ekor.rpa Protection, metering and control multifunction unit General Instructions IG-267-EN, version 01, 07/04/2017 LIB

Transcription

1 Protection, metering and control multifunction unit General Instructions IG-267-EN, version 01, 07/04/2017 LIB

2 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 It must therefore only be operated by appropriately qualified and supervised personnel, in accordance with the requirements of standard EN on the safety of electrical installations and standard EN 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 [1]. 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. 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.

3 General Instructions Contents Contents 1. General description General operating features Components Electronic relay Current sensors Voltage sensors Binox bistable tripping device and tripping coil Functionality of the unit Communications Applications Remote control of transformer and distribution substations Automatic reclosing of lines Line protection with circuit-breaker Transformer protection Automatic transfer Detection of phase with earthing Protection and control of MV interconnection stations Energy balances Metering functions Current and voltage metering Power meterings Energy meter Protection functions Overcurrent units Timed overcurrent units Instantaneous overcurrent units Block diagram Ultra-sensitive earth Directional units Phase directional units Neutral and sensitive neutral directional units Thermal image unit Estimated thermal capacity Functionality Block diagram Broken conductor unit Calculation of sequence currents Functionality Block diagram Voltage units Timed overvoltage units Instantaneous overvoltage units Timed undervoltage units Instantaneous undervoltage units Block diagram Second harmonic blocking unit Functionality Block diagram Block by I max Detection, automation and control functions Recloser automation Functionality VREF Settings Recloser statuses Voltage presence/absence automation Functionality Settings Voltage presence/absence automation statuses Switch control Introduction Settings Switch control statuses Remote control Sensors Current sensors Functional characteristics of current sensors Vector sum/zero-sequence wiring Voltage sensors Bushing ekor.evt-c Technical characteristics of the equipment Rated values Mechanical design Insulation tests Electromagnetic compatibility Climatic tests Mechanical tests Power tests CE Conformity...55 IG-267-EN versión 01; 07/04/2017 3

4 Contents General Instructions 8. Protection, metering and control models Description of models vs functions v/-100-p Relay configurator v -110-v and -120-v type units Functional description Definition of digital inputs/outputs Installation in a cubicle Checking and maintenance p -110-p and -120-p type units Functional description Definition of digital inputs/outputs Fuse protection Installation in a cubicle Checking and maintenance User configuration settings Local protection and automation settings Date and time settings Remote communication settings User interface Web server. Checking and configuring parameters Characteristics of the Web server Access to the Web server: Local and remote access Keyboard/Display Introduction Display screen Error codes Fileserver in USB memory Connection to the system Use of the interface ekor.soft-xml Communications Physical medium: RS MODBUS protocol PROCOME protocol Physical medium: Ethernet Physical medium: Mini-USB Annex Log record Fault report Data capture logic Structure of the report List of available signals Event record IG-267-EN versión 01; 07/04/2017

5 General Instructions General description 1. General description Within the ekor.sys family, the 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 -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 , EN 60068, EN IEC 60255, IEC 61000, IEC , IEC 60068, IEC 60044, IEC 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. Integrating the units in the Ormazabal cubicle system allows specific products for requirements in different facilities. The -100 units in the 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 -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 IG-267-EN versión 01; 07/04/2017 5

6 General description General Instructions 1.1. General operating features All the relays of the -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. The -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. Figure series relay 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 -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. 6 IG-267-EN versión 01; 07/04/2017

7 General Instructions General description 1.2. Components The parts which make up the -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. 1 Terminal block 2 electronic relay 3 Voltage and current sensors Figure 1.3. Parts of the assembly of -100 in cubicle IG-267-EN versión 01; 07/04/2017 7

8 General description General Instructions 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. 1 "ON" signalling LED 2 Metering and parameter setting display 3 SET key 4 Keyboard for scrolling through screens 5 Front mini-usb communication port Figure 1.4. Description of the elements available on the front of the -120 relay 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. 8 IG-267-EN versión 01; 07/04/2017

9 General Instructions General description 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. 1 Bushing 2 Current sensors Figure 1.5. Location of the current sensors 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. Figure 1.6. ekor.evt-c voltage sensors IG-267-EN versión 01; 07/04/2017 9

10 General description General Instructions 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 -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 -100 units have this tripping device installed as standard. Figure 1.7. Binox Tripping coil The operations ordered by the -100 unit digital outputs are performed by means of conventional tripping coils. This way, a redundant and therefore more reliable operational system is achieved 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. 10 IG-267-EN versión 01; 07/04/2017

11 General Instructions General description 1.4. Communications All the relays of the -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 -120 model also has a bus for temperature sensor connection. The -100 relays can be interconnected to other units in the ekor.sys family, as shown in the image below. 1 ekor.ccp 2 ekor.bus 3 ekor.rci 4 5 ekor.rpt 6 ekor.rpg Figure 1.8. Intercommunicated units of the ekor.sys family IG-267-EN versión 01; 07/04/

12 Applications General Instructions 2. Applications 2.1. Remote control of transformer and distribution substations The -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. The use of a remote control terminal and -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 different stations in the network Figure 2.1. Remote-controlled switching substation Units that include this remote control function: Unit -100 type = p -100 type = v Table 2.1. Remote control function units Type of cubicle 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) 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 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: They reduce the time in which electrical power is interrupted. Unit -100 type = v Table 2.2. Recloser function unit Type of cubicle Circuit-breaker 12 IG-267-EN versión 01; 07/04/2017

13 General Instructions Applications 2.3. Line protection with circuit-breaker 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. 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 -100 units, model -110, line protection is carried out mainly by the following functions: Figure 2.3. Feeder protection functions in -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. 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 nd Harm. Block Second harmonic blocking. Blocks overcurrent units during transformer magnetisation 79 Reclosing relay. Enables the automatic reclosing of lines. IG-267-EN versión 01; 07/04/

14 Applications General Instructions In addition, the -100 equipment, -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. 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 -100 type = v Table v Type of cubicle Circuit-breaker 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. Figure 2.4. Transformer protection functions in -100 relays 14 IG-267-EN versión 01; 07/04/2017

15 General Instructions Applications The protection functions, available in models -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 nd Harm. Block Second harmonic blocking. Blocks overcurrent units during transformer magnetisation. In addition, the -100 equipment, -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 -100 type = p -100 type = v Table p/-100-v Type of cubicle Fuse-combination switch Circuit-breaker IG-267-EN versión 01; 07/04/

16 Applications General Instructions 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 16 IG-267-EN versión 01; 07/04/2017

17 General Instructions Applications 2.7. Protection and control of MV interconnection stations In MV customers where an -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. The accessible information would be as follows: Cubicle position Trips Alarms Meterings: -- Voltage -- Current -- Power -- Energy 2.8. Energy balances By including MV energy meterings in the -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. 1 ekor.rci 2 ekor.ccp 3 4 Meters Figure unit measuring MV energies in a transformer with private customers IG-267-EN versión 01; 07/04/

18 Metering functions General Instructions 3. Metering functions 3.1. Current and voltage metering The unit has four current reading inputs (I A, I B, I C and I NS ) and three voltage reading inputs (V A, V B and V C ). 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 N and V N, 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 A, I B and I C. Line voltage: U AB, U BC and U CA and Line voltages: V A, V B and V C. Residual currents and voltages. Represented as: I N /I NS (3I o ) and V N (3V o ). 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. 18 IG-267-EN versión 01; 07/04/2017

19 General Instructions Metering functions 3.2. Power meterings 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. 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.) 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. 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). a b c d e f 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 IG-267-EN versión 01; 07/04/

20 Protection functions General Instructions 4. Protection functions 4.1. Overcurrent units The -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). 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) 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 -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. 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 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 -100 units model IG-267-EN versión 01; 07/04/2017

21 General Instructions Protection functions Instantaneous overcurrent units 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 s). 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 -100 units model Block diagram Any overvoltage unit complying with the diagram shown below: 1 Metering 2 Input signal 3 Output signal 4 Settings Figure 4.1. Block diagram IG-267-EN versión 01; 07/04/

22 Protection functions General Instructions 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 pick up ) during timing, the unit and the meter are reset and the unit remains idle. All the units generate the following signalling: Pick-up: Activated when the measured magnitude (Ix) exceeds a setpoint (I pick up setting) and disabled when the 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. 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 Ultra-sensitive earth This functionality is available in both directional and nondirectional 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. 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. 1 Voltage and current sensors 2 Zero-sequence transformers Figure 4.2. Current sensors 22 IG-267-EN versión 01; 07/04/2017

23 General Instructions Protection functions 4.3. Directional units 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. The -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) 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 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 min setting. The figure shows an example of operation of the directional unit of phase A: The settings for the phase directional unit are: Characteristic phase angle: Characteristic angle (from 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: 1 Reserve 2 Forward 3 Indeterminate zone 4 Zero torque line 5 Maximum torque line Figure 4.3. Phase A directional unit IG-267-EN versión 01; 07/04/

24 Protection functions General Instructions 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 o ) and the residual current signal (3I o ). The polarisation signal used is the 180 out-of-phase residual voltage, i.e.- 3V o. The settings for the neutral and sensitive neutral directional unit, which apply to the angular criteria, are: Characteristic neutral angle: Characteristic angle (from 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 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 min setting. The figure below shows an example of operation for the neutral directional unit: 1 Reserve 2 Forward 3 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 o ) and the residual current signal (3l o ), 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. 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 ). 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). 24 IG-267-EN versión 01; 07/04/2017

