ABB REV615 Product Manual

3. Protection functions........................................................7 4. Application..................................................................... 7 5. Supported ABB solutions............................................. 10 6. Control......................................................................... 11 7. Measurements............................................................. 12 8. Power quality................................................................12 9. Disturbance recorder....................................................12 10. Event log.....................................................................12 11. Recorded data............................................................ 12 12. Condition monitoring .................................................. 13 13. Trip-circuit supervision.................................................13 14. Self-supervision...........................................................14 15. Fuse failure supervision............................................... 14 16. Current circuit supervision........................................... 14 17. Access control............................................................ 14 18. Inputs and outputs...................................................... 14 19. Station communication................................................15 20. Technical data.............................................................20 21. Local HMI....................................................................46 22. Mounting methods...................................................... 47 23. Relay case and plug-in unit......................................... 47 24. Selection and ordering data.........................................47 25. Accessories and ordering data.................................... 48 26. Tools...........................................................................49 27. Cyber security............................................................. 50 28. Terminal diagrams.......................................................51 29. Certificates.................................................................. 53 30. References..................................................................53 31. Functions, codes and symbols....................................54 32. Document revision history........................................... 57 Disclaimer The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for any errors that may appear in this document. © Copyright 2018 ABB. All rights reserved. Trademarks ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 2 ABB

protection, control, measurement and supervision of capacitor banks used for compensation of reactive power in utility substations and industrial power systems. REV615 can also be used for protection of harmonic filter circuits, if the highest significant harmonic component is the 11th. REV615 is a member of ABB’s Relion® product family and part of its 615 protection and control product series. The 615 series relays are characterized by their compactness and withdrawable-unit design. Re-engineered from the ground up, the 615 series has been designed to unleash the full potential of the IEC 61850 standard for communication and interoperability between substation automation devices. The relay provides main protection for single star, double star, and H-bridge connected capacitor banks and harmonic filters in distribution networks. Depending on the chosen standard configuration, the relay is adapted for the protection of H-bridge connected or double star connected shunt capacitor banks. Once the standard configuration relay has been given the application-specific settings, it can directly be put into service. The 615 series relays support a range of communication protocols including IEC 61850 with Edition 2 support, process bus according to IEC 61850-9-2 LE, IEC 60870-5-103, Modbus® and DNP3. Profibus DPV1 communication protocol is supported by using the protocol converter SPA-ZC 302. 2. Standard configurations REV615 is available in two alternative standard configurations. The standard signal configuration can be altered by means of the signal matrix or the graphical application functionality of the Protection and Control IED Manager PCM600. Further, the application configuration functionality of PCM600 supports the creation of multi-layer logic functions using various logical elements, including timers and flip-flops. By combining protection functions with logic function blocks, the relay configuration can be adapted to user-specific application requirements. The relay is delivered from the factory with default connections described in the functional diagrams for binary inputs, binary outputs, function-to-function connections and alarm LEDs. Some of the supported functions in REV615 must be added with the Application Configuration tool to be available in the Signal Matrix tool and in the relay. The positive measuring direction of directional protection functions is towards the outgoing feeder. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 Issued: 2018-12-20 Revision: D ABB 3

MEASUREMENT CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION PROTECTION LOCAL HMI Object Ctrl 2) Ind 3) CB DC ES 1) Check availability of binary inputs/outputs from technical documentation 2) Control and indication function for primary object 3) Status indication function for primary object R L Clear ESC I O Configuration A System HMI Time Authorization R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× REV615 A COMMUNICATION Protocols: IEC 61850-8-1 Modbus® IEC 60870-5-103 DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP - I, Io - Limit value supervision - Load profile record - RTD/mA measurement (optional) - Symmetrical components 7 - Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs ALSO AVAILABLE - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI 2× I2> 46 3I>>> 50P/51P 3× ARC 50L/50NL Master Trip Lockout relay 94/86 3I>/Io>BF 51BF/51NBF PQM3I PQM3I 2× TCS TCM MCS 3I MCS 3I CBCM CBCM OPTS OPTM 18× MAP MAP 6xRTD 2xmA 3I> 51P-1 2× 3I>> 51P-2 TD> 55TD 3I>3I< 51C Io>> 51N-2 Io>>> 50N/51N 2× Io> 51N-1 3dI>C 51NC-2 dI>C 51NC-1 3Ith>T/G/C 49T/G/C Io Io 3Iunb Io 1 - 2 3 1 2 Master Trip Lockout relay 94/86 3× 2× 3× GUID-DFC320F5-AD45-4D28-8632-C3FB2CFDCB06 V3 EN Figure 1. Functionality overview for standard configuration A Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 4 ABB

