Transformer differential

Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

Q U A L I T Y

TP/TPD/PFS/TPC/QP-13

P R O C E D U R E

TITLE

:

Transformer Differential Protection Testing for Devices and Schemes.

REF.No

:

TP/TPD/PFS/TPC/QP - 13

Copy No.

:

AMENDMENTS ISSUE / REVISIO N NO.

1/0 2/0

Issue : 2

SUBJECT OF THE AMENDMENT

REVIEWED BY & SIGNATURE

New Procedure Prepared Entire procedure has been amended to incorporate process change and restructuring within the department. This procedure supersedes the old procedure No. TP/TPD/TPC/QP 13

Rev:0

Date: 05.12.2011

AUTHORIZED BY & SIGNATURE

DATE

05-12-11

Page 1 of 14

Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

TP/TPD/PFS/TPC/QP-13

CONTENTS

1.0

PURPOSE

2.0

SCOPE

3.0

DEFINITIONS

4.0

CROSS REFERENCES

5.0

RESPONSIBILITY

6.0

PROCEDURE

7.0

RECORDS

8.0

DISTRIBUTION

9.0

ATTACHMENTS

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Rev:0

Date: 05.12.2011

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

TP/TPD/PFS/TPC/QP-13

1.0 PURPOSE 1.1 This procedure is to explain in detail the steps to be followed for commissioning of Transformer differential protection devices and schemes and to facilitate effective control of documents. 2.0 SCOPE 2.1 This procedure applies to commissioning of Transformer differential protection devices and schemes in 132 kV and 400 kV substations. 3.0

DEFINITIONS

3.1 Approved drawing: The general arrangement, scheme drawings which are approved by TPE with status code A or B to execute the work at site. 3.2 Approved setting : The approved values, parameters & configuration of the protection relays issued by PCS to be implemented in the protection relays before putting the relay in service. 3.3

BI : Binary Inputs.

3.3

BO : Binary Outputs.

3.4

CB : Circuit breaker

3.5

CT : Current Transformer.

3.6

CM-TPC: Commissioning Manager-Transmission Protection Commissioning.

3.7

DO : Drop Off.

3.8

HV : High Voltage.

3.9

IDT : Inter-Distribution Transformer

3.10

LV : Low Voltage.

3.11

LED: Light Emitting Diode.

3.12

M-TPC: Manager- Transmission Protection Commissioning.

3.13

PCS

: Protection Calculation Setting, a section of TPD.

3.14

POC

: Primary Operating Current.

3.15

PPE

: Personal Protective Equipments.

3.16

PU

: Pick-Up.

3.17

REF

: Restricted Earth Fault.

3.18

RSI

: Relay Setting Identifier.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

TP/TPD/PFS/TPC/QP-13

3.19

TPD

: Transmission Protection Department.

3.20

VP-TP : Vice President-Transmission Protection.

3.21

Testing Engineer: Engineer from contractor or manufacturer who performs the test as per this procedure.

3.22

Witness Engineer: Engineer from DEWA / approved consultant who witness the test

4.0 4.1

CROSS REFERENCES Nil

4.2 5.0

RESPONSIBILITY

5.1 VP-TP : VP-TP is responsible for approval & modification of this procedure. 5.2 M-TPC : M-TPC is responsible for implementation of this procedure. 5.3 CM-TPC : CM-TPC is responsible to plan testing activities as per the details of this procedure. 5.4 Witness Engineer : Witness engineer is responsible to witness the testing of relay/scheme

6.0

PROCEDURE

6.1

General.

6.1.1

Ensure the availability of approved setting for the protection device from TPD-PCS. The RSI number of the setting template to be filled in the test formats

6.1.2

The TPC Witness engineer ensures the calibration certificate of measuring equipments used for testing are available at site and ensures the availability of relevant test sheets (given as attachment) prior to performing the site testing. The testing instruments details shall be recorded in the test report.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

6.1.3

TP/TPD/PFS/TPC/QP-13

Establish a communication between the relay and the computer (lap-top) for uploading / down loading settings using the appropriate application software and connecting cables.

6.1.4

Download the default settings from the relay to computer and update the approved settings with date and time.

6.1.5

Configure the input / output mappings in the application software as per the approved drawings. The date and time setting to be updated as actual

6.1.6

Upload the updated file to the relay and confirm the relay is healthy.

6.1.7

Relay soft setting and configuration file should be downloaded from the protection relay finally and saved with the filename provided on the footer of the specific setting template. A printout of the same shall be signed and attached with the test report. The setting template sheet, test reports are also to be signed by the contractor and the witness engineer.

6.1.8

Test report shall be filled during testing and the same shall be signed on the same day of testing.

6.2

Protection Device testing. Device - Siemens relay 7UT613 (Refer attachment TP/TPD/PFS/TPC/QP13:A01) 6.2.1 General Data and Inspection. • The testing engineer has to fill the General data (Relay Type, Serial No, Firmware Version, Rated Current etc.) as mentioned in the test format. •

A general visual inspection is carried out to confirm the relay installation and wirings are carried out as per the approved drawings.

•

The jumper settings to be set for the rated voltage, current and correct pick up voltage of the binary inputs. This is to be done as per Siemens relay 7UT613 manual.

6.2.2 •

Configuration of Protection functions: Relay configuration is done to enable only those protection functions which are recommended in the relay setting template.

•

Issue : 2

Transformer data and differential protection settings are entered in the test report.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

6.2.3 •

TP/TPD/PFS/TPC/QP-13

Measurements Checks: Use the secondary injection test kit to inject current in HV side CT ‘R’ phase and note down the relay display reading. Repeat the current injection in Y & B phases and note down the display readings in the test format.

•

Repeat same for LV side CT.

•

Relay Pick Up values: Using the secondary injection test kit, gradually raise the current in R phase of HV

6.2.4

side CT till the relay picks up. Note the value of differential pick-up. Repeat the same for the other phases in HV side CT. Repeat the same for LV side CT. 6.2.5 •

Timing Tests: Inject current 1.5 times setting current as mentioned in test format in R phase and note down the operating times values in the test format. The operating time should be less than that indicated in the test format.

