Open DIGSI Software, then create a new project

o Type the project name

o Save the project at the required path

Then create the project file.

Type the Short Product Code or Long Product Code

The short product code could be found on the relay name plate also we can get from the relay face plate. If didn’t respond to the Short product code and an error message appears, please click on Update Short Product Code [TNS]

From the Relay:

Relay HMI >> Menu >> Test & diagnosis >> Device Information

Choose the application template along with the configuration version that matches the relay.

From the Relay:

Relay HMI >> Menu >> Test & diagnosis >> HW/SW Information >> Main Board >> Software inform.

Right-click on the device name then select one of the following

a. Load configuration to device

Send / Upload the file to the IED [Offline file had been configured and need to be uploaded]

b. Update configuration from target device

Read / Download the file from the IED [Retrieving final configuration file from the relay]

c. Initialize device

Connect Online to the IED then initialize the preconfigured file [Relay is new and first time for setup]

d. Import or Export the File

Import or export options allow the user to choose among different file extensions. The most popular and typical files used is the

o TEA-X or DEX5 both are used for exchanging the relay file between users

o RIO is used for particular applications i.e., Distance reach testing

In this section, we will illustrate the different submenus in the relay file we have created

1. Device Information

In the device information, we can get

o The device information

As the device name, MLFB and IEC61850 edition

o Function points

When you order a SIPROTEC 5 device, you are also ordering a function-points account for use of additional functions. The remaining white bar shows the function points that have not yet been used up by your configuration. The number of function points available in a device depends on the device purchase order (position 20 of the product code). You can also order function points subsequently, and so increase the function-points account for the device.

o Resource Consumption

The CFC chart capacitances in DIGSI calculated by the load model. The ticks available for each task are shown here. The green bars represent the ticks used in the task levels.

o Logs

Access to areas of the device with restricted access rights is recorded in the security log. Unsuccessful and unauthorized access attempts are also recorded. Up to 2048 indications can be stored in the security log.

2. Hardware and Protocols

In the properties of the communication module, you can find the setting sheets for the parameterization of the device-combination settings and the settings for

protection communication.

We can select each hardware communication channel then we are able to:

o IP Interface setting (IP address, Subnet mask and Gateway address)

o Choosing the communication protocol

IEC61850 for SAS/PSA or other communication protocol for SCADA.

o Setting the redundancy protocol

3. Measuring Points Routing

We can add different connections of the Current and Voltage measuring points based on the relay actual hardware configuration and CT/VT actual connections [both relay and instrument transformers shall be matched].

• Current Measuring points

• Voltage Measuring points

We can add a new measuring point single or three phases, then we can assign the channel for a certain phase. If you select the voltage type VN broken-delta for the 1-phase voltage measuring point in the measuring point routing (see the following figure), the device measures the residual voltage VN at the broken-delta winding. The residual voltage is converted into the voltage equivalent of the zero-sequence voltage

3. Function Group connections

The function group receives the required measured values via its interfaces with the measuring points. If you are using an application template, the function group is already connected to the necessary measuring points. If you add functions to the function group, they will automatically receive the measured values from the correct measuring points. If you add protection functions to the function group but the necessary measuring point is not connected, DIGSI 5 reports an inconsistency.

a. Measuring Points with Function Group

During the relay configuration, will be illustrated later, we can create either

o A dedicated function group [Capacitor Bank Protection, Transformer Protection, etc.].

o Generic Function Group that could include universal protection functions.

Example

The following figure shows an example of a capacitor in H-configuration and tuning section. In the single line, the primary current and voltage measurement are shown. The required device measuring points and their connections to the function group interfaces are shown as well. In addition, it is indicated which protection function receives its measuring value from which measuring point.

So, after assigning the measuring points (current and voltage), we shall assign the measuring points with the associated particular functions under the Function Group.

b. Function Group with Circuit Breaker

We shall assign the protection function groups with circuit breaker/s through the below menu.

All required data are exchanged between the protection function groups and Circuit breaker/s via the interface of the Circuit-breaker function group.

This connection generally determines:

• Which circuit breaker(s) is/are activated by the protection functions of the protection function group.