MEASUREMENT CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION PROTECTION LOCAL HMI Object Ctrl 2) Ind 3) CB DC ES 1) Check availability of binary inputs/outputs from technical documentation 2) Control and indication function for primary object 3) Status indication function for primary object R L Clear ESC I O Configuration A System HMI Time Authorization R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× REV615 B COMMUNICATION Protocols: IEC 61850-8-1/-9-2LE Modbus® IEC 60870-5-103 DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP - I, U, Io, Uo, P, Q, E, pf, f - Limit value supervision - Load profile record - RTD/mA measurement (optional) - Symmetrical components 7 5 Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs 1 - 2 3 1 2 ALSO AVAILABLE - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI Master Trip Lockout relay 94/86 PQM3I PQM3I 2× TCS TCM MCS 3I MCS 3I CBCM CBCM OPTS OPTM 18× MAP MAP 2xRTD 1xmA Io>> 51N-2 2× Io>→ 67N-1 Io>>→ 67N-2 2× 3U< 27 U2> 47O- U1< 47U+ 2× 3U> 59 Uo> 59G FUSEF 60 2× I2> 46 3I>>> 50P/51P 3× ARC 50L/50NL 3I>/Io>BF 51BF/51NBF 3I> 51P-1 2× 3I>> 51P-2 TD> 55TD 3I>3I< 51C 3dI>C 51NC-2 dI>C 51NC-1 PQM3U PQM3V PQMU PQMV Uo> 59G 3Ith>T/G/C 49T/G/C 3I 3I Io Io Io Iunb Io>IEF→ 67NIEF UL1UL2UL3 UL1UL2UL3 UL1UL2UL3 Uo Uo 3× 2× Uo Master Trip Lockout relay 94/86 3× 2× PQUUB PQVUB GUID-393D9B25-06C8-42AE-A7D0-642BBCB89DBE V2 EN Figure 2. Functionality overview for standard configuration B Table 1. Standard configurations Description Std. conf. Capacitor bank overload and unbalance protection, non-directional overcurrent and earth-fault protection and circuit-breaker condition monitoring A Capacitor bank overload and unbalance protection, non-directional overcurrent and directional earth-fault protection, voltage and frequency based protection and measurements, and circuit-breaker condition monitoring B Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 5