•

Repeat the test for other phases.

•

Differential protection testing: Bias characteristics are checked by injecting a balanced current in HV side and LV

6.2.6

side CT secondary, and then gradually increasing current in HV side till differential pickup. Record the trip value of current in CT side-1. •

Inject 4 times I diff>> setting current in each phase and check trip time. Record the values. Also record LED operation.

•

Repeat the test for other phases.

•

Testing 2’nd Harmonic restraint. 2nd harmonic blocking is set at 15%.

•

16% 2nd Harmonic is generated using the secondary injection kit and applied to

6.2.7

relay for 5 periods (100 milli sec) and check differential is blocking. •

Note the value of set harmonic percentage in test kit.

•

To check cross block feature Inject 1 amp at 50 hertz in R phase and B phase along with 0.3 amps at 100 Hertz

6.2.8

in Y phase. •

With cross block feature off, the relay should trip by R phase and B phase differential protection.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

•

TP/TPD/PFS/TPC/QP-13

Set cross block feature “YES” and time for cross block as 80 milli sec. The differential trip will be blocked for 80 milli sec.

6.2.9

Testing of Add on Stabilisation for External faults: (Siemens 7UT612) •

The test is carried out to check CT saturation detection during the

•

duration of add on stabilisation as explained in the test format. Binary Inputs and Outputs: Record the function of BI/BO in the test format. Apply voltage and check the BI is

6.2.10

functioning. •

Each BO to be checked separately by operating the particular function to which it is assigned. The BO is tested by checking the continuity between contacts using a multi-meter.

•

Each LED indications are to be checked separately by operating the particular function to which it is assigned. LED resetting operation is checked by manually resetting the indications.

6.2.11 •

Other Checks: Disturbance recorder and event recorder from the relay are to be down loaded to the computer (laptop) and the printout to be attached with the test report.

•

Confirm operation of trip relay by inserting the appropriate trip link. Also confirm signals to fault recorder and SCADA system are send from the relay. Device - Areva relay Micom P 632(Refer attachment TP/TPD/PFS/TPC/QP13:A02)

6.2.12

Relay Data and General Inspection. •

The testing engineer has to fill the General data (Relay Type, Serial No, Firmware Version, Rated Current etc.) as mentioned in the test format.

•

A general visual inspection is carried out to confirm the relay installation and wirings are carried out as per the approved drawings.

6.2.13

LED, Binary Inputs and Outputs: •

Record the function of BI/BO in the test format. Apply voltage and check the BI is functioning.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

•

TP/TPD/PFS/TPC/QP-13

Each BO to be checked separately by operating the particular function to which it is assigned. The BO is tested by checking the continuity between contacts using a multi-meter.

•

Each LED indications are to be checked separately by operating the particular function to which it is assigned. LED resetting operation is checked by manually resetting the indications.

6.2.14

Measurements Checks: •

Use the secondary injection test kit to inject 1 amps current in HV side CT’s and note down the relay display reading. Repeat the current injection in LV side CT’s and note down the display readings in the test format. Compare with expected current.

6.2.15

Differential protection checks. •

Differential protection settings are entered in the test report.

•

Using the secondary injection test kit, gradually raise the current in R phase of HV side CT till the relay picks up. Note the value of differential pick-up. Repeat the same for the R phase of LV side CT.

•

Check 3 phase pickup by gradually raising the current in all phases in HV side CT till the relay picks up. Repeat the same for LV side CT.

6.2.16

Differential protection checks: •

Bias characteristics are checked by injecting a balanced current in HV side and LV side CT secondary, and then gradually increasing current in HV side till differential pickup. Record the trip value of current in CT side-1.

6.2.17

CT saturation check: (MICOM P632) •

CT saturation Check is tested by applying 1 Amps at 100 Hz to R, Y and B phases. The setting of vector group will be “YY0”, setting for 2nd harmonic should be “disable” and zero sequence filter “OFF” .Confirm the relay detect CT saturation and Block differential function. Timing Tests:

6.2.18 •

Inject current 1.0 amp current as mentioned in test format in HV side R phase and note down the operating time value in the test format. The operating time should be less than that indicated in the test format.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

• 6.2.19

TP/TPD/PFS/TPC/QP-13

Repeat the test for other phases in HV side. Repeat the same for LV side also. Testing 2’nd Harmonic restraint.

•

2nd harmonic blocking is set at 15%.

•

16% 2nd Harmonic is generated using the secondary injection kit is applied to HV side R phase of relay and check differential is blocking. Relay should not trip.

•

Reduce harmonics percentage in the injected current till the relay trips. Record the value in the test format.

• 6.2.20

Repeat the test for HV side Y and B phase. Differential High set (I diff>>)test:

•

Inject in R phase a current below “I diff>> setting and observe the tripping time. The tripping time should be the normal differential tripping time.

•

Repeat injection, gradually raising the current till the tripping time is less than the differential operating current. Record the threshold value of “I diff>>” pickup current.

•

The operating time of HIGH SET will be tested by injecting 2 times of high set differential setting current and record the time.

6.2.21

Other Checks •

Disturbance recorder and event recorder from the relay are to be down loaded to the computer (laptop) and the printout to be attached with the test report.

•

Confirm operation of trip relay by inserting the appropriate trip link. Also confirm signals to fault recorder and SCADA system are send from the relay. Device – Duo Bias M (Refer attachment TP/TPD/PFS/TPC/QP-13:A03)

6.2.22

Relay Data and General Inspection. •

The testing engineer has to fill the General data (Relay Type, Serial No, Firmware Version, Rated Current etc.) as mentioned in the test format.

•

A general visual inspection is carried out to confirm the relay installation and wirings are carried out as per the approved drawings.

