Ormazabal ekor.rpa, ekor.rpa-110, ekor.rpa-110-v, ekor.rpa-120, ekor.rpa-110-p General Instructions Manual

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ekor.rpa

Protection, metering and control multifunction unit

General Instructions

IG-267-EN, version 01, 07/04/2017

LIB

CAUTION!

When medium-voltage equipment is operating, certain components are live, other parts may be in movement and some may reach high temperatures. Therefore, the use of this equipment poses electrical, mechanical and thermal risks.

In order to ensure an acceptable level of protection for people and property, and in compliance with applicable environmental recommendations, Ormazabal designs and manufactures its products according to the principle of integrated safety, based on the following criteria:

• Elimination of hazards wherever possible.

• Where elimination of hazards is neither technically nor economically feasible, appropriate protection functions are incorporated in the equipment.

• Communication about remaining risks to facilitate the design of operating procedures which prevent such risks, training for the personnel in charge of the equipment, and the use of suitable personal protective equipment.

• Use of recyclable materials and establishment of procedures for the disposal of equipment and components so that once the end of their service lives is reached, they are duly processed in accordance, as far as possible, with the environmental restrictions established by the competent authorities.

Consequently, the equipment to which the present manual refers complies with the requirements of section 11.2 of Standard IEC 62271-1. It must therefore only be operated by appropriately qualified and supervised personnel, in accordance with the requirements of standard EN 50110-1 on the safety of electrical installations and standard EN 50110-2 on activities in or near electrical installations. Personnel must be fully familiar with the instructions and warnings contained in this manual and in other recommendations of a more general nature which are applicable to the situation according to current legislation

The above must be carefully observed, as the correct and safe operation of this equipment depends not only on its design but also on general circumstances which are in general beyond the control and responsibility of the manufacturer. More specifically:

• The equipment must be handled and transported appropriately from the factory to the place of installation.

• All intermediate storage should occur in conditions which do not alter or damage the characteristics of the equipment or its essential components.

• Service conditions must be compatible with the equipment rating.

• The equipment must be operated strictly in accordance with the instructions given in the manual, and the applicable operating and safety principles must be clearly understood.

• Maintenance should be performed properly, taking into account the actual service and environmental conditions in the place of installation.

The manufacturer declines all liability for any significant indirect damages resulting from violation of the guarantee, under any jurisdiction, including loss of income, stoppages and costs resulting from repair or replacement of parts.

[1]

Warranty

The manufacturer guarantees this product against any defect in materials and operation during the contractual period. In the event that defects are detected, the manufacturer may opt either to repair or replace the equipment. Improper handling of this equipment and its repair by the user shall constitute a violation of the guarantee.

Registered Trademarks and Copyrights

All registered trademarks cited in this document are the property of their respective owners. The intellectual property of this manual belongs to Ormazabal.

[1]

For example, in Spain the “Regulation on technical conditions and guarantees for safety in high-voltage electrical installations” – Royal Decree 337/2014 is obligatory.

In view of the constant evolution in standards and design, the characteristics of the elements contained in this manual are subject to change without prior notice. These characteristics, as well as the availability of components, are subject to confirmation by Ormazabal.

General Instructions ekor.rpa

Contents

1. General description ..................................................5

1.1. General operating features ...................6

1.2. Components.................................7

1.2.1. Electronic relay ..............................8

1.2.2. Current sensors ..............................9

1.2.3. Voltage sensors ..............................9

1.2.4. “Binox” bistable tripping device and

tripping coil ................................10

1.3. Functionality of the unit.....................10

1.4. Communications............................11

2. Applications .............................................................12

2.1. Remote control of transformer and

distribution substations .....................12

2.2. Automatic reclosing of lines .................12

2.3. Line protection with circuit-breaker..........13

2.4. Transformer protection......................14

2.5. Automatic transfer . . . . . . . . . . . . . . . . . . . . . . . . . .16

2.6. Detection of phase with earthing............16

2.7. Protection and control of

MV interconnection stations.................17

2.8. Energy balances ............................17

3. Metering functions ..................................................18

3.1. Current and voltage metering ...............18

3.2. Power meterings............................19

3.3. Energy meter ...............................19

4. Protection functions ................................................20

4.1. Overcurrent units ...........................20

4.1.1. Timed overcurrent units.....................20

4.1.2. Instantaneous overcurrent units.............21

4.1.3. Block diagram ..............................21

4.2. Ultra-sensitive earth.........................22

4.3. Directional units ............................23

4.3.1. Phase directional units ......................23

4.3.2. Neutral and sensitive neutral

directional units ............................24

4.4. Thermal image unit .........................25

4.4.1. Estimated thermal capacity..................26

4.4.2. Functionality................................27

4.4.3. Block diagram ..............................28

4.5. Broken conductor unit ......................29

4.5.1. Calculation of sequence currents ............29

4.5.2. Functionality................................32

4.5.3. Block diagram ..............................32

4.6. Voltage units ...............................33

4.6.1. Timed overvoltage units ....................34

4.6.2. Instantaneous overvoltage units.............34

4.6.3. Timed undervoltage units...................35

4.6.4. Instantaneous undervoltage units ...........35

4.6.5. Block diagram ..............................36

4.7. Second harmonic blocking unit .............37

4.7.1. Functionality................................37

4.7.2. Block diagram ..............................39

4.8. Block by I

5. Detection, automation and control functions .......42

5.1. Recloser automation ........................42

5.1.1. Functionality................................42

5.1.2. VREF........................................42

5.1.3. Settings ....................................43

5.1.4. Recloser statuses............................43

5.2. Voltage presence/absence automation ......45

5.2.1. Functionality................................45

5.2.2. Settings ....................................45

5.2.3. Voltage presence/absence

automation statuses ........................45

5.3. Switch control ..............................46

5.3.1. Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .46

5.3.2. Settings ....................................46

5.3.3. Switch control statuses......................47

5.4. Remote control .............................47

6. Sensors ......................................................................48

6.1. Current sensors .............................48

6.1.1. Functional characteristics

of current sensors...........................49

6.1.2. Vector sum/zero-sequence wiring ...........50

6.2. Voltage sensors .............................51

6.2.1. Bushing ....................................51

6.2.2. ekor.evt-c ..................................52

7. Technical characteristics of the equipment ...........53

7.1. Rated values ................................53

7.2. Mechanical design ..........................53

7.3. Insulation tests..............................54

7.4. Electromagnetic compatibility...............54

7.5. Climatic tests ...............................55

7.6. Mechanical tests ............................55

7.7. Power tests .................................55

7.8. CE Conformity ..............................55

.................................41

max

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8. Protection, metering and control models .............56

8.1. Description of models vs functions ..........56

8.1.1. ekor.rpa-110................................58

8.1.2. ekor.rpa-120................................58

8.1.3. ekor.rpa-100-v/ekor.rpa-100-p..............59

8.1.4. Relay configurator ..........................60

8.2. “v” ekor.rpa-110-v and ekor.rpa-120-v

type units...................................61

8.2.1. Functional description ......................61

8.2.2. Definition of digital inputs/outputs .........62

8.2.3. Installation in a cubicle......................63

8.2.4. Checking and maintenance .................64

8.3. “p” ekor.rpa-110-p and ekor.rpa-120-p

type units ..................................66

8.3.1. Functional description ......................66

8.3.2. Definition of digital inputs/outputs ..........67

8.3.3. Fuse protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . .68

8.3.4. Installation in a cubicle......................71

8.3.5. Checking and maintenance .................72

9. User configuration settings .....................................73

9.1. Local protection and automation settings ...73

9.2. Date and time settings ......................79

9.3. Remote communication settings ............79

11. User interface ...........................................................85

11.1. Web server. Checking and

configuring parameters .....................85

11.1.1. Characteristics of the Web server ............85

11.1.2. Access to the Web server: Local and

remote access ..............................86

11.2. Keyboard/Display ..........................90

11.2.1. Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .90

11.2.2. Display screen ..............................91

11.2.3. Error codes .................................96

11.3. Fileserver in USB memory ...................97

11.3.1. Connection to the system ...................97

11.3.2. Use of the interface .........................98

11.3.3. ekor.soft-xml ............................. 100

12. Communications ................................................... 102

12.1. Physical medium: RS-485.................. 102

12.1.1. MODBUS protocol ........................102

12.1.2. PROCOME protocol .......................107

12.2. Physical medium: Ethernet ................110

12.3. Physical medium: Mini-USB................111

13. Annex ..................................................................... 112

10. Log record .................................................................80

10.1. Fault report ................................80

10.1.1. Data capture logic ..........................80

10.1.2. Structure of the report ......................81

10.1.3. List of available signals .....................82

10.2. Event record ................................84

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General Instructions ekor.rpa

1. General description

General description

Within the ekor.sys family, the ekor.rpa range of protection, metering and control units groups together a series of multifunctional devices. Depending on the model, the equipment can incorporate voltage and current functions, along with automation functions, local/remote control, etc. All these functions are related to current and future automation, control and protection requirements in switching and transformer substations.

As a result of new demands in supply quality, there is an increasing need for automation in distribution networks and for equipment to carry out metering and control supervision functions for the switch in distribution cubicles.

The ekor.rpa-100 protection, metering and control units have been designed to meet these needs, in accordance with national and international standard requirements and recommendations that are applied to each part that makes up the unit:

• EN 60255, EN 61000, EN 62271-200, EN 60068, EN 60044.

• IEC 60255, IEC 61000, IEC 62271-200, IEC 60068, IEC 60044, IEC 61958.

Integrating the ekor.rpa units in the Ormazabal cubicle system allows speciﬁc products for requirements in diﬀerent facilities.

2. Delivering the complete integrated solution (cubicle + relay + sensors) reduces handling of interconnections when installing the cubicle in the network connection. The only connection necessary is the medium-voltage cables (MV). The possibility of wiring and installation errors is removed, thus minimising commissioning time.

3. Voltage and current sensors are installed in the cubicle cable bushing. Metering of V, I, P, Q and energies are obtained without the need for voltage transformers.

4. All the units are factory installed, adjusted and checked; each piece of equipment (relay + control + sensors) also undergoes a comprehensive check before being installed. The ﬁnal unit tests are carried out once the unit is incorporated in the cubicle before delivery.

5. Current metering is carried out by current sensors with a high transformation ratio, making it possible for the same equipment to detect a wide range of power levels. This is possible thanks to the high sensitivity and low noise of the relay's analogue channels.

The ekor.rpa-100 units in the ekor.rpa range have outputs to, either locally or remotely, open and close the switch in the cubicle where it is installed. Furthermore, the equipment series has inputs which receive the status of the cubicle switch.

The ekor.rpa-100 units also have the following beneﬁts compared to conventional systems:

1. The remote control unit (RTU or Remote Terminal Unit) and protection are integrated in the cubicle in a compact manner, simplifying the solution and minimising the need to install control boxes on the cubicles.

Figure 1.1. Protection, metering and control units: ekor.sys family

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General description General Instructions

ekor.rpa

1.1. General operating features

All the relays of the ekor.rpa-100 series include a microprocessor for processing the metering sensor signals. They process voltage and current meterings and eliminate the inﬂuence of transient states, calculate the magnitudes required to ensure current and voltage protection functions, automation, etc. At the same time they calculate the eﬃcient values of the electrical meterings that report the instantaneous value of these parameters of the installation.

Figure 1.2. ekor.rpa-100 series relay

The ekor.rpa-100 relays are equipped with a keypad for local display, set-up and operation of the unit, as well as communication ports to handle these functions from a PC, either locally or remotely. The ergonomic keyboard menus have been designed to make use as intuitive as possible.

Current metering is carried out via high transformation ratio current sensors. These transformers or current sensors maintain the accuracy class in all of their rated range.

Voltage metering is normally by capturing the voltage signal using a capacitor divider built into the cubicle's bushing. There is an option of installing ekor.evt-c external capacitive voltage sensors for applications which require high-voltage metering precision, such as applications with MV network energy meters.

The diﬀerent interfaces, local (display) or remote (Web), also provide settings parameters, logs, events, etc., in addition to instantaneous values for metering of currents, voltages, powers and energies.

From a maintenance perspective, the ekor.rpa-100 units have a series of features that reduce the time and the possibility of errors in the test and service restoration tasks. Among the main characteristics, the most prominent are the large diameter toroidal-core current transformers installed in the cubicle bushing, their built-in test bars (for easier checking), and accessible terminal blocks for current or voltage injection tests as well as for checking the relay inputs and outputs. This conﬁguration enables a comprehensive testing of the unit.

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General Instructions ekor.rpa

1.2. Components

The parts which make up the ekor.rpa-100 protection, metering and control series are the electronic relay, voltage and current sensors, auxiliary circuits (terminal block and wiring), the bistable release and the tripping coil.

General description

Terminal block

ekor.rpa electronic relay

Voltage and current sensors

Figure 1.3. Parts of the assembly of ekor.rpa-100 in cubicle

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General description General Instructions

ekor.rpa

1.2.1. Electronic relay

The electronic relay has a keyboard and display to set and view the protection and control parameters. Moreover, the display provides information of the system's meterings, alarms and control signals in real time. The keyboard includes a seal on the <<SET>> key to ensure that once the settings have been made they cannot be changed unless the seal is broken.

The protection trips are registered on the display with the following parameters:

• Trip unit

• The phasor at the moment of tripping (currents and voltages).

• Tripping time. The time passing from start-up to tripping of the unit.

• The time and date the event occurred.

Unit errors are also permanently displayed. Furthermore, it is possible to check the fault reports using the front USB port by connecting a PC to this port and using the implemented folder system.

The “ON” LED is activated when the equipment receives power from an external source and ﬂashes quickly when the relay starts up. This LED will ﬂash less frequently once the microprocessor has checked that the status of the equipment is correct and all the protection units are active. In this situation, the unit is operational to carry out protection functions.

The voltage and current analogue signals are conditioned internally by small and very accurate transformers that isolate the electronic circuits from the rest of the installation.

The system has, in all its variants, 9 inputs and 4 outputs. Both the inputs and the outputs are protected from unwanted enabling/disabling.

The unit has 2 rear Ethernet ports for conﬁguration, a front mini-USB port for maintenance, and two rear RS-485 communications ports for remote control. The standard communication protocols for all models are MODBUS and PROCOME.

"ON" signalling LED

Metering and parameter setting display

SET key

Keyboard for scrolling through screens

Front mini-USB communication port

Figure 1.4. Description of the elements available on the front of the

ekor.rpa-120 relay

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1.2.2. Current sensors

The current sensors are toroidal-core current transformers with a 300/1 A or 1000/1 A or 2500/1 ratio, depending on the models. These transformers cover the entire operation range of Ormazabal cubicles, from rated currents 5A up to 2500 A.

The phase toroidal transformers are factory-installed in the cubicle bushings, which signiﬁcantly simpliﬁes on-site assembly and connection. This way, once the mediumvoltage cables are connected to the cubicle, the installation protection is operational. Installation errors of the sensors, due to earth grids, polarities, etc., are removed upon installation and checked directly at the factory.

All the current sensors have an integrated protection against the opening of secondary circuits, which prevents overvoltages.

General description

1.2.3. Voltage sensors

Cubicle voltage metering is carried out using a capacitor divider incorporated in the cubicle’s bushing, which ensures a precision of ± 5 % in the worst case scenario.

Ormazabal ekor.evt-c capacitive sensors can be used for greater precision. These are capacitor divider voltage sensors for gas-insulated cubicles. They are designed to allow assembly in both separable T-connectors and busbars. Their operation is autonomous and passive (without external auxiliary supply), with low-voltage analogue output and low power applicable directly to the metering systems without prior conditioning, for installation in medium-voltage automation and supervision systems in networks up to 36 kV. It can also measure partial discharges and establish communication via PLC.

Bushing

Current sensors

Figure 1.5. Location of the current sensors

Figure 1.6. ekor.evt-c voltage sensors

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ekor.rpa

1.2.4. “Binox” bistable tripping device and tripping coil

The "Binox" bistable trigger is a precision electromechanical actuator which is sealed with its own reinforcement and integrated in the switch driving mechanism. This release acts upon the switch when there is a protection trip. It is characterised by the low actuation power (high energy eﬃciency) it requires for tripping. This energy is delivered in the form of a pulse from the relay in a controlled manner to ensure the proper operation of the release and the opening of the switch.

The trials and tests passed by the ekor.rpa-100 unit set and cubicle, along with quality assurance in manufacture, mean this is a highly reliable element in the tripping chain. The solutions presented by Ormazabal with ekor.rpa-100 units have this tripping device installed as standard.

Figure 1.7. “Binox” Tripping coil

The operations ordered by the ekor.rpa-100 unit digital outputs are performed by means of conventional tripping coils. This way, a redundant and therefore more reliable operational system is achieved.

1.3. Functionality of the unit

The functionality of the assembly as a unit (MV cubicles for protection, metering and control, sensors, and protection and metering transformers) is validated in a test plan carried out in an in-house controlled environment.

To achieve this, Ormazabal counts on the CIT, its Research and Technology Centre, which represents an essential instrument in R&D, in order to capture and improve existing technologies and carry out research into new ones.

The CIT facilities oﬀer services to the science and technology sector in order to carry out research, development and type tests both for Ormazabal's business unit products and also for the rest of the electricity sector.

The CIT is made up mainly of:

1. HPL: Electrotechnical power laboratory, with the goal of identifying, acquiring and disseminating process technologies and strategic products within Ormazabal.

2. UDEX: Demonstration and experimentation unit consisting of a fully conﬁgurable, independent medium-voltage singular experimentation network to allow tests for new technologies, products and services to be developed and carried out in a safe, controlled environment.

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General Instructions ekor.rpa

1.4. Communications

All the relays of the ekor.rpa-100 units have two TCP/IP connection Ethernet ports and a Web server for conﬁguration. They also have a front mini-USB port for maintenance and two rear ports with serial communication RS-485 twisted pair (COM0 and COM1) for remote control.

The standard communication protocols implemented in all equipment are MODBUS in RTU transmission mode (binary) and PROCOME, through the rear RS-485 COM0 port ﬁtted in these units.

Optionally, the ekor.rpa-120 model also has a bus for temperature sensor connection.

The ekor.rpa-100 relays can be interconnected to other units in the ekor.sys family, as shown in the image below.

General description

ekor.ccp

ekor.bus

ekor.rci

ekor.rpa

ekor.rpt

ekor.rpg

Figure 1.8. Intercommunicated units of the ekor.sys family

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Applications General Instructions

ekor.rpa

2. Applications

2.1. Remote control of transformer and distribution substations

The ekor.rpa-100 protection, metering and control units make it possible to handle remote control applications of the transformer and switching substations, by implementing the control and monitoring of each switch through the units associated with each functional unit.

Figure 2.1. Remote-controlled switching substation

The use of a remote control terminal and ekor.rpa-100 units enable the user to visualise and operate each functional unit remotely thanks to the inputs and outputs ﬁtted for this purpose.

Figure 2.2. Layout of dierent stations in the network

Units that include this remote control function:

Unit Type of cubicle

ekor.rpa-100 type = p ekor.rpa-100 type = v

Table 2.1. Remote control function units

Fuse-combination switch

Circuit-breaker

The remote controlling applications complement the ekor.rci integrated control unit associated to feeder functions (see Ormazabal document IG-158).

2.2. Automatic reclosing of lines

The reclosing function performs the automatic reclosing of lines once the protection unit has commanded the trip and the switch has opened.

This function is always associated with Ormazabal circuitbreaker cubicles.

The protection units with automatic reclosing have a series of advantages over protections without reclosing:

• They reduce the time in which electrical power is interrupted.

• They avoid the need to locally re-establish the service in substations without remote control for transient faults.

