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Commissioning of protection relays using test equipment and software

Commissioning and maintenance

With numerical protection relays commissioning and maintenance has become far less complicated as a result of the information provided by the devices as well as the integrated self-monitoring.

Commissioning of protection relays using test equipment and software
Commissioning of protection relays using test equipment and software (photo credit: directindustry.com)
The information provided here is restricted to general notes regarding the procedures. Specific instructions for the individual devices are provided in the device manuals.

Commissioning of protection relays

Pre-testing of the instrument transformers and their connections must be carried out in the same manner as with conventional protection. The measuring functions of the protection devices may already be utilised for this purpose.

The binary device outputs can be activated individually by means of the Siemens software DIGSI. This largely simplifies the pre-testing of the signalling and tripping circuits, as the internal protection functions do not have to be activated for this purpose. The testing of serial interfaces which are new to the numerical devices can also be carried out in this manner.

Protection relay test equipment
Protection relay test equipment (photo credit: megger.com)

Settings are usually applied with the setting program in the office of the protection department, off-line (without protection device) and saved onto a mass storage. In the substation the settings must then only be transferred by PC (Laptop) from the mass storage to the protection device.

Current injection testing
Current injection testing (photo credit: petoservices.com)

To test the protection function with injected signals (current and voltage) PC controlled electronic test equipment is available nowadays which provides almost fully automated test sequences. A three-phase test equipment is recommended as the modern devices monitor symmetry of the three-phase system which may pick up when single-phase tests are carried out.

Primary injection testing is only seldom applied due to cost constraints. With the feeder differential protection, testing is somewhat more complicated as the currents must be injected at geographically separated locations.

In the past, single ended injection was therefore applied for pre-testing by phase synchronous connection of the secondary injection equipment to voltage transformers of an unused feeder in both substations. The test sequence was then simultaneously initiated at both ends when the feeder was energised.

With the electronic test equipment this difficulty no longer exists as the test equipment at both line ends can be synchronised via GPS signals.

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Commissioning with load currents

The final test, whenever possible, is done with load current or a deliberately created short circuit current. The integrated overcurrent protection in the differential protection and the separate back-up protection, if available, are set to trip without delay for this test, so that the feeder is immediately cleared if a short-circuit is present.

For the commissioning of generating units, a so-called short-circuit cycle is carried out.

For this purpose, the generator is started with a deliberate short-circuit while the system CB is open. The excitation of the generator is then increased. The generator current increases but may not exceed nominal current. In this way stability and tripping of the differential protection can be checked as close to reality as possible.

A similar test with short circuit cycle could also be done on a transformer feeder and busbar protection, if a system connection to an available generator can be established.

Generally, testing can however only be done with load current. To get a definite indication of the current values and therefore the connection and polarity of the CT circuits, a test current of at least 10% of the nominal device current should be obtained by means of appropriate system switching.

To measure the feeder currents as well as the operating/restraint currents, a large number of measuring instruments had to be connected with conventional protection (12 for a transformer differential protection).

With the numerical protection the measured values are indicated by the device itself and provided in a summary on the PC monitor via the applied software. Wiring errors (e.g. swapped phase connections) are thereby very quickly identified.

When load current is flowing through the system, the operating current (tripping current) should apart from charging currents, be negligibly small and the restraint current should correspond to the sum total of all feeder currents. By reversing the polarity of one current measuring input by means of the corresponding setting parameter, an internal fault can be simulated. Restraint and operating current should in this case have approximately the same magnitude.

An oscillographic record can also be initiated via DIGSI and can then be viewed using SIGRA to calculate the phasors of the current for graphic representation.

In this manner, an error in the current comparison can immediately be detected.
SIPROTEC 4 devices provide for a web monitor (web browser). Thereby the phasor diagrams can be called up and visualised online using a common internet browser tool. See Figure 1 below.

Feeder differential protection 7SD52: Representation of the current phasors on a PC with the web monitor (web browser)
Figure 1 – Feeder differential protection 7SD52: Representation of the current phasors on a PC with the web monitor (web browser)

The new SIPROTEC 5 line relays 7SD8 and 7SL8 now allow also DIGSI to communicate not only with the local relay but also with the relay at the remote line end(s) through the communication link of the differential protection.

Following the function tests, the final settings should be applied and tripping of the CB must be tested by simulation of an internal fault. The final settings of the protection for documentation and archiving are extracted locally or from remote via PC.

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DIGSI 5 Tutorial

DIGSI 5 is the SIEMENS engineering tool for parameterization, commissioning and operating all SIPROTEC 5 protection relays. The full capabilities of DIGSI 5 are revealed when you connect it to a network of protection devices. Then you can work with all of the devices in a substation in one project.

Part 1 of 9: The task of this tutorial


Part 2 of 9: Operating DIGSI 5


Part 3 of 9: Configuring the Single line


Part 4 of 9: Inserting a device


Part 5 of 9: Adapting the application


Part 6 of 9: Setting the parameters


Part 7 of 9: Configuraing communication


Part 8 of 9: Creating CFC Functions


Part 9 of 9: Creating display pages

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Maintenance of protection relays

The self-monitoring contained in the numerical devices covers 80-90% of the protection equipment. CT circuits are included as long as load current is flowing and the signal communication is also continuously monitored to detect errors. The numerical protection therefore only has to be maintained with fairly long maintenance cycles.

Originally the German Utility Board recommended 4 year intervals for the maintenance cycle on the complete protection equipment.

At present intervals of between 5 and 6 years are however common and the tendency is towards even larger time intervals. In the periods between the tests plausibility checks with the indicated load values and the stored fault record data are however recommended.

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Reference // Numerical Differential Protection by Gerhard Ziegler (Purchase hardcover from Amazon)

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About Author //

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Edvard Csanyi

Edvard - Electrical engineer, programmer and founder of EEP. Highly specialized for design of LV/MV switchgears and LV high power busbar trunking (<6300A) in power substations, commercial buildings and industry fascilities. Professional in AutoCAD programming. Present on

2 Comments


  1. Debaranjan
    Jan 30, 2017

    A brush less excitation system with stationay field winding and rotating 3phase armature. Rotating diode are used for rectification.

    My doubts are
    1. Like a Synchronous generator, Exciter is also a three phase generator whose output is rectified. Does an Exciter armature winding produces rotating magnetic field like Synchronous generator ?

    2. How Rotating diode failure condition is detected in Brushless Excitation system ?


    • Vladimir
      Mar 16, 2017

      Off top, imho, sorry.
      1. You are quite right, Exciter is a same of Synchronous generator. Only with “inverted” function of rotor and stator. So exciter armature winding produces rotating magnetic field like Synchronous generator. Usually it is tree-phase winding.
      2. When Rotating diode failure condition appears, the pulsation of field current of an exciter changes. Both in case of short-circuit or open diode.

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