6.2.23

Measurements Checks: •

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Differential protection settings are entered in the test report. Rev:0

Date: 05.12.2011

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

•

TP/TPD/PFS/TPC/QP-13

Use the secondary injection test kit to inject 1 amps current in HV side CT’s and note down the relay display reading. Repeat the current injection in LV side CT’s and note down the display readings in the test format. Compare with expected current.

6.2.24

Differential bias characteristic. •

Bias characteristics are checked by injecting a bias current as reference, and then gradually increasing the operating current till differential pickup. Verify results with expected and measured operating values. The readings are taken keeping bias currents at 0, 1, 1.5, 2 and 4 amps for each phase.

6.2.25

Timing Tests: •

Inject current 3 times setting current or as mentioned in test format in R phase and note down the operating times values in the test format. Repeat the test for other phases.

6.2.26

Differential High set test: •

The operating time of HIGH SET will be tested by injecting 2 times of high set differential setting current and record the time. Repeat the test for other phases.

6.2.27

Harmonic Block test •

Inject a current higher than differential setting with a harmonic content of more than harmonic block settings in red phase and see that the relay blocks tripping and gives correct LED indication.

•

Repeat the Injection in the other Y & B phases.

•

LED, Binary Inputs and Outputs: Record the terminal numbers of BI/BO in the test format. Apply voltage and check

6.2.28

the BI is functioning. •

Each BO to be checked separately by operating the particular function to which it is assigned. The BO is tested by checking the continuity between contacts using a multi-meter.

•

Each LED indications are to be checked separately by operating the particular function to which it is assigned. LED resetting operation is checked by manually resetting the indications.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

6.2.29 •

TP/TPD/PFS/TPC/QP-13

Other Checks: Confirm operation of trip relay by inserting the appropriate trip link. Also confirm signals to fault recorder and SCADA system are send from the relay.

•

Disturbance recorder and event recorder from the relay are to be down loaded to the computer (laptop) and the printout to be attached with the test report.

3.3

Protection Scheme testing. Note: For Sensitivity test (refer attachment Transformer Differential Sensitivity Test Report.- TP/TPD/PFS/TPC/QP-13:A04) For Stability test (refer attachment Transformer Differential Stability Test Report.TP/TPD/PFS/TPC/QP-13:A05)

6.3.1

To avoid the operation of REF (High Imp) during the sensitivity and stability tests, ensure the REF and stabilizing resistor are by passed.

6.3.2

Sensitivity on HV Side •

The differential relay settings and calculated value of Primary Operating Current (POC) are recorded in test format.

•

Primary current shall be injected on HV Side R Phase to earth and the same shall be increased slowly form zero till the differential protection Operates. The Primary current at which the protection operates is the minimum Primary Operating Current for R Phase. Record on test formats the corresponding secondary currents and relay display readings at this POC. The value shall be with in the limits of tolerance. The same shall be confirmed for Y and B Phases.

•

The same injection is repeated for phase to phase injection (R-Y, Y-B and B-R) and the POC is compared again with the calculated values.

•

When there are 2 sets of CT’s on the HV side, the values are recorded for each set as Bus-1 and Bus-2 CT’s.

6.3.3

Sensitivity on LV Side •

Primary current shall be injected to LV side CT’s to repeat the test as in 6.3.2, to find sensitivity of LV side.

6.3.4 Issue : 2

Stability Test. Rev:0

Date: 05.12.2011

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

•

TP/TPD/PFS/TPC/QP-13

Stability test in carried out as per the details given below. A 3 phase 415 Volts shall be applied on LV (11kV Side) side of Transformer and all three phases of HV Side shall be shorted and earthed. Actual values of current on HV and LV shall be compared with the calculated value based on percentage impedance of transformer. The differential and bias currents will be compared with the primary current values.

•

Identify the IDT for the differential relay under test.

•

Isolate tripping to both HV and LV CB’s from differential relay.

•

Isolate the section of 11 kV where this IDT-LV is connected by keeping all CB’s in test position and opening the bus earth switch.

•

132 kV IDT bay is connected to either bus-1 or bus-2 and the connected bus earth switch is closed. Line isolator and CB is kept closed for IDT.

•

Supply 3 phase 415 Volts to one of the outgoing feeder in that section of 11 kV. Rack in the CB of that bay to service and close CB. 11 kV section is now energised with 415 V supply.

•

Rack in the CB of the incomer where IDT-LV is connected. Close the CB to circulate a current in primary circuit.

•

Record all values of primary and secondary currents including the Differential current and Restraint currents in the test formats. These are the normal values. The differential Current shall be zero and Restraint current shall be high. The currents are recorded while keeping the tap-changer in extreme low tap, middle tap and high tap.

•

Keep the tap changer in middle tap. The R phase of HV side CT shall be reversed without opening the CT. Record all values of primary and secondary currents including the Differential current and Restraint currents in the test formats. In this condition the Differential current shall be predominant and Restraint current shall be less. If the Differential current is more than the setting, the protections shall operate. After recording the currents, the R phase shall be normalized. Confirm the currents are normal values again. The same shall be repeated for Y and B Phase.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

•

TP/TPD/PFS/TPC/QP-13

Keeping the tap changer in middle tap, the R phase of LV side CT shall be reversed now without opening the CT and record all the above values as done for HV side CT’s. Again in this condition, the Differential current shall be high and Restraint currents shall be less. If the Differential current is more than the setting the protections shall operate. After Recording the currents the R phase shall be normalized and confirm the currents are in order. The same shall be repeated for Y and B Phase.

•

If HV side is provided with 2 sets of CT’s, each set is compared individually with the LV side CT’s. Also normal values are also taken for each set of CT’s in the beginning and end of testing.

•

After normalizing the CT’s on HV and LV the currents in Diff. Protection shall measured and confirmed that the Diff current shall be zero and Restraint current shall be high.

6.4

Risk Assessment & safety precautions. Safety measures are identified through risk assessment process as follows,

6.4.1

Risk assessment to be carried before the testing activity to identify areas of risk for both personal and equipment safety while doing the testing activity.

6.4.2

Adequate safety measures to be taken to avoid injury to persons or damages to equipment based on risk assessment.

