omicron ptl user manual enu

OMICRON PTL User manual

OMICRON electronics GmbH 1/42

OMICRON PTL

User manual

V1.100



Contents

1 Definition ....................................................................................................................................................4

2 General .......................................................................................................................................................4

3 Quick Start Information ............................................................................................................................4

4 XRIO Converter Structure ........................................................................................................................4 4.1 General Structure .................................................................................................................................4 4.2 Relay Parameter Section .....................................................................................................................4 4.3 Additional Information ...........................................................................................................................5

4.3.1 General ...........................................................................................................................................5 4.3.2 Relay Information ...........................................................................................................................5 4.3.3 Circuit Breaker ................................................................................................................................5 4.3.4 Test Information ..............................................................................................................................5

4.4 RIOplus .................................................................................................................................................5 4.5 Template Controller ..............................................................................................................................5 4.6 RIO .......................................................................................................................................................6 4.7 Activation of RIO Functions ..................................................................................................................6

5 Relay Settings Import ...............................................................................................................................6

6 Template Structure ...................................................................................................................................7 6.1 Hardware Configuration .......................................................................................................................7 6.2 Common Testing Procedures ...............................................................................................................7

6.2.1 Wiring Check ..................................................................................................................................7 6.2.2 Initial Test .......................................................................................................................................7 6.2.3 Trip Test with Circuit Breaker .........................................................................................................8

6.3 Feeder Protection Templates ...............................................................................................................8 6.3.1 Main and Backup Protection...........................................................................................................8 6.3.2 Switch onto Fault Protection ........................................................................................................ 10

6.4 Line Protection Templates ................................................................................................................. 10 6.4.1 Main Protection ............................................................................................................................ 10 6.4.2 Backup Protection ....................................................................................................................... 14 6.4.3 Switch onto Fault Protection ........................................................................................................ 15

6.5 Transformer Protection Templates .................................................................................................... 16 6.5.1 Internal Fault Protection .............................................................................................................. 16 6.5.2 External Fault Protection ............................................................................................................. 18

6.6 Generator Protection Templates ....................................................................................................... 19 6.6.1 Generator Differential Protection ................................................................................................. 19 6.6.2 Underexcitation (Loss-of-Field) Protection .................................................................................. 20 6.6.3 Pole Slipping (Out-of-Step) Protection ........................................................................................ 21 6.6.4 Accidental Energization Protection .............................................................................................. 21 6.6.5 Other Generator Protection ......................................................................................................... 21 6.6.6 Fault on Connected Network ....................................................................................................... 23

6.7 Motor Protection Templates .............................................................................................................. 25 6.7.1 Overload Protection ..................................................................................................................... 25 6.7.2 Short Circuit Protection ................................................................................................................ 26 6.7.3 Network Fault Protection ............................................................................................................. 27

6.8 Radial Feeder Recloser Test Templates ........................................................................................... 27 6.8.1 Metering Test ............................................................................................................................... 27 6.8.2 Minimum Trip Current Tests ........................................................................................................ 27 6.8.3 High Current Trip Tests ............................................................................................................... 28 6.8.4 Overcurrent Characteristic Tests ................................................................................................. 29 6.8.5 Cold Load Pickup or Delay Curve Characteristic Tests .............................................................. 29 6.8.6 Successful Reclose Sequence Tests .......................................................................................... 29 6.8.7 Reclose Sequence to Lockout Tests ........................................................................................... 30 6.8.8 Reset Timer Tests ....................................................................................................................... 31 6.8.9 High Current Lockout Tests ......................................................................................................... 32 6.8.10 Sequence Coordination Tests ................................................................................................... 32 6.8.11 Sensitive Earth Fault Min Trip ................................................................................................... 32 6.8.12 Sensitive Earth Fault Trip Time ................................................................................................. 32 6.8.13 Sensitive Earth Fault Sequence ................................................................................................ 33



6.8.14 Underfrequency Pickup ............................................................................................................. 33 6.8.15 Underfrequency Trip Times ....................................................................................................... 33

6.9 Interconnection Template .................................................................................................................. 34 6.9.1 Power Protection ......................................................................................................................... 34 6.9.2 Test of the Power-, Voltage- and Frequency-Pickup-Elements and Trip Time Tests ................. 35 6.9.3 Tests of the Interlock-Criterions of the Voltage- and Frequency-Protection ............................... 37 6.9.4 Test of the Logical-Function of the Voltage-Protection: .............................................................. 37 6.9.5 Evaluation Test of the Voltage-Protection ................................................................................... 37 6.9.6 Rate of Change of Frequency-Protection .................................................................................... 37 6.9.7 Voltage Vector Phase Shift Protection ........................................................................................ 40 6.9.8 Synchronism Check ..................................................................................................................... 41



1 Definition

Protection Test Template (PTT): A PTT is one part of a Protection Testing Library item. It consists of an *.occ file which includes and a XRIO Converter.

2 General

The OMICRON PTL User Manual describes the common aspects of all Protection Test Templates and their included XRIO Converters. The specific aspects are covered in a PTT specific manual, which is automatically installed with every PTT. Each PTT is user adaptable and can be extended by inserting additional tests or shortened by deleting tests to fit the requirements of each user. The Protection Test Templates are intended to support the advanced Test Universe user. Advanced knowledge of the Test Universe software, the XRIO standard and the LinkToXRIO concept are advised to benefit from the Protection Testing Templates. See www.omicron.at for more information on the Protection Testing Library.