• They reduce the fault time using a combination of fast switch trips and automatic reclosings, which results in lesser damage caused by the fault and generates a lower number of permanent faults derived from transient faults.

The unit which includes this function is:

Unit Type of cubicle

ekor.rpa-100 type = v

Table 2.2. Recloser function unit

Circuit-breaker

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General Instructions ekor.rpa

2.3. Line protection with circuit-breaker

Applications

The purpose of the line protection is to isolate this part of the network in case of fault, without it aﬀecting the rest of the lines. In a general way, it covers any faults that originate between the substation, transformer substation or switching substation and the consumption points.

Figure 2.3. Feeder protection functions in ekor.rpa-100 relays

The types of fault that occur in these areas of the network depend primarily on the nature of the line, overhead line or cable and the neutral used.

In networks with overhead lines, the majority of faults are transient, which makes many line reclosings eﬀective; in these cases, the reclosing function associated with circuitbreakers is used.

This is not the case for underground cables where faults are usually permanent.

On the other hand, in case of phase-to-earth faults in overhead lines, when the ground resistance is very high, the zero-sequence fault currents have a very low value In these cases, an ‘ultrasensitive’ neutral current detection is required.

The underground cables have earth coupling capacities, which causes the single phase faults to include capacitive currents. This phenomenon makes detection diﬃcult in isolated or resonant earthed neutral networks and thus requires the use of the directional function.

In ekor.rpa-100 units, model ekor.rpa-110, line protection is carried out mainly by the following functions:

• 50 ≡ Instantaneous overcurrent relay. Protects against short-circuits between phases.

• 51 ≡ Inverse time overcurrent relay. Protects against excessive overloads, which can deteriorate the installation.

• 51_2 ≡ Inverse time overcurrent relay II. Additional step to protect against excessive overloads, which can deteriorate the installation.

• 50N ≡ Instantaneous earth overcurrent relay. Protects against phase-to-earth short-circuits.

• 51N ≡ Inverse time earth overcurrent relay. Protects against highly resistive faults between phase and earth.

• 51_2_N ≡ Inverse time earth overcurrent relay II. Additional step to protect against highly resistive faults between phase and earth.

• 50NS ≡ Instantaneous sensitive earth overcurrent relay. Protects against phase to earth short-circuits of very low value.

• 51NS ≡ Inverse time sensitive earth overcurrent relay. Protects against highly resistive faults between phase and earth of very low value.

• 51_2_NS ≡ Inverse time sensitive earth overcurrent relay II. Additional step to protect against highly resistive faults between phase and earth of very low value.

• 2

Harm. Block ≡ Second harmonic blocking. Blocks

overcurrent units during transformer magnetisation

• 79 ≡ Reclosing relay. Enables the automatic reclosing of lines.

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ekor.rpa

In addition, the ekor.rpa-100 equipment, ekor.rpa-120 model, also have the following functions:

• 67/67N and 67NS ≡ Directional overcurrent relay,

directional earth fault relay and directional sensitive earth fault relay. Phase, neutral and sensitive neutral

directional functions which are associated to their corresponding overcurrent units, together allowing directional overcurrent units.

• 49 ≡ Machine or transformer thermal relay. Protects against thermal overloads in lines which cannot be detected by the overcurrent units.

• 46BC ≡ Broken conductor detection. Detects open lines, which are generally quite diﬃcult to detect using overcurrent units.

2.4. Transformer protection

The distribution transformers require various protection functions. Their selection depends primarily on the power and level of responsibility they have in the installation.

• 59/59N ≡ Overvoltage and residual overvoltage relay. Protects against phase and neutral overvoltages in the lines with 2 units for each phase and neutral, one timed and the other instantaneous.

• 27 ≡ Undervoltage relay. Protects against phase undervoltages in the lines with 2 units for each phase, one timed and the other instantaneous.

The units which provide the aforementioned functions are:

Unit Type of cubicle

ekor.rpa-100 type = v

Table 2.3. ekor.rpa-100-v

Circuit-breaker

Figure 2.4. Transformer protection functions in ekor.rpa-100 relays

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General Instructions ekor.rpa

Applications

The protection functions, available in models ekor.rpa-110, which must be implemented to protect distribution transformers with power ratings between 160 kVA and 2 MVA are the following:

• 50 ≡ Instantaneous overcurrent relay. Protects against short-circuits between phases in the primary circuit, or high value short-circuit currents between phases on the secondary side. This function is performed by the fuses when the protection cubicle does not include a circuitbreaker.

• 51 ≡ Inverse time overcurrent relay. Protects against excessive overloads, which can deteriorate the transformer, or against short-circuits in several turns of the primary winding.

• 51_2 ≡ Inverse time overcurrent relay II. Additional step to protect against excessive overloads, which can deteriorate the transformer, or against short-circuits in several turns of the primary winding.

• 50N ≡ Instantaneous earth overcurrent relay. Protects against phase to earth short-circuits or secondary winding short-circuits, from the interconnections and windings in the primary.

• 51N ≡ Inverse time earth overcurrent relay. Protects against highly resistive faults from the primary circuit to earth or to the secondary circuit.

• 51_2_N ≡ Inverse time earth overcurrent relay II. Additional step to protect against highly resistive faults from the primary circuit to earth or to the secondary.

• 50NS ≡ Instantaneous sensitive earth overcurrent relay. Protects against phase to earth short-circuits of very low value.

• 51NS ≡ Inverse time sensitive earth overcurrent relay. Protects against highly resistive faults between phase and earth of very low value.

• 51_2_NS ≡ Inverse time sensitive earth overcurrent relay II. Additional step to protect against highly resistive faults between phase and earth of very low value. 2

Harm. Block ≡ Second harmonic blocking. Blocks

overcurrent units during transformer magnetisation.

In addition, the ekor.rpa-100 equipment, ekor.rpa-120 models, also have the following functions:

• 67/67N and 67NS ≡ Directional overcurrent relay,

directional earth fault relay and directional sensitive earth fault relay. Phase, neutral and sensitive neutral

directional functions which are associated to their corresponding overcurrent units, together allowing directional overcurrent units.

• 49 ≡ Machine or transformer thermal relay. Protects against thermal overloads of transformers which cannot be detected by the overcurrent units.

• 46BC ≡ Broken conductor detection. Detects open lines. Broken conductors are quite diﬃcult to detect using overcurrent units.

• 59/59N ≡ Overvoltage relay and residual overvoltage relay. Protects against phase and neutral overvoltages in the lines with 2 units for each phase and neutral, one timed and the other instantaneous.

• 27 ≡ Undervoltage relay. Protects against phase undervoltages in the lines with 2 units for each phase, one timed and the other instantaneous.

The protection units that include the above mentioned functions are:

Unit Type of cubicle

ekor.rpa-100 type = p ekor.rpa-100 type = v

Table 2.4. ekor.rpa-100-p/ekor.rpa-100-v

Fuse-combination switch

Circuit-breaker

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Applications General Instructions

ekor.rpa

2.5. Automatic transfer

The automatic transfer of lines with circuit-breakers minimises power outages in loads fed by transformer or switching substations with more than one incoming line, thereby improving continuity of service.

Under normal conditions with voltage present on two possible incoming lines, the switch selected as preferred remains closed and the reserve one is opened. A voltage drop in the preferred line will cause the switch of this line to open and the reserve switch to close afterwards. Once normality has been re-established in the preferred line, the inverse cycle is performed, and the system returns to its initial status.

Figure 2.5. Automatic transfer

2.6. Detection of phase with earthing

In networks with isolated or resonant earthed neutral, the fault currents are very low. In the event of a fault in a system of this type, the fault current may not reach the calibrated threshold for overcurrent protection, and therefore this fault may not be detected.

Function 59 is used instead of programmed logic for detecting this type of fault, analysing both the installation’s neutral voltage and its current.

Figure 2.6. Detection of phase with earthing

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2.7. Protection and control of MV interconnection stations

Applications

In MV customers where an ekor.rpa-100 relay is installed, either in protection cubicles with circuit-breaker or fuses which protect the MV outgoing, information on this outgoing can be sent to the SCADA both by the web and via the MODBUS-TCP communications protocol.

2.8. Energy balances

By including MV energy meterings in the ekor.rpa-100 relays, it is possible to analyse non-technical losses which can be found between the Transformer Substation and the LV consumption, in order to uncover possible fraudulent use such as energy which has not been billed due to an error in the LV equipment.

The accessible information would be as follows:

• Cubicle position

• Trips

• Alarms

• Meterings:

- Voltage

- Current

- Power

- Energy

ekor.rci

ekor.ccp

ekor.rpa

Meters

Figure 2.7. ekor.rpa-100 unit measuring MV energies in a transformer

with private customers

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Metering functions General Instructions

ekor.rpa

3. Metering functions

3.1. Current and voltage metering

The unit has four current reading inputs (IA, IB, IC and INS) and three voltage reading inputs (VA, VB and VC). Each of them are conditioned and digitised in order to carry out the calculation.

The design of the equipment and sensors, along with their integration in the cubicle, form an assembly which works as a single unit to achieve maximum immunity and quality of the signal to be measured, both in the 50 Hz and 60 Hz networks.

The signal transduction and conditioning stages are designed to ensure the sensor and relay assembly reproduces both the magnitude and the phase of the current and voltage signals of the distribution network. This ensures optimal performance in real-time applications, with protection algorithms, in all operation conditions and in supply quality or load monitoring meterings.

The samples obtained for I

and VN, calculated by the sum

of samples of the corresponding phase signals, must be added to the voltage and current inputs sampled directly. These calculated signal characteristics are equivalent to those obtained by vector sum of the conventional sensor signals.

The meterings for supervision of current and voltage are measured integrated for 1.28 seconds and represented in phasorial mode (module + argument). Network load status is therefore updated regularly.

The current and voltage meterings are:

• Line currents I

• Line voltage: U

, IB and IC.

, UBC and UCA and Line voltages: VA, VB

and VC.

• Residual currents and voltages. Represented as: I

N/INS

(3Io) and VN (3Vo).

Figure 3.1. Current and voltage metering

The ﬁnal calibration is the overall calibration of sensors, metering equipment, cabling and switchgear, and is validated in an exhaustive test plan carried out in a controlled environment which reproduces the reality of the medium-voltage electrical distribution network.

All this process includes diﬀerent scenarios:

• Maximum electromagnetic interference and temperature rise scenarios of the assembly, carried out at rated switchgear current.

• Maximum thermal variation scenarios, carried out in a climate chamber between -10 °C and 60 °C.

• Scenarios with highly aggressive transient disturbance, power and lightning impulse tests with medium-voltage levels.

• etc.

These tests conclude in points such as: the ratio of the number of turns of the current transformers, impedance of the voltage reading inputs, etc. All this is tested and validated on the ﬁnal solution delivered to the customer.

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3.2. Power meterings

Metering functions

The powers which are monitored (locally or remotely) are

1.28 second integrated meterings of the calculated RMS instantaneous values.

Accredited meterings in precision class guarantee reliability in the values obtained.

The equipment acts as a metering station for load analysis or electrical supply quality monitoring tasks. The monitored meterings for active and reactive power are single-phase and three-phase, and three-phase only for apparent power.

3.3. Energy meter

The equipment is ﬁtted with an "Active and reactive electrical energy meter" which meets the particular requirements for static energy meters. This is an indirect connection threephase meter which, along with the voltage and current metering sensors, form a medium-voltage (MV) meter.

The energy meter accumulates 100 meterings of powers P and Q integrated in a semicircle (1 second for 50Hz and

1.2 seconds for 60Hz). In total, there will be four meters: three single-phase (A phase, B phase and C phase) and one three-phase.

The meterings are made up of:

• Single-phase: Active PA, PB and PC and Reactive QA, QB and QC.

• Three-phase: PT, QT and ST Powers and Power Factor (P.F.).

Each meter has two active energy records (E+ and E-) and four reactive energy records (Q1, Q2, Q3 and Q4), each of them 32 bits. These registers have a bit to indicate overﬂow and a reset option by command.

Active powers are expressed in kilovolts-hour (kWh) and reactive powers are expressed in kilovolt amperes reactivehour (kVArh).

Reactive

Inductive

Capacitive

Generated

Consumed

Active

Active energy imported (in kWh): EA + , EB + , EC + and ET + Active energy exported (kWh): EA - , EB - , EC - and ET Inductive reactive energy imported (kVArh): QA1, QB1, QC1 and QT1 Capacitive reactive energy imported (kVArh): QA2, QB2, QC2 and QT2 Inductive reactive energy exported (kVArh): QA3, QB3, QC3 and QT3 Capacitive reactive energy exported (kVArh): QA4, QB4, QC4 and QT4

Figure 3.2. Energies

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Protection functions General Instructions

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4. Protection functions

4.1. Overcurrent units

The ekor.rpa-100 systems are ﬁtted with the following overcurrent protection units:

Phases:

• Six phase overcurrent timed units (3 x 51.3 x 51(2)).

• Three phase overcurrent instantaneous units (3 x 50).

4.1.1. Timed overcurrent units

The phase, neutral and sensitive neutral timed units start up if the fundamental value of the magnitude for each unit exceeds the value 1.05 times the adjusted start-up, and are reset when this value is below 0.95 times the adjusted value.

Tripping takes place if the unit is started up for the time set. This time may be adjusted by selecting diﬀerent types of curve, in accordance with IEC and ANSI Standards.

The curves implemented in the ekor.rpa-100 units are:

IEC CURVES

• IEC DT: Deﬁned time

• IEC NI: Normally inverse curve

• IEC VI: Very inverse curve

• IEC EI: Extremely inverse curve

• IEC LTI: Long time inverse curve

• IEC STI: Short time inverse curve

ANSI CURVES

• ANSI LI: Long time inverse curve

• ANSI NI: Normally inverse curve

• ANSI VI: Very inverse curve

• ANSI EI: Extremely inverse curve

These curves are detailed in the ANNEX section.

Neutral (Calculated):

• Two neutral timed overcurrent units (1 x 51N, 1 x 51(2) N).

• A neutral instantaneous overcurrent unit (1 x 50N).

Sensitive neutral (measured):

• Two sensitive neutral timed overcurrent units (1 x 51NS, 1 x 51(2)NS).

• A sensitive neutral instantaneous overcurrent unit (1 x 50NS).

The settings for the timed units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Starting up the unit: Unit starting current. Variable ranges in accordance with current transformers used.

• Time curve: Curve type (IEC DT, IEC NI, IEC VI, IEC EI, IEC LTI, IEC STI, ANSI LI, ANSI NI, ANSI VI, ANSI EI).

• Time index: Time index, also known as time dial (from

0.05 to 1.60). This setting applies to all curve types except for IEC DT.

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s). This setting only applies to IEC DT type curves.

• Torque control: Directional tripping mask (OFF, FORWARD or REVERSE). To indicate the direction for tripping:

- OFF: Regardless of the direction, the relevant overcurrent unit will trip if the overcurrent conditions are met.

- FORWARD: The corresponding overcurrent unit will trip whenever the overcurrent conditions are met, and the directional unit will give the FORWARD signal.

- REVERSE: The corresponding overcurrent unit will trip whenever the overcurrent conditions are met, and the directional unit will give the REVERSE signal.

This setting will only be found in ekor.rpa-100 units model 120.

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4.1.2. Instantaneous overcurrent units

Protection functions

The phase, neutral and sensitive neutral instantaneous units start up if the fundamental value of the magnitude for each unit exceeds the value 1.00 times the adjusted startup, and are reset when this value is below 0.95 times the adjusted value.

Tripping takes place if the unit is started up for the time set.

The settings for the instantaneous units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Starting up the unit: Unit starting current. Variable ranges in accordance with current transformers used.

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s).

4.1.3. Block diagram

Any overvoltage unit complying with the diagram shown below:

• Torque control: Directional tripping mask (OFF, FORWARD or REVERSE). To indicate the direction for tripping:

- OFF: Regardless of the direction, the relevant overcurrent unit will trip if the overcurrent conditions are met.

- FORWARD: The corresponding overcurrent unit will trip whenever the overcurrent conditions are met, and the directional unit will give the FORWARD signal.

- REVERSE: The corresponding overcurrent unit will trip whenever the overcurrent conditions are met, and the directional unit will give the REVERSE signal.

This setting will only be found in ekor.rpa-100 units model 120.

Metering

Input signal

Output signal

Settings

Figure 4.1. Block diagram

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Basically, the diagram shows that, whenever a magnitude measured in real-time (Ix) exceeds the setpoint value (l

pick up

setting), a time counter counts down (counter: f (curve, index, time), tripping when completely expired.

If the measured magnitude (Ix) drops below the setpoint (I

) during timing, the unit and the meter are reset and

pick up

the unit remains idle.

All the units generate the following signalling:

• Pick-up: Activated when the measured magnitude (Ix) exceeds a setpoint (I

setting) and disabled when the

pick up

metering value drops below the setpoint.

• Temporize: Activated when the time counter reaches its end, and disabled when the metering value drops below the setpoint.

• Trip: Activated when the temporize signal is activated, and disabled when the metering value drops below the setpoint.

4.2. Ultra-sensitive earth

This functionality is available in both directional and nondirectional ekor.rpa and corresponds to a particular case of overcurrent detection for phase-to-earth faults. Primarily used in networks with isolated neutral, resonant earthed neutral or on highly resistive soils, where the phase-toearth fault current has a very low value.

Moreover, the overcurrent units can be blocked by the

maximum current blocking and second harmonic blocking units detailed in the following sections.

Moreover, the overcurrent units can be blocked in three diﬀerent ways:

• Unit block: Blocks the unit, preventing start-up while this input remains active.

• Timing Block: Freezes the time counter value while this input is active.

• Trip Block: Allows the unit to advance, and blocks it before the trip output.

The current ﬂowing to earth is detected using a toroidalcore current transformer which covers the three phases. In this way, the metering is independent from the phase current, thus avoiding errors in the phase metering sensors.

Using this type of toroidal-core means the measured neutral currents due to unbalanced phases are reliable in very low primary amp values. For this type of conﬁguration, the unit allows a minimum trip setting of 0.3 primary amps in its Sensitive Neutral channel.

Voltage and current sensors

Zero-sequence transformers

Figure 4.2. Current sensors

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4.3. Directional units

Protection functions

The directional units are combined with the overcurrent units when taking a decision on tripping. In accordance with the "torque control" direction setting (Forward or Reverse) and the result of the direction of the fault, the overcurrent units ﬁnish by tripping or not.

4.3.1. Phase directional units

Angular criterion

The phase directional units are units which, using the angular criterion, determine the direction of each of the 3 phases. The polarisation voltage used for each phase is the compound voltage corresponding to the other 2 phases.

These units determine direction based on:

• The calibrated settings.

• The phase diﬀerence existing between the polarisation signal and the current signal.

The settings for the phase directional unit are:

The ekor.rpa-100 model 120 systems have the following directional units:

• Three phase directional units (3 x 67)

• A neutral directional unit (1 x 67N)

• A sensitive neutral directional unit (1 x 67NS)

The Reverse direction zone will be the opposite of the Forward zone. In other words, the above formula needs to be turned around 180° in order to achieve the expression which delimits the Reverse direction zone.

The directional units will indicate ndef direction if in the indeterminate zone or polarisation voltage is below the V

setting.

min

The ﬁgure shows an example of operation of the directional unit of phase A:

• Characteristic phase angle: Characteristic angle (from - 90.0° to 90.0°). This often corresponds to the series impedance angle of the lines. Typical values in distribution: 30° and 45°.

• Minimum phases voltage: Minimum polarisation voltage (from 0.5 kV to 72.0 kV). Polarisation voltage value as of which the directional unit considers the angle reliable, and is capable of determining a direction.