25 General Instructions Protection functions The unit will indicate Forward direction in the following conditions: The figure below shows an example of operation for the neutral directional unit with wattmetric criterion: The residual current signal (3I o ) 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 min. The polarisation voltage value is lower than the V min setting. This is found in the indeterminate zone (see figure below). 1 Reserve 2 Forward 3 Indeterminate zone Figure 4.5. Neutral unit with wattmetric criterion 4.4. Thermal image unit The -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. IG-267-EN versión 01; 07/04/

26 Protection functions General Instructions Estimated thermal capacity The system estimates thermal capacity through the phase currents (I A, I B and I C ), using the following formula: Where: T n: Estimated thermal capacity at instant n T n-1: Estimated thermal capacity at instant n-1 Δt: Time interval between consecutive n and n-1 instants τ: Cooling or heating constant If T final < T n-1, the temperature rise constant will be applied in the formula If, on the other hand, T final < T n-1, the cooling constant will be applied in the formula T final: Final thermal capacity This value is calculated based on the adjusted rated current and the phase currents, in accordance with the following formula: I therm: The estimated mean thermal current based on the phase 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: I therm sequence read by the equipment: Estimated thermal capacity (T) Figure 4.6. Time (min) 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 %. 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 %, 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. Interval 1 Interval 2 Interval 3 From 0 min to 100 min From 100 min to 150 min From 150 min to 250 min 5.8 A 1.5 A 5.8 A Table 4.1. I therm read by the system 26 IG-267-EN versión 01; 07/04/2017

27 General Instructions Protection functions Functionality 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 τ c: Temperature rise constant I n: Adjusted rated current I therm: The estimated mean thermal current based on the phase currents The trip times for different temperature rise constants are shown graphically below: Figure 4.7. Trip time IG-267-EN versión 01; 07/04/

28 Protection functions General Instructions Block diagram The thermal image unit complies with the following block diagram : 1 Metering 2 Input signal 3 Output signal 4 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. 28 IG-267-EN versión 01; 07/04/2017

29 General Instructions Protection functions 4.5. Broken conductor unit The -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. 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 Calculation of sequence currents The broken conductor unit is supplied by the sequence currents (I 1, I 2 and I o ) previously calculated by the system. The sequence current calculation is carried out in accordance with these formulae: 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. IG-267-EN versión 01; 07/04/

30 Protection functions General Instructions 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 zerosequence (situation which can come about in lines which are not uniformly charged in the three phases): Line currents Direct-sequence currents Inverse-sequence currents Zero-sequence currents Figure 4.9. Calculation of sequences 30 IG-267-EN versión 01; 07/04/2017

31 General Instructions 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 through the broken conductor) and the other two counterdirection phases: Line currents Direct-sequence currents Inverse-sequence currents Zero-sequence currents Figure Calculation of sequences IG-267-EN versión 01; 07/04/

32 Protection functions General Instructions 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 n (primary rated current of the current transformer). The I n 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.). Unit timing: Unit tripping time (from 0.05 s to 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 Block diagram The broken conductor unit complies with the following block diagram: 1 Input signal 2 Output signal 3 Settings Figure Block diagram 32 IG-267-EN versión 01; 07/04/2017

33 General Instructions Protection functions The four conditions which make the broken conductor unit start up are: Figure 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. 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 Voltage units The -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) Neutral (calculated): 1. A neutral overvoltage timed unit (1 x 59N_TEMP) 2. A neutral overvoltage instantaneous unit (1 x 59N_INST) IG-267-EN versión 01; 07/04/

34 Protection functions General Instructions 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. 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 s). This setting only applies to IEC DT type curves 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 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 s). 34 IG-267-EN versión 01; 07/04/2017

35 General Instructions Protection functions Timed undervoltage units 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. 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. 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 s). This setting only applies to IEC DT type curves 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 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 s). IG-267-EN versión 01; 07/04/

36 Protection functions General Instructions Block diagram Any voltage unit complying with the diagram shown below. 1 Metering 2 Input signal 3 Output signal 4 Settings Figure 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 pick up setting), a time counter counts down (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 pick up setting), and disabled when 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. 36 IG-267-EN versión 01; 07/04/2017

37 General Instructions Protection functions 4.7. Second harmonic blocking unit The -100 systems are fitted with the second harmonic blocking unit. This function blocks the overcurrent units whenever the transformer energisation conditions are met: High fundamental current value. High second harmonic current value Functionality The second harmonic blocking unit has 5 modules, one for each current (I A, I B, I C, I N and I NS ). 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 A, I B and I C ): 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 A, I B and I C only). The fundamental value of the corresponding current must be lower than the setting Max phase current. IG-267-EN versión 01; 07/04/

38 Protection functions General Instructions 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 %). 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 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) 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). 38 IG-267-EN versión 01; 07/04/2017

39 General Instructions Protection functions Block diagram The second harmonic blocking unit complies with the following block diagram: Figure Block diagram IG-267-EN versión 01; 07/04/

40 Protection functions General Instructions 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 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. 40 IG-267-EN versión 01; 07/04/2017

41 General Instructions Protection functions 4.8. Block by I max The maximum current blocking unit is implemented in the -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 -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 -100 unit is to be installed. 1 Relay protection 2 Fuse protection Figure Block by I max IG-267-EN versión 01; 07/04/

42 Detection, automation and control functions General Instructions 5. Detection, automation and control functions 5.1. Recloser automation Functionality The recloser automation is implemented in the -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 -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. 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 VREF 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. 42 IG-267-EN versión 01; 07/04/2017

43 General Instructions Detection, automation and control functions Settings 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 s for the first reclosing, and from 1.00 s to 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 s for the first reclosing, and from 1.00 s to 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 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 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 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 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 Recloser statuses The recloser automation implemented in the -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 Activation setting Manual/automatic order Automatic On Automatic order Manual On Automatic order Manual Off Any order Table 5.1. Manual/automatic 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. IG-267-EN versión 01; 07/04/

44 Detection, automation and control functions General Instructions FINAL TRIP: Indicates that the trip caused by the overcurrent unit has been final, and there will be no subsequent reclosing. RECLOSING ORDER: This is the switch closing order which automation generates after timing the corresponding recloser time. a Busbar voltage b Line currents c Tripping order 1 Switch status 2 Reclosing order 3 Final trip 4 Standby 5 Under way TR = Reclosing time Tb = Safety time after reclosing Tbm = Safety time after manual closing Figure 5.1. Reclosing order 44 IG-267-EN versión 01; 07/04/2017

45 General Instructions Detection, automation and control functions 5.2. Voltage presence/absence automation Functionality This automation allows detection of presence or absence of voltage in those lines where the 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. 1 Presence of voltage 2 Absence of voltage Figure 5.2. Presence/absence of voltage 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). 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 s). Absence of voltage time: Timing to indicate absence of voltage (from 0.05 s to s) Voltage presence/absence automation statuses The voltage presence/absence automation implemented in the -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 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. IG-267-EN versión 01; 07/04/

46 Detection, automation and control functions General Instructions 5.3. Switch control Introduction The -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 -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. 1 Switch terminal block Figure 5.3. Switch control 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 s). Switch closing failure time: The time to control the correct closing of the switch (from 0.10 s to s). 46 IG-267-EN versión 01; 07/04/2017

47 General Instructions Detection, automation and control functions Switch control statuses The switch control unit implemented in the -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. 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 Remote control The -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 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. 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. IG-267-EN versión 01; 07/04/

48 Sensors General Instructions 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 48 IG-267-EN versión 01; 07/04/2017

49 General Instructions Sensors Functional characteristics of current sensors The current sensors are toroidal-core current transformers with a high transformation ratio and low rated burden. These sensors are encapsulated in self-extinguishing polyurethane resin. Phase current toroidal transformers Ratio 300/1 A 1000/1 A 2500/1 A Metering range Extd. 130 % Extd. 130 % Extd. 130 % Metering class S Low range metering class At 1 % of I n ± 0.4 % in amplitude and ± 85 min in phase At 0.5 % of I n ± 0.35 % in amplitude and ± 25 min in phase At 0.5 % of I n at 12.5 A: ± 0.3 % in amplitude and ± 20 min in phase Protection class 5P20 5P20 5P13 Burden 0.18 VA 0.2 VA 0.2 VA Thermal current 31.5 ka 3 s 31.5 ka 3 s 31.5 ka 3 s Dynamic current 2.5 I th 2.5 I th 2.6 I th Frequency Hz Hz Hz Insulation 0.72/3 kv 0.72/3 kv 0.72/3 kv External diameter 139 mm 139 mm 139 mm Internal diameter 82 mm 82 mm 82 mm Height 38 mm 38 mm 38 mm Weight kg kg kg Polarity S1 blue, S2 brown S1 blue, S2 brown S1 blue, S2 brown Encapsulated Self-extinguishing polyurethane Self-extinguishing polyurethane Self-extinguishing polyurethane Thermal class B (130 C) B (130 C) B (130 C) Reference standard IEC IEC IEC Table 6.2. Current sensors 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. Figure 6.2. Phase toroidal transformer All the current sensors have integrated protection against the opening of secondary circuits, which protects against overvoltages. IG-267-EN versión 01; 07/04/

50 Sensors General Instructions 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 300/1 A 1000/1 A Metering range Extd. 130 % Extd. 130 % Protection 5P10 5P10 Metering Class 3 Class 3 Burden 0.2 VA 0.2 VA Thermal current 31.5 ka 3 s 31.5 ka 3 s Dynamic current 2.6 I th 2.6 I th Frequency Hz Hz Insulation 0.72/3 kv 0.72/3 kv External dimensions 330 x 105 mm 330 x 105 mm Internal dimensions 272 x 50 mm 272 x 50 mm Height 41 mm 41 mm Weight 0.98 kg 0.98 kg Polarity S1 blue, S2 brown S1 blue, S2 brown Encapsulated Self-extinguishing polyurethane Self-extinguishing polyurethane Thermal class B (130 C) B (130 C) Reference standard IEC IEC Table 6.3. Zero-sequence current transformers 50 IG-267-EN versión 01; 07/04/2017

