

3-Phase 28.161 69.772 28.161

L-G 26.866 66.563 26.866 26.866

L-L 24.388 60.425 24.388 24.388


X0

L-L-G 27.770 68.803 27.770 27.770


Page 141 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

22

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal


From Bus ID


220KV Bus2

Total

Bus8 Bus9

%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

0.00

28.161

0.00

101.61

103.16

26.866

26.866

220KV Bus2

57.40

4.180

65.58

96.82

97.29

3.382

220KV Bus2

62.76

3.656

70.20

97.00

97.54

2.929

# 132KV BUS

220KV Bus2

63.27

2.309

66.18

98.96

99.76

2.212

2.231

# 11kV Bus.

220KV Bus2

70.74

0.123

84.45

88.18

100.00

0.996

3.222 *

Bus6

220KV Bus1

18.28

7.984

27.65

98.50

96.22

7.080

6.016

Bus7

R1


X0

9.12E-002

9.27E-001

1.32E-001

1.06E+000

2.174

8.84E-001

6.22E+000

2.60E+000

1.29E+001

1.812

1.06E+000

7.10E+000

3.21E+000

1.55E+001

1.24E+000

1.13E+001

1.23E+000

1.28E+001

2.32E+001

2.12E+002

1.98E-001

8.89E+000

2.37E-001

3.28E+000

7.78E-001

4.70E+000

220KV Bus1

18.28

7.984

27.65

98.50

96.22

7.080

6.016

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# 132KV BUS

220KV Bus1

63.27

2.309

66.18

98.96

99.76

2.212

2.231

1.24E+000

1.13E+001

1.23E+000

1.28E+001

# T11~3

220KV Bus1

70.74

0.123

84.45

88.18

100.00

0.996

3.222 *

2.32E+001

2.12E+002

1.98E-001

8.89E+000

Bus8

100.00

4.180

100.00

100.00

100.00

3.382

2.174

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

3.656

100.00

100.00

100.00

2.929

1.812

1.91E-001

2.68E+000

1.91E-001

2.68E+000

Bus13

132KV BUS

82.71

2.248

85.25

99.48

98.81

1.921

1.481

1.68E+000

7.08E+000

3.73E+000

8.71E+000

Bus11

132KV BUS

86.22

1.793

88.40

99.49

99.00

1.514

1.129

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus12

132KV BUS

86.22

1.793

88.40

99.49

99.00

1.514

1.129

2.35E+000

8.81E+000

5.36E+000

1.12E+001

Bus15

132KV BUS

88.83

1.455

90.68

99.53

99.16

1.219

0.887

3.12E+000

1.08E+001

7.22E+000

1.41E+001

220kV OG Line-1

33KV BUS 1

132KV BUS

63.27

0.000

66.18

98.96

99.76

0.000

0.000

33KV BUS 2

132KV BUS

63.27

0.000

66.18

98.96

99.76

0.000

0.000

# 11kV Bus.

132KV BUS

70.74

0.205

84.45

88.18

100.00

0.620

1.483 *

2.02E+001

7.71E+001

2.10E-001

9.46E+000

# T11~3

132KV BUS

70.74

0.205

84.45

88.18

100.00

0.620

1.483 *

2.02E+001

7.71E+001

2.10E-001

9.46E+000

0.433kV Bus-1

11kV Bus.

70.74

0.000

93.96

81.27

97.33

0.000

0.000

220kV IC Line-1

Bus6

100.00

7.984

100.00

100.00

100.00

7.080

6.016

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

7.984

100.00

100.00

100.00

7.080

6.016

1.91E-001

2.68E+000

1.91E-001

2.68E+000

U9

Bus13

100.00

2.248

100.00

100.00

100.00

1.921

1.481

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

1.793

100.00

100.00

100.00

1.514

1.129

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

1.793

100.00

100.00

100.00

1.514

1.129

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

1.455

100.00

100.00

100.00

1.219

0.887

2.40E-001

3.36E+000

2.40E-001

3.36E+000

0.433kV Bus-2

33KV BUS 2

63.27

0.000

81.30

84.70

100.00

0.000

0.000

220KV Bus1

220KV Bus2

0.00

18.153

0.00

101.61

103.16

17.363

17.457

33KV BUS 1

Bus Ref A

63.27

0.000

66.18

98.96

99.76

0.000

0.000

Page 142 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

23

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)