• Indeterminate zone: Indeterminate zone angle (from

0.0° to 90.0°). Setting to establish the indetermination zone which is close to the zero torque line.

The direction indicated by the units can be Forward, Reverse or ndef (undeﬁned).

The Forward direction zone is delimited by the following formula:

Reserve

Forward

Indeterminate zone

Zero torque line

Maximum torque line

Figure 4.3. Phase A directional unit

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4.3.2. Neutral and sensitive neutral directional units

The neutral and sensitive neutral directional units include two diﬀerent criteria to determine direction: Directional criterion and wattmetric criterion. The criterion is selected through a setting in the unit itself.

Angular criterion

The angular criterion of the neutral and sensitive neutral directional units is based on the phase diﬀerence between the polarisation signal (-3V (3Io).

The polarisation signal used is the 180° out-of-phase residual voltage, i.e.- 3V

The settings for the neutral and sensitive neutral directional unit, which apply to the angular criteria, are:

) and the residual current signal

• Characteristic neutral angle: Characteristic angle (from

- 90.0° to 90.0°). In distributions with earthed neutral, this often corresponds to the earth impedance angle.

• Minimum neutral voltage: Minimum polarisation voltage (from 0.5 kV to 72.0 kV). Polarisation voltage value as of which the directional unit considers the angle reliable, and is capable of determining a direction.

• Indeterminate zone: Indeterminate zone angle (from

0.0° to 90.0°). Setting to establish the indetermination zone which is close to the zero torque line.

The direction indicated by the units can be Forward, Reverse or ndef (undeﬁned).

The Forward direction zone is delimited by the following formula:

The directional units will indicate ndef direction if in the indeterminate zone or polarisation voltage is below the V

min

setting.

The ﬁgure below shows an example of operation for the neutral directional unit:

Reserve

Forward

Indeterminate zone

Figure 4.4. Neutral directional unit

Wattmetric criterion

The wattmetric criterion of the neutral and sensitive neutral directional units is based on the phase diﬀerence between the polarisation signal (- 3V

) and the residual current signal

(3lo), along with the magnitude of the residual active power.

The settings for the neutral and sensitive neutral directional unit, which apply to the wattmetric criteria, are:

• Minimum neutral active power: Minimum residual active power. Minimum residual active power value (in absolute value), as of which direction other than ndef (i.e. Forward or Reverse) can be considered. Variable ranges in accordance with current transformers used.

• Indeterminate zone: Indeterminate zone angle (from

0.0° to 90.0°). Angle formed by the 90° axis and the line which delimits the indeterminate zone.

The direction indicated by the units can be Forward, Reverse or ndef (undeﬁned).

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Protection functions

The unit will indicate Forward direction in the following conditions:

• The residual current signal (3I

) drops in the following

zone:

The residual active power is lower than - P

min

The reverse direction zone will be the opposite of the Forward zone. In other words, the above formula needs to be turned around 180° in order to achieve the expression which delimits the reverse direction zone. Furthermore, residual active power must be greater than + P

min

The unit will give undeﬁned direction if:

• The residual active power in absolute value is lower than P

• The polarisation voltage value is lower than the V

min

setting.

• This is found in the indeterminate zone (see ﬁgure below).

The ﬁgure below shows an example of operation for the neutral directional unit with wattmetric criterion:

Reserve

Forward

Indeterminate zone

Figure 4.5. Neutral unit with wattmetric criterion

4.4. Thermal image unit

The ekor.rpa-100 model 120 systems are ﬁtted with the thermal image unit (49) for protection of lines and transformers.

On certain occasions, the thermal overload of the element to be protected cannot be detected by conventional protection units. Furthermore, many of the elements

installed in the power system are being used ever-closer to their thermal limits, making it necessary for the protection devices used for these elements to have thermal units.

The thermal image unit is a unit which, in accordance with the estimated thermal capacity value, generates alarm and trip signals.

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4.4.1. Estimated thermal capacity

The system estimates thermal capacity through the phase currents (I

Where: T

: Estimated thermal capacity at instant n

: Estimated thermal capacity at instant n-1

n-1

Δt: Time interval between consecutive n and n-1 instants τ: Cooling or heating constant If T

constant will be applied in the formula If, on the other hand, T

ﬁnal

: Final thermal capacity This value is calculated based on the

ﬁnal

, IB and IC), using the following formula:

< T

ﬁnal

< T

, the cooling constant will be applied in the formula

n-1

, the temperature rise

n-1

adjusted rated current and the phase currents, in accordance with the following formula:

capacity (T)

Estimated thermal

Time (min)

Figure 4.6. Estimated thermal capacity

Starting from an initial thermal capacity of 0 %, during the ﬁrst 100 min where current is 16 % higher than the rated (5.8 A), estimated thermal capacity reaches a value of

84.6 %.

: The estimated mean thermal current based on the phase

therm

currents:

Example The evolution of the thermal capacity estimated by the

system for a 250 kVA transformer in a 30 kV network under the following conditions:

sequence read by the equipment:

therm

Interval 1 Interval 2 Interval 3

From 0 min

to 100 min

5.8 A 1.5 A 5.8 A

Table 4.1. I

read by the system

therm

From 100 min

to 150min

From 150 min

to 250min

In the next 50 min current drops to 30 % of rated current (1.5 A), and this makes thermal capacity drop to 58.4 %.

A third interval identical to interval 1 has been chosen to check the memory eﬀect of the estimated thermal capacity. In other words, a current which is 16 % higher than the rated (5.8 A) for 100 min. It is observed that, after these 100 min, thermal capacity reaches 106.3 %, thus exceeding 100 % (typical trip level setting).

This diﬀerence in the estimated thermal capacity between intervals 1 and 3 is due to the fact that previous statuses are taken into account in the calculation. Hence, as the ﬁrst interval starts from a thermal capacity equal to 0 %, the third interval starts from the thermal capacity accumulated up to this moment, taking into account all the thermal stress suﬀered by the element to be protected. This means the estimated thermal capacities are diﬀerent in these intervals.

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4.4.2. Functionality

Protection functions

The thermal image unit starts up (with an alarm signal) if the thermal capacity value exceeds the alarm level setting (%), tripping whenever the trip level setting is exceeded (%). Once the unit has tripped, this will reset when the thermal capacity value drops below the trip reset level setting (%).

The settings for the thermal image unit are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Temperature rise constant: Temperature rise constant (from 3 min to 60 min).

• Cooling constant: Cooling constant (from 3 min to 180 min).

• Alarm level: Alarm threshold percentage. The thermal capacity percentage from which an alarm situation is considered (from 80 % to 100 %).

• Trip level: Trip threshold percentage. The thermal capacity percentage from which a thermal overload is tripped (from 100 % to 200 %).

• Trip reset level: Reset threshold. The thermal capacity percentage below which the unit is reset (from 50 % to 99 %).

• Rated current: Rated current of the element to be protected. Variable ranges in accordance with current transformers used.

The time taken to reach tripping, based on a thermal capacity equal to zero, given by the following formula:

Where: t: Tripping time

: Temperature rise constant

: Adjusted rated current

: The estimated mean thermal current based on the phase

therm

currents

The trip times for diﬀerent temperature rise constants are shown graphically below:

Figure 4.7. Trip time

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4.4.3. Block diagram

The thermal image unit complies with the following block diagram :

Metering

Input signal

Output signal

Settings

Figure 4.8. Block diagram

The thermal image unit generates the following signal:

• Alarm: Activated when the estimated magnitude of thermal capacity (Th. C) exceeds the “Alarm Threshold” setting, and is disabled when estimated thermal capacity (Th. C) drops below the “Alarm Threshold – 5%” setting.

• Temporize: Activated when the estimated magnitude of thermal capacity (Th. C) exceeds the “Trip Threshold” setting, and is disabled when estimated thermal capacity (Th. C) drops below the “Restore Threshold” setting.

• Trip: Activated when the temporize signal is activated, and disabled when the estimated thermal capacity (Th. C) drops below the “Restore Threshold” setting.

Moreover, the thermal image unit can be blocked by the maximum current blocking unit detailed in the following sections.

The thermal image unit can be blocked in three diﬀerent ways:

• Unit Block: Blocks the unit, preventing start-up while this input remains active.

• Timing Block: Blocks the unit, allowing it to run the alarm signal but not allowing the temporize or trip signal.

• Trip Block: Allows the unit to advance, and blocks it before the trip output.

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4.5. Broken conductor unit

Protection functions

The ekor.rpa-100 model 120 systems are ﬁtted with the broken conductor unit (46BC).

Conventional protection functions cannot detect conditions in which one of the conductors is broken.

4.5.1. Calculation of sequence currents

The broken conductor unit is supplied by the sequence currents (I

, I2 and Io) previously calculated by the system.

The sequence current calculation is carried out in accordance with these formulae:

The broken conductor unit (46 Broken Conductor) can be used to detect broken conductors, by monitoring the sequence currents, and another series of conditions detailed in this section.

Where,

With the phase A sequence components known, the B and C sequence components will be identical in modules, displaced 120° in angle in the case of direct and inverse sequence, and with the same angle in the case of zerosequence.

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The following image shows an example of calculation of the sequences based on an imbalanced system. It is observed that the system has a large inverse component, but no zero-

Line currents Direct-sequence currents

sequence (situation which can come about in lines which are not uniformly charged in the three phases):

Inverse-sequence currents Zero-sequence currents

Figure 4.9. Calculation of sequences

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Protection functions

Another example which applies for the case of broken conductors could be as follows: One of the phases with no current (without the capacitive currents which can go

Line currents Direct-sequence currents

through the broken conductor) and the other two counterdirection phases:

Inverse-sequence currents Zero-sequence currents

Figure 4.10. Calculation of sequences

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4.5.2. Functionality

The broken conductor unit starts up when a series of conditions are met, as detailed below, and is reset when any of these conditions drops to 0. Tripping takes place if the unit is started up for the time set.

The settings for the broken conductor unit are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Base current: The magnitude to be used to calculate the ratios. Can be I1 (direct sequence) or I

(primary rated

current of the current transformer). The In value will vary in accordance with the current transformers used.

• Starting up the unit: Start-up value of I2 (inverse sequence)/Ib (base current) (from 0.05 to 0.5 p.u.).

4.5.3. Block diagram

The broken conductor unit complies with the following block diagram:

• Unit timing: Unit tripping time (from 0.05 s to 600.00 s).

• Minimum current threshold for phases: Phase current value, below which it is considered that the line is open. Although the line is actually open, there may be current ﬂowing through this phase (through capacitive elements of the lines, as this line continues to supply some stations located before the broken conductor). Variable ranges in accordance with current transformers used.

• Maximum current threshold for neutral: Maximum ratio of Io (zero-sequence)/Ib (base current ) as of which it is considered a single-phase fault rather than an broken conductor (from 0.00 to 0.5 p.u.). If the setting is 0.00, the 46BC unit does not make any zero-sequence current check.

Input signal

Output signal

Settings

Figure 4.11. Block diagram

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The four conditions which make the broken conductor unit start up are:

Protection functions

Figure 4.12. Conditions A, B, C and D

The broken conductor unit generates the following signal:

• Pick up: Activated when the four conditions come about at the same time, and disabled when any of the 4 conditions are no longer met.

• Temporize: Activated when the Pick up signal remains active for the time set, and disabled when any of the 4 conditions are no longer met..

• Trip: Activated when the Temporize signal is activated, and disabled when any of the 4 conditions are no longer met.

4.6. Voltage units

The ekor.rpa-100 model 120 systems are ﬁtted with the following voltage protection units:

Phases:

1. Three phase overvoltage timed units (3 x 59_TEMP)

2. Three phase overvoltage instantaneous units

(3 x 59_INST)

3. Three phase undervoltage timed units

(3 x 27_TEMP)

4. Three phase undervoltage instantaneous units

(3 x 27_INST)

Moreover, the broken conductor unit can be blocked by the maximum current blocking unit detailed in the following sections.

The broken conductor unit can be blocked in three diﬀerent ways:

• Unit Block: Blocks the unit, preventing start-up while this input remains active.

• Timing Block: Freezes the time counter value while this input is active.

• Trip Block: Allows the unit to advance, and blocks it before the trip output.

Neutral (calculated):

1. A neutral overvoltage timed unit (1 x 59N_TEMP)

2. A neutral overvoltage instantaneous unit

(1 x 59N_INST)

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4.6.1. Timed overvoltage units

The phase and neutral timed units start up if the fundamental value of the magnitude (single or compound voltage, which can be set by the user) for each unit is below the value 1.05 times the adjusted start-up, and are reset when this value exceeds 0.95 times the adjusted value.

Tripping takes place if the unit is started up for the time set. This time may be adjusted by selecting diﬀerent types of curve, in accordance with IEC and ANSI Standards. The curves implemented for the voltage units are identical to those in the overcurrent units.

4.6.2. Instantaneous overvoltage units

The phase and neutral timed units start up if the fundamental value of the magnitude for each unit exceeds the value 1.00 times the adjusted start-up, and are reset when this value is below 0.95 times the adjusted value.

Tripping takes place if the unit is started up for the time set.

The settings for the timed units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Working voltage: Selection of the magnitude for working: Single or compound voltage (Phase to neutral or Phase to phase).

• Starting up the unit: Unit starting voltage (from 0.5 kV to 72.0 kV).

• Time curve: Curve type (IEC DT, IEC NI, IEC VI, IEC EI, IEC LTI, IEC STI, ANSI LI, ANSI NI, ANSI VI, ANSI EI).

• Inverse curve time index: Time index, also known as time dial (from 0.05 to 1.60). This setting applies to all curve types except for IEC DT.

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s). This setting only applies to IEC DT type curves.

The settings for the instantaneous units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Working voltage: Selection of the magnitude for working: Single or compound voltage (Phase to Phase or Phase to Neutral).

• Starting up the unit: Unit starting voltage (from 0.5 kV to 72.0 kV).

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s).

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4.6.3. Timed undervoltage units

Protection functions

The phase timed units start up if the fundamental value of the magnitude (single or compound voltage, which can be set by the user) for each unit is below the value 0.95 times the adjusted start-up, and are reset when this value exceeds

1.05 times the adjusted value.

4.6.4. Instantaneous undervoltage units

The phase instantaneous units start up if the fundamental value of the magnitude (single or compound voltage, which can be set by the user) for each unit is below the value 1.00 times the adjusted start-up, and are reset when this value exceeds 1.05 times the adjusted value

Tripping takes place if the unit is started up for the time set.

The settings for the timed units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Working voltage: Selection of the magnitude for working: Single or compound voltage (Phase to neutral or Phase to phase).

• Starting up the unit: Unit starting voltage (from 0.5 kV to 72.0 kV).

• Time curve: Curve type (IEC DT, IEC NI, IEC VI, IEC EI, IEC LTI, IEC STI, ANSI LI, ANSI NI, ANSI VI, ANSI EI).

• Inverse curve time index: Time index, also known as time dial (from 0.05 to 1.60). This setting applies to all curve types except for IEC DT.

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s). This setting only applies to IEC DT type curves.

The settings for the instantaneous units are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Working voltage: Selection of the magnitude for working: Single or compound voltage (Phase to Phase or Phase to Neutral).

• Starting up the unit: Unit starting voltage (from 0.5 kV to 72.0 kV).

• Fixed time: Unit tripping time (from 0.00 s to 100.00 s).

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4.6.5. Block diagram

Any voltage unit complying with the diagram shown below.

Metering

Input signal

Output signal

Settings

Figure 4.13. Block diagram

The diagram represents, whenever the magnitude measured in real time (Vx) is: a) higher in the case of overvoltage units: 59 or, b) lower in the case of undervoltage units: 27 than the setpoint value (V

setting), a time counter counts down

pick up

(counter: ƒ (curve, index, time) tripping once completely expired.

If the measured magnitude (Vx) drops (overvoltage units: 59) or increases (undervoltage units: 27) over setpoint (V

pick up

the unit and the counter are reset, with the unit remaining idle

All the units generate the following signalling:

• Pick-up: Activated when the measured magnitude (Vx) is higher (overvoltage units: 59) or below (undervoltage units: 27) a setpoint (V

setting), and disabled when

pick up

the metering value is lower (overvoltage units: 59) or higher (undervoltage units: 27) than the setpoint.

• Temporize: Activated when the time counter reaches its end, and disabled when the metering value is lower (overvoltage units: 59) or higher (undervoltage units: 27) than the setpoint.

• Trip: Activated when the Temporize signal is activated, and disabled when the metering value is lower (overvoltage units: 59) or higher (undervoltage units: 27) than the setpoint.

Moreover, the voltage units can be blocked by the maximum current blocking unit detailed in the following sections.

Moreover, the voltage units can be blocked in three diﬀerent ways:

• Unit Block: Blocks the unit, preventing start-up while this input remains active.

• Timing Block: Freezes the time counter value while this input is active.

• Trip Block: Allows the unit to advance, and blocks it before the trip output.

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4.7. Second harmonic blocking unit

Protection functions

The ekor.rpa-100 systems are ﬁtted with the second harmonic blocking unit.

This function blocks the overcurrent units whenever the transformer energisation conditions are met:

4.7.1. Functionality

The second harmonic blocking unit has 5 modules, one for each current (I

, IB, IC, IN and INS). Each of these modules

generates a blocking signal associated to the overcurrent unit whenever the following conditions are met simultaneously:

• The ratio between the second harmonic and the corresponding current fundamental must be higher than the setting “2nd harmonic threshold ratio”.

• The fundamental value of the corresponding current must be higher than the setting “Min. phase/neutral/ senst. neutral current”.

Moreover, the following condition must be met in the three phase current modules (I

, IB and IC):

• The fundamental value of the corresponding current must be lower than the setting “Max phase current”.

• High fundamental current value.

• High second harmonic current value.

Any of the following conditions must come about to disable the block:

• The ratio between the second harmonic and the corresponding current fundamental must be lower than the setting “Second harmonic threshold”.

• The fundamental value of the corresponding current must be lower than the setting “Min. phase/neutral/ senst. neutral current”.

• The time during which it remains blocked must be lower than the setting “Max. blocking time”.

• The fundamental value of the corresponding current must be higher than the setting “Max phase current” (modules for I

, IB and IC only).

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The settings for the second harmonic blocking unit are:

• Enabling the unit: Enable/disable the unit (ON/OFF).

• Second harmonic threshold: Second harmonic current threshold (as a percentage relative to the fundamental current) as of which the second harmonic condition is met (from 5.0 % to 100.0 %).

• Cross-blocking: Setting to select how blocking a phase (A, B or C) aﬀects the other phases (also known as crossblocking). Possible settings:

- OFF: Indicates that there is no cross-blocking. In other words, the second harmonic blocking signal is only activated in those phases which meet the conditions.

- 1 OUT OF 3: Indicates that there is cross-blocking. In other words, blocking conditions simply need to exist in any of the three phases in order to activate the second harmonic blocking signal in all phases (A, B and C).

- 2 OUT OF 3: As in the previous case, although this time the blocking conditions must be found in at least 2 of the 3 phases in order to activate the second harmonic blocking signal in all phases (A, B and C).

• Minimum current threshold for phases: Fundamental phase current as of which the condition corresponding to minimum fundamental current is met. Variable ranges in accordance with the current transformers used.

• Minimum current threshold for neutral: Fundamental neutral current as of which the condition corresponding to minimum fundamental current is met. Variable ranges in accordance with the current transformers used.

• Minimum current threshold for sensitive neutral: Fundamental sensitive neutral current as of which the condition corresponding to minimum fundamental current is met. Variable ranges in accordance with the current transformers used.

• Maximum current threshold for phases: Fundamental phase current below which the condition corresponding to maximum fundamental phase current is met. Variable ranges in accordance with the current transformers used.