3 Quick Start Information

Follow these steps before testing:

Read the PTT specific manual first. Open the Protection Test Template. Enter the relay settings into the Relay Parameter Section of the XRIO Converter or import them

using one of the available import filters. Check and adapt the Additional Information parameters in the XRIO Converter. Check the Hardware Configuration and adapt it if necessary. See the connection diagram and establish all connections between the test set and the relay. Check the test points in each test module and adapt them if necessary. Follow the specific instructions contained in the Pause modules.

4 XRIO Converter Structure

4.1 General Structure

The XRIO Converter is already included in the Protection Test Template. It can be accessed by opening the Test Object. Relay settings can be entered into the XRIO Converter either manually or automatically, using one of the available import filters. The XRIO Converters are divided into two root blocks, the CUSTOM block and the RIO block. The RIO block contains the standard RIO test module interface. The CUSTOM block is normally re-named to match the protection relay type modeled in the XRIO Converter. It normally has four sub-blocks:

Relay Parameter Section Additional Information RIOplus Template Controller

4.2 Relay Parameter Section

The Relay Parameter Section is a collection of setting parameters of the modeled relay. Each XRIO Converter has its own individual Relay Parameter Section to match the parameter structure of the corresponding relay setting software as close as possible. The Foreign ID in the XRIO Converter can be



used to identify the relay parameters. This helps to find the correct parameters when the settings are entered into the Relay Parameter Section manually. In some XRIO Converters, the Relay Parameter Section has been renamed to better match the relay setting software.

4.3 Additional Information

The Additional Information block stores parameters and information, which are required for testing and not a part of the relay settings. It contains at least the following sub-blocks:

General Relay Information Circuit Breaker Test Information

4.3.1 General

The General block contains detailed information for the test report, like manufacturer, device type, substation name etc. These parameters are linked to the NamePlate block in RIOplus and from there to the Device sub block of the RIO block. The parameters of this block have to be set by the user.

4.3.2 Relay Information

The block Relay Information contains relay specific parameters such as tolerances or angles of directional elements, which should not be set by the user because they are constant values. The values set in this block can be found in the relay documentation. Typically, this block does not have to be changed.

4.3.3 Circuit Breaker

The Circuit Breaker block includes information which is required for the CB test. This section includes parameters which have to be defined by the user.

4.3.4 Test Information

The Test Information block is used to store calculations required for the configuration of test modules. Calculated test points may be stored in this block.

4.4 RIOplus

The RIOplus section is divided into different sub-blocks, which include either relay information or modeling of a certain protection function. The sub-blocks of these protection functions include all the data required for testing the respective function. The RIOplus block is not visible in the Standard view of the Test Object. The RIOplus block can be extended, but existing parameters must not be deleted or changed. This will disable formulas.

4.5 Template Controller

The Template Controller block contains special test data, which cannot be mapped into the standardized RIOplus section, like the flags for the automated activation of test modules. This block can be extended by the user with new customized blocks and parameters. The Template Controller block is not visible in the Standard view of the Test Object. It can be extended, but existing parameters must not be deleted.



4.6 RIO

The RIO section of the XRIO Converter contains all functions required to use the specialized test modules (like Advanced Distance or Overcurrent) provided by the OMICRON Test Universe software.

4.7 Activation of RIO Functions

If multiple RIO-Functions of one type exist in a converter, the desired one has to be selected for each test module. Open therefore the local Test Object of the module and activate the RIO function you intend to use as shown below. Test modules in standard OMICRON PTTs are configured with the corresponding RIO block as default and thus they normally don't have to be changed.

Figure 1: Activating a RIO function

5 Relay Settings Import

Some relay manufacturers offer an export of the relay settings. Multiple relay settings import filters are available to import these settings into the XRIO Converter of the corresponding Protection Test Template.The following import filters are currently available:

Filter for AREVA S&R 103 .txt Settings Filter for SEL 5010-5030 .txt Settings: A filter for SEL AcSELerator Quickset setting export files. Filter for Siemens Digsi V3 .asc Settings Filter for Toshiba RSM100 .csv Settings Filter for GE Enervista .csv Settings Standard Filter for XRIO files: A filter for relay settings in XRIO format.

Currently Siemens Digsi V4.81 and higher (Digsi V4 relays) and ABB PCM600 2.2 settings can be exported in the XRIO format.

The handling of the import filters listed above is similar. Click the File menu in the menu bar of the Test Object and click Import relay settings.... Select the matching import filter in the Import Relay Settings dialog box.



After the relay settings have been imported successfully, a message box shows the number of imported parameters.

Figure 2: Report after parameter import

Additionally, the imported parameters are shown as Information in the Error View of the Test Object. When the import of a parameter fails, it gets shown as an Error or Warning.

Figure 3: Error View with information about imported parameters

6 Template Structure

6.1 Hardware Configuration

Each Protection Test Template contains an individual Hardware Configuration, which is specially adapted to the specific relay and tests. All binary inputs are preset to Potential Free and can be set as potential sensing inputs if necessary.

6.2 Common Testing Procedures

Some tests are standard tests and appear in all Protection Test Templates.

Wiring check Initial test Trip test with circuit breaker

6.2.1 Wiring Check

The wiring test is used to check the Analog Output connections between the CMC test set and the relay. The QuickCMC test module is used to inject asymmetrical voltage and current values. For transformer protection or some feeder protection PTTs, only asymmetrical currents are injected. If the injected values match the values measured by the relay, the test can be manually assessed as Passed.