• Starting the Circuit-breaker failure protection function (if available in the Circuit-breaker function group) through the protection functions of the connected protection function group

• Starting the Automatic reclosing function (AREC, if available in the Circuit-breaker function group).

4. Information Routing

The Information Routing (Signal Matrix or Masking Input/Output as called in DIGSI-4) is the place where we can configure:

o Relay Binary Inputs with the Functions Virtual Inputs

o Functions Virtual Output with the Relay Hardware Binary Outputs

o Functions Virtual Output with the Relay LEDs

o Functions Inputs/Outputs with the Disturbance Fault Recorder (DFR)

o Functions Signals with the Continuous Function Chart (CFC)

o Any Signal with the Logs (Operational Log, Fault Log or User Defined Log)

Also, Function Keys could be configured through this menu to navigate to certain pages once clicked

Under the Device Settings, Some settings shall be default and others shall be set carefully,

A. Device Settings

Very Important Note:

Each Binary Input threshold voltage could be set individually through the Binary Input Properties window while selected in the Information Routing Menu as shown in the following figure.

Example of Trip Circuit Supervision through Relay Binary Inputs

B. General Settings

We shall identify the system phase rotation and Instrument Transformers relative settings

A. General

The Phase-sequence Switchover enables correct execution of the protection of the device and supervision functions, independently of the phase sequence of the phases in a system or system section. You can select between the phase sequences ABC or ACB. Binary inputs also provide the option of switching over the phase sequence with respect to the parameter setting.

For example, in pumped-storage hydropower plants with motor or motor/generator operation you temporarily change the direction of rotation by changing over the phase sequence.

The phase sequence has an effect on calculation of the positive-sequence and negative-sequence systems values and on calculation of phase-to-phase values. A phase-rotation reversal therefore has an effect on all protection and supervision functions that use these values. You can change the phase sequence in 2 ways via binary inputs.

o Change over the phase sequence for the entire device. In doing so, all 3-phase measuring points are switched over. All analog inputs are therefore affected (for example current and voltage inputs simultaneously).

o Change over the phase sequence per measuring point. In doing so, only the activated measuring points are switched over. The other measuring points remain unaffected.

The below logic illustrates how to activate the Phase sequences ABC or ACB either through the parameter settings or via relay binary inputs

The switchover of the phase sequence is only authorized for a time at which no measured values are pending. The switchover command must be present for at least 200 mSec. The change of phase sequence is only permissible when the machine is at standstill. If the current and voltage values of all 3-phase measuring points are below 5 % of the rated variables, this is recognized as machine standstill.

B. Current Measuring Point

The current Transformer settings shall be set as below

C. Voltage Measuring Point

The voltageTransformer settings shall be set as below

We start to add the protection functions that we want to apply on our Feeder. A group of protection functions is available and applicable based on the relay order number.

Choose the relay type, then drag and drop the required Function Group [FG]. Under the function group we have all the available functions related to the relay type. Drag and drop the applicable function for the feeder protection.

As shown in the below sample, the relay has some free built-in functions, and based on the user requirements additional functions could be added.

In the General section, we shall apply the following settings:

The Overcurrent protection, ground function (ANSI 50/51):

• Detects short circuits in electrical equipment

• Can be used as backup overcurrent protection in addition to the main protection

The Overcurrent protection, phase function is used in protection function groups. 2 kinds of functions are available for the 3-phase overcurrent protection:

• Overcurrent protection – advanced (50/51 OC-3ph-A)

• Overcurrent protection – basic (50/51 OC-3ph-B)

The function type Basic is provided for standard applications. The function type Advanced offers more functionality and is provided for more complex applications.

In the Overcurrent protection, phases – basic function type, the following stages can be operated simultaneously:

• Maximum of 4 stages Definite-time overcurrent protection – basic

• 1 stage Inverse-time overcurrent protection – basic

We will apply the Overcurrent settings for different characteristics, then configure the associated Virtual Inputs and Outputs.

1. Phase Overcurrent Settings

We will activate two stages for the phase overcurrent as shown below

o Definite Time Overcurrent

o Inverse Time Overcurrent

2. Phase Overcurrent Logic Diagram

The below is the logic diagram for the Overcurrent Protection

3. Phase Overcurrent Configuration

Outputs and LEDs shall be configured through the Information Routing. However, different options are available as shown below

1. Feeder Protection (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all protection functions listed under this Function Group.