51 General Instructions Sensors 6.2. Voltage sensors 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: Figure 6.5. Voltage pickup Bushing Type Conventional Standard Calibration on site Double screen Maximum voltage (compound) 40.5 kv Transformation ratio 10 kv/ µa 10 kv/ µa Metering class (together with the equipment) Protection class (together with the equipment) 6P 6P 6P Burden mva Frequency Hz Voltage range (compound) kV IP Grade IP65 Temperature range - 10 C to + 60 C Reference standard IEC IEC Table 6.4. Bushing Figure 6.6. Zero-sequence toroidal transformer IG-267-EN versión 01; 07/04/

52 Sensors General Instructions 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) 36 kv Transformation ratio 10 kv/100 µa Metering class (together with the equipment) 0.5 Protection class (together with the equipment) 3P Burden: mva Frequency Hz Voltage range (compound) kv IP Grade IP65 Temperature range - 10 C to + 60 C Connectors BNC Metering cable Coaxial 50 Ω model RG1747/U Reference standard IEC IEC For the BNC output identified as PLC communications, contact Ormazabal's technical-commercial department Table 6.5. ekor.evt-c sensor Figure 6.8. ekor.evt-c dimensions 52 IG-267-EN versión 01; 07/04/2017

53 General Instructions Technical characteristics of the equipment 7. Technical characteristics of the equipment 7.1. Rated values Power supply AC 40 V AC...90 V AC ± 20 %; 12 VA DC 24 V DC V DC ± 10 %; 6 W 1A Current inputs Secondary phase Metering 1 ma A Protection 1.3 A...25 A Secondary earth Metering 0.25 ma ma Protection 325 ma A I thermal/dynamic 31.5 A (3 s) 2.5 I th Impedance 0.02 Ω Voltage inputs Metering and protection 1 µa µa Impedance 2.7 kω Accuracy 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) UNE EN IEC IEC Active class B Active class 1 Reactive class 2 Frequency 50 Hz; 60 Hz ± 1 % Output contacts Voltage 250 V AC Current 6 A (AC) Switching power 1500 VA (resistive load) Digital inputs ED1-5 With internal polarisation ED6-9 External polarisation (max. 48 V dc + 15 %) Temperature Operation - 40 C C Storage - 40 C C Communications Front port USB Mini-B Rear ports 4 x RJ-45: - COM0: 1 x RS COM1: 2 x RS ETH0: Ethernet - ETH1: Ethernet LOCAL Protocol MODBUS (RTU)/PROCOME slave Table 7.1. Rated values 7.2. Mechanical design Protection grade Terminals IP2X In cubicle IP3X Dimensions (h x w x d): 146 x 47 x 165 mm Weight 0.3 kg Connection Cable/Terminal mm 2 Table 7.2. Mechanical design IG-267-EN versión 01; 07/04/

54 Technical characteristics of the equipment General Instructions 7.3. Insulation tests Insulation resistance IEC (2000) 500 V DC; >100 MΩ Dielectric strength IEC (2000) 2 kv AC; 50 Hz; 1 min 1 kv AC; 50 Hz; 1 min Insulation with voltage impulses IEC (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 (2010) CLASS B MHz: Radiated radio emissions EN (2010) Class A MHz Immunity Electrostatic discharges IEC (2008) LEVEL 4 - Indirect contact mode: ± 8 kv - Air mode: ± 15 kv Radiofrequency electromagnetic field IEC (2010) LEVEL 3 10V/m ; MHz Fast transients IEC (2012) LEVEL 4 ± 4 kv; 5 khz ± 2 kv; 5 khz Shockwaves IEC (2005) LEVEL 4 -Common mode: ± 4 kv ± 2 kv ± 1 kv - Differential mode: ±2 kv ±1 kv Conducted interference IEC (2008) LEVEL 3 10 V RMS; MHz Industrial frequency electromagnetic field IEC (2009) LEVEL 5 - Continuous: 100 A/m; 50 Hz; 1 min - Transient: 1000 A/m; 50 Hz; 2 s Damped magnetic field IEC (2001) LEVEL A/m; 2 s Damped wave IEC (2011) LEVEL 3 - Common mode: ± 2.5 kv - Differential mode: ± 1 kv Dips, variations and zero voltage DC IEC (2000) DC Power supply voltage PNI (January 2013) DC current peaks PNI (January 2013) Voltage dips: Rated Voltage 48 V DC - Brief: 100 % dips; 100 ms - Prolonged: 60 % dips; 1 s Short interruptions: 0 %; 1 s Voltage variations: 10 % steps, from 38 V DC to 62.5 V DC Maximum voltage without failing: 72 V DC (+ 50 % V rated) Maximum and minimum voltage within the operation range: V DC (- 20 % V rated) V DC (+ 30 % V rated) Voltage below the operation range: V DC (70 % V rated) - 24 V DC (50 % V rated) V DC (30 % V rated) V DC (10 % V rated) Maximum and minimum voltage within the operation range: V DC (- 20 % V rated); < 2.5 A V DC (+ 30 % V rated); < 4 A Table 7.4. Electromagnetic compatibility 54 IG-267-EN versión 01; 07/04/2017

55 General Instructions Technical characteristics of the equipment 7.5. Climatic tests Damp heat IEC (2001) 40 C; 93 % humidity; 96 h Dry heat IEC (2007) 70 C; 16 h Cold IEC (2001) 25 C; 16 h Temperature variation IEC (2009) - 25 C/70 C; h; 5 cycles Table 7.5. Climatic tests 7.6. Mechanical tests IEC (2008) Fh 7.82 m/s2; 3 x 30 min; X, Y, Z axes: Vibration Hz: 1 m2/s3 ETSI EN ( ) CLASS 2.3 (random) Hz: - 3 db/octave IP Protection grade IEC (1989) + A1 (1999) IP2XB Table 7.6. Mechanical tests 7.7. Power tests No-load cable making and breaking IEC (1999) kv; 85 A Mainly active load making and breaking IEC (1999) kv; 200 A ; cos(ϕ)= kv; 630 A ; cos(ϕ)= 0.7 Earth fault making and breaking IEC (1999) kv; 200 A; IN= 50 A; cos(ϕ)= 0, kv; 200 A; IN= 5 A; cos(ϕ)= 0,7 Short-circuit making and breaking IEC (1999) 3 kv; 1 ka 10 kv; 3 ka 3 kv; 10 ka 3 kv; 16 ka Table 7.7. Power tests 7.8. CE Conformity This product complies with the European Union directive 2014/30/EU on electromagnetic compatibility, and with the IEC 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. IG-267-EN versión 01; 07/04/

56 Protection, metering and control models General Instructions 8. Protection, metering and control models 8.1. Description of models vs functions The units to be described are the 110 and -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 -120 model also has a bus for temperature sensor connection. 56 IG-267-EN versión 01; 07/04/2017

57 General Instructions Protection, metering and control models Bistable output Digital inputs: Switch status, earthing switch 1 status, external trip, etc. Terminals X2 Digital outputs: Trip signal. Open switch. 2 Close the switch. Error (WD)... Terminals X2 3 Binox bistable release output Tripping terminal block 4 Current reading inputs (I 1, I 2, I 3 and I n) Terminals X1 5 Voltage reading inputs (V 1, V 2 and V 3) Terminals X1 6 RJ-45 Ethernet port (Local configuration): Display meterings, switch position statuses, alarms, settings, etc. Parametrisation of the system Collection of faults and events records. Ethernet 0/1 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. 7 Send meters: Active energy, etc. COM0 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) 8 * Optionally for the -120 model only COM1 Figure connections 1 ETH-0 2 ETH-1 3 Terminal Block X1 4 Terminal Block X2 5 COM0 6 COM1 7 Binox release output Figure connections IG-267-EN versión 01; 07/04/

58 Protection, metering and control models General Instructions The -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. It supervises the current meterings and detects the presence/absence of voltage The -120 protection unit is a multifunction unit, which has additional functions to the 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 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. 58 IG-267-EN versión 01; 07/04/2017

59 General Instructions Protection, metering and control models v/-100-p The -110 and -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: -110-v -110-p -120-v -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 Protection, metering and control units Model Type v p v p General Phase current sensors Earth current pickup (with zero-sequence current transformer) Op Op Op Op Voltage sensors Power supply V DC ± 10 %/40-90 V AC ± 20 % Yes Yes Yes Yes Metering 50/60 Hz Yes Yes Yes Yes Time synchronisation (according to time zone) Yes 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) Yes 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 Yes 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 Continued on next page IG-267-EN versión 01; 07/04/

60 Protection, metering and control models General Instructions Continuation -100 Protection, metering and control units Model Type v p v p Active/reactive/apparent power No No Yes 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 Yes Yes Yes Yes 2 x Ethernet, local configuration with Web server Yes Yes Yes Yes 2 x RS-485, for remote control Yes Yes Yes Yes * For further information please ask Ormazabal s technical-commercial department Table 8.1. characteristics Relay configurator The following configurator will be used to select the right unit within the -100 series, in accordance with the characteristics of the installation: Family Range Model Type Func. I> ED/SD I Pwr. V ekor.rpa v B p Table 8.2. Configurator 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 neutral with zero-sequence toroidal transformers 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 Inputs/outputs: 2 9 inputs/4 outputs 60 IG-267-EN versión 01; 07/04/2017