From Bus ID


%V From Bus



kA Symm. rms

Va


kA Symm. rms Ia 3I0

R1

33KV BUS 2

33KV BUS 1

63.27

0.000

66.18

98.96

99.76

0.000

0.000

33KV BUS 2

Bus Ref B

63.27

0.000

66.18

98.96

99.76

0.000

0.000


: : : :

3-Phase 28.161 69.772 28.161

L-G 26.866 66.563 26.866 26.866

L-L 24.388 60.425 24.388 24.388


X0

L-L-G 27.770 68.803 27.770 27.770


Page 143 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

24

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Bus Ref A = 33.000 = 1.00 (Minimum If) Contribution

From Bus ID


Bus Ref A

Total

132KV BUS 0.433kV Bus-2

%V From Bus



kA Symm. rms

Va


0.00

9.625

0.00

99.84

33KV BUS 1

91.59

4.812

91.79

33KV BUS 2

0.00

0.000

57.70

132KV BUS

33KV BUS 2

91.59

4.813

Bus13

132KV BUS

96.06

Bus11

132KV BUS

Bus12

132KV BUS

Bus15

kA Symm. rms Ia 3I0

R1


X0

99.94

9.646

9.646

7.79E-001

1.82E+001

8.03E-001

1.80E+001

99.84

99.94

4.823

4.823

1.82E+000

3.63E+001

1.87E+000

3.61E+001

57.65

100.00

0.000

0.000

91.79

99.84

99.94

4.823

4.823

1.30E+000

3.63E+001

1.35E+000

3.61E+001

0.512

96.45

99.91

99.70

0.463

0.365

1.68E+000

7.08E+000

3.73E+000

8.71E+000

96.86

0.408

97.21

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

96.86

0.408

97.21

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

132KV BUS

97.46

0.331

97.76

99.91

99.79

0.293

0.219

3.12E+000

1.08E+001

7.22E+000

1.41E+001

# 220KV Bus2

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# 11kV Bus.

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

# 220KV Bus1

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# T11~3

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

U9

Bus13

100.00

0.512

100.00

100.00

100.00

0.463

0.365

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.331

100.00

100.00

100.00

0.293

0.219

2.40E-001

3.36E+000

2.40E-001

3.36E+000

Bus8

220KV Bus2

99.19

0.080

99.34

99.94

99.90

0.065

0.034

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

99.29

0.070

99.43

99.94

99.91

0.056

0.029

1.06E+000

7.10E+000

3.21E+000

1.55E+001

220KV Bus2

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

0.433kV Bus-1

11kV Bus.

90.82

0.000

98.11

93.86

98.89

0.000

0.000

Bus6

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

Bus7

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# T11~3

220KV Bus1

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

# 11kV Bus.

220kV OG Line-1

Bus8

100.00

0.080

100.00

100.00

100.00

0.065

0.034

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.070

100.00

100.00

100.00

0.056

0.029

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

0.00

9.625

0.00

99.84

99.94

9.646

9.646

33KV BUS 2

33KV BUS 1

0.00

4.813

0.00

99.84

99.94

4.823

4.823

33KV BUS 2

Bus Ref B

0.00

0.000

0.00

99.84

99.94

0.000

0.000

Page 144 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

25

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)


Bus Ref A = 33.000 = 1.00 (Minimum If) Contribution

From Bus ID

220KV Bus1


%V From Bus

220KV Bus2


kA Symm. rms

98.12

: : : :

3-Phase 9.625 25.636 9.625



0.078

Va


98.19

L-G 9.646 25.692 9.646 9.646

99.95

99.98

L-L 8.335 22.201 8.335 8.335

kA Symm. rms Ia 3I0

0.073

R1


X0

0.064

L-L-G 9.640 25.676 9.640 9.640


Page 145 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL


Page:

11.1.0C

Study Case: HPL

26

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Bus Ref B = 33.000 = 1.00 (Minimum If) Contribution