6.4.3

Follow safety guidelines and procedures while working in substations.

6.4.4

Regarding the activity mentioned in the QP, The risk assessment & safety Precautions are identified in, •

6.5

TP/TPD/TPC-A01 – Conducting relay testing during commissioning

KPI / measurements. KPI are identified, measured & results analysed to monitor the process/activity and implement actions to achieve planned results and work for continual improvement.

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Transmission Power Division. Transmission Protection Department Protection Field Services Transmission Protection Commissioning Quality Procedure

6.5.1

TP/TPD/PFS/TPC/QP-13

The measurement of the procedure output will be recorded in KPI sheet by measuring the number of problems and abnormalities noticed after Energization of substation due to lapses in commissioning activities.

7.0

RECORDS

7.1

The test report shall be signed and kept in concerned file.

7.2

The relay configuration and settings file (soft copy)and signed setting template in PDF format is submitted to TPD-PCS

8.0

DISTRIBUTION

8.1

VP-TP

8.2

M-TPC

9.0

ATTACHMENTS

9.1

Final Setting Test Report Siemens 7UT612 – TP/TPD/PFS/TPC/QP-13:A01(5 pages)

9.2

Final Setting Test Report MICOM P632 - TP/TPD/PFS/TPC/QP-13:A02(4 pages)

9.3

Final Setting Test Report Duo Bias-M - TP/TPD/PFS/TPC/QP-13:A03(3 pages)

9.4

Transformer Differential Sensitivity Test Report.- TP/TPD/PFS/TPC/QP-13:A04 (7 pages)

9.5

Transformer Differential Stability Test Report.- TP/TPD/PFS/TPC/QP-13:A05(5 pages)

9.6

Risk assessment – TP/TPD/TPC-A01

9.7

Process form – TP/TPD/PFS/TPC/PM-07

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TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUBSTATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No: Dt. Final Settings Tests of DIFFERENTIAL RELAY Type: 7UT612.

Manufacturer

RSI: ………………………………………

ELECTROSTATIC DISCHARGE (ESD) The relay incorporate CMOS static sensitive devices, which may be damaged by static electricity discharged from the body. When handling care should be taken to avoid contact with components and electrical connections. If the relay is removed from its case for any period of time. It should be placed in an electrically conducting anti-static bag. If making measurements on the internal electronic circuitry, its preferable you are earthed to he case with a conductive strap having a resistance to ground between 500k Ohms – 10 m Ohms

REFERENCE DOCUMENT: SIPROTEC Transformer Differential PROTECTION 7UT612: ……………………….…………..

1- GENERAL DATA Ordered MLFB:

Serial No.

Built in MLFB:

Ordered Version:

Ordered rated current IN: 1A

Ordered rated auxiliary voltage (DC): 110 V DC

Built-in rated current IN: 1A

Built-in rated auxiliary voltage (DC): 110 V DC

Software used:

DIGSI

Serial interface configuration RS 232 Front Port Fault recording setting

Built-in Version:

4.5/4.6

Substation address: Relay address: By pick-up

Feeder address: Baud rate: 38400 By trip command

2- General Inspection and Testing: i. ii. iii. iv. v. vi. vii.

Visual inspection ……………… Confirmation of unique Sr. Number on Case and inside the relay ……………… Correctness of installation and wiring as per approved drawings ……………… Confirmation of Earthing of relay case to local earth bar ……………… Confirmation of Jumpers on A-CPU for 110- 250VDC Rated Voltage……………… Confirmation of Jumpers on A-I/O-3 for 1 Amp. Rated current ……………… Confirmation of Jumpers A-CPU for High Binary input voltage ………………

CONFIGURATION OF PROTECTION FUNCTIONS •

Differential Protection

Configured

•

Back Up O/C Time Protection

Configured

•

Thermal over Load Protection

Configured

•

Cold Load Pick Up

Configured

TP/TPD/PFS/TPC/QP-13:A01

Page 1 of 5

CONTRACT NO:

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUBSTATION:

Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No: Dt. Final Settings Tests of DIFFERENTIAL RELAY Type: 7UT612. RSI: ………………………………………

3- Transformer Data: Transformer Data Primary Winding Secondary Winding UN 132 kV 12kV PN 50 MVA 50 MVA IN (calculated) 218.7 A 2405.7 CT Ratio 300/1 3200/1 4- Settings of Diff. Protection: I diff > : I/ In = t diff > delayed : I diff >> : I/ In = t diff >> delayed : 2nd. Harmonic : Slope 1: 5th. Harmonic : Slope 2: Vector Group: Base Point 1: Base Point 2: 5- Measurements Checks: Primary I diff. I Rest. Tested Secondary Tested Winding Measured Measured Measured Phases Injected (A) (A) (I/In) (I/In) 1.0 R Y Winding side 1 1.0 B 1.0 1.0 R Y Winding side 2 1.0 B 1.0 6- Relay Pickup Values: Test Function Tested Winding Phases R Y Side 1 B R Y Side 2 B 7- Timing Test: Test Tested Winding Function Side 1 or Side 2 Phases R Y 1.5 X Idiff > B

Expected

Current Inj. (A)

8- DIFFERENTIAL PROTECTION TESTING:

TP/TPD/PFS/TPC/QP-13:A01

Page 2 of 5

Current (A) P/U

Timing Test Expected (mSec) 38 38 38

D/O

Act (mSec)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUBSTATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No: Dt. Final Settings Tests of DIFFERENTIAL RELAY Type: 7UT612. RSI: ………………………………………

Current Injection on CT-1 (A)

Current Injection on CT-2 (A)

Expected Trip Value CT Side 1

Phases

Relay Settings

R

0.2

0.2

0.2

0.4

Y

0.2

0.2

0.2

0.4

B

0.2

0.2

0.2

0.4

Obtained Trip Value at Increasing current on CT Side-1

Trip Time 4 x Idiff Inj. (A)

7- DIFF (HIGH SET) TESTING I Diff >> (High Set):

Injected Current (A)

LED Indication: ________

8- HARMONIC BLOCK TESTING Setting 15 % ≥ 15 % ≥ 15 % ≥

Harmonic Block in Red Phase Harmonic Block in Yellow Phase Harmonic Block in Blue Phase a. Testing of 2nd Harmonic Restraint :

b. Testing of Cross Blocking of 2nd Harmonics: - Cross-blocking of Harmonics Setting: 15%

TP/TPD/PFS/TPC/QP-13:A01

Page 3 of 5

LED Indication

TIME (Sec)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUBSTATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No: Dt. Final Settings Tests of DIFFERENTIAL RELAY Type: 7UT612.