6.2.2 Initial Test

The Initial test is used to check whether the relay reacts correctly in case of a protected object fault. Additionally, the wiring of the trip signal between the test set and the relay is checked. The Initial test simulates a fault event that is clearly different from normal load conditions. Usually, a high fault current is injected into all three phases with the State Sequencer test module. The relay should trip on this event, regardless of the active protection functions. The trip command and the reset of the trip command are measured and assessed during the Initial test.



6.2.3 Trip Test with Circuit Breaker

For testing the opening time of the circuit breaker, the State Sequencer test module is used. This test is divided into three states: pre-fault, fault and post-fault. Usually a three-phase short circuit is simulated in the fault stage. The time between the trip command and the opening of the circuit breaker main- and auxiliary contacts is measured and assessed.

6.3 Feeder Protection Templates

Feeder protection templates mostly cover directional or non-directional overcurrent protection functions. If a distance protection function is covered by a feeder protection test template, see section 6.4 for details on distance protection specific tests.

6.3.1 Main and Backup Protection

Pickup Test

The overcurrent pickup is tested using the Overcurrent test module. The smallest pickup of all active phase, residual and negative sequence overcurrent elements is tested. The pickup and the drop off value are assessed. See the online help of the Test Universe for further information on the Pickup/Drop-off Test tab of the Overcurrent test module.

Figure 4: Phase overcurrent pickup test

Directional Test

The overcurrent directional characteristic is tested with the Overcurrent test module. Two test shots are placed inside the directional (forward or reverse) sector. Two more shots are placed just outside the directional sector. It is sufficient to attest the difference between the forward and non-directional, alternatively between the reverse and non-directional or the forward and reverse characteristics.



Figure 5: Phase overcurrent directional test

Trip Time Test

The trip times are tested with the Overcurrent test module. To minimize influences from overcurrent stages covering different fault types (e.g. phase overcurrent in phase to ground tests) the following three fault types are tested:

A-B-C for testing the phase overcurrent elements

3I0 for testing ground or residual overcurrent elements

I2 for testing negative sequence overcurrent elements



Figure 6: Phase overcurrent trip time test

6.3.2 Switch onto Fault Protection

There are several different versions of switch onto fault tests, due to the different algorithms used by the relays. These tests are individually designed for each PTT. See the specific PTT manual for a detailed description of the switch onto fault tests.

6.4 Line Protection Templates

6.4.1 Main Protection

Directional Test

If a directional overcurrent function is covered by the line protection PTT, the directional test is similar to the feeder protection directional test. Most line protection PTTs cover distance protection functions, where the Advanced Distance test module is used for testing the directional characteristic. It is sufficient to attest the difference between the forward and non-directional, alternatively between the reverse and non-directional characteristics. Set the test points for the directional test similar to the test points shown in Figure 7 and Figure 8. The distance direction is tested separately for fault loop A-N and fault loop A-B-C. The directional test is not necessary for mho distance characteristics.



Figure 7: Directional test point placement example 1 (quadrilateral zone characteristic)

Figure 8: Directional test point placement example 2 (circle zone characteristic)



Trip Characteristic Test

If a directional overcurrent function is covered by the line protection template, the trip characteristic test is similar to the feeder protection trip characteristic test. For distance protection relays, the trip characteristic test is divided into two parts, a trip time test and a distance reach test.

Trip Time Test

The zone trip time is tested by a test shot placed at 90% of each active zone and 110% of all zones. These shots are set on the line angle.

Figure 9: Distance protection trip times

Possibly there are more test shots than necessary in the trip time test modules, because the preset test points are set relative to all possibly active distance zones in forward and reverse direction. If a distance zone is exclusively not active or directional, the test points set relative to this distance zone collapse into the origin of the R-X test plane. In this case, delete all unnecessary test points. The unnecessary test points can be identified by a very small impedance value - nearly zero (e.g. 8.333e-10 ) or by their zone reference, which is set to Line length.



Figure 10: Unnecessary test points

The pink test shots shown below are out of range. In this case, remove the link of the test current and set the test current manually. The test current can be found in the Settings tab. Keep in mind that the test current has to be higher than the distance protection release current.

Figure 11: Test current too high



Reach Test

The distance reaches are tested by Check Tests with check lines at 0, 90, 180 and 270. Each check line is set relative to a length of 120% of all active distance zones. In some Protection Test Templates, the check lines might be placed at the line angle instead of 90 and 270. The check lines at 0 and 180 are not necessary for mho distance characteristics.

Figure 12: Distance reach test

6.4.2 Backup Protection

The backup protection in line protection templates is usually the non-directional overcurrent protection. The pickup and trip time are tested similar to the feeder protection templates. The backup protection is activated by a loss of potential, which means that zero voltage and a small load current are injected into the relay. A preset time duration for this loss of potential state is defined. If this time is too short to block the main protection function, increase the time manually.



Figure 13: Backup overcurrent pickup test

Figure 14: Backup overcurrent trip time test

6.4.3 Switch onto Fault Protection

There are several different versions of switch onto fault tests, due to the different algorithms used by the relays. These tests are individually designed for each PTT. See the specific PTT manual for a detailed description of the switch onto fault tests.



6.5 Transformer Protection Templates

6.5.1 Internal Fault Protection

Internal faults are detected by the differential protection. The tripping and the non-operating characteristics of the differential protection are tested. The external fault protection may trip during this test, especially if higher fault currents are injected into the relay.

Trip Characteristic Test

The trip characteristic test is intended to check the differential protection trip in case of an internal fault. Internal single phase and multi phase faults are tested with the Diff Operating Characteristic test module. A search test is performed to verify the trip characteristic. Change the predefined test lines to fit the characteristic set in the protection relay.