• Maximum block time: Maximum time blocking will remain active (from 0.01 s to 5.00 s). If the block persists after this time, the unit will be reset, releasing the overcurrent units.

• Overcurrent units blocking mode: Mode in which the corresponding overcurrent unit can be blocked (OFF, UNIT, TIMING or TRIP).

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4.7.2. Block diagram

The second harmonic blocking unit complies with the following block diagram:

Protection functions

Figure 4.14. Block diagram

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The second harmonic blocking unit generates the following signal:

• UHARM_IA_BLOCK: Signal which indicates whether phase A complies with the conditions necessary for second harmonic blocking or not.

• UHARM_IB_BLOCK: Signal which indicates whether phase B complies with the conditions necessary for second harmonic blocking or not.

• UHARM_IC_BLOCK: Signal which indicates whether phase C complies with the conditions necessary for second harmonic blocking or not.

• UHARM_IN_BLOCK: Signal which indicates whether the calculated neutral complies with the conditions for second harmonic blocking or not.

• UHARM_INS_BLOCK: Signal which indicates whether the sensitive neutral complies with the conditions necessary for second harmonic blocking or not.

The diagram below shows how to wire the second harmonic blocking signals to the overcurrent units:

Figure 4.15. Cabling by second harmonic

The blocking input signals of the overcurrent units are the result of the logic carried out between the “U2HARM_IX_ BLOCK” blocking signal generated by the second harmonic blocking unit and the “Blocking mode” setting of the corresponding overcurrent unit. In consequence, whenever blocking conditions exist, the corresponding overcurrent unit is blocked in the way indicated by the “Blocking mode” setting of the associated unit.

The possible blocking modes are:

• OFF: The unit is not blocked even when the conditions necessary for blocking come about.

• UNIT: Blocks the unit, preventing start-up whenever the conditions necessary for blocking come about.

• TIMING: Freezes the time counter value whenever the conditions necessary for blocking come about.

• TRIP: Allows the unit to advance and blocks it before the trip output, whenever the conditions necessary for blocking come about.

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Protection functions

4.8. Block by I

max

The maximum current blocking unit is implemented in the ekor.rpa-100 systems, p type, used in fuse protection cubicles, allowing the protection units to be blocked when the line current exceeds certain set values.

Below the current set in the maximum current blocking unit, the element in charge of protection will be the ekor.rpa-100 unit. On the other hand, the unit will be blocked if the current exceeds this value, in which case the fuses will be entrusted with protection.

If the current in any of the 3 phases is above the value set in the maximum current blocking unit, all protection units will be blocked until current drops below the set value.

The settings for this unit are not accessible by the user and will be set by the manufacturer in accordance with the characteristics of the cubicle where the ekor.rpa-100 unit is to be installed.

Relay protection

Fuse protection

Figure 4.16. Block by I

max

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5. Detection, automation and control functions

5.1. Recloser automation

5.1.1. Functionality

The recloser automation is implemented in the ekor.rpa-100 systems used in protection cubicles with circuit-breaker. This allows automatic line reclosing, once one of the overcurrent units has ordered tripping and the switch has opened.

This function is primarily used in overhead lines, where a great number of faults are usually transient: electrical arcs due to the proximity of two conductors caused by the wind, tree falling on lines, etc. Transient faults can be cleared by momentarily de-energising the line. Once enough time has elapsed to deionise the air, there is a very high probability that the fault will not re-occur when power is re-established.

The recloser function implemented in the ekor.rpa-100 systems is of three-core type, with simultaneous reclosing for the three phases. The recloser can carry out up to four reclosing attempts, and it is possible to deﬁne a diﬀerent reclosing time for each of them. Furthermore, there are independent recloser time settings for earth faults or between phases.

5.1.2. VREF

The recloser cycle starts when any of the overcurrent units trip whilst the recloser is in automatic and unblocked. Under these conditions, the relay waits for the ﬁrst reclosing time and sends a command signal for the switch to close.

When the switch closes, the block timing starts counting. As with the recloser times, there are 2 independent blocking times: that associated to earth faults, and that associated to faults between phases. The reclosing is considered successful if, once the block timing has elapsed, the fault disappears after the switch closes. Any trip that occurs afterwards is considered to be caused by a new fault and the ﬁrst reclosing timing restarts.

If, after the ﬁrst closing, a new trip occurs before blocking time has elapsed, it is considered to be caused by the same fault, meaning the function will start the timing of the second reclosing.

The logic explained in the above paragraph will continue to be applied until the number of conﬁgured reclosings is exhausted. This means that the fault is permanent and it will change to the ﬁnal trip condition.

There is the option of controlling reclosing by way of a status programmable in the user PLC (ESP_VREF). Whenever this function is used, this status must be active after tripping in order to allow reclosing. Whenever it is active, it will continue with the recloser cycle as described above. On the other hand, the automation will wait for a time equal to the Tvref setting if the aforementioned status is disabled after tripping, and will deﬁnitively trip if it is not enabled over the course of this time.

This functionality can be useful when monitoring voltage in busbars. Reclosings can be made conditional on the presence of voltage in busbars by associating voltage in busbars to the programmable status.

By defect, the ESP_VREF status will be 1, with the function related to Vref remaining disabled.

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5.1.3. Settings

Detection, automation and control functions

The setting parameters of the recloser automation are:

• Enabling the unit: Corresponds to recloser automation activation (ON/OFF).

• Number of reclosings: Deﬁnes the number of reclosings (from 1 to 4).

• Reclosing time for phases: Time which passes from tripping of one of the phase overcurrent units until the reclosing order is given. This can be used to deﬁne a diﬀerent timing for each of the reclosing orders, from the 1st to 4th (from 0.05 s to 600.00 s for the ﬁrst reclosing, and from 1.00 s to 600.00 s for other reclosings).

• Reclosing time for neutral: Time which passes from tripping of one of the neutral overcurrent units until the reclosing order is given. This can be used to deﬁne a diﬀerent timing for each of the reclosing orders, from the 1st to 4th (from 0.05 s to 600.00 s for the ﬁrst reclosing, and from 1.00 s to 600.00 s for other reclosings).

• Unit X reclosing permission: This setting can be used to individually conﬁgure which overcurrent units cause reclosing and which do not once tripped (ON/OFF).

• Reference voltage standby time: Deﬁnes the time to wait after the overcurrent unit trips until the Vref programmable status is set to 1 (from 1.00 s to 600.00 s). The automation will pass to ﬁnal tripping if the status does not set to 1 during this time.

• Safety time after reclosing for phase faults: Deﬁnes the time passed from the recloser giving the closing order until a new cycle can be carried out (from 1.00 s to 600.00 s). This time is used if reclosing is caused by a fault between phases.

• Safety time after reclosing for earth faults: Deﬁnes the time passed from the recloser giving the closing order until a new cycle can be carried out (from 1.00 s to 600.00 s). This time is used if reclosing is caused by an earth fault.

• Safety time after external or manual close: This is deﬁned as the time the recloser waits to pass into idle condition following a manual close, whether locally or remotely (1.00 s to 600.00 s). If a trip occurs during this time period, the recloser will signal ﬁnal trip due to manual closing against short-circuit. The recloser does not pass to idle status until this time expires.

5.1.4. Recloser statuses

The recloser automation implemented in the ekor.rpa-100 system generates a series of signals which report its status. These statuses are:

• Manual/automatic: Depending on the enable setting and the orders received, the recloser may be in manual or automatic status:

Status

Automatic Manual Manual

Table 5.1. Manual/automatic

Activation

setting

On Automatic order On Automatic order Oﬀ Any order

Manual/automatic

order

When the enable setting changes from OFF to ON, it starts from automatic status. If it is in manual status (either due to the enable setting or an order received), the recloser automation will not be operational in the event of overcurrent tripping.

• Blocked/unblocked: Regardless of whether recloser automation is in manual or automatic, it may be blocked due to errors detected by the switch error automation. If this automation detects any failure in the switch, the recloser will switch to blocked status, preventing the recloser from advancing in the event of overcurrent trips.

The recloser automation will only be operational in the event of diﬀerent overcurrent trips if it is in automatic status and unlocked. In these statuses it generates the following signalling:

• Standby: Indicates that the recloser is awaiting overcurrent trips in order to start up with the recloser cycle.

• Under way: Indicates that the recloser is in the recloser cycle. Either by timing a recloser time, or by timing safety time after reclosing.

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• FINAL TRIP: Indicates that the trip caused by the overcurrent unit has been ﬁnal, and there will be no subsequent reclosing.

Busbar voltage

Line currents

Tripping order

Switch status

Reclosing order

Final trip

Standby

Under way

TR = Reclosing time Tb = Safety time after reclosing Tbm = Safety time after manual closing

• RECLOSING ORDER: This is the switch closing order which automation generates after timing the corresponding recloser time.

Figure 5.1. Reclosing order

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5.2. Voltage presence/absence automation

5.2.1. Functionality

This automation allows detection of presence or absence of voltage in those lines where the ekor.rpa unit is installed.

The voltage presence/absence automation individually checks for the presence or absence of voltage in each of the line phases. There are three input signals, one per phase.

Moreover, it determines the presence of voltage in each of the phases, when the measured voltage exceeds a “voltage

level for presence” percentage of the voltage deﬁned as “line voltage”, for a time above the value set as “voltage presence time”. Likewise, it determines the absence of voltage when the voltage drops below a percentage "voltage level for absence" of the line voltage for a period of time longer than the value adjusted as "voltage absence time”. The "line voltage" parameter is the habitual rated phase-to-phase

operating voltage of the medium-voltage line.

Detection, automation and control functions

Presence of voltage

Absence of voltage

Figure 5.2. Presence/absence of voltage

5.2.2. Settings

The setting parameters for the voltage presence/absence automation are:

• Enabling the unit: Corresponds to voltage presence/ absence automation activation (ON/OFF).

• Line voltage: Line voltage setting (from 0.5 kV to

72.0 kV).

• Presence of voltage level: Line voltage percentage above which the automation will consider presence of voltage (from 10% to 120% of line voltage).

5.2.3. Voltage presence/absence automation statuses

The voltage presence/absence automation implemented in the ekor.rpa-100 system generates a series of signals which report its status. These signallings are:

• Presence of voltage for each phase: Independent indication of the presence of voltage for each phase.

• Absence of voltage for each phase: Independent

• Absence of voltage level: Line voltage percentage below which the automation will consider absence of voltage (from 10% to 120% of line voltage).

• Voltage presence/absence hysteresis: Voltage presence/ absence hysteresis (from 10% to 120% of line voltage).

• Presence of voltage time: Timing to indicate presence of voltage (from 0.05 s to 200.00 s).

• Absence of voltage time: Timing to indicate absence of voltage (from 0.05 s to 200.00 s).

indication of the absence of voltage for each phase.

• Presence of line voltage: Indication of presence of line voltage. Can be conﬁgured by user PLC. By default, this indication will be an OR of the phase presences.

• Absence of line voltage: Indication of absence of line voltage. Can be conﬁgured by user PLC. By default, this indication will be an AND of the phase absences.

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5.3. Switch control

5.3.1. Introduction

The ekor.rpa-100 units are equipped with inputs and outputs to operate the switch of the cubicle where are installed, and monitoring functions that detect the status of the primary circuit. The unit ensures that the switch operation is performed within the time allowed by the switchgear. The ekor.rpa-100 units also indicate the earthing switch position. Moreover, the unit can monitor the tripping circuit.

Apart from the functions of operating and monitoring the status of the switch and other functions mentioned above, the switch control unit includes the switch error automation (50BF/State method). This automation consists of timing using a conﬁgurable meter once the system has activated the opening order (due to protection tripping, remote opening operations, external tripping, etc.) or the closing order (due to reclosing, remote closing orders, etc.). If the meter expires before the system detects the change in switch status, it will give a switch error indication, indicating the origin of the opening or closing order. If the system sees the change in switch status before the meter expires, it will give an opening or closing correct indication, indicating the origin of the opening or closing order.

Switch terminal block

Figure 5.3. Switch control

5.3.2. Settings

The setting parameters associated to the switch control shown in the switch error automation (50BF/State method) are:

• Switch opening failure time: The time to control the correct opening of the switch (from 0.10 s to 600.00 s).

• Switch closing failure time: The time to control the correct closing of the switch (from 0.10 s to 600.00 s).

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5.3.3. Switch control statuses

Detection, automation and control functions

The switch control unit implemented in the ekor.rpa-100 system generates a series of signals which report its status. These signallings are:

• Switch status: Indicates the current status of the switch: open or closed.

• Opening correct by protection trip: Indicates that the switch opening caused by protection tripping or external tripping was correct.

• Opening failure by protection trip: Indicates that there was an error in the switch opening caused by protection tripping or external tripping.

• Opening correct by remote opening command: Indicates that the switch opening caused by a remote control order was correct.

5.4. Remote control

The ekor.rpa-100 units are ﬁtted with a serial communication port which can be used for telecontrol, following standard RS-485, allowing connection of up to a maximum of 32 units in a single bus. The 485 port has a twisted pair connection. The Distribution or Transformer Substation telecontrol terminal sends the encoded frames for each of the ekor.rpa-100 units they are connected to via the RS-485 bus. The communication between the communications terminal and the dispatching centre depends on the protocol used.

Some of the functions available through remote control are:

• Switch status display.

• Earthing switch display.

• Switch operation.

• Switch error monitoring.

• Opening failure by remote opening command: Indicates that there was an error in the switch opening caused by a remote control order.

• Correct closing by reclosing: Indicates that the switch closing caused by a reclosing order was correct.

• Closing failure by reclosing: Indicates that there was an error in the switch closing caused by a closing order.

• Correct closing by remote closing command: Indicates that the switch closing caused by a remote control order was correct.

• Closing failure by remote closing command: Indicates that there was an error in the switch closing caused by a remote control order.

• Coil monitoring.

• Phase and neutral current metering with module and angle relative to VA.

• Phase and neutral voltage metering with module and angle relative to VA.

• Active, reactive and apparent power metering.

• Energy metering.

• Display presence/absence of voltage in each phase A, B and C.

• Display and set system parameters.

• Fault reports record.

• Event record.

• Time synchronisation.

• Error/alarm indications.

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6. Sensors

6.1. Current sensors

The sensors are designed for optimal adaptation to the technology of current digital equipment. The protection, metering and control units for these sensors operate with the same algorithms and have the same consistency as conventional devices, adding more advanced algorithms and functions.

Main advantages derived from the use of sensor based systems:

1. Low volume. The decreased power consumption of these transformers enables drastic reduction of their volume.

2. Improved accuracy. Signal acquisition is much more accurate due to high transformation ratios.

3. Wide range. It is not necessary to replace the sensors with others with higher ratios when the power of the installation is increased.

4. Greater safety. Open-air live parts are eliminated to enhance personnel safety.

5. Greater reliability. Comprehensive insulation of the entire installation provides greater levels of protection against external agents.

6. Easy maintenance. It is not necessary to disconnect the sensors when the cable or cubicle is being tested.

Figure 6.1. Current sensor

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6.1.1. Functional characteristics of current sensors

Sensors

The current sensors are toroidal-core current transformers with a high transformation ratio and low rated burden.

Phase current toroidal transformers

Ratio Metering range Metering class

Low range metering class

Protection class Burden Thermal current Dynamic current Frequency Insulation External diameter Internal diameter Height Weight Polarity Encapsulated Thermal class Reference standard

Table 6.2. Current sensors

Self-extinguishing polyurethane Self-extinguishing polyurethane Self-extinguishing polyurethane

300/1 A 1000/1 A 2500/1 A

Extd. 130 % Extd. 130 % Extd. 130 %

0.5 0.5 0.2S

At 1 % of I

± 0.4 % in amplitude

and ± 85 min in phase

31.5 kA – 3 s 31.5 kA – 3 s 31.5 kA – 3 s

50 – 60 Hz 50 – 60 Hz 50 – 60 Hz

0.72/3 kV 0.72/3 kV 0.72/3 kV

S1 – blue, S2 – brown S1–blue, S2–brown S1–blue, S2–brown

B (130 °C) B (130 °C) B (130 °C)

IEC 60044-1 IEC 60044-1 IEC 61869-2

5P20 5P20 5P13

0.18 VA 0.2 VA 0.2 VA

2.5 I

139 mm 139 mm 139 mm

82 mm 82 mm 82 mm 38 mm 38 mm 38 mm

1.350 kg 1.650 kg 1.225 kg

These sensors are encapsulated in self-extinguishing polyurethane resin.

At 0.5 % of I

± 0.35 % in amplitude and

± 25 min in phase

2.5 I

at 12.5 A: ± 0.3 % in amplitude and

At 0.5 % of I

± 20 min in phase

2.6 I

Figure 6.2. Phase toroidal transformer

These toroidal transformers are factory-installed in the cubicle bushings, which signiﬁcantly simpliﬁes the on-site assembly and connection. This means the installation protection is operational once the MV cables are connected to the cubicle. There are no sensor installation errors, due to earthing grids, polarities, etc. since they are previously installed and tested at the factory.

All the current sensors have integrated protection against the opening of secondary circuits, which protects against overvoltages.

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6.1.2. Vector sum/zero-sequence wiring

The transformers described above can be connected in two ways, depending on whether a zero-sequence toroidal current transformer is used or not.

Figure 6.3. Detection of earth current by vector sum Figure 6.4. Detection of earth current with zero-sequence transformer

Zero-sequence current toroidal transformers

Ratio Metering range Protection Metering Burden Thermal current Dynamic current Frequency Insulation External dimensions Internal dimensions Height Weight Polarity Encapsulated Thermal class Reference standard

Table 6.3. Zero-sequence current transformers

Self-extinguishing polyurethane Self-extinguishing polyurethane

300/1 A 1000/1 A

Extd. 130 % Extd. 130 %

5P10 5P10

Class 3 Class 3

0.2 VA 0.2 VA

31.5 kA – 3 s 31.5 kA – 3 s

2.6 I

50 – 60 Hz 50 – 60 Hz

0.72/3 kV 0.72/3 kV

330 x 105 mm 330 x 105 mm

272 x 50 mm 272 x 50 mm

41 mm 41 mm

0.98 kg 0.98 kg

S1 – blue, S2 – brown S1–blue, S2–brown

B (130 °C) B (130 °C)

IEC 60044-1 IEC 60044-1

2.6 I

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6.2. Voltage sensors

6.2.1. Bushing

The cubicle voltage is detected using a capacitor divider incorporated in the cubicle’s bushings. The following precisions are ensured, in accordance with the type of acquisition:

Sensors

Type

Maximum voltage (compound) Transformation ratio Metering class (together with the equipment) Protection class (together with the equipment) Burden Frequency Voltage range (compound) IP Grade Temperature range

Reference standard

Table 6.4. Bushing

Figure 6.5. Voltage pickup

Bushing

Conventional

Standard Calibration on site

40.5 kV

10 kV/60 - 100 µA 10 kV/70 - 100 µA

5 3 1

6P 6P 6P

0.0025 – 0.25 mVA 50 – 60 Hz

10 – 40.5kV

IP65

- 10 °C to + 60 °C IEC 61869-3

IEC 60044-7

Double screen

Figure 6.6. Zero-sequence toroidal transformer

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6.2.2. ekor.evt-c

The ekor.evt-c sensor comprises two elements: an initial EPOXI element which houses an encapsulated capacitor which joins the medium-voltage part to the low-voltage part, applying a transformation ratio at output. The output signal will be conditioned by the second element, a plastic box containing the electronics and the BNC outputs which will connect to the relay or to the corresponding metering equipment.

The sensor measures the voltage through a capacitive coupling. This voltage metering can be delivered in current or voltage, adapting to the diﬀerent relay inputs of current manufacturers on the market. It can also measure partial discharges and establish communication via PLC.