From Bus ID


%V From Bus 0.00



kA Symm. rms

Bus Ref B

Total

9.625

0.433kV Bus-2

33KV BUS 2

0.00

0.000

132KV BUS

33KV BUS 2

91.59

4.813

132KV BUS

33KV BUS 1

91.59

4.812

Bus13

132KV BUS

96.06

Bus11

132KV BUS

Bus12

132KV BUS

Bus15

Va


0.00

kA Symm. rms Ia 3I0

99.84

99.94

9.646

9.646

57.70

57.65

100.00

0.000

0.000

91.79

99.84

99.94

4.823

91.79

99.84

99.94

0.512

96.45

99.91

96.86

0.408

97.21

96.86

0.408

97.21

132KV BUS

97.46

0.331

R1


X0

7.79E-001

1.82E+001

8.03E-001

1.80E+001

4.823

1.30E+000

3.63E+001

1.35E+000

3.61E+001

4.823

4.823

1.82E+000

3.63E+001

1.87E+000

3.61E+001

99.70

0.463

0.365

1.68E+000

7.08E+000

3.73E+000

8.71E+000

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

99.91

99.75

0.365

0.278

2.35E+000

8.81E+000

5.36E+000

1.12E+001

97.76

99.91

99.79

0.293

0.219

3.12E+000

1.08E+001

7.22E+000

1.41E+001

# 220KV Bus2

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# 11kV Bus.

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

# 220KV Bus1

132KV BUS

98.12

0.401

98.19

99.95

99.98

0.367

0.295

3.60E-001

9.27E+000

5.35E-001

1.17E+001

# T11~3

132KV BUS

90.82

0.021

95.03

95.84

100.00

0.108

0.365 *

6.75E+000

1.74E+002

2.10E-001

9.46E+000

U9

Bus13

100.00

0.512

100.00

100.00

100.00

0.463

0.365

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U24

Bus11

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U8

Bus12

100.00

0.408

100.00

100.00

100.00

0.365

0.278

2.40E-001

3.36E+000

2.40E-001

3.36E+000

U10

Bus15

100.00

0.331

100.00

100.00

100.00

0.293

0.219

2.40E-001

3.36E+000

2.40E-001

3.36E+000

Bus8

220KV Bus2

99.19

0.080

99.34

99.94

99.90

0.065

0.034

8.84E-001

6.22E+000

2.60E+000

1.29E+001

Bus9

220KV Bus2

99.29

0.070

99.43

99.94

99.91

0.056

0.029

1.06E+000

7.10E+000

3.21E+000

1.55E+001

220KV Bus2

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

0.433kV Bus-1

11kV Bus.

90.82

0.000

98.11

93.86

98.89

0.000

0.000

Bus6

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

Bus7

220KV Bus1

98.47

0.153

98.66

99.95

99.86

0.134

0.095

2.37E-001

3.28E+000

7.78E-001

4.70E+000

# T11~3

220KV Bus1

90.82

0.013

95.03

95.84

100.00

0.026

0.051 *

3.76E+000

3.90E+001

1.98E-001

8.89E+000

# 11kV Bus.

220kV OG Line-1

Bus8

100.00

0.080

100.00

100.00

100.00

0.065

0.034

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV OG Line-2

Bus9

100.00

0.070

100.00

100.00

100.00

0.056

0.029

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-1

Bus6

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

220kV IC Line-2

Bus7

100.00

0.153

100.00

100.00

100.00

0.134

0.095

1.91E-001

2.68E+000

1.91E-001

2.68E+000

33KV BUS 1

Bus Ref A

0.00

0.000

0.00

99.84

99.94

0.000

0.000

33KV BUS 1

33KV BUS 2

0.00

4.812

0.00

99.84

99.94

4.823

4.823

33KV BUS 2

Bus Ref B

0.00

9.625

0.00

99.84

99.94

9.646

9.646

Page 146 of 160

Project:

ETAP


Page:

11.1.0C

Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Study Case: HPL

27

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

(Cont.)