Figure 15: Differential operating characteristic test

Trip Time Test

The differential trip time test is intended to check the trip of the differential protection function. The Diff Trip Time Characteristic test module is used. A three phase fault is preset in this test, but any required test point can be added.



Figure 16: Differential trip time test

Non-Operating Characteristic Test

The non-operating characteristic tests are intended to check the relay behavior in case of load current or an external fault condition: the differential protection function must not operate whereas the external fault protection trips. Multi phase and single phase currents through the transformer are tested with the Diff Configuration test module. The single phase test additionally checks the correct zero sequence current elimination. The test has to be assessed by clicking the Passed or Failed button after a sufficient time.

Figure 17: Differential non-operating test external fault condition



6.5.2 External Fault Protection

The external fault protection is usually a combination of timed and instantaneous overcurrent protection functions, which can be set individually for each transformer winding. Tests are prepared for the external fault protection of each transformer winding.

Pickup Test

The pickup of the smallest active overcurrent stage is tested with the Overcurrent test module. The fault current (single phase and multi phase faults) is ramped until the relay picks up.

Figure 18: Overcurrent pickup test

Trip Time Test

The overcurrent trip times are tested for multi and single phase faults. The Overcurrent test module is used for this test.



Figure 19: Overcurrent trip time test

6.6 Generator Protection Templates

The generator protection templates contain tests for the protection of low or high voltage generators. Since the characteristic of the different protection functions may overlap, it may be necessary to block some functions during a test. Therefore, follow the test instructions given in the template Pause modules.

6.6.1 Generator Differential Protection

Stability Test

The blocking test is intended to check the differential protection stability in case of an external fault that occurs on the connected power system. Three phase and single phase external faults are tested with the Diff Configuration test module. The single phase test additionally checks the correct zero sequence current elimination in case a step up transformer is also inside the protected zone. The test has to be assessed by clicking the Passed or Failed button after a sufficient time.

Characteristic Test

The characteristic test is intended to check the differential protection trip in case of an internal fault. Single phase and multi phase faults are tested with the Diff Operating Characteristic test module. A search test is performed to verify the trip characteristic. Change the predefined test lines to fit the characteristic set in the protection relay.



Figure 20: Differential operating characteristic test

Other protection functions used to protect the generator may trip during this test, especially if higher fault currents are injected into the relay.

Trip Time

The differential trip time test is intended to check the differential protection trip time. The Diff Trip Time Characteristic test module is used. Single phase and multi phase faults are tested. One test point is preset for each fault type, but any required test point can be added.

6.6.2 Underexcitation (Loss-of-Field) Protection

The underexcitation protection function is tested using the Advanced Distance test module. The underexcitation zones are modeled in the impedance plane. This enables testing of the operating characteristic as well as the trip times of the different zones. No test points are preset for this test. The user has to set the test shots manually. An example of how the user can place the test shots is shown in the figure below.

Figure 21: Test shots example for underexcitation test



6.6.3 Pole Slipping (Out-of-Step) Protection

The relay response is tested during a power swing condition centered in the generator protection zone. The State Sequencer test module is used. For each power swing at least four test states are used to simulate this phenomenon. The Impedance View of the State Sequencer test module can be used to visualize and control the test points.

Figure 22: Pole slipping states 1 to 4 (power swing in the generator) Impedance View

Depending on the specific relay, more test points (inserted between the points shown above) may be required for the simulation.

6.6.4 Accidental Energization Protection

The accidental (inadvertent) energization test is intended to check the behavior of the generator protection relay when a not-synchronized or offline generator is accidentally connected to the network. This function is usually predefined in relays as a combination of timed undervoltage and instantaneous overcurrent elements. The pickup values (voltage and current), the trip times and the blocking logic of this function are tested. The accidental energizing tripping conditions are simulated using the State Sequencer test module. See the template specific documentation for a detailed description of this test.

6.6.5 Other Generator Protection

The following protection functions are also covered in the generator protection templates:

Frequency (over/under);

Phase and residual Voltage (over/under);

Overexcitation (V/Hz);

Unbalanced load (negative sequence overcurrent);

Overcurrent; (phase and residual);

Power protection (reverse and forward). The pickup values and the trip times are tested for these functions.

Pickup Test

The pickup is tested with the Ramping test module. It is tested with a first ramp, increasing (decreasing) the related quantity (frequency, voltage, current or power) until the pickup value is reached. If applicable, a second ramp decreases (increases) the quantity until the pickup signal is reset. The pickup and drop off values are measured and assessed.



Figure 23: Overfrequency pickup test

Figure 24: Phase overcurrent pickup test

Trip Time Test

The trip time is tested by simulating a suitable fault and checking the relay response. Different test modules are used depending on the tested protection function. The State Sequencer test module is used for the frequency, voltage, overexcitation and power trip time tests. This test is divided into three states: pre-fault, fault and post-fault.



Figure 25: Overvoltage trip time test

The Overcurrent test module is used for the unbalanced load and overcurrent trip time tests. Test points are preset in this test, but they can be adjusted if necessary.

Figure 26: Unbalanced load trip time test

6.6.6 Fault on Connected Network

The generator protection template also covers tests for protection functions that usually protect the generator from faults on the connected power system or on the connected transformer/bus. These protection functions may also be used as a backup protection for generator faults.



Under Impedance Protection

The under impedance protection test is divided into two parts, a trip time test and a reach test. The Advanced Distance test module is used. Test shots are placed usually at 0 and/or 90 of each active zone. The test points can be adapted if necessary.