The electronic circuit has two BNC outputs. The ﬁrst one is for voltage metering, whilst the second one is for ﬁltering high frequency signals, PLC communication and metering of partial discharges.

Figure 6.7. ekor.evt-c

ekor.evt-c Voltage sensors (BNC metering output)

Maximum voltage (compound) Transformation ratio Metering class (together with the equipment) Protection class (together with the equipment) Burden: Frequency Voltage range (compound) IP Grade Temperature range Connectors Metering cable

Reference standard

For the BNC output identiﬁed as PLC communications, contact Ormazabal's technical-commercial department

Table 6.5. ekor.evt-c sensor

Coaxial 50 Ω model RG1747/U

36 kV

10 kV/100 µA

0.5 3P

0.01 – 0.15 mVA 50 – 60 Hz

12.1 – 33 kV IP65

- 10 °C to + 60 °C BNC

IEC 61869-3 IEC 60044-7

Figure 6.8. ekor.evt-c dimensions

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General Instructions ekor.rpa

7. Technical characteristics of the equipment

7.1. Rated values

Technical characteristics of the equipment

Power supply

1A Current inputs

Voltage inputs

Accuracy

Frequency Output contacts

Digital inputs

Temperature

Communications

Table 7.1. Rated values

AC 40 VAC...90 VAC ± 20 %; 12 VA DC 24 V Secondary phase Metering 1 mA...1.3 A

Protection 1.3 A...25 A

Secondary earth Metering 0.25 mA...325 mA

Protection 325 mA...6.25 A I thermal/dynamic 31.5 A (3 s) – 2.5 I Impedance 0.02 Ω Metering and protection 1 µA...350 µA Impedance 2.7 kΩ Timing ± 5 % Current Metering class 0.5

Protection class 5P25 Voltage Metering class 0.5

Protection class 3P P/Q Power ± 1.5 % Energy metering

(checking against energy meter standards)

Voltage 250 V Current 6 A (AC) Switching power 1500 VA (resistive load) ED1-5 With internal polarisation ED6-9 External polarisation (max. 48 V Operation - 40 °C...+ 70 °C Storage - 40 °C...+ 70 °C Front port USB Mini-B Rear ports 4 x RJ-45:

Protocol MODBUS (RTU)/PROCOME slave

UNE EN 50470-3 Active class B

IEC 62053-21

IEC 62053-23

...120 VDC ± 10 %; 6 W

Active class 1 Reactive class 2

50 Hz; 60 Hz ± 1 %

- COM0: 1 x RS-485

- COM1: 2 x RS-485

- ETH0: Ethernet

- ETH1: Ethernet LOCAL

+ 15 %)

7.2. Mechanical design

Protection grade

Dimensions (h x w x d): Weight Connection

Table 7.2. Mechanical design

Terminals IP2X In cubicle IP3X

146 x 47 x 165 mm

0.3 kg

Cable/Terminal 0.5...2.5 mm

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7.3. Insulation tests

Insulation resistance Dielectric strength

IEC 60255-5 (2000) 500 VDC; >100 MΩ IEC 60255-5 (2000) 2 kVAC; 50 Hz; 1 min

1 kVAC; 50 Hz; 1 min

Insulation with voltage impulses

IEC 60255-5 (2000) - Common mode:

± 2 kV; 1.2/50 µs; 0.5 J ± 5 kV; 1.2/50 µs; 0.5 J

- Diﬀerential mode: ± 1 kV; 1.2/50 µs; 0.5 J

Table 7.3. Insulation tests

7.4. Electromagnetic compatibility

Radioelectrical interference

Conducted radio emissions EN 55022 (2010) CLASS B 0.15 – 30 MHz: Radiated radio emissions EN 55022 (2010) Class A 30 – 1000 MHz

Immunity

Electrostatic discharges IEC 61000-4-2 (2008) LEVEL 4

Radiofrequency electromagnetic ﬁeld IEC 61000-4-3 (2010) LEVEL 3 10V/m ; 80-3000 MHz

Fast transients IEC 61000-4-4 (2012) LEVEL 4

Shockwaves IEC 61000-4-5 (2005) LEVEL 4

Conducted interference IEC 61000-4-6 (2008) LEVEL 3 10 V

Industrial frequency electromagnetic ﬁeld IEC 61000-4-8 (2009) LEVEL 5

Damped magnetic ﬁeld IEC 61000-4-10 (2001) LEVEL 5 100 A/m; 2 s

Damped wave IEC 61000-4-18 (2011) LEVEL 3

Dips, variations and zero voltage DC IEC 61000-4-29 (2000)

DC Power supply voltage PNI 35.60.01 (January 2013)

DC current peaks PNI 35.60.01 (January 2013)

Table 7.4. Electromagnetic compatibility

- Indirect contact mode: ± 8 kV

- Air mode: ± 15 kV

± 4 kV; 5 kHz ± 2 kV; 5 kHz

- Common mode: ± 4 kV ± 2 kV ± 1 kV

- Diﬀerential mode:

±2 kV ±1 kV

; 0.15 - 80 MHz

RMS

- Continuous: 100 A/m; 50 Hz; 1 min

- Transient: 1000 A/m; 50 Hz; 2 s

- Common mode: ± 2.5 kV

- Diﬀerential mode: ± 1 kV

Voltage dips: Rated Voltage 48 V

- Brief: 100 % dips; 100 ms

- Prolonged: 60 % dips; 1 s

Short interruptions: 0 %; 1 s Voltage variations: 10 % steps, from 38 VDC to 62.5 V

Maximum voltage without failing: 72 VDC (+ 50 % V

rated

) Maximum and minimum voltage within the operation range:

- 38.5 VDC (- 20 % V

- 62.5 VDC (+ 30 % V Voltage below the operation range:

- 33.6 V

- 24 VDC (50 % V

(70 % V

rated

- 14.4 VDC (30 % V

- 4.8 VDC (10 % V

rated

Maximum and minimum voltage within the operation range:

- 38.5 V

(- 20 % V

- 62.5 VDC (+ 30 % V

rated

)

rated

)

rated

)

); < 2.5 A

); < 4 A

rated

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7.5. Climatic tests

Technical characteristics of the equipment

Damp heat Dry heat Cold Temperature variation

Table 7.5. Climatic tests

7.6. Mechanical tests

Vibration

IP Protection grade

Table 7.6. Mechanical tests

IEC 60068-2-64 (2008) Fh

ETSI EN 300 019-2-2 (2012-01) CLASS 2.3 (random)

IEC 60529 (1989) + A1 (1999) IP2XB

7.7. Power tests

No-load cable making and breaking Mainly active load making and breaking

Earth fault making and breaking

Short-circuit making and breaking

Table 7.7. Power tests

IEC 60068-2-78 (2001) 40 °C; 93 % humidity; 96 h IEC 60068-2-2 (2007) 70 °C; 16 h IEC 60068-2-1 (2001) 25 °C; 16 h IEC 60068-2-14 (2009) - 25 °C/70 °C; 3 + 3 h; 5 cycles

7.82 m/s2; 3 x 30 min; X, Y, Z axes:

- 5 – 20 Hz: 1 m2/s3

- 20 – 200 Hz: - 3 dB/octave

IEC 60265-1 (1999) 24 - 36 kV; 85 A IEC 60265-1 (1999) 24 - 36 kV; 200 A ; cos(ϕ)= 0.7

24 - 36 kV; 630 A ; cos(ϕ)= 0.7

IEC 60265-1 (1999) 24 - 36 kV; 200 A; IN= 50 A; cos(ϕ)= 0,7

24 - 36 kV; 200 A; IN= 5 A; cos(ϕ)= 0,7

IEC 60265-1 (1999) 3 kV; 1 kA

10 kV; 3 kA 3 kV; 10 kA 3 kV; 16 kA

7.8. CE Conformity

This product complies with the European Union directive 2014/30/EU on electromagnetic compatibility, and with the IEC 60255 international regulations. The unit has been designed and manufactured for use in industrial areas,

in accordance with EMC standards. This conformity is a result of the test carried out in accordance with article 7 of the Directive.

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8. Protection, metering and control models

8.1. Description of models vs functions

The units to be described are the ekor.rpa-110 and ekor.rpa-120 models. Some models are ﬁtted with v type

(installed in circuit-breaker protection cubicles) and p type (installed in fuse protection circuit-breakers).

These units are located inside the cubicle and interconnect to it via digital inputs and outputs, collecting information from the cubicle elements and operating on its actuators. The connection between the cubicle and the unit is by way of a speciﬁc interconnection terminal block.

The current and voltage sensors, also located inside the cubicle, have their own special terminal block to connect to the unit.

The cubicles (functional units) interconnect to each other and to the ekor.uct (Compact remote control unit, associated technical documentation IG-151) by way of interconnection sleeves, thus extending the communications bus (remote control bus) and distributing the power and control signals to each functional units (cubicle).

The system is conﬁgured via the Web server. The system has an Ethernet port for this purpose. In the event of absence of external power (unit oﬀ), the front mini-USB port (maintenance port) can be used to supply the unit and conﬁgure it using ekor.soft-xml.

Optionally, the ekor.rpa-120 model also has a bus for temperature sensor connection.

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Bistable

output

Protection, metering and control models

Digital inputs: Switch status, earthing switch

status, external trip, etc. Digital outputs: Trip signal. Open switch.

Close the switch. Error (WD)...

Binox bistable release output

Current reading inputs (I1, I2, I3 and In) Terminals X1

Voltage reading inputs (V1, V2 and V3) Terminals X1

RJ-45 Ethernet port (Local conﬁguration):

• Display meterings, switch position statuses, alarms, settings, etc.

• Parametrisation of the system

• Collection of faults and events records.

RS-485 port (Remote control):

• Send signals: Switch position statuses, automation statuses, start-up and tripping signals, substation alarms, voltage presence, etc.

• Send meterings: Currents, voltage, power, etc.

• Send meters: Active energy, etc.

• Receive orders: Open/close, start up automation, etc.

• Time synchronisation

• Upload and download settings

• Collection of faults and events records...

RS-485 Port (Temp sensors bus)

* Optionally for the ekor.rpa-120 model only

Figure 8.1. ekor.rpa-100 connections

Terminals X2

Tripping terminal block

Ethernet 0/1

COM0

COM1

ETH-0

ETH-1

Terminal Block X1

Terminal Block X2

COM0

COM1

Binox release output

Figure 8.2. ekor.rpa-100 connections

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ekor.rpa

8.1.1. ekor.rpa-110

The ekor.rpa-110 protection unit is a unit with multilevel overcurrent protection functions (50/51(1)/51(2)/50N/51N (1)/51N(2)/50NS/51NS(1)/51NS(2)), automatic recloser (79), command and control of the switch (52), etc.

8.1.2. ekor.rpa-120

The ekor.rpa-120 protection unit is a multifunction unit, which has additional functions to the ekor.rpa-110. The overcurrent protection units are supplemented with phase (67) and earth (67N/67NS) directional units. Broken conductor protection (46) and thermal image (49) functions are also included. Since it has voltage metering with protection and precision class, phase overvoltage (59_TEMP/59_INST), residual (59N_TEMP/59N_INST) and phase undervoltage (27_TEMP/27_INST) functions are also added, along with meterings for supervision of voltages, active power, reactive power, and apparent power.

The main applications are facilities where directional methods are required for stopping faults and for greater control and supervision of the facility.

It supervises the current meterings and detects the presence/absence of voltage.

It also has a three-phase energy meter and three singlephases for advanced network supervision functions.

In order to collect direct temperature readings in real time for diﬀerent parts of the facility, there is an option of connecting a series of electronic temperature sensors to the equipment via communications.

These sensors are classiﬁed in two types:

• Environmental metering.

• Transformer interior metering.

The metering obtained through these sensors can be used for monitoring of the cubicle or switch control automations.

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8.1.3. ekor.rpa-100-v/ekor.rpa-100-p

Protection, metering and control models

The ekor.rpa-110 and ekor.rpa-120 models include two types of unit: v type for protection cubicles with circuitbreaker, or p type for protection with fuses. Four diﬀerent systems are therefore deﬁned:

• ekor.rpa-110-v

• ekor.rpa-110-p

• ekor.rpa-120-v

• ekor.rpa-120-p

The main applications v type units (circuit-breaker) are used in are: general protection of lines, private installations, transformers, capacitor stacks, etc. The unit has inputs and outputs for switch monitoring and control.

In the case of p type units (switch with fuses), the electronic unit performs all the protection functions except for the high value polyphase short-circuits that occur in the transformer’s primary. It has inputs and outputs for switch monitoring and control.

ekor.rpa-100 Protection, metering and control units

Model ekor.rpa-110 ekor.rpa-120

Type v p v p

General

Phase current sensors 3 3 3 3 Earth current pickup (with zero-sequence current transformer) Op Op Op Op Voltage sensors 3 3 3 3 Power supply 24 - 120 V Metering 50/60 Hz Ye s Yes Yes Yes Time synchronisation (according to time zone) Ye s Yes Yes Yes Timer curve types: IEC and ANSI/IEEE Yes Yes Yes Yes

Current protection

Phase overcurrent (50-51(1)-51(2)) Yes Yes Yes Yes Earth leakage overcurrent (50 N-51(1) N -51(2) N) Ye s Yes Yes Yes Earth leakage ultrasensitive (50 Ns-51(1) Ns-51(2) Ns) Yes Yes Yes Yes Block by 2nd harmonic Yes Yes Yes Yes Phase directional (67) No No Yes Yes Neutral directional (67N) and sensitive neutral (67Ns) No No Yes Yes Broken conductor detection (46FA) No No Yes Yes Coordination with fuses No Yes No Yes

Voltage protection

Overvoltage (59) and undervoltage (27) No No Yes Yes Residual overvoltage (59N) No No Yes Yes

Temperature protection

Thermal image (49) No No Yes Yes

Detection, automation and control

Detection of voltage presence/absence Yes Yes Yes Yes Detection of energised/de-energised line Op Op Op Op Switch command and control Yes Yes Yes Yes Recloser Yes No Yes No Switch monitoring and control by temperature No No Op Op Other automations No No Op Op 9 inputs/4 outputs Ye s Yes Yes Yes

Indications

Indication of reason for tripping Yes Yes Yes Yes Indication of reason for error Yes Yes Yes Yes

Meterings

Current Yes Yes Yes Yes Voltage No No Yes Yes Voltage and current phasor angles No No Yes Yes

± 10 %/40 - 90 VAC ± 20 % Yes Yes Yes Yes

Continued on next page

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ekor.rpa

Continuation

ekor.rpa-100 Protection, metering and control units

Model ekor.rpa-110 ekor.rpa-120

Type v p v p

Active/reactive/apparent power No No Ye s Yes Energy P+, P-, Q1,…,Q4 No No Yes Yes Thermal image accumulation No No Yes Yes Temperature* No No Op Op

Check (test)

Test blocks for voltage and current injection Yes No Yes No

Communications

MODBUS-RTU Yes Yes Yes Yes Slave PROCOME Yes Yes Yes Yes

Communications ports

Mini USB (front), local conﬁguration with ekor.soft-xml Ye s Yes Yes Yes 2 x Ethernet, local conﬁguration with Web server Ye s Yes Yes Yes 2 x RS-485, for remote control Ye s Yes Yes Yes

* For further information please ask Ormazabal’s technical-commercial department

Table 8.1. ekor.rpa characteristics

8.1.4. Relay configurator

The following conﬁgurator will be used to select the right unit within the ekor.rpa-100 series, in accordance with the characteristics of the installation:

Family Range Model Type Func. I> ED/SD I Pwr. V

ekor .rpa -120 -v 20 2 1 B p

Table 8.2. Congurator

Model:

• 110 – Non-directional overcurrent relay

• 120 – Directional overcurrent relay with voltage functions

Type:

• v – For protection cubicle with circuit-breaker

• p – For protection cubicle with fuses

Overcurrent protection functions:

• 10 – No protection

• 20 – Three phases, neutral (calculated) and sensitive neutral with vector sum

• 30 – Three phases, neutral (calculated) and sensitive

Toroidal-core transformers:

• 0 – No toroidal-core transformers, control only

• 1 – Ratio 300/1

• 2 – Ratio 1000/1

• 4 – Ratio 2500/1

Power supply:

• B – Auxiliary power supply (Battery, UPS, etc.)

Voltage sensors

• P – Conventional/double screen bushing (in accordance with cubicle conﬁguration)

• EVT – Voltage sensor

neutral with zero-sequence toroidal transformers

Inputs/outputs:

• 2 – 9 inputs/4 outputs

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General Instructions ekor.rpa

8.2. “v” type ekor.rpa-110-v and ekor.rpa-120-v units

8.2.1. Functional description

The ekor.rpa-110-v and ekor.rpa-120-v units are designed for general protection of lines, transformer protection, etc. They are installed in circuit-breaker protection cubicles, where all protection functions are performed by the electronic unit.

The main function of this equipment is to protect, i.e. it has the capability to quickly, unequivocally and quickly detect anomalies in the network, and to send the trip order to the cubicle where it is installed safely and without delay. Safety of the whole tripping chain starts from the correct reading of the meterings and ﬁnishes with the disconnection of the section aﬀected by the failure or incident. All this chain is made up of several diﬀerent parts which interlink in a serial manner, meaning failure in any of them can lead to an error in opening or false tripping. Given their importance, the solutions delivered with these systems are for all the parts overall.

Protection, metering and control models

The equipment can give the trip order directly (with energy stored in the system itself) on the low energy bistable release (Binox) and/or on a tripping coil by activating a physical output.

Interconnection terminal block

ekor.rpa-110-v or ekor.rpa-120-v Unit

Voltage and current sensors

Figure 8.3. ekor.rpa-100-v

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ekor.rpa

8.2.2. Definition of digital inputs/outputs

The ekor.rpa-110-v and ekor.rpa-120-v protection, metering and control units are ﬁtted with a series of physical inputs and outputs that are isolated from the other independent circuits (terminals X2). The standard deﬁnition of the inputs and outputs is as follows:

Physical inputs Physical ouputs

External trip

Switch closed

Switch open

Disconnector in busbar position

Disconnector in open position

Switch in earthing position

Springs loaded

Anti-pumping relay

Monitoring of the closing coil (in the open and closed positions)

E9*

* Where E9 must be associated to open coil monitoring

S1 S2 S3 S4

Trip indication Watchdog Opening sequence Closing order

Table 8.3. ekor.rpa inputs/outputs

The functionality of the inputs and outputs presented is typical of cubicle installations: However, there is always the option of including diﬀerent or new conﬁgurations. Contact Ormazabal's technicalcommercial department in order to ensure new conﬁgurations are properly installed in the functional unit, or to obtain further information and details.

The inputs and outputs conﬁguration of the relay, signals accessible from the ekor.rpa-110-v and ekor.rpa-120-v terminal block is shown below.

Figure 8.4. ekor.rpa inputs/outputs conguration

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8.2.3. Installation in a cubicle

Protection, metering and control models

The components of the ekor.rpa-110-v and ekor.rpa-120-v units are the electronic relay, voltage and current sensors, bistable tripping device (Binox), tripping coil and interconnection terminal block.

The electronic relay is secured to the cubicle driving mechanism with anchors. The front of the device, which houses the components of the user interface, display, keys, mini-USB port, etc., is accessible from the outside without the need to remove the mechanism enclosure.

The connectors for the relay (Relay Terminal Block), which interconnects with the driving mechanism connectors (Terminal Block-A) and the current and voltage sensors

Terminals

group

Interconnection

terminal block

ekor.rpa-110-v

ekor.rpa-120-v

electronic relay

Voltage and

current sensors

Table 8.4. Installation

Subgroup Terminals Functionality and common use

1.1

Power and

communications bus

1.2

Relay terminal block

1.3.