2. OC Group Indication

The pickup and Trip virtual signals under this group is a group indication for all current protection functions listed under this Group.

3. 50/51 OC-3ph B1

The pickup and Trip virtual signals under this group is a group indication for all overcurrent protection stages listed under this Group.

4. Definit-T1 / Inverse-T1

The pickup and Trip virtual signals related to each single overcurrent protection level individually.

So, we will use the individual stages for assigning the Pickup and Trip Virtual Signals. This for only testing the relay. However, in the final setting configuration the Group Indication under the Function Group (Feeder Protection) could be used for the general tripping and the signals under each individual stage could be used for Trip Segregation Indication on the LEDs.

4. Phase Overcurrent Testing

• Testing of Definite-T1 Stage [Pickup and Drop Off]

Inject only one phase current. Increase only one phase current (e.g., Phase-A) gradually until the relay picks up then decrease same phase current until the relay drops off.

The indication of pickup shall be taken from LED configured with corresponding phase under test.

Repeat the test again for the other two phases

• Testing of Definite-T1 Stage [Trip Time]

Inject double the pickup value. The output contact configured with Definite-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after definite trip time 0.1 Sec.

Trip Time = 112mSec

• Testing of Inverse-T1 Stage [Pickup and Drop Off]

Inject only one phase current. Increase only one phase current (e.g., Phase-A) gradually until the relay picks up at a current which is approximately 1.1 x threshold value then decrease same phase current until the relay drops off.

The indication of pickup shall be taken from LED configured with corresponding phase under test.

• Testing of Definite-T1 Stage [Trip Time]

Inject double the pickup value. The output contact configured with Inverse-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after:

5. Phase Overcurrent Limits/Tolerences

The below are the tolerances for the Phase Overcurrent Protection related to our settings. Refer to the manual of the relay we can get all the details for other settings.

• Currents, method of measurement = fundamental component

1 % of the setting value or 5 mA (I_rated = 1 A) or 25 mA (I_rated = 5 A)

• Dropout

The dropout ratio is 95%

• Pickup delay

For Definite Time Stage

1 % of the setting value or 10 mSec

For Inverse Time stage

5 % of the reference (calculated) value +2 % current tolerance or 30 mSec

The Overcurrent protection, ground function (ANSI 50N/51N):

• Detects short circuits in electrical equipment

• Can be used as backup overcurrent protection in addition to the main protection

The Overcurrent protection, ground function is used in protection function groups. 2 kinds of functions are available for the 3-phase overcurrent protection:

• Overcurrent protection, ground – advanced (50N/51N OC-gnd-A)

• Overcurrent protection, ground – basic (50N/51N OC-gnd-B)

The function type Basic is provided for standard applications. The function type Advanced offers more functionality and is provided for more complex applications.

In the Overcurrent protection, ground – basic function type, the following stages can be operated simultaneously:

• Maximum of 3 stages Definite-time overcurrent protection – basic

• 1 stage Inverse-time overcurrent protection – basic

We will apply the Ground Overcurrent settings for different characteristics, then configure the associated Virtual Inputs and Outputs.

1. Ground Overcurrent Settings

We will activate two stages for the phase overcurrent as shown below

o Definite Time Ground Overcurrent

o Inverse Time Ground Overcurrent

2. Ground Overcurrent Logic Diagram

The below is the logic diagram for the Ground Overcurrent Protection

3. Ground Overcurrent Configuration

Outputs and LEDs shall be configured through the Information Routing. However, different options are available as shown below

1. Feeder Protection (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all protection functions listed under this Function Group.

2. OC Group Indication

The pickup and Trip virtual signals under this group is a group indication for all current protection functions listed under this Group.

3. 50N/51N OC-ground B1

The pickup and Trip virtual signals under this group is a group indication for all ground overcurrent protection stages listed under this Group.

4. Definit-T1 / Inverse-T1

The pickup and Trip virtual signals related to each single ground overcurrent protection level individually.