Bus Ref B = 33.000 = 1.00 (Minimum If) Contribution

From Bus ID

220KV Bus1


%V From Bus

220KV Bus2


kA Symm. rms

98.12

: : : :

3-Phase 9.625 25.636 9.625



0.078

Va


98.19

L-G 9.646 25.692 9.646 9.646

99.95

99.98

L-L 8.335 22.201 8.335 8.335

kA Symm. rms Ia 3I0

0.073

R1


X0

0.064

L-L-G 9.640 25.676 9.640 9.640


Page 147 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

28

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Short-Circuit Summary Report 3-Phase, LG, LL, LLG Fault Currents Bus ID

3-Phase Fault kV

I"k

Line-to-Ground Fault

ip

Ik

I"k

ip

Ib

Line-to-Line Fault Ik

I"k

ip

Ib

*Line-to-Line-to-Ground Ik

I"k

ip

Ib

Ik

0.433kV Bus-1

0.433

11.367

18.617

11.367

11.425

18.711

11.425

11.425

9.844

16.122

9.844

9.844

11.427

18.714

11.427

11.427

0.433kV Bus-2

0.433

16.075

26.364

16.075

16.182

26.539

16.182

16.182

13.922

22.832

13.922

13.922

16.185

26.543

16.185

16.185

11kV Bus.

11.000

26.699

71.651

26.699

0.000

0.000

0.000

0.000

23.122

62.051

23.122

23.122

23.122

62.051

23.122

23.122

33KV BUS 1

33.000

9.625

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

33KV BUS 2

33.000

9.625

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

132KV BUS

132.000

28.281

63.930

28.281

28.986

65.523

28.986

28.986

24.492

55.365

24.492

24.492

28.911

65.355

28.911

28.911

220KV Bus1

220.000

28.161

69.772

28.161

26.866

66.563

26.866

26.866

24.388

60.425

24.388

24.388

27.770

68.803

27.770

27.770

220KV Bus2

220.000

28.161

69.772

28.161

26.866

66.563

26.866

26.866

24.388

60.425

24.388

24.388

27.770

68.803

27.770

27.770

Bus Ref A

33.000

9.625

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

Bus Ref B

33.000

9.625

25.636

9.625

9.646

25.692

9.646

9.646

8.335

22.201

8.335

8.335

9.640

25.676

9.640

9.640

All fault currents are in rms kA. Current ip is calculated using Method C. * LLG fault current is the larger of the two faulted line currents.

Page 148 of 160

Project:

ETAP


Location:

Dehradun

Contract:

HPL

Engineer:

Marimuthu.N

Filename:

HPL

Page:

11.1.0C

Study Case: HPL

29

Date:

16-09-2013

SN:

VOLTECHENG

Revision:

Base

Config.:

Normal

Sequence Impedance Summary Report Bus ID

Positive Seq. Imp. (ohm) kV

Resistance

Reactance

Impedance

Negative Seq. Imp. (ohm) Resistance

Reactance

Impedance

Zero Seq. Imp. (ohm) Resistance

Reactance

Impedance

Fault Zf (ohm) Resistance

Reactance

Impedance

0.433kV Bus-1

0.433

0.01143

0.01749

0.02089

0.01143

0.01749

0.02089

0.01141

0.01712

0.02058

0.00000

0.00000

0.00000

0.433kV Bus-2

0.433

0.00805

0.01239

0.01477

0.00805

0.01239

0.01477

0.00803

0.01205

0.01448

0.00000

0.00000

0.00000

11kV Bus.

11.000

0.00892

0.23770

0.23787

0.00892

0.23770

0.23787

0.00000

0.00000

0.00000

33KV BUS 1

33.000

0.08485

1.97772

1.97954

0.08485

1.97772

1.97954

0.08746

1.96469

1.96664

0.00000

0.00000

0.00000

33KV BUS 2

33.000

0.08485

1.97772

1.97954

0.08485

1.97772

1.97954

0.08746

1.96469

1.96664

0.00000

0.00000

0.00000

132KV BUS

132.000

0.50447

2.64711

2.69475

0.50447

2.64711

2.69475

0.54616

2.43871

2.49913

0.00000

0.00000

0.00000

220KV Bus1

220.000

0.44146

4.48871

4.51036

0.44146

4.48871

4.51036

0.64068

5.12409

5.16399

0.00000

0.00000

0.00000

220KV Bus2

220.000

0.44146

4.48871

4.51036

0.44146

4.48871

4.51036

0.64068

5.12409

5.16399

0.00000

0.00000

0.00000

Bus Ref A

33.000

0.08485

1.97772

1.97954

0.08485

1.97772

1.97954

0.08746

1.96469

1.96664

0.00000

0.00000

0.00000

Bus Ref B

33.000

0.08485

1.97772

1.97954

0.08485

1.97772

1.97954

0.08746

1.96469

1.96664

0.00000

0.00000

0.00000

Page 149 of 160

Project:


ETAP

Page:

1

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL

OCR:

11kV

MFR:

AREVA

Model:

P127

Overcurrent Relay Settings

Tag #:

CT

Base kV

Phase:

100/1

11.000

GND:

100/1

11.000

Phase:

400/1

If (kA)

OC Level: OC1 Range

Setting

Phase TOC IEC - Standard Inverse Pickup (Tap)

0.1 - 25 xCT Sec

0.230

0.5 - 40 xCT Sec

1.000

0 - 150

0.300

Time Dial Phase INST Pickup Time Delay

OCR:

132KV LINE-1

MFR:

GE Multilin

Model:

F650

0.740

Tag #:

CT

Base kV 132.000

If (kA) 29.03 3 ph, Asym. (Calc.) 29.03 LG, Asym. (Calc.)

GND:

400/1

132.000

29.03 LG, Asym. (Calc.)

Sen. GND:

400/1

132.000


OC Level: OC1 Range

Setting

Setting

Phase TOC IEC - Curve A Pickup (Tap)

0.05 - 160 Sec - 1A

Time Dial

1.000 0.150

Phase 67 Direction

Reverse

MTA

45.00

Polarization Neutral TOC IEC - Curve A Pickup (Tap)

Neutral 67 Direction 0.05 - 160 Sec - 1A

Time Dial

OCR:

132KV LINE-2

MFR:

GE Multilin

Model:

F650

Voltage Reverse

0.200

MTA

0.300

Polarization

45.00

Tag #:

Voltage

CT

Base kV

Phase:

400/1

132.000

GND:

400/1

132.000

Sen. GND:

400/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.150

Phase 67 Direction MTA Polarization

Neutral TOC IEC - Curve A Pickup (Tap) Time Dial


0.200

MTA

0.330

Polarization

Reverse 45.00 Voltage Reverse 45.00 Voltage

Page 150 of 160

Project:


ETAP

Page:

2

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:

132KV LINE-3

MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

400/1

132.000

GND:

400/1

132.000

Sen. GND:

400/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.150

Phase 67 Direction

Reverse

MTA

45.00

Polarization Neutral TOC IEC - Curve A Pickup (Tap)


Time Dial

OCR:

132KV LINE-4

MFR:

GE Multilin

Model:

F650

Voltage Reverse

0.200

MTA

45.00

0.330

Polarization

Tag #:

Voltage

CT

Base kV

Phase:

400/1

132.000

GND:

400/1

132.000

Sen. GND:

400/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.150

Phase 67 Direction MTA Polarization



0.200

MTA

0.330

Polarization

Reverse 45.00 Voltage Reverse 45.00 Voltage

Page 151 of 160

Project:


ETAP

Page:

3

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:


MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

800/1

132.000

GND:

800/1

132.000

Sen. GND:

800/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 5A

0.960

0.05 - 160 Sec - 1A

9.480

0 - 900

0.500


0.170

Neutral TOC IEC - Curve A Pickup (Tap)

Time Delay

Forward

MTA

45.00

Polarization Neutral 67 Direction

0.200

MTA

0.230

Polarization

0.05 - 160 Sec - 1A

2.500

0 - 900

0.600

OCR:


MFR:

GE Multilin

Model:

F650

Voltage Forward

0.05 - 160 Sec - 1A

Time Dial Neutral INST Pickup

Phase 67 Direction

45.00

Tag #:

Voltage

CT Phase:

Base kV

800/1

220.000

If (kA) 33.57 3 ph, Asym. (Calc.) 33.57 LG, Asym. (Calc.)