Cubicle terminal block

* See relay terminals. * See relay terminals functionality.

3.1.

Current transformer

connectors

3.2.

Capacitive sensor

connectors

Interconnection

connectors

Terminal block–A

Terminal block–G

Temperature bus

connector

P.M. • Additional energy module for bistable release.

Terminal block-52

Terminal block–J

Connector-CTD

Connector-Ip

Connector-D

(Terminal Block-G: Test blocks for voltage and current injection) are located in the top of the relay and at the back of the driving mechanism.

The cubicle with the integrated ekor.rpa-100 unit interconnects with other cubicles, with the power units and with the remote control unit using interconnection sleeves (communications and power bus). This interconnection feeds the diﬀerent cubicle devices (relay, coils, motors, etc.) and closes the substation's local communications bus.

Installation by functional unit can be classiﬁed in the following parts:

• Interconnection between cubicles.

• Interconnection power system and communications bus.

• Cubicle power supply (relay, coils, motors, etc.)

• Relay communication.

• Cabled signalling exchange.

• Interconnection terminal block between the cubicle terminal block and the relay.

• Accessible points for checks or tests.

• Voltage and current secondary circuit shortable and disconnectable terminals.

• Current and voltage injection for relay tests through the secondary circuit.

• Communications interconnection connector between relay and temperature sensors and power supply sensors.

• Connection point for new sensors and sensor check.

• Interconnection terminal block between the relay terminal block and the switch control.

• Interconnection terminal block between earthing and busbar sectionaliser control with the relay terminal block.

• Connector which interconnects with the relay (optionally with the energy module) and the Binox bistable.

• Checkpoint relay trip and Binox bistable activation correct.

• Interconnection connector between current sensors and test terminal block.

• Sensor disconnection in cable compartment.

• Interconnection connector between voltage sensors and test terminal block.

• Sensor disconnection in cable compartment.

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ekor.rpa

The description presented is for standard conﬁguration. Optionally, other alternatives can be assessed, such as positioning the unit in a control box installed on the cubicle.

For further information or details on conﬁgurations (schematic, etc.), contact Ormazabal's technical-

Release

I&V Sensors

Interconnection terminal block

Power and communications bus

1.1

Relay terminal block

1.2

Cubicle terminal block

1.3

ekor.rpa-110-v or ekor.rpa-120-v Electronic relay

Voltage and current sensors

Sensors interconnection

3.1

Figure 8.5. ekor.rpa installation

commercial department for your zone.

8.2.4. Checking and maintenance

The ekor.rpa-110-v and ekor.rpa-120-v control units are designed to carry out the operating checks necessary for both commissioning and regular maintenance checks. Several levels are available, depending on the possibility of interrupting service and accessing the medium-voltage cubicle cable compartment.

Primary check (for current circuit)

In this case the tests are performed on the system when it is completely shut down, since it involves actuating the circuit-breaker and earthing the outgoing cables from the cubicle. Current is injected through the toroidal-core current transformers, and it must be checked that the protection opens the circuit-breaker within the selected time. In addition, you must make sure that the tripping indications are correct and that all the events are being recorded in the log.

In circuit-breaker cubicles, the current transformers are installed in the cubicle's bushing (for most types of connectors). This means there are no problems with connection errors in the earthing grid. Additionally, these toroidal-core current transformers are equipped with a test connection (test ﬂat bar) for maintenance operations.

To perform this check, follow the steps indicated below:

1. Follow the cubicle switching sequence for earthing, in order to access the cable compartment.

2. Access the cable compartment and connect the test cable to the test connector of the toroidal-core current transformers.

3. Connect the test cable to the current circuit of the tester.

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Protection, metering and control models

4. Connect the trip indication signal (depending on the

programmed function) to the tester's timer stop input.

5. Inject the test currents, additionally secondary circuit voltage, in order to test the directional or voltage units and ensure that the switch opens and the tripping times are correct.

6. Trip tests must be performed for all toroidal-core current transformers to check the proper operation of the complete unit.

1. For phase trip tests, the test cable must be connected to the test ﬂat bars of two toroidal-core current transformers. Current therefore passes through them in contrary direction and neutral current is not generated. In the case of neutral trips, the test cable is connected to a single toroidal-core current transformer (zero-sequence or phase, depending on whether a zero-sequence transformer is available or not).

2. Injecting through these test ﬂatbars means the current ﬂow direction is opposite to that of an output cubicle; this must be taken into account when carrying out tests involving current direction.

Check by secondary

The current and voltage injection tests for checks by secondary are carried out through the test terminals enabled for this purpose. These terminals allow the unit's sensors to be disconnected, leaving the sensor circuits closed and the unit inputs open in order to connect the test kit.

Important: correct connection between sensors and relay must be ensured once the tests have concluded.

Check by secondary with circuit-breaker operation

In this case, the tests are performed on the equipment when the cable compartment is not accessible. This occurs because the cubicle outgoing cables are energised and cannot be connected to earth. In this case, the test cable cannot be connected to the test connection in the toroidalcore current transformers and the current injection is performed through the test terminal block.

This testing method is also used when the primary circuit current values being tested are much greater than those produced by test equipment (normally greater than 100 A), and in consequence the tests cannot be carried out from primary.

1. To perform this check, follow the steps indicated below:

2. Access the driving mechanism upper compartment,

where the checks and tests terminal block is located.

3. Short-circuit, and then disconnect the voltage and current circuit terminals. This procedure short-circuits the current transformer secondary circuits and branches the voltage sensor signal to earth.

4. Connect the test cable to the terminals, taking into account the diﬀerentiation between current and voltage circuits, and the channel through which it is to be injected.

5. Connect the test cable to the current and/or voltage circuit of the tester.

6. Connect the trip indication output (depending on the programmed functionality) to the tester’s timing stop input.

7. If the circuit-breaker can be opened, put it in closed position. If the circuit-breaker cannot be operated, make sure the bistable release (BINOX) and the tripping coil remain disconnected, and start the check as explained in the following section "Check by secondary without using the circuit-breaker”.

8. Inject secondary test voltages and currents, taking into account the current transformer ratios, and calibrate voltage injection with the test capacitors.

Check by secondary without circuit-breaker operation

The protection cubicle circuit-breaker often cannot be operated and therefore the maintenance checks are performed exclusively on the electronic unit. In these cases, the following points should be taken into account:

1. Always disconnect the bistable release and the tripping coil. This way, the relay can trip without acting upon the opening mechanism.

2. Then inject the current according to the section above, called "Check through secondary with circuit-breaker operation”.

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8.3. “p” type ekor.rpa-110-p and ekor.rpa-120-p units

8.3.1. Functional description

The ekor.rpa-110-p and ekor.rpa-120-p protection, metering and control units are focused on protection for distribution transformers. They are installed in fusecombination switch cubicles so the electronic system performs all the protection functions, except high polyphase short-circuit values, which are cleared by the fuses.

When an overcurrent that is within the values in which the load break switch can open is detected, the relay acts on a low-power bistable release that opens the switch. If the fault current is greater than the breaking capacity of the load break switch, the switch trip is blocked so that the fuses will blow to protect the cubicle. On the other hand, the equipment is disconnected and the fuses do not remain energised.

Terminal block

ekor.rpa-110-p or ekor.rpa-120-p electronic relay

Voltage and current sensors

Figure 8.6. ekor.rpa-100-p

Figure 8.7. Transformer protection

Figure 8.8. General protection (customer supply in MV)

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8.3.2. Definition of digital inputs/outputs

The ekor.rpa-110-p and ekor.rpa-120-p protection, metering and control units are ﬁtted with a series of physical inputs and outputs that are isolated from the other independent circuits (terminals X2). The standard deﬁnition of the inputs and outputs is as follows:

Physical inputs Physical ouputs

External trip

Switch closed

Switch open

Disconnector closed

Fuse blow closed

General purpose

Table 8.5. Ratio of signals available for the nine inputs and

four outputs module

S1 S2 S3 S4

Protection, metering and control models

Trip indication Watchdog Opening sequence Closing order

The speciﬁc functions of the inputs and outputs depend on the installation and can be diﬀerent to that shown in the tables above. Please see the installation diagrams to check the speciﬁc functions of these inputs and outputs.

The inputs and outputs conﬁguration of the relay, signals accessible from the ekor.rpa-110-p and ekor.rpa-120-p terminal block for 9 inputs 4 outputs is shown below.

Figure 8.9. Relay inputs and outputs conguration

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ekor.rpa

8.3.3. Fuse protection

The ekor.rpa-110/120-p unit is used for transformer protection, and works in combination with the fuse protection.

The process for choosing the protection parameters for the

ekor.rpa-110/120-p cubicle unit is as follows:

1. Determine the required fuse rating to protect the

transformer in accordance with the fuse table of each cubicle family. Check the maximum and minimum calibres in the (IG) for each cubicle system, in accordance with the line voltage level where they are to be used.

2. Calculate the machine's rated current I

= S/√3 x Un.

3. Deﬁne the continuous overload level I>. Normal values in transformers of up to 2000 kVA are 20 % for distribution installations and 5 % for power generation installations.

4. Select the transient overload curve. Coordination between relay curves and LV fuses is performed with the EI type curve.

5. Deﬁne the delay time in transient overload K. This parameter is deﬁned by the transformer’s thermal constant. This way, the greater the constant, the longer it takes for the transformer’s temperature to increase under an overload condition; and therefore, the protection trip can be delayed longer. The normal value for distribution transformers is K = 0.2, which means that it trips in 2 s if the overload is 300 % in the EI curve.

6. Short-circuit level I>>. The maximum value of the transformer’s magnetisation current must be determined. The current peak produced when a noload transformer is connected, due to the eﬀect of a magnetised nucleus, is several times greater than the rated current. This peak value, up to 12 times the rated value (10 times for more than 1000 kVA) has a very high harmonic content, so its fundamental 50 Hz component is much less. Therefore, a usual setting value for this parameter is between 7 and 10.

7. Instantaneous timing T>>. This value corresponds to protection trip time in the event a short-circuit occurring. It depends on coordination with other protections and the normal values are between 0.1 and 0.5 s. Whenever the short-circuit value is high, the fuses will act in the time speciﬁed by their characteristic curve.

8. Determine the current value in case of secondary threephase short-circuit. This fault must be cleared by the fuses, and it corresponds with the intersection point’s maximum value between the relay and the fuse curves. If the intersection point is greater than the secondary short-circuit value, the settings must be adjusted to meet this requirement.

Example: When protecting a transformer with following characteristics in a cgmcosmos cubicle system up to 24 kV:

a. Choice of fuse in accordance with IG-078.

Fuse 10/24 kV 125 A

b. Rated current.

I = S/√3 x U = 1250 kVA/√3 x 15 kV = 48 A

c. Continuous withstand overload 20 %.

x I> = 48 A x 1.2 = 58 A

d. Extremely Inverse Curve type. E.I. e. Transient overload factor. K = 0.2 f. Short-circuit level. I> x I>> = 58 x 7 = 404 A g. Instantaneous timing T>> = 0.4 s h. Secondary short-circuit.

= In x 100/Uk = 48 A x 100/5 = 960 A

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General Instructions ekor.rpa

Protection, metering and control models

Choice of fuse 125 A

Rated current 48 A

Continuous overload 58 A

Curve type E.I.

Factor K = 0.2

Short-circuit level 404 A

Instantaneous timing 400 ms

Secondary three-phase short-circuit 960 A

Fuse operation zone

Relay operation zone

Time

(s)

Current

(A)

Figure 8.10. Example for SIBA SSK fuse

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ekor.rpa

The earth unit setting depends on the characteristics of the line where the unit is installed. In general, the earth fault values are high enough to be detected as overcurrent. Even in isolated or resonant earthed neutral networks, the fault value in transformer protection installations is clearly diﬀerent from the capacitive currents of the lines. The values of the setting parameters must guarantee selectivity with the main switch protections. Given the variety of protection

Unit Type Designation Value

Enabling the unit Enable ON

Phase timed unit (1)

(UNIT_51)

Phase instantaneous unit (1)

(UNIT_50)

Sensitive neutral timed unit

(1)

(UNIT_51NS)

Sensitive neutral

instantaneous unit

(UNIT_50NS)

Table 8.6. Settings

Starting up the unit Pick_up* 58 (A) Time curve Curve EI Inverse curve time index Index 0.20 Fixed time Time --Torque control Direction OFF Enabling the unit Enable ON Starting up the unit Pick_up 404 (A) Unit timing Time 0.40 (s) Torque control Direction --Enabling the unit Enable ON Starting up the unit Pick_up 2 (A) Time curve Curve NI Inverse curve time index Index 0.20 Fixed time Time --Torque control Direction OFF Enabling the unit Enable ON Starting up the unit Pick_up 10 (A) Unit timing Time 0.40 (s) Torque control Direction OFF

criteria and types of neutral used in the networks, a single parameterisation cannot be indicated; each case requires a speciﬁc parameterisation. For transformers up to 2000 kVA, the settings below are given as a general example. It must be ensured that they properly apply to the protections upstream (general, line or main switch protections, among others.)

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General Instructions ekor.rpa

8.3.4. Installation in a cubicle

The components of the ekor.rpa-110-p and ekor.rpa-120-p units are, as with the ekor.rpa-110/120-v, the electronic relay, voltage and current sensors, bistable tripping device (binox), tripping coil and interconnection terminal block.

The main diﬀerence is that the circuit-breaker cubicle has terminal block-52 (switch control terminal), while the fuse protection cubicle has terminal block-R (fuse status indication terminal block). Furthermore, the G-tests terminal blocks are not included as a standard option in the fuse-protected cubicle.

Installation by functional unit can be classiﬁed in the following parts:

The description presented is for standard conﬁguration. Optionally, other conﬁgurations or test terminals can be added, as well as positioning the unit in a control box installed on the cubicle.

For further information or details on conﬁgurations (schematic, etc.), contact Ormazabal's technicalcommercial department for your zone.

Protection, metering and control models

Release

I&V Sensors

Interconection terminal block

Power and communications bus

1.1

Relay terminal block

1.2

Cubicle terminal block

1.3

ekor.rpa-110-p or ekor.rpa-120-p electronic relay

Voltage and current sensors

Sensors interconnection

3.1

Figure 8.11. ekor.rpa installation

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ekor.rpa

8.3.5. Checking and maintenance

The solution for facilities with ekor.rpa-110-p and ekor.rpa-120-p units does not have a test terminal block in

the standard solution, with the option of making the checks from primary only.

In this type of cubicles, the current transformers are installed on the cable. This means special care must be taken, since any incorrect installation of the transformers can result in unwanted tripping which is not real. Incorrect installation is not detected in the commissioning tests and must be taken into account when installing.

The indications to be taken into account are detailed below:

1. The toroidal-core current transformers are installed on the outgoing cables of the cubicle.

2. The earthing screen MUST go through the toroidalcore current transformer when it comes out of the part of cable remaining above the toroidal-core current transformer. In this case, the twisted pair goes through the inside of the transformers before it is connected to the cubicle's earthing collector. The twisted pair must not touch any metal part, such as the cable support or other areas of the cable compartment, before it is connected to the cubicle's earth.

3. The earthing screen must NOT go through the toroidalcore current transformer when it comes out of the part of the cable remaining under the toroidal-core current transformer. In this case, the twisted pair is connected directly to the earthing collector of the cubicle. If there is no twisted pair for the earthing screen, because it is connected at the other end (as in metering cubicles), the twisted pair should also not go through the toroidal-core current transformer.

Earth screen: It must pass through the inside of the current

transformers

Figure 8.12. Installation of toroidal-core current transformers

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General Instructions ekor.rpa

9. User configuration settings

User configuration settings

The current units have a large number of conﬁguration parameters and logical organisation is fundamental in order to avoid errors in generating and translating the settings. A tree structure for easier browsing can be achieved by organising them by groups of diﬀerent levels. The ultimate goal is to help end-users to use the system correctly and avoid ambiguities.

The format used for settings is based on XML (eXtensible Markup Language). XML is a standard language for exchanging structured information. This format gives the system the scalability and ﬂexibility necessary in order to continue growing when new functions come about in the future.

9.1. Local protection and automation settings

The settings list is classiﬁed as follows:

• System information (INFORMATION). Read-only.

• System settings (SETTINGS)

- General settings (GENERAL_SETTINGS)

System information (INFORMATION)

The applications necessary to transform the data into information or to share information are applications which follow the rules of this same standard, thus improving compatibility between the systems in a secure, reliable and straightforward manner.

The system conﬁguration settings ﬁles, at user level, are made up of the following main groups:

• Local protection and automation settings

• Date and time settings.

• Remote communication settings.

• Automation settings for the facility.

- Protection settings (PROTECTION)

- Automation settings (AUTOMATISM)

- Local port communication settings (COMMUNICATION)

Node

System Device ekor.rpa-100 Read Only Equipment model Model 10202021/2022/2024/3021/3022/3024 Read Only Range Range 110/120 Read Only Type Type V/P Read Only

System

Table 9.1. Information

Type of coupling Coupling

System serial number Serial_Number Aaabbccddd (family/year/week/unit) Read Only System ﬁrmware version FW_Version aa.bb.cc (Version. Subversion. Revision) Read Only Logic conﬁguration identiﬁer Logic_Conﬁguration_Id. 6 digits with logic conﬁguration identiﬁer Read Only

Type Designation Possible values Value by default

System settings (SETTINGS)

General settings (GENERAL_SETTINGS)

Node

General

Table 9.2. Settings

Network frequency Frequency 50 – 60 (Hz) Time zone Time_Zone

Type Designation

Information

One-core/Three-core/Calibrated/EVTC/ Busbar1/Busbar2/Busbar3/Busbar4/Busbar5/ Busbar6/cgm3/cosmos/etc.