So, we will use the individual stages for assigning the Pickup and Trip Virtual Signals. This for only testing the relay. However, in the final setting configuration the Group Indication under the Function Group (Feeder Protection) could be used for the general tripping and the signals under each individual stage could be used for Trip Segregation Indication on the LEDs

4. Ground Overcurrent Testing

• Testing of Definite-T1 Stage [Pickup and Drop Off]

Inject only one phase current. Increase only one phase current (e.g., Phase-A) gradually until the relay picks up then decrease same phase current until the relay drops off.

The indication of pickup shall be taken from LED configured with corresponding phase under test.

• Testing of Definite-T1 Stage [Trip Time]

Inject double the pickup value. The output contact configured with Definite-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after definite trip time 0.1 Sec.

Trip Time = 160 mSec

Also, we can inject a 3 phase balanced currents, while increasing only one phase (any phase) until 3Io = 0.6A

• Testing of Inverse-T1 Stage [Pickup and Drop Off]

Inject only one phase current. Increase only one phase current (e.g., Phase-A) gradually until the relay picks up at a current which is approximately 1.1 x threshold value then decrease same phase current until the relay drops off.

The indication of pickup shall be taken from LED configured with corresponding phase under test.

• Testing of Definite-T1 Stage [Trip Time]

Inject double the pickup value. The output contact configured with Inverse-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after:

5. Ground Overcurrent Limits/Tolerences

The below are the tolerances for the Ground Overcurrent Protection related to our settings. Refer to the manual of the relay we can get all the details for other settings.

• Currents, method of measurement = fundamental component

1 % of the setting value or 5 mA (I_rated = 1 A) or 25 mA (I_rated = 5 A)

• Dropout

The dropout ratio is 95%

• Pickup delay

For Definite Time Stage

1 % of the setting value or 10 mSec

For Inverse Time stage

5 % of the reference (calculated) value +2 % current tolerance or 30 mSec

The function Undervoltage protection with 3-phase voltage (ANSI 27):

• Monitors the permissible voltage range

• Protects equipment (for example, plant components and machines) against damages caused by undervoltage

• Handles disconnection or load shedding tasks in a system

1. Undervoltage Settings

We will activate only one definite time stage; however, more stages are required based on the application as:

o One Alarm Stage and One Protection Stage

o Three stages for Load Shedding

o ACCS control logic

Very Important Note:

Current-flow criterion

Depending on the system, the voltage transformers are arranged on either the supply side or the junction side. These 2 possible voltage transformer locations induce a different behavior of the function after tripping and opening of the circuit breaker:

• If they are located on the supply side, the voltage still exists.

• If they are located on the junction side, the voltage does not exist

The Threshold I> parameter makes it possible to detect when the circuit breaker is closed. Siemens recommends setting the Threshold I> parameter to 5% of the rated current. With a secondary rated transformer current of 1 A, the secondary setting value for Threshold I> would be 0.05 A.

If the sensitivity of the Threshold I> parameter is set too high, compensation processes in the secondary circuit of the current transformer extend the dropout time when breaking extremely high currents. To speed up dropout, increase the default setting.

The Pickup delay parameter is only available if you are using the current-flow criterion of the function (parameter Current-flow criterion = on). If the current-flow criterion is deactivated, no pickup delay is required.

With the Pickup delay parameter, you set whether pickup of the stage is to be delayed by approximately 40 mSec or not. The delay avoids possible brief pickup of the stage when the circuit breaker opens. When applied in parallel, the pickup delay and the delay through pickup stabilization add up.

2. Undervoltage Logic Diagram

The below is the logic diagram for the Undervoltage Protection

3. Undervoltage Configuration

Outputs and LEDs shall be configured through the Information Routing. However, different options are available as shown below

1. Feeder Protection (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all protection functions listed under this Function Group.

2. 27 Undervolt-3ph 1 (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all undervoltage protection stages listed under this Group.

3. Definit-T1

The pickup and Trip virtual signals related to each single undervoltage protection level individually.

So, we will use the individual stages for assigning the Pickup and Trip Virtual Signals. This for only testing the relay. However, in the final setting configuration the Group Indication under the Function Group (Feeder Protection) could be used for the general tripping and the signals under each individual stage could be used for Trip Segregation Indication on the LEDs.