61 General Instructions Protection, metering and control models 8.2. v type -110-v and -120-v units Functional description The -110-v and -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. 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. 1 Interconnection terminal block v or -120-v Unit 3 Voltage and current sensors Figure v IG-267-EN versión 01; 07/04/

62 Protection, metering and control models General Instructions Definition of digital inputs/outputs The -110-v and -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 E1 External trip S1 Trip indication E2 Switch closed S2 Watchdog E3 Switch open S3 Opening sequence E4 Disconnector in busbar position S4 Closing order E5 Disconnector in open position E6 Switch in earthing position E7 Springs loaded E8 Anti-pumping relay E9* Monitoring of the closing coil (in the open and closed positions) * Where E9 must be associated to open coil monitoring Table 8.3. 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 -110-v and -120-v terminal block is shown below. Figure 8.4. inputs/outputs configuration 62 IG-267-EN versión 01; 07/04/2017

63 General Instructions Protection, metering and control models Installation in a cubicle The components of the -110-v and -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 (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 -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: Terminals group 1. Interconnection terminal block v or -120-v electronic relay 3. Voltage and current sensors Subgroup Terminals Functionality and common use 1.1 Power and communications bus 1.2 Relay terminal block 1.3. Cubicle terminal block Interconnection connectors Terminal block A Terminal block G Temperature bus connector P.M. Terminal block-52 Terminal block J Connector-CTD * See relay terminals. * See relay terminals functionality Current transformer connectors 3.2. Capacitive sensor connectors Connector-Ip Connector-D 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. Additional energy module for bistable release. 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. Table 8.4. Installation IG-267-EN versión 01; 07/04/

64 Protection, metering and control models General Instructions Release 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 technicalcommercial department for your zone. I&V Sensors 1 Interconnection terminal block 1.1 Power and communications bus 1.2 Relay terminal block 1.3 Cubicle terminal block v or -120-v Electronic relay 3 Voltage and current sensors 3.1 Sensors interconnection Figure 8.5. installation Checking and maintenance The -110-v and -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. 64 IG-267-EN versión 01; 07/04/2017

65 General Instructions 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. IG-267-EN versión 01; 07/04/

66 Protection, metering and control models General Instructions 8.3. p type -110-p and -120-p units Functional description The 110 p and -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. Figure 8.7. Transformer protection 1 Terminal block p or -120-p electronic relay 3 Voltage and current sensors Figure p Figure 8.8. General protection (customer supply in MV) 66 IG-267-EN versión 01; 07/04/2017

67 General Instructions Protection, metering and control models Definition of digital inputs/outputs The 110 p and -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 E1 External trip S1 Trip indication E2 Switch closed S2 Watchdog E3 Switch open S3 Opening sequence E4 Disconnector closed S4 Closing order E5 Fuse blow closed E6 General purpose E7 General purpose E8 General purpose E9 General purpose Table 8.5. Ratio of signals available for the nine inputs and four outputs module 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 -110-p and -120-p terminal block for 9 inputs 4 outputs is shown below. Figure 8.9. Relay inputs and outputs configuration IG-267-EN versión 01; 07/04/

68 Protection, metering and control models General Instructions Fuse protection The -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 -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 n = S/ 3 x U n. 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 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 %. I n 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. I cs = I n x 100/U k = 48 A x 100/5 = 960 A 68 IG-267-EN versión 01; 07/04/2017

69 General Instructions Protection, metering and control models 1 Choice of fuse 125 A 2 Rated current 48 A 3 Continuous overload 58 A 4 Curve type E.I. 5 Factor K = Short-circuit level 404 A 7 Instantaneous timing 400 ms 8 Secondary three-phase short-circuit 960 A 9 Fuse operation zone 10 Relay operation zone (s) Time (A) Current Figure Example for SIBA SSK fuse IG-267-EN versión 01; 07/04/

70 Protection, metering and control models General Instructions 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 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.) Unit Type Designation Value Enabling the unit Enable ON Phase timed unit (1) (UNIT_51) Starting up the unit Inverse curve time index Pick_up* Index 58 (A) 0.20 Time curve Fixed time Curve Time EI --- Torque control Direction OFF Phase instantaneous unit (1) (UNIT_50) Enabling the unit Unit timing Enable Time ON 0.40 (s) Starting up the unit Torque control Pick_up Direction 404 (A) --- Sensitive neutral timed unit (1) (UNIT_51NS) Sensitive neutral instantaneous unit (UNIT_50NS) 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 Table 8.6. Settings 70 IG-267-EN versión 01; 07/04/2017

71 General Instructions Protection, metering and control models Installation in a cubicle The components of the -110-p and -120-p units are, as with the -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. Release I&V Sensors 1 Interconection terminal block 1.1 Power and communications bus 1.2 Relay terminal block 1.3 Cubicle terminal block p or -120-p electronic relay 3 Voltage and current sensors 3.1 Sensors interconnection Figure installation IG-267-EN versión 01; 07/04/

72 Protection, metering and control models General Instructions Checking and maintenance The solution for facilities with 110 p and -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. 1 Figure Earth screen: It must pass through the inside of the current transformers Installation of toroidal-core current transformers 72 IG-267-EN versión 01; 07/04/2017

73 General Instructions User configuration settings 9. 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. 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 Local protection and automation settings The settings list is classified as follows: System information (INFORMATION). Read-only. System settings (SETTINGS) -- General settings (GENERAL_SETTINGS) -- Protection settings (PROTECTION) -- Automation settings (AUTOMATISM) -- Local port communication settings (COMMUNICATION) System information (INFORMATION) Node System Table 9.1. Information Type Designation Possible values Value by default System Device -100 Read Only Equipment model Model /2022/2024/3021/3022/3024 Read Only Range Range 110/120 Read Only Type Type V/P Read Only One-core/Three-core/Calibrated/EVTC/ Type of coupling Coupling Busbar1/Busbar2/Busbar3/Busbar4/Busbar5/ Read Only Busbar6/cgm3/cosmos/etc. 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 Information System settings (SETTINGS) General settings (GENERAL_SETTINGS) Node General Table 9.2. Settings Type Designation Range Min. Max. Step (unit) Network frequency Frequency (Hz) Time zone Time_Zone Settings IG-267-EN versión 01; 07/04/

74 User configuration settings General Instructions Protection settings (PROTECTION) Type Class Node Current protection (CURRENT_PROTECTION) Overcurrent protection (OVERCURRENT) Phase timed unit (1) (UNIT_51) Phase timed unit (2) (UNIT_51_2) Phase instantaneous unit (1) (UNIT_50) Neutral timed unit (1) (UNIT_51N) Type Settings Designation Range Min. Max. Step (unit) Enabling the unit Enable ON/OFF Starting up the unit Pick_up* (A) 0.1 (A) 0.1 (A) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* , , (A) 0.1 (A) 0.1 (A) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* , , (A) 0.1 (A) 0.1 (A) Unit timing Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* , , (A) 0.1 (A) 0.1 (A) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Neutral timed unit (2) Time curve (UNIT_51_2_N) Neutral instantaneous unit (UNIT_50N) Pick_up* Curve , ,000.0 IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI 0.1 (A) 0.1 (A) 0.1 (A) Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* , , (A) 0.1 (A) 0.1 (A) Unit timing Time (s) Torque control Direction OFF/FORWARD/REVERSE Continued on next page 74 IG-267-EN versión 01; 07/04/2017

75 General Instructions User configuration settings Continuation Type Class Node Current protection (CURRENT_PROTECTION) Overcurrent protection (OVERCURRENT) Directional units (DIRECTIONAL) Sensitive neutral timed unit (1) (UNIT_51NS) Sensitive neutral timed unit (2) (UNIT_51_2_ NS) Sensitive neutral instantaneous unit (UNIT_50NS) Phase directional unit (UNIT_67) Neutral directional unit (UNIT_67N) Sensitive neutral directional unit (UNIT_67NS) Settings Type Designation Range Min. Max. Step (unit) Enabling the unit Enable ON/OFF Starting up the unit Pick_up* (with vector sum) Pick_up* (with zero-sequence toroidal) (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* (with vector sum) Pick_up* (with zero-sequence toroidal) , (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Torque control Direction OFF/FORWARD/REVERSE Enabling the unit Enable ON/OFF Starting up the unit Pick_up* (with vector sum) Pick_up* (with zero-sequence toroidal) , (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) Unit timing Time (s) Torque control Direction OFF/FORWARD/REVERSE Characteristic phase angle Characteristic Angle (º) Minimum phases voltage V_min (kv) Indeterminate zone Indeterminate_zone (º) Directional method type Type ANG/WAT Characteristic neutral angle Characteristic Angle (º) Minimum neutral active power P_min (kw) Minimum neutral voltage V_min (kv) Indeterminate zone Indeterminate_zone (º) Directional method type Type ANG/WAT Characteristic sensitive neutral angle Characteristic Angle (º) Minimum neutral active power P_min , (kw) Minimum neutral voltage V_min (kv) Indeterminate zone Indeterminate_zone (º) Continued on next page IG-267-EN versión 01; 07/04/