Figure 27: Under Impedance trip time test

Voltage-Dependent Overcurrent Protection

The pickup value and the trip time are tested. The Ramping test module is used for the pickup test. If applicable, the VI Starting test module may be used to check the voltage-dependent pickup characteristic. In this case, the overcurrent pickup value is checked for different voltage levels.

Figure 28: Voltage-dependent overcurrent pickup test

The Overcurrent test module is used for the trip time test. A voltage value is preset in the test module to be provided during the test, but can be changed if necessary.



Figure 29: Voltage-dependent overcurrent trip time test with a preset voltage

Overload Protection

The trip time is tested by simulating a three-phase overload condition. The Overcurrent test module is used. A test shot is preset, but can be changed if necessary.

6.7 Motor Protection Templates

Motor protection templates contain tests of protection functions supervising the magnitude of current or voltage to protect the motor.

6.7.1 Overload Protection

The overload protection comprises tests for multiple current (or voltage and current) magnitude dependent elements, protecting the motor from overload caused by problems in the powered process. These functions are often depending on a thermal image with additional restart inhabitation. Therefore it may be necessary to reset the thermal image after each test shot for a correct display of the tripping characteristic. The thermal reset unlatches the trip command and enables the next test sequences. In some configurations the trip command will not unlatch without an additional confirmation to the relay. In this case it is necessary to assure the unlatching manually after every test shot.

Motor Starting Protection (Acceleration Time) Trip Time Test

The Overcurrent test module is used for trip time tests of startup supervision functions. The pre-fault time is set to 0 s to assure activation of this function. If an additional logic is configured for this function, corresponding conditions need to be set manually to arm the function. One test shot relative to the minimum trip value of this function is preset in this test, but it can be adjusted if necessary.



Figure 30: Motor Starting Protection Trip Time Test

Thermal Overload Trip Time Test

The Overcurrent test module is used for trip time tests of the Thermal Overload function. One test relative to the minimum trip value of this function is preset in this test, but it can be adjusted if necessary.

Stall after Startup (Mechanical Jam) Trip Time Test

The Overcurrent test module is used for trip time tests of the mechanical jam function. A pre-fault time is set to a time longer than the minimum running time duration of the motor. One test shot relative to the minimum trip value of the function is preset, but it can be adjusted if necessary.

6.7.2 Short Circuit Protection

Current Differential Protection

Stability Test

The stability test is intended to check the stability of the differential protection function in case of an external fault that occurs on the connected power system (the protected motor supplies the fault) and under a normal load condition (three phase, symmetrical conditions). Both cases are simulated using the Diff Configuration test module. The test has to be assessed by clicking the Passed or Failed button after a sufficient time.

Characteristic Test

The characteristic test is intended to check the differential protection trip in case of an internal fault. Single phase and multi phase faults are tested with the Diff Operating Characteristic test module. A search test is performed to verify the trip characteristic. Change the predefined test lines to fit the characteristic set in the protection relay. Other protection functions used to protect the motor may trip during this test, especially if higher fault currents are injected into the relay.

Trip Time Test

The differential trip time test is intended to check the differential protection trip time. The Diff Trip Time Characteristic test module is used for this test. Single phase and multi phase faults are tested. One test point is preset for each fault type, but any required test point can be added.



Overcurrent Protection

Pickup Test

The overcurrent pickup is tested using the Overcurrent test module. The smallest pickup of all active phase, residual, negative sequence and zero sequence overcurrent elements is tested. The pickup current is assessed.

Trip Time Test

The trip times are tested with the Overcurrent test module.

6.7.3 Network Fault Protection

Current Amplitude Unbalance Protection

Pickup Test

The current unbalance protection pickup is tested using the Overcurrent test module. This test is similar to test described in the Overcurrent Protection Pickup Test chapter. Depending on the type of the unbalance element used in the relay the value of the positive sequence current is at motor nominal level (elements comparing ratio of negative and positive sequence currents magnitude) or at zero (elements supervising only negative sequence current magnitude).

Trip Time Test

The trip times of the current unbalance protection are tested with the Overcurrent test module. This test is similar to test described in Overcurrent Protection Trip Time Tests chapter. Additionally the load current is at motor nominal level (elements comparing ratio of negative and positive sequence currents magnitude) or at zero (elements supervising only negative sequence current magnitude).

Overvoltage / Undervoltage Protection

Pickup Test

The pickup is tested with the Ramping test module. It is tested with a first ramp, increasing (decreasing) the related quantity (phase voltage magnitude or negative sequence voltage magnitude,) until the pickup value is reached. If applicable, a second ramp decreases (increases) the quantity until the pickup signal is reset. The pickup and drop-off values are measured and assessed.

Trip Time Test

The trip time of the function is tested by simulating a suitable fault and checking the relay response. The State Sequencer test module is used. This test is divided into three states: pre-fault, fault and post-fault.

6.8 Radial Feeder Recloser Test Templates

6.8.1 Metering Test

The purpose of the Metering Test is to check the correct analog input configuration of the recloser controller under test. The Quick CMC test module is used to inject slightly asymmetrical voltages and currents, which can be compared with the currents and voltages measured by the recloser controller. If the injected values match the measured values, the test can be assessed manually as Passed.

6.8.2 Minimum Trip Current Tests

The Minimum Trip Current of phase and neutral/ground overcurrent elements is tested using the Ramping test module. The Minimum Trip Current setting of all active phase, neutral and residual ground overcurrent elements is tested. The test current is ramped until it exceeds the set Min. Trip Current. The dt setting of the ramp, which specifies the time between two ramp steps, is not linked and preset to sufficient time to test the Min. Trip Current of inverse overcurrent characteristics. This setting can be adapted manually if longer or shorter time intervals are needed.