4. Undervoltage Testing

• Testing of Definite-T1 Stage [Pickup and Drop Off]

Inject three phase balanced and healthy phases voltages, decrease only one/two phase voltages gradually until the relay picks up at 108V (ph to ph), then increase same phase voltage until the relay drops off at value equal to (pickup value * Reset Ratio) = 108*1.05 =113.4 Volt (ph to ph)

The indication of pickup shall be taken from LED configured with corresponding phase under test.

Monitoring of the phase-to-phase voltage could be through the relay secondary measurement page of using multimeter connected to the injection test probs.

• Testing of Definite-T1 Stage [Trip Time]

Inject a value less than the pickup value for example 100V. The output contact configured with Definite-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after definite trip time 5 Sec.

Trip Time = 5.017 Sec

5. Undervoltage Limits/Tolerences

The below are the tolerances for the Phase Undervoltage Protection related to our settings. Refer to the manual of the relay we can get all the details for other settings.

• Voltages measurement

0.5 % of the setting value or 0.05 V

• Current measurement

1 % of the setting value or 5 mA (I_rated = 1 A) or 25 mA (I_rated = 5 A), valid for protection-class CT.

• Pickup delay

For Definite Time Stage

1 % of the setting value or 10 mSec

For Inverse Time stage

5 % of the reference (calculated) value or 30 mSec >> Operate time for 0 < V/V_Thresh < 0.9

The function Overvoltage protection with 3-phase voltage (ANSI 59):

• Monitor the permissible voltage range

• Protect equipment (for example, plant components, machines, etc.) against damages caused by overvoltage

• Decouple systems (for example, wind power supply)

Abnormally high voltages in power systems are caused by voltage controller failure at the transformer or on long transmission lines under low-load conditions. When using common-mode reactors in the protected power system, the device must shut down the line quickly if the reactors fail (for example, due to fault clearance). The insulation is endangered by the overvoltage condition.

Overvoltages at capacitor banks can be caused by resonances with line or transformer inductances. In power plants increased voltage levels can be due to one of these factors:

• Incorrect operation when controlling the excitation system manually

• Failure of the automatic voltage controller

• After full load shedding of a generator

• Generators which are disconnected from the network or in island mode

1. Overvoltage Settings

We will activate only one definite time stage; however, more stages are required based on the application as:

o One Alarm Stage and One Protection Stage

o ACCS control

2. Overvoltage Logic Diagram

The below is the logic diagram for the Overvoltage Protection

3. Overvoltage Configuration

Outputs and LEDs shall be configured through the Information Routing. However, different options are available as shown below

1. Feeder Protection (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all protection functions listed under this Function Group.

2. 59 Undervolt-3ph 1 (Group Indication)

The pickup and Trip virtual signals under this group is a group indication for all overvoltage protection stages listed under this Group.

3. Definit-T1

The pickup and Trip virtual signals related to each single overvoltage protection level individually.

So, we will use the individual stages for assigning the Pickup and Trip Virtual Signals. This for only testing the relay. However, in the final setting configuration the Group Indication under the Function Group (Feeder Protection) could be used for the general tripping and the signals under each individual stage could be used for Trip Segregation Indication on the LEDs.

4. Overvoltage Testing

• Testing of Definite-T1 Stage [Pickup and Drop Off]

Inject three phase balanced and healthy phases voltages, increase only one/two phase voltages gradually until the relay picks up at 132V (ph to ph), then increase same phase voltage until the relay drops off at value equal to (pickup value * Reset Ratio) = 132*0.95 =125.4 Volt (ph to ph)

The indication of pickup shall be taken from LED configured with corresponding phase under test.

Monitoring of the phase-to-phase voltage could be through the relay secondary measurement page of using multimeter connected to the injection test probs.

• Testing of Definite-T1 Stage [Trip Time]

Inject a value more than the pickup value for example 140 V. The output contact configured with Definite-T1 Stage shall Operate and feedback indication shall be recognized by the test kit after definite trip time 3 Sec.