76 User configuration settings General Instructions Continuation Settings Type Class Node Type Designation Range Min. Max. Step (unit) Enabling the unit Enable ON/OFF Current protection (CURRENT_PROTECTION) Voltage protection (VOLTAGE_PROTECTION) Negative sequence protection (NEGATIVE SEQUENCE) Blocking units (BLOCKING) Undervoltage protection UNDERVOLTAGE Broken conductor unit (UNIT_46BC) Second harmonic blocking unit (SECOND_ HARMONIC) Undervoltage timed unit (UNIT_27_ TEMP) Undervoltage instantaneous unit (UNIT_27_ INST) Base current Base_current I n/i1 Starting up the unit (I2/I1) Pick_up_ratio (pu) Unit timing Time (s) Current threshold for phases Min_phase_current* (A) 0.1 (A) 0.1 (A) Maximum current threshold for neutral Max_homo_current_ ratio (s) Enabling the unit Enable ON/OFF Second harmonic threshold Second_harmonic_ threshold (%) Type of cross-blocking Cross_blocking OFF/1_OUT_OF_3/2_OUT_OF_3 Minimum current threshold for phases Minimum current threshold for calculated neutral Minimum current threshold for measured neutral Maximum current threshold for phases Min_phase_current Min_neutral_current Min_sensit_neutral_ current Max_phase_current , , , , , , (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) 0.1 (A) Maximum block time Max_blocking_time (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 PHASE-TO-NEUTRAL PHASE-TO-PHASE Starting up the unit Pick_up (kv) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Enabling the unit Enable ON/OFF Working voltage Voltage PHASE-TO-NEUTRAL PHASE-TO-PHASE Starting up the unit Pick_up (kv) Unit timing Time (s) Continued on next page 76 IG-267-EN versión 01; 07/04/2017

77 General Instructions User configuration settings Continuation Type Class Node Voltage protection (VOLTAGE_PROTECTION) Overvoltage protection (OVERVOLTAGE) Overvoltage timed unit(unit_59_ TEMP) Overvoltage instantaneous unit (UNIT_59_ INST) Neutral overvoltage timed unit (UNIT_59N_ TEMP) Settings Type Designation Range Min. Max. Step (unit) Enabling the unit Enable ON/OFF Working voltage Voltage PHASE-TO-NEUTRAL PHASE-TO-PHASE Starting up the unit Pick_up (kv) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Enabling the unit Enable ON/OFF Working voltage Voltage PHASE-TO-NEUTRAL PHASE-TO-PHASE Starting up the unit Pick_up (kv) Unit timing Time (s) Enabling the unit Enable ON/OFF Starting up the unit Pick_up (kv) Time curve Curve IEC: DT, NI, VI, EI, STI and LTI ANSI: NI, VI, EI and LI Inverse curve time index Index Fixed time Time (s) Neutral overvoltage instantaneous unit(unit_59n_ INST) Enabling the unit Enable ON/OFF Starting up the unit Pick_up (kv) Unit timing Time (s) Temperature protection (TEMPERATURE_ PROTECTION) Thermal overload protection (THERMALOVERLOAD) Thermal image unit (UNIT_49) Enabling the unit Enable ON/OFF Temperature rise constant Heating_Constant (min) Cooling constant Cooling_Constant (min) Alarm level Alarm_Threshold (%) Trip level Trip_Threshold (%) Trip reset level Restore_Threshold (%) Rated current Nominal_Current* , ,000.0 * The different ranges for these settings are relative to the current transformers installed (300/1, 1000/1 and 2500/1 respectively) 0.1 (A) 0.1 (A) 0.1 (A) Table 9.3. Protection IG-267-EN versión 01; 07/04/

78 User configuration settings General Instructions Automation settings (AUTOMATISM) Node Recloser automation (RECLOSER) Settings Type Designation Range Min. Max. Step (unit) Enabling the unit Enable ON/OFF Number of reclosings Reclose_Number First recl. time for phases Phase_Reclosing_Time_ (s) First recl. time for neutral Neutral_Reclosing_ Time_ (s) Second recl. time for phases Phase_Reclosing_Time_ (s) Second recl. time for neutral Neutral_Reclosing_ Time_ (s) Third recl. time for phases Phase_Reclosing_Time_ (s) Third recl. time for neutral Neutral_Reclosing_ Time_ (s) Fourth recl. time for phases Phase_Reclosing_Time_ (s) Fourth recl. time for neutral Neutral_Reclosing_ Time_ (s) 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 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 (s) Safety time following phase fault reclosing Phase_Blocking_Time (s) Safety time following neutral fault reclosing Neutral_Blocking_Time (s) Safety time after external or manual close Manual_Blocking_Time (s) Switch error automation (UNIT_50BF) State method (STATUS_METHOD) Switch opening failure time Opening_Error_time (s) Switch closing failure time Closing_Error_Time (s) Voltage presence/ absence automation (VOLTAGE PRESENCE_ ABSENCE) Enabling the unit Enable ON/OFF Line voltage Grid_Voltage (kv) Presence of voltage level Presence_Voltage (%) Absence of voltage level Absence_Voltage (%) Voltage presence/absence hysteresis Hysteresis_Voltage (%) Presence of voltage time Presence_Time (s) Absence of voltage time Absence_Time (s) Table 9.4. Automation 78 IG-267-EN versión 01; 07/04/2017

79 General Instructions User configuration settings Communication settings (COMMUNICATION) Settings Node Range Type Designation Min. Max. Step (unit) Peripheral number Perif_Num Speed Baud rate 1200/2400/4800/9600/19200/38400 baud COM_485 Parity Parity No/Odd/Even Length Length Stop bits Stopbits Protocol Protocol CIRBUS/MODBUS/PROCOME COM_ Peripheral number Perif_Num VIRTUAL Protocol Protocol CIRBUS/MODBUS/PROCOME Table 9.5. Communication 9.2. Date and time settings Settings (LOCAL_TIME_CLOCK) Node Date (DATE) Time (TIME) Table 9.6. Settings Type Designation Range Min. Max. Step (unit) Day Day (day) Month Month (month) Year Year (year) Time Time (hour) Minute Min (minute) Second Sec (second) Date and time setting 9.3. Remote communication settings IP addresses Node IP_Local IP_RTU1 IP_RTU2 Table 9.7. Settings Type Designation Format 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) IP setting IG-267-EN versión 01; 07/04/

80 Log record General Instructions 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. 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 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. 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 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. 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. 1 Fault report capture window 2 Start of capture 3 Start of fault 4 End of capture Figure Faults 80 IG-267-EN versión 01; 07/04/2017

81 General Instructions Log record Structure of the report The fault report can be divided into five functional parts: 1. Information on the system the report belongs to. 2. Fault summary or report. 3. Status of system protection units at the moment of the fault. 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 System (DEVICE): Serial number (S.N.): Available units (Available units) Fault report -XXX-v/p Aaabbccddd (family/year/week/unit) Start (Fault Start) Tripping order (TRIP Command) End of Fault (Fault end) 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) Tripping time (Trip time) Unit_Type-Group-Subgroup xxx.xxx.xxx (ms) xxx.xxx.xxx (ms) Enabled (Enable) Started-up (Picked up) Curve met (Temporized) Length of fault (Fault Duration) Tripped (Tripped) Unit_Node-Phase-Temp. No (Empty)/Yes (X) No (Empty)/Yes (X) No (Empty)/Yes (X) No (Empty)/Yes (X)... Phase 1: Module (A) Argument (º) Phase 2: Module (A) Argument (º) Switch opening current Phase 3: Module (A) Argument (º) (TRIPPED Current): Neutral (N.C.): Module (A) Argument (º) N. Sensitive (N.S.): Module (A) Argument (º) Event record (Event Record) Date/Time Phasor currents and voltages Pre-fault event Unit_Type-Group-Subgroup_Signal-ON/OFF Date: dd-mm-yy Time: hh-mm-ss-ms Date: dd-mm-yy Time: hh-mm-ss-ms... Close Fault Report_Reason for close Date: dd-mm-yy Time: hh-mm-ss-ms Empty 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 ( ) 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 ( ) Table Fault report (FAULT REPORT) IG-267-EN versión 01; 07/04/

82 Log record General Instructions 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 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) Type Pre-fault event Reason for end fault: UPs OFF, Fault cleared Loss of power (V dc 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 82 IG-267-EN versión 01; 07/04/2017

83 General Instructions Log record 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) Subgroup 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) (-) Type 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) Table Available signals IG-267-EN versión 01; 07/04/

84 Log record General Instructions 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 operations, software changes log, synchronisation, etc. The system stores up to 4000 events in a circular buffer, ordered in ascending chronological order, i.e. when the events queue is full, the oldest one is eliminated and the new one is registered automatically. 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). These events have a specific structure and are classified by functional groups, in order to use filters which help in querying or analysing incidents The defined structure is: N event Flag Date/Time Group Type Description Position Table Structure 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. 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 0 Proprietary Activated list of events to check correct operation of the system. 1 Urgent Relative to those classified as urgent flaws. 2 Alarm Grouping of existing alarms. 3 Protection and automations Relative to protection and automations 4 Driving elements statuses and orders Relative to the statuses and orders of the positions 5 Other events All events which are not saved as special events. 6 High occurrence Relative to communications. Table Functional groups 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. 84 IG-267-EN versión 01; 07/04/2017

85 General Instructions User interface 11. 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: Configuration settings (XML Format) Date/time (XML format) Fault records (TXT format) Event record (XLS format) System information (PDF format) 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 mini- USB 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: Figure Files Web server. Checking and configuring parameters 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 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 IG-267-EN versión 01; 07/04/

86 User interface General Instructions Access to the Web server: Local and remote access The 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 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. 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. Login control 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: 1 IP address 2 User 3 Password Figure Local access User login The local access IP address by default is 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 Figure 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 86 IG-267-EN versión 01; 07/04/2017