Figure 31: Phase Minimum Trip Current Test

The Ground Minimum Trip Current Test might interfere with the Sensitive Earth Fault function, when SEF is set with a low minimum trip current and a long trip time. To avoid this interference, the Ground Minimum Trip Current Test uses the Pulse Ramping test module when a SEF function is activated in the recloser controller. The test current is pulsed with the current amplitude being raised in each new current pulse. The time of each of the current pulses is short enough to force the ground overcurrent element to trip without tripping the SEF element.

6.8.3 High Current Trip Tests

The High Current Trip of phase and neutral/residual ground overcurrent elements is tested using the Pulse Ramping test module. The test current is pulsed with the current amplitude being raised in each new current pulse. The time of each of the current pulses is short enough to force the High Current Trip overcurrent element to trip without tripping the inverse overcurrent element.



Figure 32: Phase High Current Trip Test

6.8.4 Overcurrent Characteristic Tests

The overcurrent characteristic of the phase and neutral/residual ground overcurrent elements is tested with the Overcurrent test module. Test points are preset but can be adapted to fit all needs. Basically, the test of the overcurrent characteristic is similar to the overcurrent characteristic tests in feeder applications described in the Feeder Protection chapter of this manual.

6.8.5 Cold Load Pickup or Delay Curve Characteristic Tests

The delay curve of recloser controllers is tested in combination with the Cold Load Pickup function. When a Close command is sent by pressing the Close button on the recloser controller, the Cold Load Pickup function is activated and disables fast curve tripping for a set time. The Overcurrent test module is used for the Delay Curve Characteristic Test. To test the delayed overcurrent curve, three test points are defined on this curve and one test point is defined to verify the modified Minimum Trip Current setting. The Close button on the recloser controller has to be pressed before a test point is executed. A message box instructs the user to press the close button. Both phase and ground delay curves and Cold Load Pickup Minimum Trip Current settings are tested.

6.8.6 Successful Reclose Sequence Tests

Successful reclosing sequences are tested using the State Sequencer test module. A successful reclosing sequence is tested for all possible combinations of shots. If four shots to lockout are set, successful reclosing sequences are tested with one shot, two shots and three shots. The Successful Reclose Sequence tests start with either a Defeat CLPU / Reset Recloser state, when the recloser locked out at the end of the preceding test, or a pre fault state, when the preceding test finished with a closed recloser. Each shot is tested with a fault state, forcing the recloser to trip, and an Interval state, awaiting the close command. If necessary, Transition States between Fault and Interval states are added to allow the CB simulation to react before switching to the next state if the recloser controller evaluates trip and close operations very strictly (Cooper F6 or F5). The Successful Reclose Sequence Tests end with a Fault Cleared state, simulating normal load conditions after the fault has been cleared. The time settings for all fault states are not linked. they may have to be adapted if the preset time is not sufficient for the active settings.



All trip times are measured; all Interval times are measured and assessed. Additionally, a Level Assessment of the Fault Cleared state is implemented, which assesses that no trip command must be sent during the Fault Cleared state. Successful reclosing sequences are tested for phase and ground faults.

Figure 33: 1 Shot successful reclosing sequence

6.8.7 Reclose Sequence to Lockout Tests

Reclosing Sequences to Lockout are tested using the State Sequencer test module. The reclosing sequence to lockout test is similar to the Successful Reclose Sequence Tests. The test starts with a pre fault state simulating normal load conditions, followed by a sequence of Fault and Interval states. The number of Fault and Interval states depends on the number of shots to lockout set in the recloser controller. Four shots to lockout means there are three Fault states followed by an Interval state and one last Fault State driving the recloser controller to lockout. The Lockout State will time out after 2 times the longest set interval time. This ensures that no Close command is sent after the last fault in the sequence. To assess that there is no follow up close after the last fault, an End of Test state is added, which serves as a stop condition for a time measurement of the Lockout state. All trip times are measured; all Interval times and the time out of the Lockout state are measured and assessed. Sequence-to-Lockout tests are performed for phase and ground faults.



Figure 34: 4 Shots to Lockout reclosing sequence

6.8.8 Reset Timer Tests

The reset timer is tested with the State Sequencer test module. The test is divided into two parts: The first part interrupts a reclosing sequence (shot counter > 1) and waits until just before the reset timer times out. The second test interrupts a reclosing sequence and waits until the reset times out. A new reclosing sequence is then started and continues until the recloser controller locks out.

Figure 35: Reset Timer Test - Timer Expired (4 Shots to Lockout)



Figure 36: Reset Timer Test - Timer Active (4 Shots to Lockout)

Only the Interval times are measured and assessed in the Reset Timer tests. Additionally, Level Assessments are active to ensure that no Trip command is sent during the Reset Time state and that no Close command is sent during the Lockout state.

6.8.9 High Current Lockout Tests

High Current Lockout is tested with the State Sequencer test module. The tests are intended to check the correct interruption of a reclosing sequence when the set High Current Lockout current is exceeded. A high current fault is simulated, which drives the recloser controller into lockout immediately. The time out of the Lockout state is measured and assessed. Additionally, a Level Assessment is active to check that no Close command is sent during the Lockout state. High Current Lockout is tested for phase and ground faults.