Trip Time = 3.015 Sec

5. Overvoltage Limits/Tolerences

The below are the tolerances for the Phase Undervoltage Protection related to our settings. Refer to the manual of the relay we can get all the details for other settings.

• Voltages measurement

0.5 % of the setting value or 0.05 V

• Pickup delay

For Definite Time Stage

1 % of the setting value or 10 mSec

For Inverse Time stage

5 % of the reference (calculated) value or 30 mSec >> Operate time for 1.2 ≤ V/V_Thresh ≤ 20

The Circuit-breaker failure protection function (ANSI 50BF) monitors the tripping of the associated circuit breaker (CB) and generates a backup trip signal if the circuit-breaker fails.

1. Circuit Breaker Failure Settings

We will activate only Backup/2^nd Stage; however, Retrip/1^st Stage may be required based on the application

2. Circuit Breaker Failure Logic Diagram

The below is the logic diagram for the CBF Protection

3. Circuit Breaker Failure Configuration

Deactivate the Internal Initiation. Uncheck the CBF initiation from the Circuit Breaker interaction

Inputs, Outputs and LEDs Configuration

4. Circuit Breaker Failure Testing

Testing of T2 (Backup Trip time) under CB healthy Condition

We will test the Tripping time T2 with the two criterions, the current flow criterion and CB auxiliary contact.

o Current Flow Criterion

Inject external binary input from the test kit to Start the CBF along with either (please check the logic diagram)

• Two phases (A&B or B&C or C&A) with current higher than the Threshold phase current setting

• One phase current (A or B or C) higher than Threshold phase current setting along with 3Io or I₂ values higher than Threshold Sensitive setting.

o CB Auxiliary contact

Inject external binary inputs from the test kit to Start the CBF simultaneously with a CB close status.

The indication of pickup shall be taken from LED configured with CBF Trip.

Testing of T2 (Backup Trip time) under CB healthy Condition

Inject external binary inputs from the test kit to Start the CBF simultaneously with CB Defective and use either the Current flow criterion or the CB status criterion.

Trip Time = 25 mSec

IEDs have a fault memory in which fault recordings are kept securely. Fault recording documents operations within the power system and the way in which protection devices respond to them. You can read out fault recordings from the device and analyze them afterwards using evaluation tools such as SIGRA. A fault record contains the following information:

o Sample values of the analog input channels

o Measured values calculated internally

o Any binary signals (for example, pickup signals and trip signals of protection functions)

Very Important Notes

• The fault memory of the device is automatically updated with every recording. When the fault memory is filled completely, the oldest recordings are overwritten automatically. Thus, the most recent recordings are always stored safely. The maximum number of recordings is 128

• The Fault recorder function records the sampled values, specific to each device, of all analog inputs, the internally calculated measured values, and the binary signals. The configuration, which is predefined for each device via an application template, can be adapted individually.

1. DFR Settings

You can individually configure the signals to be recorded. Furthermore, you can define the starting condition, the record duration, and the saving criterion of a recording. Fault records saved in the device are also available after a loss of auxiliary voltage.

2. DFR Memory

The device manages its available fault memory dynamically, so that the maximum recording capacity is always available. When exceeding the limits of the fault memory, the oldest recordings are automatically overwritten. This means that the most recent recordings are always available. The sampling rate, type, and number of measured value trends to be recorded are the crucial variables when it comes to restricting the length and number of recordings possible. Parallel to the sampled tracks, up to 50 tracks with function-specific measured values and up to 200 binary tracks can be recorded. The following table provides an overview of the maximum storage capacities, in seconds, for different connection variations of the protection devices.

3. DFR Configuration

Through the Information Routing, we can configure all required signal to be recorded once the DFR initiated as:

• All pick up signals from the protection functions

• All Tripping signals from the protection functions

• All Binary Inputs as (CBF Start, CB defect, CB status Close and Open, Alarm Signals, etc.)

After that, you can revise all the signals that you have configured as shown below

4. Checking the Records and Exporting COMTRADE Files

The Continuous Function Chart (CFC) is a programming language. It is used for programmable logic controllers. CFC is a graphic programming language. Function blocks are linked to one another.

The graphic user interface is used to connect items of information and program, for example, interlocks and switching sequences. In addition, you can edit measured values and generate messages.