87 General Instructions User interface Checking and modifying parameters using the Web server The website is divided into four main tabs: Maintenance, Logs, Configure and Leave. Meterings: The different meterings of the system are shown. 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. Figure 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 and the protection units is displayed. 1 Display tab 2 Switchgear status 3 Cubicle status indicators 4 Meterings Figure 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. Figure 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. 1 Active alarm 2 Inactive alarm Figure Alarm tab 1 Input disabled 2 Input enabled Figure I/O inputs tab IG-267-EN versión 01; 07/04/

88 User interface General Instructions 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. 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: N event Flag Date/Time Group Type Description Position Table Structure The tab can be used to apply filters to display the events registered in : Filter by date, by group and/or type of event, select the number of events to be displayed per page, etc. 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 Faults 1 Display filter 2 Save 3 Events 4 Events summary 5 Protection unit events Figure Event record 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 Software versions record 88 IG-267-EN versión 01; 07/04/2017

89 General Instructions User interface Configuration This tab is used to configure the different parameters of the substation: Protection unit settings, remote IP addresses Password: Used to change the passwords for administrator mode and display mode (when not managed by LDAP). Protection: Display and change protection unit settings. Figure Change administrator mode and display mode passwords Figure Configuration IP RTU: Display and change IP parameters, NTP parameters, LDAP parameters, timings, etc. They can be loaded and downloaded in an.xml file. Special automation menus: Used to change the configuration parameters of the different automations implemented. Figure Menus screen Figure Display and change RTU parameters IG-267-EN versión 01; 07/04/

90 User interface General Instructions Keyboard/Display Introduction 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 has 6 keys: 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. 1 SET 2 ESC 3 Up 4 Down 5 Left 6 Right Figure 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. 90 IG-267-EN versión 01; 07/04/2017

91 General Instructions User interface Example: 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. Figure Tree structure implemented in the display of the -100 units 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 Display screen The main browsing branch is as follows: General display screen for user settings General display screen for date and time Current and voltage phasor. Double screens: Module + argument General display screen for statuses General display screen for fault reports General display screen for meterings General display screen for system information Table Display IG-267-EN versión 01; 07/04/

92 User interface General Instructions 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. Clock The screens structure for the date and time is: Figure Clock Status The screens structure for different system statuses is: Figure Status 92 IG-267-EN versión 01; 07/04/2017

93 General Instructions User interface Logs The screen structure for the last 10 reports stored in the system is: Figure 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. The user should press the ESC key in order to leave the priority screen and return to the initial fault screen. IG-267-EN versión 01; 07/04/

94 User interface General Instructions Measures The screens structure for the system meterings is: Figure Measures 94 IG-267-EN versión 01; 07/04/2017

95 General Instructions User interface Information The screens structure for system information is: Figure Information IG-267-EN versión 01; 07/04/

96 User interface General Instructions Error codes The -100 units have a series of error codes used to warn the user regarding the different anomalies that may occur in the system. Figure Error Each type of error has a unique error number defined, meaning its identification cannot be mistaken: Code shown on the display ER 03 ER 04 ER 05 ER 06 ER 07 ER 08 ER 09 ER 0A Meaning 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 Switches between the error code and the screen where the user is at this moment Table Errors 96 IG-267-EN versión 01; 07/04/2017

97 General Instructions User interface 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. Figure Connections with USB cable 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 Detection of a new drive unit IG-267-EN versión 01; 07/04/

98 User interface General Instructions 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). Faults folder: Directory where the faults recorded by the system are saved. "Measures folder: Directory where system meterings are saved. Figure Drive units 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, 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 1 Import Update system firmware Upgrade.hex 2 Import Update system setting Ecu_log.ekp 3 Import Update user settings User_PSWU.xml 4 Import Update date/time RTC_PSWU.xml 5 Export Restore files in USB memory 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 Table Priority order 98 IG-267-EN versión 01; 07/04/2017

99 General Instructions User interface The firmware or configuration 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 configuration 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 configure 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 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 Drive screen IG-267-EN versión 01; 07/04/

100 User interface General Instructions 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. 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: 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: Figure 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.). Figure ekor.soft-xml 100 IG-267-EN versión 01; 07/04/2017

101 General Instructions User interface The new settings can be sent to the system as follows: Click on the "Send to Device" button. The software will ask for a password. Enter the correct Password (0000 by default) and click on the OK button: Confirm that the update is correct by clicking on the Check button: Figure Check Screen Figure Password screen The software then asks to run the update order. This means the ESC and the right-arrow keys should be kept pressed down at the same time for an instant (approximately 1s is enough). This order will reset the system and apply the new settings. These keys have a circular symbol around them, in order to clearly identify them as keys which can carry out this order. When clicking on the Check button, the software will indicate whether it has loaded correctly or there are any errors. The update/display settings procedure is the same for both user settings and for date/time settings. In order to reload any of the files in the software, click on the Setting Selection button, select the file to be displayed and click on the OK button. IG-267-EN versión 01; 07/04/

102 Communications General Instructions 12. Communications Physical medium: RS-485 The physical medium used to establish telecontrol communications for the -100 series is a twisted pair cable which connects to the rear RS-485 port (identified as COM0 and COM1) through an RJ-45 connector. Figure RS Not used 7 Not used 6 GND (-) (+) 3 Not used 2 Not used 1 Not used 8 Not used 7 Not used 6 GND (-) 485 (1) (+) 3 GND (-) 485 (2) (+) The COM0 is the port used when the unit works as a telecontrol slave (MODBUS or PROCOME slave). The communication parameters for the RS-485 COM0 port can be modified using the user settings. These settings are classified in the field Communications/COM_485 and are as follows: Peripheral number: To set the slave number (from 1 to 99). Bauds: Transmission speed (1200, 2400, 4800, 9600, or bauds). Parity: Parity (No, Even or Odd). Length: Length (7 or 8 bits) Stop bits: Stop bits (1 or 2 bits) Protocol: Protocol which speaks through report 485 (Cirbus, MODBUS or PROCOME). The COM1 port is the port used when the unit works as a MODBUS master for the temperature sensors connected to the bus. This connection may be carried out in either of the 2 RS-485 ports (can be chosen by configuration) available in the COM1. Temperature supervision through the temperature sensors will only be functional as an option in the -120 models, meaning the COM1 will only apply for these models MODBUS protocol The -100 unit can be configured for the COM0 port communication protocol to be MODBUS. The system therefore works as a MODBUS slave in RTU transmission mode (Binary). The main advantage of this mode over the ASCII mode is that the information is packed tighter, allowing a higher data transmission rate at the same communication speed. Each message is transmitted as a continuous string, as silences are used to detect the end of the message. The minimum duration of the SILENCE is 3.5 characters. RTU message frame Start Address Function Data CRC End Silence 8 bits 8 bits n x 8 bits 16 bits Silence Table RTU message frame The MODBUS ADDRESS of the relay (also called peripheral number) is a byte that takes values between 0 and 99. The master addresses the slave, indicating its address in the respective field, and the slave answers by indicating its own address. The "0" address is reserved for the broadcast mode so it can be recognised by all slaves. 102 IG-267-EN versión 01; 07/04/2017

103 General Instructions Communications Read/write functions In principle, only two functions will be implemented, one for reading and another for writing data. Data reading Question: Start Address Function Data CRC End Silence DESC 3 ADDR-H ADDR-L NDATA-H NDATA-L 16 bits Silence Table Data reading. Question Response: Start Address Function Nº of Bytes Data CRC End Silence DESC 3 N DATA1-H DATA1-L bits Silence Table Data reading. Response where: DESC Slave address ADDR-H High byte of the address for the first register to be read ADDR-L Low byte of the address for the first register to be read NDATA-H High byte of the number of registers to be read NDATA-L Low byte of the number of registers to be read DATA1-H High byte of the first register requested DATA 1-L Low byte of the first register requested N Total number of data bytes This will be equal to the number of registers requested Data writing This makes it possible to write a single register at the address indicated. Question: Start Address Function Data CRC End Silence DESC 6 ADDR-H ADDR-L DATA-H DATA-L 16 bits Silence Table Data writing. Question Response: The normal response is an echo of the query received. where: DESC Slave address ADDR-H High byte of the address for the register to be written ADDR-L Low byte of the address for the register to be written DATA-H High byte of the data to be written DATA-L Low byte of the data to be written IG-267-EN versión 01; 07/04/