Manufacturer

RSI: ………………………………………

Set Cross-block time (ms)

Injected Current (A)

Phase

Frequency/ Harmonics (Hz)

R 1.0 Y 0.30 B 1.0 9- Testing of Add on Stabilization for External faults : 100

- I-ADD ON STAB setting:

3xI/In and

Measured Cross-block time (ms)

Result with LED indication

50 100 50

Set duration of ADD-on stabilization: 10 Cycles.

Simulate in state sequencer the saturation condition of one side CT: Inject through fault currents (3.25 Amps) for 2 ms in state1 and then inject decreased currents through one side of relay for 2 ms in state2 while other side current is unchanged and then in state3, inject more decreased currents for time longer than blocking duration to observe trip blocking within the ADD-on stabilization period and trip release after the period is over. The relay will detect CT saturation within 5 ms after the fault incidence and saturation of CT and block trip for settable duration only. Set duration of ADD-on stabilization (msec)

Measured duration of ADD-on stabilization (msec)

200

10- BINARY OUTPUT CONTACTS Binary Output

Terminal No.

BO 1

F6 – F7

BO 2

F8 – F9

BO 3

F10 – F11

BO 4

F12 – F13

BO 5

F14 – F15

Watch Dog

F3 – F5

Assigned for

Test Result

F4 – F5 Note: check status of Watch Dog contacts while the relay is energized and de-energized.

10- BINARY INPUTS Binary Output

Terminal No.

BI 1

F14 – F15

BI 2

F16 – F15

BI 3

F17 – F18

Assigned for

11- LEDS CHECK

TP/TPD/PFS/TPC/QP-13:A01

Page 4 of 5

Test Result

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUBSTATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No: Dt. Final Settings Tests of DIFFERENTIAL RELAY Type: 7UT612.

Manufacturer

RSI: ………………………………………

LEDs

Assigned for

1

I Diff > Trip I Diff >> Trip Diff 2nd Harm L1/L2/L3 Diff 5th Harm L1/L2/L3 Cross Blk by 2nd Harm Cross Blk by 5th Harm Diff blk. EXT.Flt. L1/L2/L3

2 3 4 5 6 7

Test Result

RESETTING OPERATION I. OTHER CHECKS: A) Check Operation & Resetting Of All Front Panel LED's

:…………

B) Trip Relay Operation And All Alarms

: …………

C) DR, ER's Downloaded and print out attached/ Final setting print out attached: ………..

Testing Instruments Details Particulars

Make

Type

Tested By (Manufacturer) Signature Name

TP/TPD/PFS/TPC/QP-13:A01

Page 5 of 5

Sr.No.

Cal. Due Date

Witnessed By (DEWA)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUB STATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No:

Dt.

Final Settings Tests of DIFFERENTIAL RELAY Type MICOM P632 RSI: ………………………….. ELECTROSTATIC DISCHARGE (ESD) The relay incorporate CMOS static sensitive devices, which may be damaged by static electricity discharged from the body. When handling care should be taken to avoid contact with components and electrical connections. If the relay is removed from its case for any period of time. It should be placed in an electrically conducting anti-static bag. If making measurements on the internal electronic circuitry, its preferable you are earthed to he case with a conductive strap having a resistance to ground between 500k Ohms – 10 m Ohms

1- RELAY DATA

Current In Voltage Vn Frequency Aux. Voltage

Model No. SL.No. Software Ref.

2- GENERAL INSPECTION  Visual inspection/ Correctness of Installation and wiring Sr.No. on module, case and cover are identical Relay case connected to a local earth bar Installation & wiring correct to relevant drawings Wiring and installation checks Wiring and installation checks Check for correct voltage polarity/Record the level at rear of the relay 3- LED CHECK

Check the operation of all LED’s on the relay front panel. LED No. Allocation LRD H1 Healthy LED H2 Out of Service LED H3 Alarm LED H4 Main Gen Trip Signal LED H5 LED H6 LED H7 LED H8 LED H9 LED H10 LED H11 LED H12 LED H13 LED H14 LED H15 LED H16 LED H17 Edit Mode

TP/TPD/PFS/TPC/QP-13:A02

Page 1 of 4

Result

CONTRACT NO:

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No:

Dt.

Final Settings Tests of DIFFERENTIAL RELAY Type MICOM P632 RSI: …………………………..

4- OUTPUT RELAY CHECKS

Terminal No. X18:2 - X18:3 X18:5 - X18:6 X18:8 - X18:9 X18:11 - X18:12 X18:14 - X18:15 X18:17 - X18:18 X18:20 - X18:21 X18:23 - X18:24 X18:26 - X18:27 X20:1 - X20:2 X20:3 - X20:4 X20:6 - X20:7 X20:8 - X20:9 X20:10 - X20:11 X20:10 - X20:12 X20:10 - X20:13 X20:10 - X20:14

Output Relay No.

Contact Resistance ( …………………. M1 ………………………….M2 ……………………..  IR, m2 …………………….

TP/TPD/PFS/TPC/QP-13:A02

Page 2 of 4

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUB STATION:

CONTRACT NO: Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No:

Dt.

Final Settings Tests of DIFFERENTIAL RELAY Type MICOM P632 RSI: …………………………..

7- BINARY INPUTS CHECK:

Binary input No. U 2001

Terminal No. X20: 18 & 19

Pick up Volgage

Results

8- DIFFERENTIAL PROTECTION CHECKS:

8. a.