6.8.10 Sequence Coordination Tests

Sequence Coordination is tested with the State Sequencer test module. The Sequence Coordination tests are intended to check if the recloser controller is "in step" with an assumed downstream recloser, when the downstream device clears a fault without reaction of the local recloser controller. The reclose sequence in this test is similar to the Reclose Sequence to Lockout test. The main difference is that one or more Fault states of the original sequence are replaced with a Sequence Coordination state. The Sequence Coordination State simulates the same fault conditions as a Fault state from the original sequence, but it times out before the recloser controller is able to send a trip command. The shot counter will increment as the Sequence Coordination state is recognized as a fault. All possible combinations of Sequence Coordination and Fault operations are tested. The trip times in all Fault states are measured; all Interval times are measured and assessed. Sequence Coordination is tested for phase and ground faults.

6.8.11 Sensitive Earth Fault Min Trip

Sensitive Earth Fault Min Trip is tested with the Ramping test module. The current in one phase is ramped until the SEF Min Trip setting is exceeded. The time between two ramp steps is greater than the SEF trip time setting. The Min Trip Current is measured and assessed.

6.8.12 Sensitive Earth Fault Trip Time

Sensitive Earth Fault Trip Times are tested with the State Sequencer test module. The test contains three states: Defeat CLPU / Reset Recloser, Fault and End of Test. In the Fault state, a current exceeding the SEF Min Trip setting is injected in one phase. The trip time is measured and assessed.



6.8.13 Sensitive Earth Fault Sequence

The Sensitive Earth Fault Sequence Tests are similar to the ground reclosing sequence tests. See the Successful Reclose and Reclose Sequence to Lockout chapters for details.

6.8.14 Underfrequency Pickup

The Underfrequency Pickup is tested with the Ramping test module. The voltage frequency in all three phases is decreased until the frequency protection trips. The time between two ramp steps is greater than the underfrequency trip time. The frequency pickup is measured and assessed.

6.8.15 Underfrequency Trip Times

Underfrequency Trip Times are tested with the State Sequencer test module. The test contains three states: Pre fault, Fault and Post Fault. In the Fault state, a voltage frequency below the Underfrequency Min Trip setting is injected in all three phases. The trip time is measured and assessed.



6.9 Interconnection Template

The Interconnection Template contains tests for typical interconnection applications. Since the characteristic of different protection functions may overlap, it may be necessary to block some functions during a test. Therefore, follow the test instructions given in the template Pause modules.

6.9.1 Power Protection

Power Direction Test

Figure 37: Power Direction Test

To allow a test of a relay with a power protection function, the reference arrow system of the template and of the used relay has to be verified. The Interconnection PTT is built-up using the load reference arrow system (LARS). To ensure that the relay is working in the same reference arrow system, a power output of the generator is simulated with the Quick CMC. The user has to ensure, that the measured values of the active and reactive power of the relay have a negative algebraic sign. In that case the test can be manually assessed as PASSED. The measured values can be entered in the table, which is already inserted in the protocol.



6.9.2 Test of the Power-, Voltage- and Frequency-Pickup-Elements and Trip Time Tests

Within this chapter general information is given, how the pickup and trip time tests of the mentioned protection function are built up.

Pickup-Test of the first Element (P>,U>,U,f

The pickup is tested with the Ramping test module. It is tested with a first ramp, increasing (decreasing) the related quantity (power, frequency or voltage) until the pickup value is reached. If applicable, a second ramp decreases (increases) the quantity until the pickup signal is reset. The pickup and drop off values are measured and assessed.



Pickup-Test of the second Element (P>>,U>>,U,f

The pickup of the second element is tested with the Pulse Ramping test module. The test quantity is pulsed with the quantity amplitude, which is being increased (decreased) in each new pulse. The time of each of the pulses is short enough to force the second element to trip without tripping of the first element.

Trip Time Tests of the active Elements

Figure 40: Under-Frequency Protection: Trip Time Test f<

For each active element the corresponding trip time has to be tested. For this test the State Sequencer test module is used. The trip time is tested by simulating a suitable fault and checking the relay response. This test is divided into three states: pre-fault, fault and post-fault.



6.9.3 Tests of the Interlock-Criterions of the Voltage- and Frequency-Protection

Figure 41: Test of Under-Voltage-Protection Minimum Current Criterion

The correct value of the Interlock-Criterion is tested with the Ramping test module. During those tests a suitable fault state for the locked protection function is continuously simulated, which causes a trip, if the Interlock-Criterion is not fulfilled. The interlock value is tested with a first ramp increasing the related quantity (in case of the Voltage Protection: Current; in case of the Frequency Protection: Voltage) until the relay trips. If applicable, a second ramp decreases (increases) the quantity until the trip signal is reset. The pickup and drop off values are measured and assessed.

6.9.4 Test of the Logical-Function of the Voltage-Protection:

Within these tests the logical function supervising the voltage protection (Over- and under-voltage) and their different stages are tested. This logic is intended to ensure that voltage faults in every phase cause a trip of the relay. If the relay operates in phase-to-ground-measuring mode, the voltage in every phase is increased (decreased), until the relay trips. If the active measuring mode is phase-to-phase, the voltage amplitude is increased (decreased) in two phases. In that case the three phase-to-phase-voltages are increased (decreased), but only one phase-to-phase-voltage will cause a trip. The Logical-Function-Test is tested with the State Sequencer test module. For every Phase-to-Ground- respectively Phase-to-Phase-Voltage the test is divided into three states: pre-fault, fault, post-fault.