104 Communications General Instructions Response in case of error Start Address Function Error-Code CRC End Silence DESC FUNC_ERR CODE_ERROR 16 bits Silence Table Data Writing. Response in case of error Where: DESC Slave address FUNC_ERR Code of the function requested, with the most significant bit at 1 CODI_ERROR Code of the error occurred 1 Function error Function not supported by the system 2 Incorrect address due to undeclared address or readings/writings in records with read-only/right-only privileges 3 Data to be entered in record incorrect 4 Error independent of the protocol in the master or slave when running the function Password-protected write Some of the parameters of the MODBUS map are protected from writing using different PASSWORDs. A write session of Password-protected parameters starts by entering the PASSWORD in the respective address. The write session ends with the update of registers once the respective PASSWORD has been transmitted again. If the timeout period has elapsed, the process is aborted and the system returns to normal mode. In normal mode, any attempt to write a protected registration will result in an error code '2'. CRC Generation The cyclical redundancy check (CRC) field contains two bytes that are added to the end of the message. The receiver must re-calculate it and compare it with the received value. Both values must be equal. The CRC is the remainder obtained when dividing the message by a binary polynomial. The receiver must divide all bits received (information plus CRC) by the same polynomial used to calculate the CRC. If the remainder obtained is 0, the information frame is deemed correct. The polynomial used will be: X 15 + X Register Map Information (0 x 02XX) Address Field Description Size Read/write 0 x 0226 Set at 0 x FF Set at 0 x FF 16 bits Read-only 0 x 0227 Set at 0 x FF Set at 0 x FF 16 bits Read-only 0 x 0228 NOT USED NOT USED 16 bits Read-only 0 x 0229 NOT USED NOT USED 16 bits Read-only 0 x 022A System Set at 0 x FF FAMILY (LOW) 16 bits Read-only 0 x 022B Identifier CHARACTERISTICS (HIGH) VER. FW (LOW) 16 bits Read-only 0 x 022C (Table 2) VER. HW (HIGH) FUNCTIONALITY (LOW) 16 bits Read-only 0 x 022D SUBVER. FW (HIGH) VER. FW DEVELOPMENT (LOW) 16 bits Read-only 0 x 022E Update control NOT USED UPDATE CONTROL (LOW) 16 bits Read-only 0 x bits Read-only 0 x 0233 Serial nº in BCD format 16 bits Read-only Serial number 0 x 0234 (Big Endian) 16 bits Read-only 0 x bits Read-only 0 x º digit (ASCII 8 bits) 2nd digit (ASCII 8 bits) 16 bits Read-only 0 x 0237 Logic table identifier 3rd digit (ASCII 8 bits) 4th digit (ASCII 8 bits) 16 bits Read-only 0 x th digit (ASCII 8 bits) 6th digit (ASCII 8 bits) 16 bits Read-only Table Information 104 IG-267-EN versión 01; 07/04/2017

105 General Instructions Communications Clock (0 x 03XX) Address Field Description Size Read/write 0 x 0300 YEAR Year (from 2000 to 2059) 16 bits Read/write 0 x 0301 MONTH DAY Month (from 1 to 12) DAY (FROM 1st to 31st) 16 bits Read/write 0 x 0302 TIME MIN Time (FROM 0 to 23) MINUTE (from 0 to 59) 16 bits Read/write 0 x SEC 0 SECOND (from 0 to 59) 16 bits Read/write Table Clock Password (0 x 05XX) Address Field Description Size Read/write 0 x 0500 User Key. Key to access settings with user privileges (From 0 to 9999) 16 bits Write-only Table Password Commands and outputs (0 x 06XX) Address Field Description Size Read/write 0 x 0600 cmb0-cmb15 Write: From cmb0 (LSB) to cmb15 (MSB) Read: From SAL1 (LSB) to SAL7 and from cmb7 to cmb15 (MSB) 16 bits Read/write 0 x 0601 cmb16-cmb31 Read and write: From cmb16 (LSB) to cmb31 (MSB) 16 bits Read/write 0 x 0602 cmb32-cmb47 Read and write: From cmb32 (LSB) to cmb47 (MSB) 16 bits Read/write 0 x 0603 cmb48-cmb63 Read and write: From cmb48 (LSB) to cmb63 (MSB) 16 bits Read/write Table Command and outputs Meterings and statuses (0 x 07XX) Address Field Description Size Read/write 0 x 0700 VA A Phase voltage (Volts) 32 bits Read 0 x 0702 VB B Phase voltage (Volts) 32 bits Read 0 x 0704 VC C Phase voltage (Volts) 32 bits Read 0 x 0706 VN Neutral voltage (Volts) 32 bits Read 0 x 0708 IA A phase current (Hundredths of an ampere) 32 bits Read 0 x 070A IB B phase current (Hundredths of an ampere) 32 bits Read 0 x 070C IC C phase current (Hundredths of an ampere) 32 bits Read 0 x 070E INS Sensitive neutral current (Hundredths of an ampere) 32 bits Read 0 x 0710 emb0-emb15 MODBUS statuses of the 0 (LSB) 15 (MSB) 16 bits Read 0 x 0711 emb16-emb31 MODBUS statuses of the 16 (LSB) 31 (MSB) 16 bits Read 0 x 0712 emb32-emb47 MODBUS statuses of the 32 (LSB) 47 (MSB) 16 bits Read 0 x 0713 emb48-emb63 MODBUS statuses of the 48 (LSB) 63 (MSB) 16 bits Read 0 x 0714 emb64-emb79 MODBUS statuses of the 64 (LSB) 79 (MSB) 16 bits Read 0 x 0715 emb80-emb95 MODBUS statuses of the 80 (LSB) 95 (MSB) 16 bits Read 0 x 0716 emb96-emb111 MODBUS statuses of the 96 (LSB) 111 (MSB) 16 bits Read 0 x 0717 emb112-emb127 MODBUS statuses of the 112 (LSB) 127 (MSB) 16 bits Read 0 x 0718 PA Active power of phase A (Watts) 32 bits Read 0 x 071A PB Active power of phase B (Watts) 32 bits Read 0 x 071C PC Active power of phase C (Watts) 32 bits Read 0 x 071E PT Total active power (Watts) 32 bits Read 0 x 0720 QA Reactive power of phase A (VAr) 32 bits Read 0 x 0722 QB Reactive power of phase B (VAr) 32 bits Read 0 x 0724 QC Reactive power of phase C (VAr) 32 bits Read 0 x 0726 QT Total reactive power (VAr) 32 bits Read 0 x 0730 Set at 0 x FF Set at 0 x FF 16 bits Read 0 x 0731 ANG(VA/VA) VA/VA angle [always 0] 16 bits Read 0 x 0732 ANG(VB/VA) VB/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read Continued on next page IG-267-EN versión 01; 07/04/

106 Communications General Instructions Continuation Address Field Description Size Read/write 0 x 0733 ANG(VC/VA) VC/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0734 ANG(VN/VA) VN/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0735 ANG(IA/VA) IA/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0736 ANG(IB/VA) IB/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0737 ANG(IC/VA) IC/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0738 ANG(INS/VA) INS/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0739 ANG(INC/VA) INC/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0740 INC Calculated neutral current (Hundredths of an ampere) 32 bits Read 0 x 0750 IA (1) Circuit-Breaker Direct sequence (hundredths of an ampere) 32 bits Read 0 x 0752 IA (2) Circuit-breaker inverse sequence (hundredths of an ampere) 32 bits Read 0 x 0754 IA (0) Circuit-breaker zero-sequence (hundredths of an ampere) 32 bits Read 0 x 0756 ANG(IA (1) /VA) IA(1)/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0757 ANG(IA (2) /VA) IA(2)/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0758 ANG(IA (0) /VA) IA(0)/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0770 UAB A-B Compound voltage (Volts) 32 bits Read 0 x 0772 UBC B-C Compound voltage (Volts) 32 bits Read 0 x 0774 UCA C-A Compound voltage (Volts) 32 bits Read 0 x 0776 ANG(UAB/VA) UAB/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0777 ANG(UBC/VA) UBC/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0778 ANG(UCA/VA) UCA/VA angle [from 0 (0.0 ) to 3599 (359.9 )] 16 bits Read 0 x 0780 SA Apparent power of phase A (VAs) 32 bits Read 0 x 0782 SB Apparent power of phase B (VAs) 32 bits Read 0 x 0784 SC Apparent power of phase C (VAs) 32 bits Read 0 x 0786 ST Total apparent power (VAs) 32 bits Read 0 x 0788 FPA F.P. phase A [from 0000 (0.000) to 1000 (1,000)] 16 bits Read 0 x 0789 FPB F.P. phase B [from 0000 (0.000) to 1000 (1,000)] 16 bits Read 0 x 078A FPC F.P. phase C [from 0000 (0.000) to 1000 (1,000)] 16 bits Read 0 x 078B FPT F.P. total [from 0000 (0.000) to 1000 (1.000)] 16 bits Read Table Meterings and statuses Meters (0 x 0AXX) Energy (from 0 x 0A00 to 0 x 0A1F) Three-phase Address (HEX) Field Description Size Read/write 0 x 0A00 ET+ Active energy imported (in kwh) total. 32 bits Read 0 x 0A02 ET- Active energy exported (in kwh) total 32 bits Read 0 x 0A04 QT1 Reactive energy Q1 (in kvarh) total 32 bits Read 0 x 0A06 QT2 Reactive energy Q2 (in kvarh) total 32 bits Read 0 x 0A08 QT3 Reactive energy Q3 (in kvarh) total 32 bits Read 0 x 0A0A QT4 Reactive energy Q4 (in kvarh) total 32 bits Read Table Three-phase Single-phase Address (HEX) Field Description Size Read/write 0 x 0A0C EA+ Active energy imported (in kwh) phase A 32 bits Read 0 x 0A0E EA- Active energy exported (in kwh) phase A 32 bits Read 0 x 0A10 QA1 Reactive energy Q1 (in kvarh) phase A 32 bits Read 0 x 0A12 QA2 Reactive energy Q2 (in kvarh) phase A 32 bits Read 0 x 0A14 QA3 Reactive energy Q3 (in kvarh) phase A 32 bits Read 0 x 0A16 QA4 Reactive energy Q4 (in kvarh) phase A 32 bits Read Continued on next page 106 IG-267-EN versión 01; 07/04/2017