Settings

Range

Min. Max. Step (unit)

Read Only

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User configuration settings General Instructions

ekor.rpa

Protection settings (PROTECTION)

Settings

Type Class Node

Phase timed

unit (1)

(UNIT_51)

Phase timed

unit (2)

(UNIT_51_2)

Phase

instantaneous

unit (1)

(UNIT_50)

Current protection

(CURRENT_PROTECTION)

(OVERCURRENT)

Overcurrent protection

Neutral timed

unit (1)

(UNIT_51N)

Neutral timed

unit (2)

(UNIT_51_2_N)

Neutral

instantaneous

unit

(UNIT_50N)

Type Designation

Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Unit timing Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit Pick_up*

Unit timing Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE

Min. Max. Step (unit)

5.0

15.0

37.5 IEC: DT, NI, VI, EI, STI and LTI

5.0

15.0

37.5 IEC: DT, NI, VI, EI, STI and LTI

5.0

15.0

37.5

5.0

15.0

37.5 IEC: DT, NI, VI, EI, STI and LTI

5.0

15.0

37.5 IEC: DT, NI, VI, EI, STI and LTI

5.0

15.0

37.5

Range

6000.0 20 000.0 50 000.0

ANSI: NI, VI, EI and LI

6000.0 20,000.0 50,000.0

ANSI: NI, VI, EI and LI

6000.0 20,000.0 50,000.0

ANSI: NI, VI, EI and LI

6000.0 20,000.0 50,000.0

ANSI: NI, VI, EI and LI

6000.0 20,000.0 50,000.0

Continued on next page

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General Instructions ekor.rpa

Continuation

Type Class Node

Sensitive

neutral timed

unit (1)

(UNIT_51NS)

Sensitive

neutral timed

unit (2)

(UNIT_51_2_

Current protection

(CURRENT_PROTECTION)

(OVERCURRENT)

Overcurrent protection

(DIRECTIONAL)

Directional units

NS)

Sensitive

neutral

instantaneous

unit

(UNIT_50NS)

Phase

directional unit

(UNIT_67)

Neutral

directional unit

(UNIT_67N)

Sensitive

neutral

directional unit

(UNIT_67NS)

User configuration settings

Settings

Type Designation

Enabling the unit Enable ON/OFF

Pick_up*

(with vector sum)

Starting up the unit

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF

Starting up the unit

Unit timing Time 0.00 100.00 0.01 (s) Torque control Direction OFF/FORWARD/REVERSE

Characteristic phase angle

Minimum phases voltage V_min 0.5 72.0 0.1 (kV) Indeterminate zone Indeterminate_zone 0.0 90.0 0.1 (º) Directional method type Type ANG/WAT

Characteristic neutral angle

Minimum neutral active power P_min 2.5 15 000.0 0.1 (kW) Minimum neutral voltage V_min 0.5 72.0 0.1 (kV ) Indeterminate zone Indeterminate_zone 0.0 90.0 0.1 (º) Directional method type Type ANG/WAT

Characteristic sensitive neutral angle

Minimum neutral active power P_min 2.5 15,000.0 0.1 (kW) Minimum neutral voltage V_min 0.5 72.0 0.1 (kV ) Indeterminate zone Indeterminate_zone 0.0 90.0 0.1 (º)

Pick_up*

(with zero-sequence

toroidal)

Pick_up*

(with vector sum)

Pick_up*

(with zero-sequence

toroidal)

Pick_up*

(with vector sum)

Pick_up*

(with zero-sequence

toroidal)

Characteristic

Angle

Characteristic

Angle

Characteristic

Angle

Min. Max. Step (unit)

0.5

1.5

0.3

0.3 IEC: DT, NI, VI, EI, STI and LTI

0.5

1.5

3.7

0.3

0.3 IEC: DT, NI, VI, EI, STI and LTI

0.5

1.5

3.7

0.3

90.0 90.0 0.1 (º)

-90.0 90.0 0.1 (º)

Range

1500.0

5000.0

1500.0

5000.0

ANSI: NI, VI, EI and LI

1500.0

5000.0

12,500.0

1500.0

5000.0

ANSI: NI, VI, EI and LI

1500.0

5000.0

12,500.0

1500.0

5000.0

Continued on next page

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ekor.rpa

Continuation

Settings

Type Class Node

Broken

conductor unit

(UNIT_46BC)

protection

Negative sequence

(NEGATIVE SEQUENCE)

Current protection

Voltage protection

(CURRENT_PROTECTION)

(VOLTAGE_PROTECTION)

Undervoltage protection

harmonic

blocking unit

(SECOND_

HARMONIC)

Blocking units (BLOCKING)

Undervoltage

timed unit (UNIT_27_

Undervoltage

UNDERVOLTAGE

instantaneous

(UNIT_27_

Second

TEMP)

unit

INST)

Type Designation

Enabling the unit Enable ON/OFF

Base current Base_current I

Starting up the unit (I2/I1) Pick_up_ratio 0.05 0.50 0.01 (pu)

Unit timing Time 0.05 600.00 0.01 (s)

Current threshold for phases Min_phase_current*

Maximum current threshold for neutral

Enabling the unit Enable ON/OFF

Second harmonic threshold

Type of cross-blocking Cross_blocking OFF/1_OUT_OF_3/2_OUT_OF_3

Minimum current threshold for phases Min_phase_current

Minimum current threshold for calculated neutral

Minimum current threshold for measured neutral

Maximum current threshold for phases Max_phase_current

Maximum block time Max_blocking_time 0.01 5.00 0.01 (s) Unit blocking mode 51 Blocking_51 OFF/TRIP/TIMING/UNIT Unit blocking mode 51_2 Blocking_51_2 OFF/TRIP/TIMING/UNIT Unit blocking mode 50 Blocking_50 OFF/TRIP/TIMING/UNIT Unit blocking mode 51N Blocking_51N OFF/TRIP/TIMING/UNIT Unit blocking mode 51N_2 Blocking_51N_2 OFF/TRIP/TIMING/UNIT Unit blocking mode 50N Blocking_50N OFF/TRIP/TIMING/UNIT Unit blocking mode 51NS Blocking_51NS OFF/TRIP/TIMING/UNIT Unit blocking mode 51NS_2 Blocking_51NS_2 OFF/TRIP/TIMING/UNIT Unit blocking mode 50NS Blocking_50NS OFF/TRIP/TIMING/UNIT Enabling the unit Enable ON/OFF

Working voltage Voltage

Starting up the unit Pick_up 0.5 72.0 0.1 (kV)

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Enabling the unit Enable ON/OFF

Working voltage Voltage

Starting up the unit Pick_up 0.5 72.0 0.1 (kV) Unit timing Time 0.00 1800.00 0.01 (s)

Max_homo_current_

ratio

Second_harmonic_

threshold

Min_neutral_current

Min_sensit_neutral_

current

Min. Max. Step (unit)

0.3

10.0

25.0

0.00 0.50 0.01 (s)

5.0 100.0 0.1 (%)

5.0

15.0

37.5

5.0

15.0

37.5

0.3

5.0

15.0

37.5

IEC: DT, NI, VI, EI, STI and LTI

Range

/I1

300.0

1000.0

2500.0

6000.0 20,000.0 50,000.0

1500.0

5000.0

6000.0 20,000.0 50,000.0

PHASE-TO-NEUTRAL

PHASE-TO-PHASE

ANSI: NI, VI, EI and LI

PHASE-TO-NEUTRAL

PHASE-TO-PHASE

Continued on next page

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User configuration settings

ekor.rpa

Continuation

Settings

Type Class Node

Overvoltage

timed

unit(UNIT_59_

TEMP)

Overvoltage

instantaneous

unit

(UNIT_59_

INST)

Neutral

PROTECTION)

Thermal overload

(OVERVOLTAGE)

Overvoltage protection

protection

(THERMALOVERLOAD)

overvoltage

timed unit

(UNIT_59N_

TEMP)

Neutral

overvoltage

instantaneous

unit(UNIT_59N_

INST)

Thermal image

unit

(UNIT_49)

Voltage protection

(VOLTAGE_PROTECTION)

(TEMPERATURE_

Temperature protection

Enabling the unit Enable ON/OFF

Working voltage Voltage

Starting up the unit Pick_up 0.5 72.0 0.1 (kV)

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s) Enabling the unit Enable ON/OFF

Working voltage Voltage

Starting up the unit Pick_up 0.5 72.0 0.1 (kV) Unit timing Time 0.00 1800.00 0.01 (s) Enabling the unit Enable ON/OFF Starting up the unit Pick_up 0.5 72.0 0.1 (kV)

Time curve Curve

Inverse curve time index Index 0.05 1.60 0.01 Fixed time Time 0.00 100.00 0.01 (s)

Enabling the unit Enable ON/OFF

Starting up the unit Pick_up 0.5 72.0 0.1 (kV)

Unit timing Time 0.00 100.00 0.01 (s)

Enabling the unit Enable ON/OFF Temperature rise constant Heating_Constant 3 60 1 (min) Cooling constant Cooling_Constant 3 180 1 (min) Alarm level Alarm_Threshold 80 100 1 (%) Trip level Trip_Threshold 100 200 1 (%) Trip reset level Restore_Threshold 50 99 1 (%)

Rated current Nominal_Current*

Type Designation

Min. Max. Step (unit)

IEC: DT, NI, VI, EI, STI and LTI

5.0

15.0

37.5

* The diﬀerent ranges for these settings are relative to the current transformers installed (300/1, 1000/1 and 2500/1 respectively)

Range

PHASE-TO-NEUTRAL

PHASE-TO-PHASE

ANSI: NI, VI, EI and LI

PHASE-TO-NEUTRAL

PHASE-TO-PHASE

ANSI: NI, VI, EI and LI

6000.0 20,000.0 50,000.0

0.1 (A)

Table 9.3. Protection

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ekor.rpa

Automation settings (AUTOMATISM)

Settings

Node

Recloser automation

Type Designation

Enabling the unit Enable ON/OFF Number of reclosings Reclose_Number 0 4 1 First recl. time for phases Phase_Reclosing_Time_1 0.05 600.00 0.01 (s)

First recl. time for neutral

Second recl. time for phases Phase_Reclosing_Time_2 1.00 600.00 0.01 (s)

Second recl. time for neutral

Third recl. time for phases Phase_Reclosing_Time_3 1.00 600.00 0.01 (s)

Third recl. time for neutral

Fourth recl. time for phases Phase_Reclosing_Time_4 1.00 600.00 0.01 (s)

Fourth recl. time for neutral

Reclosing Permission for unit 50 Mask 50 ON/OFF Reclosing Permission for unit 51 (1) Mask 51 ON/OFF Reclosing Permission for unit 51 (2) Mask 51_2 ON/OFF

(RECLOSER)

Reclosing Permission for unit 50N Mask 50N ON/OFF Reclosing Permission for unit 51N (1) Mask 51N ON/OFF Reclosing Permission for unit 51N (2) Mask 51N_2 ON/OFF Reclosing Permission for unit 50NS Mask 50NS ON/OFF Reclosing Permission for unit 51NS (1) Mask 51NS ON/OFF Reclosing Permission for unit 51NS (2) Mask 51NS_2 ON/OFF Reference voltage standby time Vref_Time 1.00 600.00 0.01 (s) Safety time following phase fault

reclosing Safety time following neutral fault

reclosing Safety time after external or manual

Neutral_Reclosing_ Time_1

Neutral_Reclosing_ Time_2

Neutral_Reclosing_ Time_3

Neutral_Reclosing_ Time_4

Phase_Blocking_Time 1.00 600.00 0.01 (s)

Neutral_Blocking_Time 1.00 600.00 0.01 (s)

Manual_Blocking_Time 1.00 600.00 0.01 (s)

Min. Max. Step (unit)

0.05 600.00 0.01 (s)

1.00 600.00 0.01 (s)

Range

Switch opening failure time Opening_Error_time 0.10 600.00 0.01 (s)

(UNIT_50BF)

State method

Switch closing failure time Closing_Error_Time 0.10 600.00 0.01 (s)

Switch error automation

Voltage presence/

Table 9.4. Automation

(STATUS_METHOD)

Enabling the unit Enable ON/OFF

Line voltage Grid_Voltage 0.5 72.0 0.1 (kV)

Presence of voltage level Presence_Voltage 10.0 120.0 1.0 (%)

Absence of voltage level Absence_Voltage 10.0 120.0 1.0 (%)

Voltage presence/absence hysteresis Hysteresis_Voltage 0.0 100.0 0.1 (%)

ABSENCE)

Presence of voltage time Presence_Time 0.05 200.00 0.01 (s)

absence automation

Absence of voltage time Absence_Time 0.05 200.00 0.01 (s)

(VOLTAGE PRESENCE_

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General Instructions ekor.rpa

Communication settings (COMMUNICATION)

Node

Peripheral number Perif_Num 1 99 1 Speed Baud rate 1200/2400/4800/9600/19200/38400 baud

COM_485

COM_

VIRTUAL

Table 9.5. Communication

Parity Parity No/Odd/Even Length Length 7 8 1 Stop bits Stopbits 1 2 1 Protocol Protocol CIRBUS/MODBUS/PROCOME Peripheral number Perif_Num 1 99 1 Protocol Protocol CIRBUS/MODBUS/PROCOME

Type Designation

9.2. Date and time settings

Settings (LOCAL_TIME_CLOCK)

User configuration settings

Settings

Range

Min. Max. Step (unit)

Node

Date

(DATE)

Time

(TIME)

Table 9.6. Date and time setting

Day Day 1 31 1 (day) Month Month 1 12 1 (month) Year Year 1970 9999 1 (year) Time Time 0 23 1 (hour) Minute Min 0 59 1 (minute) Second Sec 0 59 1 (second)

Type Designation

9.3. Remote communication settings

IP addresses

Node

IP_Local

IP_RTU1

IP_RTU2

Table 9.7. IP setting

Local IP address IP_LOCAL 20 char (IP pattern) Local IP mask MASK_LOCAL 20 char (IP pattern) Dynamic IP IP_DYNAMIC 20 char (IP pattern) Remote IP address IP_RTU1 20 char (IP pattern) Remote IP mask MASK_RTU1 20 char (IP pattern) Gateway GTW_RTU1 20 char (IP pattern) Remote IP address IP_RTU2 20 char (IP pattern) Remote IP mask MASK_RTU2 20 char (IP pattern) Gateway GTW_RTU2 20 char (IP pattern)

Type Designation Format

Settings

Range

Min. Max. Step (unit)

Settings

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10. Log record

The logic equipment is organised into functional modules, as indicated previously, grouped together in accordance with their condition, meaning any type of data is represented in a speciﬁc structure with a speciﬁc name.

10.1. Fault report

The system stores 10 fault records in a circular buﬀer, meaning the last 10 faults seen by the system are always stored. The fault reports are issued in text format, meaning they can be displayed in any text-based programme.

A summary of each report is shown in the display with the most relevant data.

10.1.1. Data capture logic

Starting from idle status, the system opens a new fault report every time a unit starts up. This new report is correct if the unit gives a tripping order.

The classiﬁcation for the diﬀerent types of data is:

• Digital signals: TYPE/GROUP or CLASS/SUBGROUP or NODE/NUMBER SIGNAL

• Meterings: TYPE/GROUP or CLASS/SUBGROUP or NODE/ METERING

The ﬁlename includes:

(System fault number_Name type of record_Date_ Time_Fault number.txt)

aaaa_Faults_dd-mm-aa_hh-mm-ss-ms_vv_.txt

Each fault report contains information on the 60 milliseconds prior to the start-up which opens the new fault report, meaning we can see the status prior to the start of fault.

If start-up fails and the system does not generate a trip, the report is discarded and not saved.

Whenever several units start up during a fault, they are all entered in the same fault record.

The reasons for closing a report after tripping are:

• Fault open successfully.

• Fault not cleared successfully. In this case, it waits for a second after the trip before closing the report.

• Loss of system power before fault end.

In any of the cases above, each report will set out the reason for closing the report.

The entries programmed as "external trip" also generate a fault report.

Fault report capture window

Start of capture

Start of fault

End of capture

Figure 10.1. Faults

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10.1.2. Structure of the report

Log record

The fault report can be divided into ﬁve functional parts:

1. Information on the system the report belongs to.

2. Fault summary or report.

4. Current open by the switch.

5. Record of events generated during the time window of

the fault. This collects the instantaneous values of the meterings (module, argument) along with each event.

3. Status of system protection units at the moment of the fault.

Fault report

System (DEVICE): ekor.rpa -XXX-v/p Serial number (S.N.): Aaabbccddd (family/year/week/unit)

… …

Start

(Fault Start)

Available units (Available units)

Unit_Node-Phase-Temp. No (Empty)/Yes (X) No (Empty)/Yes (X) No (Empty)/Yes (X) No (Empty)/Yes (X)

... … … … …

Switch opening current

(TRIPPED Current):

Event record (Event Record) Date/Time Phasor currents and voltages

Pre-fault event

dd-mm-yy_hh-mm-ss-ms dd-mm-yy_hh-mm-ss-ms dd-mm-yy_hh-mm-ss-ms

Fault type (Trip type)

Unit_Type-Group-Subgroup xxx.xxx.xxx (ms) xxx.xxx.xxx (ms)

Enabled (Enable)

Phase 1: Module (A) Argument (º) Phase 2: Module (A) Argument (º) Phase 3: Module (A) Argument (º) Neutral (N.C.): Module (A) Argument (º) N. Sensitive (N.S.): Module (A) Argument (º)

Date: dd-mm-yy Time: hh-mm-ss-ms

Unit_Type-Group-Subgroup_Signal-ON/OFF

... … …

Close Fault Report_Reason for close

Table 10.1. Fault report (FAULT REPORT)

Date: dd-mm-yy Time: hh-mm-ss-ms

Tripping order

(TRIP Command)

Tripping time

(Trip time)

Started-up

(Picked up)

Curve met

(Temporized)

Phase 1: Module (A/kV))/Argument (°) Phase 2: Module (A/kV))/Argument (°) Phase 3: Module (A/kV))/Argument (°) Phase N: Module (A/kV))/Argument (°) Phase N.s: Module (A/kV))/Argument (°)

Empty

End of Fault

(Fault end)

Length of fault

(Fault Duration)

Tripped

(Tripped)

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10.1.3. List of available signals

Unit:

type/group

Records

Timed overcurrent unit

(UNIT 51)

Timed overcurrent unit

(UNIT 51(2))

Instantaneous overcurrent

unit

(UNIT 50)

Timed overvoltage unit

(UNIT 59-T)

Instantaneous overvoltage

unit

(UNIT 59-I)

Timed undervoltage unit

(UNIT 27-T)

Instantaneous

undervoltage unit

(UNIT 27-I)

Subgroup Type

• Pre-fault event

• Reason for end fault:

• UPs OFF, Fault cleared

Fault report unit

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

• Loss of power (Vdc KO. Autosaved PowerDown)

• Timeout reached. (Fault not cleared)

• Fault saved, External trip

• End fault case unknown

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by counter direction (NO TRIP DIR ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by counter direction (NO TRIP DIR ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by counter direction (NO TRIP DIR ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

Continued on next page

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Continuation

Unit:

type/group

Timed overvoltage unit

(UNIT 59N-T)

Instantaneous overvoltage

unit

(UNIT 59N-I)

Broken conductor unit

(UNIT 46BC)

Thermal image unit

(UNIT 49)

Switch error

(UNIT 50BF)

Trip unit

(TRIP LOGIC)

Table 10.2. Available signals

Subgroup Type

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Phase_1,2,3,N and NS

(P1) (P2) (P3)

(N)

(NS)

Broken conductor unit

(BROKEN CONDUCTOR)

Thermal image unit

(THERMAL OVERLOAD)

State method

(STATE METHOD)

(-)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (PICK UP ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Curve started up (ALARM ON/OFF)

• Curve met (TEMPORIZED ON/OFF)

• Unit blocked (UNIT BLOCK ON/OFF)

• Timing Blocked (TIMING BLOCK ON/OFF)

• Tripping Blocked (TRIPPING BLOCK ON/OFF)

• Trip (TRIP ON)

• No trip by blocked unit (NO TRIP BLOCK ON)

• Overcurrent trip correct (OVERCURRENT TRIP OK ON)

• Overcurrent trip fail (OVERCURRENT TRIP FAIL ON)

• General trip correct (GENERAL TRIP OK ON)

• General trip fail (GENERAL TRIP FAIL ON)

• Unexpected trip (UNEXPECTED TRIP ON)

• Open command correct (OPEN COMMAND OK ON)

• Open command incorrect (OPEN COMMAND FAIL ON)

• Close command correct (OPEN COMMAND OK ON)

• Close command incorrect (CLOSE COMMAND FAIL ON)

• Reclosing order correct (RECLOSE ORDER OK ON)

• Reclosing order incorrect (RECLOSE ORDER FAIL ON)

• Manual opening (MANUAL OPEN ON)

• Manual close (MANUAL CLOSE ON)

• Breaker error BREAKER FAIL (ON/OFF)

• Phase overcurrent trip (PHASE OVERCURRENT TRIP ON/OFF)

• Neutral overcurrent trip (NEUTRAL OVERCURRENT TRIP ON/OFF)

• Sensitive neutral overcurrent trip (SENSITIVE NEUTRAL OVERCURRENT TRIP ON/OFF)

• Phase voltage trip (PHASE VOLTAGE TRIP ON/OFF)

• Neutral voltage trip (PHASE VOLTAGE TRIP ON/OFF)

• Temperature trip (TEMPERATURE TRIP ON/OFF)

• Inverse sequence current trip (NEGATIVE SEQUENCE CURRENT TRIP ON/OFF)

• External trip (EXTERNAL TRIP ON/OFF)

• General trip (GENERAL TRIP ON/OFF)

Log record

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10.2. Event record

The diﬀerent events logs which can be downloaded from the system are related to the signals generated by the protection units, alarms and cubicle or substation

The events ﬁle can be displayed on the system's Web or can be downloaded in CSV format (open format with simple representation of data in a table).

operations, software changes log, synchronisation, etc.