Function IEC 61850 A B Protection Three-phase non-directional overcurrent protection, low stage PHLPTOC 1 1 Three-phase non-directional overcurrent protection, high stage PHHPTOC 2 2 Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 1 1 Non-directional earth-fault protection, low stage EFLPTOC 2 Non-directional earth-fault protection, high stage EFHPTOC 1 1 Non-directional earth-fault protection, instantaneous stage EFIPTOC 1 Directional earth-fault protection, low stage DEFLPDEF 2 Directional earth-fault protection, high stage DEFHPDEF 1 Transient/intermittent earth-fault protection INTRPTEF 1 1) Negative-sequence overcurrent protection NSPTOC 2 2 Residual overvoltage protection ROVPTOV 1 22) Three-phase undervoltage protection PHPTUV 2 Three-phase overvoltage protection PHPTOV 2 Positive-sequence undervoltage protection PSPTUV 1 Negative-sequence overvoltage protection NSPTOV 1 Three-phase thermal overload protection, two time constants T2PTTR 1 1 Circuit breaker failure protection CCBRBRF 1 1 Master trip TRPPTRC 2 (3) 3) 2 (3) 3) Arc protection ARCSARC (3) (3) Multipurpose protection MAPGAPC 18 18 Three-phase overload protection for shunt capacitor banks COLPTOC 1 1 Current unbalance protection for shunt capacitor banks CUBPTOC 1 4) 1 4) Three-phase current unbalance protection for shunt capacitor banks HCUBPTOC 1 4) 1 4) Shunt capacitor bank switching resonance protection, current based SRCPTOC 1 1 Power quality Current total demand distortion CMHAI (1) 5) (1) 6) Voltage total harmonic distortion VMHAI (1) 6) Voltage variation PHQVVR (1) 6) Voltage unbalance VSQVUB (1) 6) Control Circuit-breaker control CBXCBR 1 1 Disconnector control DCXSWI 2 2 Earthing switch control ESXSWI 1 1 Disconnector position indication DCSXSWI 3 3 Earthing switch indication ESSXSWI 2 2 Condition monitoring and supervision Circuit-breaker condition monitoring SSCBR 1 1 Trip circuit supervision TCSSCBR 2 2 Current circuit supervision CCSPVC 1 1 Fuse failure supervision SEQSPVC 1 Runtime counter for machines and devices MDSOPT 1 1 Measurement Disturbance recorder RDRE 1 1 Load profile record LDPRLRC 1 1 Fault record FLTRFRC 1 1 Three-phase current measurement CMMXU 1 1 Sequence current measurement CSMSQI 1 1 Residual current measurement RESCMMXU 1 1 Three-phase voltage measurement VMMXU 1 Residual voltage measurement RESVMMXU 2 Sequence voltage measurement VSMSQI 1 Three-phase power and energy measurement PEMMXU 1 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 6 ABB

Function IEC 61850 A B RTD/mA measurement XRGGIO130 (1) (1) Frequency measurement FMMXU 1 IEC 61850-9-2 LE sampled value sending 7)8) SMVSENDER (1) IEC 61850-9-2 LE sampled value receiving (voltage sharing) 7)8) SMVRCV (1) Other Minimum pulse timer (2 pcs) TPGAPC 4 4 Minimum pulse timer (2 pcs, second resolution) TPSGAPC 1 1 Minimum pulse timer (2 pcs, minute resolution) TPMGAPC 1 1 Pulse timer (8 pcs) PTGAPC 2 2 Time delay off (8 pcs) TOFGAPC 4 4 Time delay on (8 pcs) TONGAPC 4 4 Set-reset (8 pcs) SRGAPC 4 4 Move (8 pcs) MVGAPC 2 2 Generic control point (16 pcs) SPCGAPC 2 2 Analog value scaling (4 pcs) SCA4GAPC 4 4 Integer value move (4 pcs) MVI4GAPC 1 1 1, 2, ... = Number of included instances. The instances of a protection function represent the number of identical protection function blocks available in the standard configuration. () = optional 1) "Io measured" is always used. 2) "Uob measured" is always used. 3) Master trip is included and connected to the corresponding HSO in the configuration only when the BIO0007 module is used. If additionally the ARC option is selected, ARCSARC is connected to the corresponding master trip input in the configuration. 4) The Iunb measurement values are taken from this block and put in the Measurent view. 5) Power quality option includes only current total demand distortion. 6) Power quality option includes current total demand distortion, voltage total harmonic distortion, voltage variation and voltage unbalance. 7) Available only with IEC 61850-9-2 8) Available only with COM0031-0037 3. Protection functions The relay offers three-phase overload protection with undercurrent and reconnection inhibit functionality for capacitors, single or three-phase current-based unbalance protection for capacitors including compensation for natural unbalance and a current-based switching resonance protection. The relay features non-directional overcurrent and thermal overload protection as well as non-directional earth-fault protection. Additionally, the standard configuration B includes directional earth-fault protection, residual voltage protection, overvoltage protection and undervoltage protection functions. Enhanced with optional hardware and software, the relay also features three light detection channels for arc fault protection of the circuit breaker, busbar and cable compartment of metal- enclosed indoor switchgear. The arc-fault protection sensor interface is available on the optional communication module. Fast tripping increases staff safety and security and limits material damage in an arc fault situation. A binary input and output module can be selected as an option - having three high speed binary outputs (HSO) it further decreases the total operate time with typically 4...6 ms compared to the normal power outputs. 4. Application REV615 is intended for the protection of capacitor banks used for reactive power compensation in utility substations and industrial power systems. REV615 offers protection functionality especially for H-bridge, double star and single star connected capacitor banks and the feeder cable. The protection relay can also be used for the protection of harmonic filter circuits, if the highest significant harmonic component is the 11th. Standard configurations A and B offer three-phase overload protection, unbalance protection with compensation for natural unbalance and switching resonance protection for capacitor banks. An integrated undercurrent function in the overload protection function block detects the disconnection of a capacitor bank and inhibits the closing of the circuit breaker as long as the capacitor bank is still partially discharged. A three- phase thermal overload protection can be used for the thermal protection of the reactors and resistors in the harmonic filter circuits. The relay features non-directional overcurrent and earth-fault protection for the feeder cable and the capacitor bank. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 7