107 General Instructions Communications Continuation Address (HEX) Field Description Size Read/write 0 x 0A18 EB+ Active energy imported (in kwh) phase B 32 bits Read 0 x 0A1A EB- Active energy exported (in kwh) phase B 32 bits Read 0 x 0A1C QB1 Reactive energy Q1 (in kvarh) phase B 32 bits Read 0 x 0A1E QB2 Reactive energy Q2 (in kvarh) phase B 32 bits Read 0 x 0A20 QB3 Reactive energy Q3 (in kvarh) phase B 32 bits Read 0 x 0A22 QB4 Reactive energy Q4 (in kvarh) phase B 32 bits Read 0 x 0A24 EC+ Active energy imported (in kwh) phase C 32 bits Read 0 x 0A26 EC- Active energy exported (in kwh) phase C 32 bits Read 0 x 0A28 QC1 Reactive energy Q1 (in kvarh) phase C 32 bits Read 0 x 0A2A QC2 Reactive energy Q2 (in kvarh) phase C 32 bits Read 0 x 0A2C QC3 Reactive energy Q3 (in kvarh) phase C 32 bits Read 0 x 0A2E QC4 Reactive energy Q4 (in kvarh) phase C 32 bits Read Table Single-phase Thermal capacity (from 0 x 0A80 to 0 x 0A9F) Address (HEX) Field Description Size Read/write 0 x 0A80 T [tenths of %] Thermal capacity 32 bits Read Table Thermal capacity PROCOME protocol The -100 unit can be configured for the COM0 port communication protocol to be PROCOME. The system therefore works as a PROCOME slave. PROCOME is an asynchronous serial communication protocol conceived for data transfer between control and protection equipment in electrical installations, following standards IEC The PROCOME implementation in the 100 unit has initialisation functions (without key) and control functions, along with file transfer in order to exchange different types of information: Inputs + digital statuses. Meterings. Settings files. Fault records Orders. Link Level The link layer follows the indications given about the PROCOME protocol. These frames follow the T1.2 frames standard of the IEC, However, the length of the address field of the equipment is 8 bits. The value 0xFF in the addresses is reserved for broadcasting. The fixed-length frames structure (without application data) is as follows: Offset Name Value Description 0 Start 0 x 10 Fixed-length frame start indication 1 Control 0 x 00 0 x FF Control word 2 Address 0 x 00 0 x FF Destination/source node address 3 Sum 0 x 00 0 x FF Sum of offsets 0 and 1 data (control and address) 4 End 0 x 16 End of frame indication Table Fixed length frames structure IG-267-EN versión 01; 07/04/

108 Communications General Instructions The variable-length frames (with application data) have the following length: Offset Name Value Description 0 Start1 0 x 68 Variable-length frame start indication 0.1 Length 0 x 02 0 x FB User data length (in Little Endian), from Offset 3 to Offset immediately before the addition The contents of the first byte are copied on the second byte, therefore if length = 10 bytes, the value of the field is 0x0A0A 2 Start2 0 x 68 User data start indication 3 Control 0 x 00 0 x FF Control word 4 Address 0 x 00 0 x FF Destination/source node address 5 Data User data. The ASDUs are included here - Length + 3 Length + 4 Sum 0 x 00 0 x FF Sum of the control, address and data fields Length + 5 End 0 x 16 End of frame indication Table Variable length frames The following frames are used in PROCOME in the Master to Slave direction: # Name Fcv Description 0 SEND RESET UC No Reset order of the slave link level The slave must delete its queue of changes from ED and set the value of the last FCB received to 0 Positive (0, CONFIRM ACK) or negative (1, CONFIRM NACK) confirmation from the slave is awaited. 3 SEND DATA Yes Data sending with confirmation The performance orders are sent to the ekor.rp.ci units by this system Positive 0, CONFIRM ACK or negative 1, CONFIRM NACK confirmation from the slave is awaited. 4 SEND DATA NR No Data sending without confirmation The date/time of the system is sent to the ekor.rp.ci using this system.no response is awaited from the slaves 6* REQUEST DATA S Yes Specific data request. It is used to obtain control data from the slaves. The value of ED, EA and EC, as well as the changes to ED, are obtained from the ekor.rp.ci units with this mechanism A response with data is awaited (8, RESPOND DATA), with the data not yet available (9, RESPOND NO DATA) or not yet implemented (15*, RESPOND NO IMP) 7* SEND RESET FCB No Reset order of the slave FCB bit level The slave must set the value of the last FCB received to 0, without deleting its queue of changes. Positive confirmation from the slave is awaited. (0, CONFIRM ACK) or negative (1, CONFIRM NACK) 9 REQUEST LSTS No Link level status request It is used to check if the slave is connected. A response 11 is awaited, RESPONDF LSTS 10 REQUEST DATA C1 Yes Category 1 (urgent) data request It is used to obtain urgent data from the slaves. This mechanism only allows the cause of the equipment restart to be obtained from the ekor.rp.ci units A response with data is awaited (8, RESPOND DATA), with the data not yet available (9, RESPOND NO DATA) or not yet implemented (15*, RESPOND NO IMP) 11 REQUEST DATA C2 Yes Category 2 (non-urgent) data request It is used to obtain non-urgent data from the slaves A response with data is awaited (8, RESPOND DATA), with the data not yet available (9, RESPOND NO DATA) or not yet implemented (15*, RESPOND NO IMP) Table Frames in master to slave direction 108 IG-267-EN versión 01; 07/04/2017

109 General Instructions Communications And in slave to master direction: # Name Description 0 CONFIRM ACK Positive confirmation 1 CONFIRM NACK Negative confirmation 8 RESPOND DATA Response with application data 9 RESPOND NO DATA Response without application data 11 RESPOND LSTS Response to link status request 14* RESPOND LERROR Response indicating the slave link level does not work properly 15* RESPOND NO IMP Response indicating the functionality associated to the requested data has not been implemented in the slave Table Frames in slave to master direction Application level For exchanging data between the application functions, between the master and slave equipment, data are encapsulated in the variable-length frames. The application data are named ASDU (Application Service Data Unit) and have a common header that indicates their type followed by specific data for each one. The structure of the header, or data unit identification, is as follows: Offset Name Description 0 Typ Data type identifier The numeric value stored in this field is used to name the application data in an unequivocal way 1 Vsq Variable structure qualifier Indicates the number of data structures included in ASDU 2 Cot Cause of transmission. Indicates the cause of the data transmission 3 Addr ASDU address ASDU application level address. It does not have to be the same as the link level address, since a link connection could be used for several application connections. However, in PROCOME it is the same Table Data unit identification structure The table below shows the information object associated to the data type. The structure of this object depends on the data transmitted in each case, but each of them have the same start, the information object identifier whose structure is as follows: Offset Name Description 4 Fun Function type 5 Inf Information number Table Information object identifier structure Finally, the information object data from offset 6 is included in the application data field. The ASDUs used in PROCOME have preset values for each of the header fields. IG-267-EN versión 01; 07/04/

110 Communications General Instructions The ASDUs used in the data exchange between masters and slaves correspond to an application profile that supports the start of the secondary stations, the control functions, the control enquiry, the control digital signals refresh (supporting the possible overflow corresponding to the buffer of changes) and the command orders. This means the ASDUs in secondary (slaves) to primary (master) direction are as follows: Typ Description 5 Identification 100 ED changes and meterings (photo EA and changes) transmission 101 Counters transmission (photo EC) 103 ED current status transmission (photo ED) 121 Command orders 200 Transmission of MODBUS records on the PROCOME protocol 203 Time zone transmission Table ASDUs in secondary direction (slaves) to primary (master) In primary to secondary direction they are as follows: Typ Description 6 Slave time synchronisation 100 Control data request (photo EA, ED changes, stop EC and photo EC) 103 ED current status request (photo ED) 121 Command orders 200 Read/write modbus records on the PROCOME protocol 203 Read/write time zone Table ASDUs in primary direction (master) to secondary (slaves) Physical medium: Ethernet The physical medium used for connection to the web implemented in the -100 is an Ethernet cable which connects to the rear Ethernet ports (identified as ETH0 and ETH1) through an RJ-45 connector. The Ethernet ETH1 port is the local access port and the associated default IP address is The Ethernet ETH0 port is the remote access port and the default IP address is The web can be accessed through either of the 2 ports, provided the IP address is correct. Go to section Web server. Checking and configuring parameters for further details on the information displayed in the system's Web server. Figure Rear Ethernet ports 110 IG-267-EN versión 01; 07/04/2017

111 General Instructions Communications Physical medium: Mini-USB The physical medium used to access the USB memory of the -100 systems is a USB cable which connects to the mini-usb port on the front. Figure USB cable Table Pins Pin Name Description 1 Vbus 5V 2 D- Data - 3 D+ Data + 4 ID Distinguishes between the host or device in accordance with whether it is connected to earth or does not connect 5 GND Earth Current operating systems can read and write to USB memories by simply attaching a USB connector to the system, receiving power through the connector itself. In other words, if a user connects to the mini-usbusb port of the -100 via a computer, the system will come on and the user may access the USB memory without the need for any auxiliary power. The user can therefore carry out maintenance work (display/configure settings, change time, display fault reports, et cetera) even in the absence of auxiliary power. For further details on the folders system used in the USB memory of the -100 and applications, see section Web server. Checking and configuring parameters. Furthermore, the -100 equipment has a COMVirtual installed in the USB port, focused on maintenance work (internal system settings) to be carried out by qualified operators from Ormazabal. IG-267-EN versión 01; 07/04/

112 Annex General Instructions 13. Annex Figure DT IEC curve Figure VI IEC curve Figure NI IEC curve Figure EI IEC curve 112 IG-267-EN versión 01; 07/04/2017

113 General Instructions Annex Figure LTI IEC curve Figure NI ANSI curve Figure STI IEC curve Figure VI ANSI curve IG-267-EN versión 01; 07/04/

114 Annex General Instructions Figure EI ANSI curve Figure LI ANSI curve 114 IG-267-EN versión 01; 07/04/2017