• Information

Types of information often used are:

o The position of the switching devices and other process elements.

o Measured values.

o Binary information on the state of the bay and the devices.

o Protective information.

o General messages.

o Interrupts.

• Interconnecting items of information

Items of information are interconnected in DIGSI CFC by means of the supplied CFC blocks:

o Arithmetic.

o Basic logic.

o Information status.

o Memory.

o Control commands.

o Type converters,

o Comparison.

o Metered value.

o Time & Clock.

A CFC chart, and thus the configured CFC function, runs in the SIPROTEC 5 device on exactly one of the 4 task levels. The individual task levels differ on the one hand, in the priority of processing tasks and, on the other, in the cyclic or event-triggered processing of the CFC charts.

You can select between the following task levels:

a. High priority Event triggered

Use the High priority Event-triggered task level for time-critical tasks, for example, if a signal should block a protection function within 2 mSec to 3 mSec. Functions on this task level are processed in an event-triggered way with the highest priority. Each change to a logical input signal is immediately processed. Processing can interrupt the execution of protection functions and functions on the Event-Triggered task level.

b. Event triggered

Use the Event-triggered task level preferably for logic functions that need not be executed with highest priority. Each change to a logical input signal is immediately processed. Protection functions or functions on the

High priority Event-triggered task level can disrupt processing. Functions on the Event-triggered task level are typically processed within a maximum of 5 mSec in all devices. For busbar protection or line protection, the functions on the Event-triggered task level are processed within a maximum of 10 mSec.

c. Low priority Cyclic triggered

Use the Low priority Cyclic-triggered task level for processing measured values. Functions on this task level are processed cyclically every 500 mSec.

d. Low priority Event triggered

Use the Low priority Event-triggered task level preferably for logic functions that should be executed with lower priority than functions in the Event-triggered task level. If the available ticks of the Event-triggered task level shown in the following figure are sufficient for the required CFC functionality, you do not need to use the Low priority Event-triggered task level.

A. CFC Example

When programming functions with DIGSI CFC, you must observe a set of guidelines in order to avoid problems

with program processing.

Work through the following eight steps consecutively when programming functions with DIGSI CFC:

o Configure generic signals if required in the Information routing

o Insert a CFC chart

o Specify the Task Level

o Draw the chart

o Check the run sequence

o Compile the chart

1. Configure generic signals if required in the Information routing

From the Library, drag and drop a user defined function group and rename it to Generic Logic for example.

Right click and add new signal >> choose the required signal type (for example SPS)

Rename the signal as (Phase_A General Trip) and configure it to the required destination as (Binary Output, LED, Fault Recorder or Logs)

2. Insert CFC Chart

3. Specify the Task Level

4. Draw the CFC Chart

o Drag and drop the required logic among all possible logic gates available in the library for different purposes.

o Drag and Drop the signals to the gate terminals

o From the properties for logic gates you can configure the number of Inputs.

5. Optimize Run Sequence

6. Compile

Very Important Notes:

o While pressing one click on the logic gate, properties window would be opened and then we can define number of inputs to the OR gate. (other settings would be available based on the Logic Gate type)

o You can also review your logic gate run sequence by pressing on the below symbol to unhide the Run Sequences

o Online Monitoring for Function chart.

The Online Mode of the Siprotec-5 Relays offers practical facilities that help during the commissioning stage. While the PC is connected to the Relay via USB, the user opens the Online access then click on Update accessible devices.

Now we can access different pages as:

• Browser

• Logs

• Records

• Measurements

• Test Suits

Open Browser

o Change the settings of the relay

o Retrieve the Disturbance Fault Recorder

o Read the measurements

o Check the different Logs

o Monitor inputs, outputs, and LEDs statuses

Testing of Binary Inputs, Binary Outputs and LEDs

• Inject DC voltage on the BI and monitor its status.

• Force Closing the Binary Outputs and measure its resistance

• Force illuminates the LEDs and check it physically

This will be allowed only if the relay in Test mode, you can press on Activate Commissioning Mode. To abort the test mode, press again Activate Process Mode.

Check the Relay Measurement Quantities

Online Monitoring for the Different Protection Functions