connected capacitor banks. Three-phase current unbalance protection is used for unbalance. Standard configuration B offers directional earth-fault protection, residual voltage protection, overvoltage protection and undervoltage protection functions. It is pre-configured for double star connected capacitor banks. Single current unbalance protection is used for unbalance. The second and third stage of the residual voltage protection in the standard configuration B can be used as voltage-based unbalance protection mainly for single star connected capacitor banks, with unearthed star point. Dedicated voltage input Uob is used for this purpose. This functionality is available in standard configuration B and needs to be configured before it is taken into use. 3I R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A REV615 Std. conf. ANSI IEC 50L/50NL 50P/51P 51C 51NC-2 51P/51N 55TD ARC 3I>>> 3I> 3I< 3dI>C 3I>/Io> TD> A Io 3Iunb GUID-B7F0755C-006A-4806-91D3-8C290EE3ECA0 V1 EN Figure 3. Protection of a H-bridge connected capacitor bank Figure 3 illustrates the protection of an H-bridge connected capacitor bank. Standard configuration A is used with overload, three-phase connected current unbalance and undercurrent protection for the capacitor bank. Overcurrent and earth-fault protection functions are used for protecting the feeder cable and capacitor bank combination. 3I REV615 Std. conf. ANSI IEC 27/59/59G 50L/50NL 50P/51P 51C 51NC-1 51P/51N 55TD 67N 3U/Uo> ARC 3I>>> 3I> 3I< dI>C 3I>/Io> TD> Io>→ B 3U Uo R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A Io Iunb GUID-5F33A1B7-2B6F-4CFA-9DD6-71E633C46846 V1 EN Figure 4. Protection of a double star connected capacitor bank in a distribution network with a compensated or isolated neutral Protection of a double star connected capacitor bank in a distribution network with a compensated or isolated neutral is shown in Figure 4. Standard configuration B is used with overload, single phase connected current unbalance and undercurrent protection for the capacitor bank. Overcurrent and directional earth-fault protetion functions are used for protecting the feeder cable and capacitor bank combination. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 8 ABB