Checking of the first section of tripping characteristics.

Test Winding Expected operating current Measured current 3-phase current a = (Idiff>* Inom)/Kam,a injection = = 3-phase current b = (Idiff>* Inom)/Kam,b injection = = 1-phase current a = (Idiff>*Inom)/(Kam,a*Ks,1,a) injection (R phase) = = 1-phase current b = (Idiff>*Inom)/(Kam,b*Ks,1,b) injection (R phase) = = 8. b. Checking of second/third section of tripping characteristic: Section of tripping char. Under test

Test method : 3 phase currents injected in winding “a” and “b”. Sec. phase Sec. phase Differential Restrain current currents at currents at current measured measured by operating point operating point by relay at relay at Winding “a” Winding “b” operating point operating point

Theoretical diff. current for measured restrain current

Second Second Third Third 8. c.

CT Saturation Checks :

Connection

Phase

– YY0

Current

2nd Harmonic – Disabled

Frequency

Current

Zero Sequence Filter - Off LED Indications

Frequency

IR IY IB

8. d.

Operating Time Measurements: (Expected < 40 m Sec.)

TP/TPD/PFS/TPC/QP-13:A02

Page 3 of 4

CONTRACT NO:

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment:

Manufacturer

SCADA No:

Dt.

Final Settings Tests of DIFFERENTIAL RELAY Type MICOM P632 RSI: …………………………..

Injected current = 1A

Operating time

IR HV IY HV IB HV

Injected current = 1A IR LV IY LV IB LV

8. e. 2nd Harmonic Magnetizing Inrush Restraint Checks: Injected Current 1 Amp nd 2 Harmonic inrush Block Setting 15 % R Phase Y Phase Relay performance for 2nd Harmonic BLK TRIP BLK TRIP content

Operating time

B Phase BLK TRIP

9- HIGH SET FUNCTION CHECKS : Idiff >>

Phase

Operating Current expected

Setting

Operating Current (Actual)

Operating Time at Twice the Setting

IR IY IB 10- OTHER CHECKS: Check Operation Of All Front Panel LED's Setting Printout taken and Confirmed with Approved Settings Fault recorder and Events Print out taken and Verified Operation of Trip Relay F94.1 Confirmed SCADA Alarms Confirmed Fault Recorder initiation Confirmed Particulars

Make

Testing Instruments Details Type

Tested By (Contractor) Signature Name

TP/TPD/PFS/TPC/QP-13:A02

Page 4 of 4

: ……………. : …………… : …………… : …………… : …………… : …………… Sr.No.

Cal. Due Date

Witnessed By (DEWA)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No:

Manufacturer

Dt.

Final Settings Tests of Differential Relay Type DUOBIAS-M RELAY SETTING IDENTIFIER: …………………………

ELECTROSTATIC DISCHARGE (ESD) The relay incorporate CMOS static sensitive devices, which may be damaged by static electricity discharged from the body. When handling care should be taken to avoid contact with components and electrical connections. If the relay is removed from its case for any period of time. It should be placed in an electrically conducting anti-static bag. If making measurements on the internal electronic circuitry, its preferable you are earthed to he case with a conductive strap having a resistance to ground between 500k Ohms – 10 m Ohms

1. GENERAL DATA Relay Type In Serial No

: : :

Model No Vx

: :

2- GENERAL INSPECTION i)

Visual inspection

: __________

ii)

Installation & Wiring Correct To Relevant Drawings

: __________

iii)

Relay Case Connected To Earth Bars

: __________

iv)

Insulation Resistance With 500v Megger

: __________

v)

Aux. Supply Connected To Correct Terminal 13 (+Ve), 14(-Ve)

: __________

vi)

Relay Test Block CT Shorting Proved

: __________

2. SECONDARY INJECTION TEST RELAY SETTING ADOPTED H.V. CT RATIO H.V.INTERPOSING CT CONNECTION MULTIPLIER

:___________ :___________ : __________ : ___________

L.V. CT RATIO :___________ L.V.INTERPOSING CT :___________ CONNECTION :___________ MULTIPLIER :___________

4. METERING CHECK WINDING

PHASES

I-APPLIED

TP/TPD/PFS/TPC/QP-13:A03

RELAY DISPLAY RELAY CURRENT L1

L2

Page 1 of 3

W1

W2

OPERATE

REST.

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No:

Manufacturer

Dt.

Final Settings Tests of Differential Relay Type DUOBIAS-M RELAY SETTING IDENTIFIER: …………………………

BIAS SETTING

SETTINGINITIAL

PHASES

5A. BIAS CHARACTERISTIC TEST

BIAS SLOPE LIMIT:

0 MEAS.

1 EXPT.

MEAS.

BIAS CURRENT (A1) 1.5 2 OPERATING CURRENT (A2) EXPT. MEAS EXPT MEAS EXPT

4 MEAS

EXPT

R Y B 5B. OPERATING TIME CURRENT INJECTED RELAY SETTING

R

Y

OPERATING TIME AT 3 X Is B

R

Y

B

5 C. HIGHEST ELEMENT CURRENT INJECTED RELAY SETTING

R

Y

OPERATING TIME AT 2 X Is B

B

Y

B

6. MAGNETIZING INRUSH RESTRAIN TEST: PHASE

SETTING

R Y B

20% 20% 20%

SECOND HARMONIC CURRENT % 19 20 22 25

RESULT

7. STATUS INPUT CHECKS

Opto input no.

Terminal No.

Pickup (V)

Drop Off (V)

S1 S2 S3 S4

TP/TPD/PFS/TPC/QP-13:A03

Opto input no. S7 S8 S9 S10

Page 2 of 3

Terminal No.

Pickup (V)

Drop Off (V)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No:

Manufacturer

Dt.

Final Settings Tests of Differential Relay Type DUOBIAS-M RELAY SETTING IDENTIFIER: ………………………… S11

S5

S6 8- LED FUNCTIONAL LABEL AND OPERATION: LED FUNCTION OPERATION NO. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

LED NO.