6.9.5 Evaluation Test of the Voltage-Protection

The intention of this test is to ensure that, in case of a not grounded network, neither the overvoltage-protection nor the undervoltage-protection causes a trip, if a ground fault occurs. For this test the State Sequencer test module is used. The test is divided into two states: pre-fault and fault. The absence of the trip signal in the fault state is assessed.

6.9.6 Rate of Change of Frequency-Protection

The Rate of Change of Frequency-Protection is divided into three blocks.

df/dt (absolute, positive, negative)

f> and df/dt positive

f< and df/dt negative The test of df/dt-absolute-protection contains the test of the df/dt-positive and the df/dt-negative protection.



Pickup Test over-frequency-element f> or under-frequency-element f<

Figure 42: Test of f> and RoCoF: Pickup f>

The pickup is tested with the Ramping test module. To allow a pickup test of the over-frequency- respectively the under-frequency-protection the RoCoF-criterion has to be fulfilled. Under that condition, the pickup value is tested with a first ramp, increasing (decreasing) the frequency until the corresponding value is reached. The pickup value is measured and assessed.

Pickup Test df/dt (absolute, positive or negative)

Figure 43: Test of RoCoF: Pickup df/dt positive

The pickup of df/dt-positive- and df/dt-negative-element is tested with the Pulse Ramping test module. The test quantity df/dt is pulsed with a value, which is being increased (decreased) in each new pulse. The time of each of the pulses is long enough to force the element to trip. The pickup value is measured and assessed. If the df/dt-protection is combined with an over- or under-frequency-protection and the df/dt-pickup-value has to be tested, the over- respectively the under-frequency-criteria must be fulfilled.



Trip Time Test

Figure 44: Test of RoCoF: f< and df/dt Trip Time

For the active RoCoF-function the corresponding trip time has to be tested. For this test the State Sequencer test module is used. The trip time is tested by simulating a suitable fault and checking the relay response. This test is divided into three states: pre-fault, fault and post-fault.

Tests of the Interlock-Criterion

Figure 45: Test of RoCoF: Minimum Voltage Criterion for f< and df/dt neg.

The functionality of the Interlock-Criterion is tested with the State Sequencer test module. The test is divided into a pre-fault, a Voltage-Fault, which activates the interlock, and a fault, whose settings fulfill the criteria of the protection functions. The absence of the trip signal is measured and assessed.



6.9.7 Voltage Vector Phase Shift Protection

Pickup Test

Figure 46: Voltage Vector Phase Shift Protection: Test of Pickup delta phi (positive)

The pickup of delta-phi-positive- and delta-phi-negative- element is tested with the Pulse Ramping test module. The test quantity angle is pulsed with a value, which is being increased (decreased) in each new pulse. The time of each of the pulses is long enough to force the element to trip. The pickup value is measured and assessed.

Trip Time Test

Figure 47: Voltage Vector Phase Shift Protection: Test of Pickup delta phi (positive)

For Voltage Vector Phase Shift-Protection the corresponding trip time has to be tested. For this test the State Sequencer test module is used. The trip time is tested by simulating a suitable fault and checking the relay response. This test is divided into three states for a positive and negative voltage vector phase shift: pre-fault, fault and post-fault.



Tests of the Interlock-Criterion

Figure 48: Test of Voltage Vector Phase Shift: Minimum Voltage Criterion

The functionality of the Interlock-Criterion is tested with the State Sequencer test module. The test is dived in a pre-fault, a Voltage-Fault, which activates the interlock, and a fault, whose settings fulfill the criteria of the protection functions. The absence of the trip signal is measured and assessed.

6.9.8 Synchronism Check

If the CB auxiliary contacts are needed to test the synchronism check, the CB Configuration test modules, which are already inserted in the template, can be used.

Test of the allowed voltage- and frequency-difference

Figure 49: Synchronism Check: Test of the allowed voltage- and frequency-difference



For the test of the allowed voltage- and frequency-difference, the Synchronizer test module is used. It checks whether the set differences for a successful synchronization are within their tolerances.

Test of the allowed angle-difference

To test the allowed angle-difference the State Sequencer test module is used. Within this test it is checked, whether the allowed angle-difference is within its tolerance. The states for a point outside of the allowed tolerance are named with Pre-Fault, No Close Command and Post-Fault. The states for a point inside of the allowed tolerance are named Pre-Fault, Close Command and Post-Fault.

Dead Line and Dead Busbar

To test the override of the synchronism check in case of a dead line and a dead busbar the State Sequencer test module is used. Within this test it is checked, whether the correct functionality is given and the voltage values of the dead detection of the line and busbar are set correctly. The states for a point outside of the allowed tolerance are named with Pre-Fault, No Close Command and Post-Fault. The states for a point inside of the allowed tolerance are named Pre-Fault, Close Command and Post-Fault.

Live Line and Dead Busbar

To test the override of the synchronism check in case of a live line and a dead busbar the State Sequencer test module is used. Within this test it is checked, whether the correct functionality is given and the voltage value of the live detection of the line is set correctly. The states for a point outside of the allowed tolerance are named with Pre-Fault, No Close Command and Post-Fault. The states for a point inside of the allowed tolerance are named Pre-Fault, Close Command and Post-Fault.

Dead Line and Live Busbar

To test the override of the synchronism check in case of a dead line and a live busbar the State Sequencer test module is used. Within this test it is checked, whether the correct functionality is given and the voltage value of the live detection of the busbar is set correctly. The states for a point outside of the allowed tolerance are named with Pre-Fault, No Close Command and Post-Fault. The states for a point inside of the allowed tolerance are named Pre-Fault, Close Command and Post-Fault.

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