These events have a speciﬁc structure and are classiﬁed The system stores up to 4000 events in a circular buﬀer, ordered in ascending chronological order, i.e. when the

by functional groups, in order to use ﬁlters which help in

querying or analysing incidents events queue is full, the oldest one is eliminated and the new one is registered automatically.

N° event

Table 10.3. Structure

Flag

Date/Time

• N° event: Position of the event in the stored events list.

• Flag (synchronisation): Indicates whether the events are

synchronised with an external clock server or not.

The deﬁned structure is:

Group

Type

• System time and date.

• Group: Refers to the logical grouping of the unit in accordance with the origin of the diﬀerent events. This grouping is distributed in seven groups.

Group Designation Description

Proprietary Activated list of events to check correct operation of the system.

Urgent Relative to those classiﬁed as urgent ﬂaws.

Alarm Grouping of existing alarms.

Protection and automations Relative to protection and automations

Driving elements statuses and orders Relative to the statuses and orders of the positions

Other events All events which are not saved as special events.

High occurrence Relative to communications.

Table 10.4. Functional groups

Description

Position

• Type: The numeration given to each event within each group.

• Description: The description text added to each event.

• Position: The numeration of the position this signal belongs to within the transformer substation.

For further information or details of the events list of each speciﬁc installation, contact Ormazabal's technicalcommercial department.

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General Instructions ekor.rpa

11. User interface

User interface

The system works as a ﬁle server (central ﬁle system) where the ﬁles can be displayed through diﬀerent user interfaces. Diﬀerent ﬁles can be loaded and displayed by sending import and extraction orders with the name and address of the ﬁle.

These ﬁles can be displayed through diﬀerent user interfaces:

• Through the system's Web server. The user can connect to the system's local IP via an Ethernet cable in order to display the WEB and the contents of the diﬀerent ﬁles.

• Through the system's Keyboard-Display.

• By exporting to the system's USB memory (ekor.softxml) The user can connect to the system via the miniUSB connector, using it as a drive unit (EKOR_DISK(E):), where we will have access to the diﬀerent ﬁles in their corresponding folders.

The imported and exported ﬁles can have diﬀerent formats and can be extended in accordance with requirements. The diﬀerent types of ﬁles used are:

• Conﬁguration settings (XML Format)

• Date/time (XML format)

• Fault records (TXT format)

• Event record (XLS format)

• System information (PDF format)

Figure 11.1. Files

11.1. Web server. Checking and configuring parameters

11.1.1. Characteristics of the Web server

The web has an optimised design, since it has been put together based on CSS3 and HTML5 standards, making it compatible with most web browsers:

• Internet Explorer version 8.0 or later

• Chrome

• Firefox

• Safari version 5 or later

• Opera version 10.63 or later

• …

Access is possible even in slow connections, it being completely functional. The time taken to load and the number of page requests is kept to a minimum thanks to the small size of the pages, less than 15 kB.

Web browsing, along with the system upgrade, has been tested and validated in slow connections and in communication error environments. The characteristics of the environments where the system has been validated are:

• Radio communication at 2.4 kbps and 1.2 kbps

• GPRS communication at 40 kbps

• Environments:

- Loss of packets up to 90%

- Reordering of packets up to 35 %

- Packet duplication up to 35 %

- Delays up to 2 seconds

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11.1.2. Access to the Web server: Local and remote access

The ekor.rpa has a web application server which is accessible by both HTTP and HTTPS.

This access can be in local or remote mode, using any of the system's Ethernet ports. Querying and/or modifying parameters, querying records and records, ﬁrmware upgrades, etc., are carried out through this server.

The website can be accessed via any Web browser (Internet Explorer, Firefox, etc.). A communication system with WAN access connected to the ekor.rpa unit must be conﬁgured for remote access.

As a requirement for Web access, the user must log in with the username and password deﬁned by the client.

IP address

User

Password

Figure 11.2. User login

Local access

The local access IP address by default is 100.0.0.1.

There are two types of users: one with rights to view and/or modify substation and remote control parameters, and one only with rights to view the information, without being able to make any changes to the conﬁguration.

The default passwords for installer mode (which can be modiﬁed via the website) are:

• User: admin

• Password: change

Remote access

The remote access IP address will be the one deﬁned in the IP1 and IP2 associated to the substation, using the same default passwords as described above.

Access mode, display mode (without modiﬁcation permission) or administrator mode can be selected from both local and remote access once logged in with administrator privileges:

Figure 11.3. Access control

There may be up to 2 users connected simultaneously in display mode and 1 in administration mode. A new user wishing to connect in administration mode via the web when there is already one connected will be given the following options:

• Cancel the previous administrator's session and log in as administrator.

• Enter display-only mode (provided there are free sessions).

• Leave and try again later.

The connected user has the option to open tabs in diﬀerent windows simultaneously.

The default passwords for user mode (which can be modiﬁed via the website) are:

• User: user

• Password: mira

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User interface

Checking and modifying parameters using the Web server

The website is divided into four main tabs: Maintenance, Logs, Congure and Leave.

Maintenance

This tab is used to keep users informed on data in real time and provide information on the status of the cubicle, alarms, current and voltage meterings, etc.

In turn, it is divided into 5 menus: Display, Alarms, Meterings, Description and Communications.

• Display: The cubicle information is displayed, showing the status of the installed cubicles in real time.

• Meterings: The diﬀerent meterings of the system are shown.

Figure 11.6. Meterings per cubicle tab

• Filiation: This enables users to enter text giving information on the substation and on each cubicle in the installation. The serial number of the ekor.rpa and the protection units is displayed.

Display tab

Switchgear status

Cubicle status indicators

Meterings

Figure 11.4. Display tab

• Alarms: A list of all the alarms deﬁned and the realtime status of each one are displayed. When an alarm is activated, its status changes from OFF to ON and the alarm box turns red.

Active alarm

Inactive alarm

Figure 11.5. Alarm tab

Figure 11.7. Filiation

• I/O inputs: Real-time display of the status of the system's inputs and outputs. When an alarm is activated, its status changes from OFF to ON and the indication box turns red.

Input disabled

Input enabled

Figure 11.8. I/O inputs tab

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Logs

This tab shows the diﬀerent logs which can be downloaded from the system: Substation events and alarms log, faults log, and changes of software version log.

N° event

Table 11.1. Structure

Flag

Date/Time

The tab can be used to apply ﬁlters to display the events registered in ekor.rpa: Filter by date, by group and/or type of event, select the number of events to be displayed per page, etc.

Display ﬁlter

Save

Events

Events summary

Protection unit events

Figure 11.9. Event record

• Events and operations record: Shows detailed information on the events and alarms of the substation and each cubicle, ordered in descending chronological order with the format:

Group

Type

Description

Position

The ﬁrst column of the table will allow the user to select the reports to be downloaded: one, several or all. The "Download" button enables downloading.

Figure 11.10. Faults

• Versions: One event is collected for each change of system software version. The date of the change, type of ﬁle updated and the loaded version are shown. The log can be downloaded in a .csv ﬁle.

• Faults: The system faults can be downloaded. The faults record can be downloaded upon request. First

the user should download the index of the fault reports in order to select the records to be downloaded. This can be done by clicking on the "see index" button.

Figure 11.11. Software versions record

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User interface

Configuration

This tab is used to conﬁgure the diﬀerent parameters of the substation: Protection unit settings, remote IP addresses…

• Protection: Display and change protection unit settings.

Figure 11.12. Conguration

• IP RTU: Display and change IP parameters, NTP parameters, LDAP parameters, timings, etc. They can be loaded and downloaded in an .xml ﬁle.

• Password: Used to change the passwords for administrator mode and display mode (when not managed by LDAP).

Figure 11.14. Change administrator mode and display mode passwords

• Special automation menus: Used to change the conﬁguration parameters of the diﬀerent automations implemented.

Figure 11.13. Display and change RTU parameters

Figure 11.15. Menus screen

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11.2. Keyboard/Display

11.2.1. Introduction

As with the diﬀerent parts of the ﬁrmware platform, the Display is organised in a tree structure, meaning navigation is more straightforward and intuitive for users.

The user can navigate through the navigation screens to reach the data screens.

The purpose of the navigation screens is to organise the display in a tree structure, meaning they do not contain any type of data. New navigation or data screens may depend on this type of screens, in accordance with the how the structure is deﬁned.

The data screens, on the other hand, are screens which show diﬀerent types of data (settings, meterings, digital signals, information, etc.). No other screen will depend on this type of screen, since they are ﬁnal screens within the display tree structure. There is the option of a double data screen. For example, in the metering data screens with modules and angle, the data screens will be double, i.e. one with information of the module, and the other with information of the angle. The “right” button is used for switching between them.

The keyboard has 6 keys:

SET

ESC

Down

Left

Right

Figure 11.16. Keyboard

The “up” and “down” keys are used to move around between same level screens. The “right” key is used to enter lowerlevel screens (whenever this screen has lower levels). The “left” or “ESC” key, on the other hand, is used to pass to the upper level screen it depends on.

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User interface

Example:

Figure 11.17. Tree structure implemented in the display of the

ekor.rpa-100 units

11.2.2. Display screen

The main browsing branch is as follows:

In this example, part of the tree structure implemented in the display is shown; speciﬁcally, the navigation screens which should be used to access the sequence current metering (data screens) are shown. Based on the main “RPA MODEL” screen, the path to follow to access the sequences screens is as follows:

First navigate through the main navigation screens using the “down”, key, through to the “MEASURES” screen. The next step is to click on the “right” key to enter the lower level navigation screens associated with the “MEASURES” screen.

The same logic is used to reach the last “SEQUENCE” navigation screen, which the data screens corresponding to the sequence currents depend on. Having reached these data screens, and knowing that they are double data screens, it is possible to switch between the screen for module and angle by clicking on the “right” key.

Table 11.2. Display

General display screen for

user settings

General display screen for

date and time

General display screen for

statuses

Current and voltage phasor.

Double screens: Module + argument

General display screen for

fault reports

General display screen for

meterings

General display screen for

system information

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The screens which depend on each of the general screens mentioned in the table above are presented below.

Settings

The screens for user settings (SETTINGs) are structured in the same way as in the .xml settings ﬁle.

Status

Clock

The screens structure for the date and time is:

Figure 11.18. Clock

The screens structure for diﬀerent system statuses is:

Figure 11.19. Status

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Logs

The screen structure for the last 10 reports stored in the system is:

User interface

Figure 11.20. Logs

Every time there is a fault, it is shown on the display and a priority screen with the fault information. The information displayed on these priority screen is identical to that shown in the LOGS section.

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The user should press the ESC key in order to leave the priority screen and return to the initial fault screen.

User interface General Instructions

ekor.rpa

Measures

The screens structure for the system meterings is:

Figure 11.21. Measures

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Information

The screens structure for system information is:

User interface

Figure 11.22. Information

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11.2.3. Error codes

The ekor.rpa-100 units have a series of error codes used to warn the user regarding the diﬀerent anomalies that may occur in the system.

Figure 11.23. Error

Each type of error has a unique error number deﬁned, meaning its identiﬁcation cannot be mistaken:

Code shown on the display Meaning

ER 03 ER 04 ER 05 ER 06 ER 07 ER 08 ER 09 ER 0A

Switches between the error code and the screen where the user is at this moment

Table 11.3. Errors

Switch error (error during opening or closing) Closing coil error in closed position Closing coil error in open position Opening coil error Miniature circuit-breaker alarm Springs unloaded alarm Status of the protections out of service (including with 51, 50, 51N, 50N, 51NS, 50NS ON) Pumping activation

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11.3. Fileserver in USB memory

The device shares diﬀerent types of ﬁles with the user using a USB memory. This ﬂash memory acts as a ﬁle server, where the system can update its conﬁguration or information using the import and export commands (commands sent by the user by activating two pushbuttons). The PC user has access to the ﬁles with the read/edit/load option using a USB cable.

The operations which can be carried out using this interface are:

• Display/change system settings.

• Display fault reports.

• Display meterings.

• Update the system's ﬁrmware or settings.

User interface

Figure 11.24. Connections with USB cable

11.3.1. Connection to the system

If the cable conﬁguration is correct, the PC user will see the new drive detected when connecting to the system:

Figure 11.25. Detection of a new drive unit

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The following elements can be found on the drive:

• ekorSoftXML.exe: Settings display software.

• "Settings” folder: Directory where the system's settings are saved (.xml + .xsd).

Figure 11.26. Drive units

11.3.2. Use of the interface

In order for the interface to Work correctly, the user must interact with the system by sending ﬁle extract or import commands (using the escape and right-arrow keys).

The device distinguishes the operation to be carried out in accordance with an order of priority of the tasks to be run. The tasks are unique for each command and are run linearly,

• “Faults” folder: Directory where the faults recorded by the system are saved.

• "Measures” folder: Directory where system meterings are saved.

i.e. if the system detects that the ﬁrst one should not be run, it looks for the next one, and so on until it reaches the last one. The last task is always run, since it updates the system information on the ﬂash memory.

The tasks to be run by the system in order of priority are the following:

Nº Order Task to be carried out Filename

Import Update system ﬁrmware Upgrade.hex

Import Update system setting Ecu_log.ekp

Import Update user settings User_PSWU.xml

Import Update date/time RTC_PSWU.xml

Export Restore ﬁles in USB memory

Table 11.4. Priority order

• User settings

• Date/time

• Fault reports

• Instantaneous metering

• User.xml

• RTC.xml

• x_Faults_Date_time_vv_.txt (w: from 1 to 10)

• Measures.txt

IG-267-EN versión 01; 07/04/2017

General Instructions ekor.rpa

User interface

The rmware or conguration update tasks are important device updates and should only be carried out when necessary and by qualiﬁed personnel. These ﬁles are for import only and must be supplied by the manufacturer. They are loaded, leaving a copy in the USB memory root directory and sending an input command. If the contents of these ﬁles are incorrect, the system will return an error message in text format.

If the system does not have any ﬁle to update, it exports all the conguration and information when a command is received, meaning the USB memory is updated with the last information collected by the system. This last task is useful to:

1. Download the latest system faults. (EKOR_DISK:/Faults)

2. Download the instantaneous meterings of the unit

at the moment the command is sent. (EKOR_DISK:/ Measures)

3. Download the system's user and date/time settings. (EKOR_DISK:/Settings/Actual or Backup)

The following is required to congure the system with “user.xml” for user settings and “RTC.xml” for date/time:

1. Open the ﬁles in “EKOR_DISK:/Settings/Actual” using an XML ﬁle editor.

2. Conﬁgure, edit, with the required values.

3. Save the new ﬁle in the folder “EKOR _DISK:/Settings/

Upgrade” using the pertinent ﬁlename and password.

4. Generate an import command so the system is updated with the new conﬁguration.

The default “user Password (PSWU)” is “0000”. The conﬁguration XML ﬁles to be updated would therefore be as follows:

• User_0000.xml

• RTC_0000.xml

EKOR _DISK:/Settings/Backup” can store the settings prior to the last upgrade.

EKOR _DISK:/Settings/XSD” stores the ranges, steps, etc. of the settings used.

It is recommended to send a USB memory update command as soon as the system is connected following an update. This ensures that work is always carried out with the last conﬁguration and that the system has been conﬁgured as required.

Figure 11.27. Drive screen

IG-267-EN versión 01; 07/04/2017

User interface General Instructions

ekor.rpa

11.3.3. ekor.soft-xml

The ﬁle “ekor.soft-xml.exe” as an executable ﬁle for browsing the USB drive ﬁleserver. This executable ﬁle is on the system itself and does not need any communications connection, since the import/export commands are entered using the keyboard.

The ﬁle “ekor.soft-xml.exe” only runs on the Windows operating system. For any other type of operating system, there is the option of editing the conﬁguration ﬁles manually using XML ﬁle editors. The USB memory connection uses the “USB mass storage device class” protocol, making it compatible with diﬀerent operating systems.

The steps to follow in order to display/edit/load system settings are shown below.

It is recommended to copy the display software to the computer and run it there in order to display or modify settings.

Once the Software has been run, this will detect an external drive called EKOR_DISK:

Choose the drive, and the right-hand column will show the ﬁles which can be displayed and/or modiﬁed (USER: User and RTC settings: Date/time).

Select the ﬁle to be displayed or modiﬁed and click on OK:

Figure 11.28. ekor.soft-xml

Figure 11.29. Display screen

Once the ﬁle is open, the settings can be modiﬁed provided the limits shown in the columns most to the right are respected (Min Value, Max Value, etc.).

100

IG-267-EN versión 01; 07/04/2017

Ormazabal ekor.rpa, ekor.rpa-110, ekor.rpa-110-v, ekor.rpa-120, ekor.rpa-110-p General Instructions Manual

Specifications and Main Features

Frequently Asked Questions

User Manual

1. General description

1.1. General operating features

1.2. Components

1.2.1. Electronic relay

1.2.2. Current sensors

1.2.3. Voltage sensors

1.2.4. “Binox” bistable tripping device and tripping coil

1.3. Functionality of the unit

1.4. Communications

2. Applications

2.1. Remote control of transformer and distribution substations

2.2. Automatic reclosing of lines

2.3. Line protection with circuit-breaker

2.4. Transformer protection

2.5. Automatic transfer

2.6. Detection of phase with earthing

2.7. Protection and control of MV interconnection stations

2.8. Energy balances

3. Metering functions

3.1. Current and voltage metering

3.2. Power meterings

3.3. Energy meter

4. Protection functions

4.1. Overcurrent units

4.1.1. Timed overcurrent units

4.1.2. Instantaneous overcurrent units

4.1.3. Block diagram

4.2. Ultra-sensitive earth

4.3. Directional units

4.3.1. Phase directional units

4.3.2. Neutral and sensitive neutral directional units

4.4. Thermal image unit

4.4.1. Estimated thermal capacity

4.4.2. Functionality

4.4.3. Block diagram

4.5. Broken conductor unit

4.5.1. Calculation of sequence currents

4.5.2. Functionality

4.5.3. Block diagram

4.6. Voltage units

4.6.1. Timed overvoltage units

4.6.2. Instantaneous overvoltage units

4.6.3. Timed undervoltage units

4.6.4. Instantaneous undervoltage units

4.6.5. Block diagram

4.7. Second harmonic blocking unit

4.7.1. Functionality

4.7.2. Block diagram

5. Detection, automation and control functions

5.1. Recloser automation

5.1.1. Functionality

5.1.2. VREF

5.1.3. Settings

5.1.4. Recloser statuses

5.2. Voltage presence/absence automation

5.2.1. Functionality

5.2.2. Settings

5.2.3. Voltage presence/absence automation statuses

5.3. Switch control

5.3.1. Introduction

5.3.2. Settings

5.3.3. Switch control statuses

5.4. Remote control

6. Sensors

6.1. Current sensors

6.1.1. Functional characteristics of current sensors

6.1.2. Vector sum/zero-sequence wiring

6.2. Voltage sensors

6.2.1. Bushing

6.2.2. ekor.evt-c

7. Technical characteristics of the equipment

7.1. Rated values

7.2. Mechanical design

7.3. Insulation tests

7.4. Electromagnetic compatibility

7.5. Climatic tests