FUNCTION

17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE

GENERAL TRIP HIGHE SET OPTD PHASE A TRIP PHASE B TRIP PHASE C TRIP NEW DATA STORED SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE SPARE

OPERATION

9. OUTPUT RELAY CHECK Opto input no.

Terminal No.

Contact Resistance

Result

RL1 RL2 RL3 RL4 RL5 RL6 RL7

Opto input no.

Terminal No.

Contact Resistance

Result

RL8 RL9 RL10 RL11 RL12 RL13

Note: check status of Watch Dog contacts while the relay is energized and de-energized. 10- OTHER CHECKS: 1. Trip relay operation, protection operated signal verified in SCS and FRP : ………. 2. Disturbance Recorder and Events printout attached : ………. 3. Date and time set in the relay/ Final setting printout attached with test format : ………. Testing Instrument Details

Particulars

Make

Type

Tested By (Contractor)

TP/TPD/PFS/TPC/QP-13:A03

Page 3 of 3

Sr. No.

Cal. Due Date

Witnessed By (DEWA)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant:

Equipment: SCADA No:

Manufacturer

Dt.

Final Settings Tests of Differential Relay Type DUOBIAS-M RELAY SETTING IDENTIFIER: …………………………

Signature Name

TP/TPD/PFS/TPC/QP-13:A03

Page 4 of 3

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

RELAY SETTING I-DIFF > Setting Calculated I POC Slope 1 Base point 1 CT Ratio

Phases Injected

: : : :

I/Inob Amps

Primary Current (Amps)

I-DIFF >> Setting

: I/Inob

Slope-2 Base Point-2

: :

Enter details of measured current in mA at Relay Panel XA (mA) 1

2

X87 (mA)

3

21 22

4

23 24

X64 (mA)

25 26

27 28

25

27 26

28

R–E Y–E

TR. DIFF & REF 300/1 (132 KV T1.1 SIDE) BUS-1

B–E Relay Display R

HV (A) Y

B

R

Relay Current (mA) LV (kA) Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–E Y–E B–E Rest Current (IN)

Oper. Current (IN)

Relay Display R

Y

Led Indication

Relay Display B

R

SEQ (HV) (A) I2 3I0

I1

Y

B

R–E Y–E B–E I1 R–E Y–E B–E

TP/TPD/PFS/TPC/QP-13:A04

Page 1 of 7

SEQ (LV) (kA) I2 3I0

Relay Display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

CT Ratio

Phases Injected

Primary Current (Amps)

Enter details of measured current in mA at Relay Panel

XA (mA) 1

2

X87 (mA)

3

21 22

4

23 24

X64 (μA)

25 26

27 28

25 26

27 28

R–Y Y–B

BUS-1TR. DIFF & REF 300/1 (132 KV T1.1 SIDE)

B–R Relay Display LV (kA)

HV (A) R

Relay Current (mA)

Y

B

R

Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–Y Y–B B–R

R

Rest Current (IN)

Oper. Current (IN)

Relay Display

Relay Display

Y

B

R

Y

Led Indication B

R–Y Y–B B–R I1

SEQ (HV) (A) I2 3I0

R–Y Y–B B–R

TP/TPD/PFS/TPC/QP-13:A04

Page 2 of 7

I1

SEQ (LV) (kA) I2 3I0

Relay Display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

CT Ratio

Phases Injected

Primary Current (A)

Enter details of measured current in mA at Relay Panel XA (mA) 1

2

X87 (mA)

3

21 22

4

23 24

X64 (mA)

25 26

27 28

25 26

27 28

R–E Y–E

BUS-2TR. DIFF & REF 300/1 (132 KV T1.2 SIDE)

B–E Relay Display LV (kA)

HV (A) R

Y

Relay Current (mA)

B

R

Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–E Y–E B–E

R

Rest Current (IN)

Oper. Current (IN)

Relay Display

Relay Display

Y

B

R

Y

Led Indication B

R–E Y–E B–E I1

SEQ (HV) (A) I2 3I0

R–E Y–E B–E

TP/TPD/PFS/TPC/QP-13:A04

Page 3 of 7

I1

SEQ (LV) (kA) I2 3I0

Relay Display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

CT Ratio

Phases Injected

Primary Current (Amps)

Enter details of measured current in mA at Relay Panel

XA (mA) 1

2

X87 (mA)

3

21 22

4

23 24

X64 (μA)

25 26

27 28

25 26

27 28

R–Y Y–B

BUS-2TR. DIFF & REF 300/1 (132 KV T1.2 SIDE)

B–R Relay Display LV (kA)

HV (A) R

Y

Relay Current (mA)

B

R

Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–Y Y–B B–R Rest Current (IN)

Oper. Current (IN)

RELAY DISPLAY R

Y

Led Indication

RELAY DISPLAY B

R

Y

B

R–Y Y–B B–R I1

SEQ (HV) (A) I2 3I0

R–Y Y–B B–R

TP/TPD/PFS/TPC/QP-13:A04

Page 4 of 7

I1

SEQ (LV) (kA) I2 3I0

Relay Display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

CT Ratio

Phases Injected

Primary Current (Amps)

Enter details of measured current in mA at Relay Panel XA (mA) 9

10

X87 (mA)

11

5 6

12

7 8

X64 (mA) (11KV)

9 10

11 12

25 26

27 28

R–E Y–E B–E

TR. DIFF & REF 3200/1 (11 KV SIDE)

Relay Display LV (kA)

HV (A) R

Y

Relay Current (mA)

B

R

Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–E Y–E B–E

R

Rest Current (IN)

Oper. Current (IN)

Relay Display

Relay Display

Y

B

R

Y

Led Indication B

R–E Y–E B–E I1

SEQ (HV) (A) I2 3I0

R–E Y–E B–E

TP/TPD/PFS/TPC/QP-13:A04

Page 5 of 7

I1

SEQ (LV) (kA) I2 3I0

Relay display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer CT Ratio

Phases Injected

Primary Current (Amps)