GND:

800/1

220.000


Sen. GND:

800/1

220.000


OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A


0.580 0.190

0.05 - 160 Sec - 1A

5.690

MTA

0 - 900

0.350

Polarization

0.05 - 160 Sec - 1A

0.200

MTA

0.240

Polarization

0.05 - 160 Sec - 5A

2.000

0 - 900

0.500


Neutral 67 Direction

Time Dial Neutral INST Pickup Time Delay

Phase 67 Direction

Forward 0.00 Voltage Forward 45.00 Voltage

Page 152 of 160

Project:


ETAP

Page:

4

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:


MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

800/1

132.000

GND:

800/1

132.000

Sen. GND:

800/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

0.960

0.05 - 160 Sec - 1A

9.480

0 - 900

0.100


0.170


Time Delay

Forward

MTA

45.00


0.200

MTA

0.230

Polarization

0.05 - 160 Sec - 1A

2.500

0 - 900

0.600

OCR:


MFR:

GE Multilin

Model:

F650

Dual Forward

0.05 - 160 Sec - 1A


Phase 67 Direction

45.00

Tag #:

Voltage

CT

Base kV

Phase:

800/1

220.000

GND:

800/1

220.000

Sen. GND:

800/1

220.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A


0.580 0.190

0.05 - 160 Sec - 1A

5.690

MTA

0 - 900

0.350

Polarization

0.05 - 160 Sec - 1A

0.200

MTA

0.240

Polarization

0.05 - 160 Sec - 1A

2.000

0 - 900

0.500




Phase 67 Direction

Forward 45.00 Voltage Reverse 45.00 Voltage

Page 153 of 160

Project:


ETAP

Page:

5

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:

220 KV LINE

MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

If (kA)

Phase:

1600/1

220.000

GND:

1600/1

220.000


Sen. GND:

1600/1

220.000


33.57 3 ph, Asym. (Calc.) 33.57 LG, Asym. (Calc.)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.200


0.05 - 160 Sec - 1A

Time Dial

OCR:

220 KV LINE-1

MFR:

GE Multilin

Model:

F650

0.200 0.300

Tag #:

CT

Base kV

If (kA)

Phase:

1600/1

220.000

33.57 3 ph, Asym. (Calc.)

GND:

1600/1

220.000


Sen. GND:

1600/1

220.000



OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.200


0.05 - 160 Sec - 1A

Time Dial

OCR:

220 KV LINE-3

MFR:

GE Multilin

Model:

F650

0.200 0.250

Tag #:

CT

Base kV

Phase:

800/1

220.000

GND:

800/1

220.000

Sen. GND:

800/1

220.000

If (kA)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.200


0.05 - 160 Sec - 1A

0.200 0.250

Page 154 of 160

Project:


ETAP

Page:

6

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:

220 KV LINE-4

MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

800/1

220.000

GND:

800/1

220.000

Sen. GND:

800/1

220.000

If (kA)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.200


0.05 - 160 Sec - 1A

Time Dial

OCR:

33 KV LINE

MFR:

GE Multilin

Model:

F650

0.200 0.250

Tag #:

CT

Base kV

Phase:

400/1

33.000

GND:

400/1

33.000

Sen. GND:

400/1

33.000

CT

Base kV

Phase:

800/1

33.000

GND:

800/1

33.000

Sen. GND:

800/1

33.000

If (kA)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.030


0.05 - 160 Sec - 1A

Time Dial

OCR:

33KV BUS COUPLER

MFR:

GE Multilin

Model:

F650

0.200 0.060

Tag #:

If (kA)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

0.960 0.070


0.05 - 160 Sec - 1A

0.200 0.100

Page 155 of 160

Project:


ETAP

Page:

7

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:

33KV Capacitor Bank

MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

If (kA)

Phase:

200/1

33.000

7.24 3 ph, Asym. (Calc.)

GND:

200/1

33.000


Sen. GND:

200/1

33.000



OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

Time Dial

0.960 0.040

Phase 67 Direction

Forward

MTA

0.00

Polarization

Voltage


0.05 - 160 Sec - 1A

Time Dial

0.200 0.070

OCR:


MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

400/1

132.000

GND:

400/1

132.000

Sen. GND:

400/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

0.480

0.05 - 160 Sec - 1A

4.000

MTA

0 - 900

0.300

Polarization

0.05 - 160 Sec - 1A

0.200

MTA

0.440

Polarization

0.05 - 160 Sec - 1A

5.600

0 - 900

0.350


0.300




Phase 67 Direction

Forward 0.00 Voltage Forward 45.00 Voltage

Page 156 of 160

Project:


ETAP

Page:

8

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:


MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

400/1

132.000

GND:

400/1

132.000

Sen. GND:

400/1

132.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A

0.480

0.05 - 160 Sec - 1A

4.000

0 - 900

0.300


0.300


Time Delay

Forward

MTA

0.00


0.200

MTA

0.440

Polarization

0.05 - 160 Sec - 1A

2.000

0 - 900

0.350

OCR:


MFR:

GE Multilin

Model:

F650

Voltage Forward

0.05 - 160 Sec - 1A


Phase 67 Direction

45.00

Tag #:

Voltage

CT

Base kV

Phase:

800/1

33.000

GND:

800/1

33.000

Sen. GND:

800/1

33.000

If (kA)

OC Level: OC1 Range

Setting

Setting


0.05 - 160 Sec - 1A


0.960 0.120

0.05 - 160 Sec - 1A

8.000

0 - 900

0.250

0.05 - 160 Sec - 1A

0.200

MTA

0.250

Polarization

0.05 - 160 Sec - 5A

2.000

0 - 900

0.300




Reverse 45.00 Voltage

Page 157 of 160

Project:


ETAP

Page:

9

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:


MFR:

GE Multilin

Model:

F650

Tag #:

CT

Base kV

Phase:

800/1

33.000

GND:

800/1

33.000

Sen. GND:

800/1

33.000

Phase:

1600/1

If (kA)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

0.960

0.05 - 160 Sec - 1A

8.000

0 - 900

0.250

0.05 - 160 Sec - 1A

0.200

0.05 - 160 Sec - 1A

2.000

0 - 900

0.300


0.120

Neutral TOC IEC - Curve A Pickup (Tap) Time Dial Neutral INST Pickup Time Delay

OCR:

BUS COUPLER

MFR:

GE Multilin

Model:

F650

0.250

Tag #:

CT

Base kV 220.000

If (kA) 22.10 3 ph, Sym. (Calc.) 22.10 LG, Sym. (Calc.)

GND:

1600/1

220.000

22.10 LG, Sym. (Calc.)

Sen. GND:

1600/1

220.000

22.10 LG, Sym. (Calc.)

OC Level: OC1 Range

Setting


0.05 - 160 Sec - 1A

Time Dial

1.000 0.200


0.05 - 160 Sec - 1A

0.200 0.300

Page 158 of 160

Project:


ETAP

Page:

10

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL

OCR:

MSB BC

MFR:

AREVA

Model:

P127


Tag #:

CT

Base kV

Phase:

1000/1

0.433

GND:

1000/1

0.433

CT

Base kV

Phase:

1000/1

0.433

GND:

1000/1

0.433

If (kA)

OC Level: OC1 Range

Setting


0.1 - 25 xCT Sec

0.590

0.5 - 40 xCT Sec

1.500

0 - 150

0.100


0.100

Ground TOC IEC - Standard Inverse Pickup (Tap)

0.002 - 1 xCT Sec

Time Dial Ground INST Pickup Time Delay

OCR:

MSB IC-1

MFR:

AREVA

Model:

P127

0.200 0.150

0.002 - 1 xCT Sec

1.000

0 - 150

0.100

Tag #:

If (kA)

OC Level: OC1 Range

Setting


0.1 - 25 xCT Sec


0.590 0.200

0.5 - 40 xCT Sec

1.500

0 - 150

0.200


0.002 - 1 xCT Sec


0.200 0.300

0.002 - 1 xCT Sec

1.000

0 - 150

0.200

Page 159 of 160

Project:


ETAP

Page:

11

Location:

Dehradun

11.1.0C

Date:

16-09-2013

Contract:

HPL

Revision:

Base

Engineer:

Marimuthu.N

Filename:

HPL


OCR:

MSB IC-2

MFR:

AREVA

Model:

P127

Tag #:

CT

Base kV

Phase:

1000/1

0.433

GND:

1000/1

0.433

If (kA)

OC Level: OC1 Range

Setting


0.1 - 25 xCT Sec

0.920

0.5 - 40 xCT Sec

2.000

0 - 150

0.200


0.200


0.002 - 1 xCT Sec


0.200 0.300

0.002 - 1 xCT Sec

1.000

0 - 150

0.200

Page 160 of 160

R0 VE J108 D E212 Relay Setting Calculation HPL16 09 13

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