Enter details of measured current in mA at Relay Panel XA (mA) 9

10

X87 (mA)

11

5 6

12

7 8

X64 (μA) (11KV)

9 10

11 12

25 26

27 28

R–Y Y–B B–R

TR. DIFF & REF 3200/1 (11 KV SIDE)

Relay Display LV (kA)

HV (A) R

Y

Relay Current (mA)

B

R

Y

HV B

Q1

Q3

Q5

LV Q6

R1

R3

R5

R–Y Y–B B–R

R

Rest Current (IN)

Oper. Current (IN)

Relay Display

Relay Display

Y

B

R

Y

Led Indication B

R–Y Y–B B–R I1

SEQ (HV) (A) I2 3I0

R–Y Y–B B–R

TP/TPD/PFS/TPC/QP-13:A04

Page 6 of 7

I1

SEQ (LV) (kA) I2 3I0

Relay Display

R6

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION SENSITIVITY TESTS

Consultant: Manufacturer

Particulars

Make

Testing Instruments Details Type

Tested By (Contractor) Signature Name

TP/TPD/PFS/TPC/QP-13:A04

Page 7 of 7

Sr.No.

Cal. Due Date

Witnessed By (DEWA)

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION STEBILITY TESTS

Consultant: Manufacturer

RELAY SETTING I-DIFF > Setting Calculated I POC Slope 1 Base point 1

: : : :

I/Inob Amps

I-DIFF >> Setting

: I/Inob

Slope-2 Base Point-2

: :

RY:…………….., YB:…………… , BR:…………….

APPLIED VOLTAGE AT LV SIDE [WHILE HV SIDE SHORTED]:

132KV BUS-1 CT : NORMAL 11KV CT : NORMAL Primary Current Secondary current

Relay Display

HV REF

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA)

Tap position: 1 R

Y

B

Tap position: 10 N

B

N

R

Y

B

N

---

---

---

---

---

---

---

---

---

---

---

---

---

---

Relay current (mA) Operation

CT RATIO: 132 KV : 300/1A 11 KV : 3200/1A

TP/TPD/PFS/TPC/QP-13:A05

Y

---

Operation LV REF

R

Tap position: 19

Page 1 of 5

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION STEBILITY TESTS

Consultant: Manufacturer

132KV BUS-2 CT : NORMAL 11KV CT : NORMAL Primary Current

11 KV (A)

132 KV (F87T) mA 11 KV (f87T) mA Line current (H.V) (A) Line current (L.V) (KA) Relay Display Differential current Restraining current Relay current (mA) HV REF Operation Relay current (mA) LV REF Operation 132 Reversal

Tap position: 1 R

Y

B

Tap position: 10 N

R

Y

B

Tap position: 19 N

R

Y

B

N

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

Tap position: 10 R - REVERSE R Y B N

Tap position: 10 Y- REVERSE Y B N

Tap position: 10 B - REVERSE Y B N

Secondary current

132KV BUS-1 CT : REVERSE 11KV CT : NORMAL Primary Current Secondary current

Relay Display

HV REF

LV REF

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA) Operation Relay current (mA) Operation

TP/TPD/PFS/TPC/QP-13:A05

R

R

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

Page 2 of 5

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant: Manufacturer

132KV BUS-2 CT : REVERSE 11KV CT : NORMAL Primary Current Secondary current

Relay Display

HV REF LV REF

Equipment: SCADA No: Dt. IDT Differential PROTECTION STEBILITY TESTS Tap position: 10 Tap position: 10 R - REVERSE Y- REVERSE R Y B N R Y B N R

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA) Operation Relay current (mA) Operation

Tap position: 10 B - REVERSE Y B N

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

Tap position: 10 R - REVERSE R Y B N

Tap position: 10 Y- REVERSE Y B N

Tap position: 10 B - REVERSE Y B N

11kV Reversal 132KV BUS-1 CT : NORMAL 11KV CT : REVERSE Primary Current Secondary current

Relay Display

HV REF

LV REF

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA) Operation Relay current (mA) Operation

TP/TPD/PFS/TPC/QP-13:A05

R

R

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

Page 3 of 5

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay:

Consultant: Manufacturer

132KV BUS-2 CT : NORMAL 11KV CT : REVERSE Primary Current Secondary current

Relay Display

HV REF

LV REF

Equipment: SCADA No: Dt. IDT Differential PROTECTION STEBILITY TESTS Tap position: 10 Tap position: 10 R - REVERSE Y- REVERSE R Y B N R Y B N R

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA) Operation Relay current (mA) Operation

Tap position: 10 B - REVERSE Y B N

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Normalising 132KV BUS-1 CT : NORMAL 11KV CT : NORMAL Primary Current Secondary current

Relay Display

HV REF

TAP POSISTION: 10 R

Y

11 KV (A) 132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA)

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Relay current (mA) Operation

TP/TPD/PFS/TPC/QP-13:A05

N ---

Operation LV REF

B

Page 4 of 5

TRANSMISSION POWER DIVISION PROTECTION DEPARTEMENT/ COMMISSIONING SECTION SITE TEST REPORT CONTRACT NO:

NAME OF SUB STATION:

Main Contractor

Name of Bay: Equipment: SCADA No: Dt. IDT Differential PROTECTION STEBILITY TESTS

Consultant: Manufacturer

TAP POSISTION: 10

132KV BUS-2 CT : NORMAL 11KV CT : NORMAL Primary Current

R

Y

B

N

11 KV (A)

Secondary current

Relay Display

HV REF

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132 KV (F87T) mA 11 KV (F87T) mA Line current (H.V) (A) Line current (L.V) (KA) Differential current Restraining current Relay current (mA)

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Operation Relay current (mA)

LV REF

Operation

Particulars

Make

Testing Instruments Details Type

Tested By (Contractor) Signature Name

TP/TPD/PFS/TPC/QP-13:A05

Page 5 of 5

Sr.No.

Cal. Due Date

Witnessed By (DEWA)