P 0.00 kW Q 0.00 kVAr IL2 0 A A 3I REV615 Std. conf. ANSI IEC 27/59/59G 49T 50L/50NL 50P/51P 51C 51NC-2 51P/51N 55TD 3U/Uo> 3Ith>T ARC 3I>>> 3I> 3I< 3dI>C 3I>/Io> TD> B Io 3Iunb GUID-30461537-C53B-460B-BA27-9667D6977F77 V1 EN Figure 5. Protection of a harmonic filter circuit in an industrial network Figure 5 illustrates the protection of a harmonic filter circuit in an industrial network. Standard configuration B is used with overload, three-phase connected current unbalance and undercurrent protection for the harmonic filter and with an additional thermal protection mainly for the coil. Overcurrent and earth-fault protection functions are used for protecting the feeder cable and harmonic filter circuit combination. 3U Uo R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A 3I REV615 Std. conf. ANSI IEC 27/59/59G 50L/50NL 50P/51P 51C 51P 55TD 67N 3U/Uo> ARC 3I>>> 3I> 3I< 3I> TD> Io>→ B Uob Io GUID-9C6F9938-FB13-4615-842A-9606411B47FC V1 EN Figure 6. Protection of a single star connected capacitor bank The protection of a single star connected capacitor bank is shown in Figure 6. Standard configuration B is used with overload, voltage-based unbalance (Uob) and undercurrent protection for the capacitor bank. Overcurrent and earth-fault protection functions are used for protecting the feeder cable and the capacitor bank combination. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 9

The 615 series protection relays together with the Substation Management Unit COM600S constitute a genuine IEC 61850 solution for reliable power distribution in utility and industrial power systems. To facilitate the system engineering, ABB's relays are supplied with connectivity packages. The connectivity packages include a compilation of software and relay-specific information, including single-line diagram templates and a full relay data model. The data model includes event and parameter lists. With the connectivity packages, the relays can be readily configured using PCM600 and integrated with COM600S or the network control and management system MicroSCADA Pro. The 615 series relays offer native support for IEC 61850 Edition 2 also including binary and analog horizontal GOOSE messaging. In addition, process bus with the sending of sampled values of analog currents and voltages and the receiving of sampled values of voltages is supported. Compared to traditional hard-wired, inter-device signaling, peer-to-peer communication over a switched Ethernet LAN offers an advanced and versatile platform for power system protection. Among the distinctive features of the protection system approach, enabled by the full implementation of the IEC 61850 substation automation standard, are fast communication capability, continuous supervision of the protection and communication system's integrity, and an inherent flexibility regarding reconfiguration and upgrades.This protection relay series is able to optimally utilize interoperability provided by the IEC 61850 Edition 2 features. At substation level, COM600S uses the data content of the bay- level devices to enhance substation level functionality. COM600S features a Web browser-based HMI, which provides a customizable graphical display for visualizing single-line mimic diagrams for switchgear bay solutions. The SLD feature is especially useful when 615 series relays without the optional single-line diagram feature are used. The Web HMI of COM600S also provides an overview of the whole substation, including relay-specific single-line diagrams, which makes information easily accessible. Substation devices and processes can also be remotely accessed through the Web HMI, which improves personnel safety. In addition, COM600S can be used as a local data warehouse for the substation's technical documentation and for the network data collected by the devices. The collected network data facilitates extensive reporting and analyzing of network fault situations by using the data historian and event handling features of COM600S. The historical data can be used for accurate monitoring of process and equipment performance, using calculations based on both real-time and historical values. A better understanding of the process dynamics is achieved by combining time-based process measurements with production and maintenance events. COM600S can also function as a gateway and provide seamless connectivity between the substation devices and network-level control and management systems, such as MicroSCADA Pro and System 800xA. GOOSE Analyzer interface in COM600S enables the following and analyzing the horizontal IEC 61850 application during commissioning and operation at station level. It logs all GOOSE events during substation operation to enable improved system supervision. Table 3. Supported ABB solutions Product Version Substation Management Unit COM600S 4.0 SP1 or later 4.1 or later (Edition 2) MicroSCADA Pro SYS 600 9.3 FP2 or later 9.4 or later (Edition 2) System 800xA 5.1 or later Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 10 ABB

Industry: OPC COM600S Web HMI ABB MicroSCADA Pro/ System 800xA Analog and binary horizontal GOOSE communication IEC 61850 PCM600 Ethernet switch COM600S Web HMI Analog and binary horizontal GOOSE communication IEC 61850 GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V4 EN Figure 7. ABB power system example using Relion relays, COM600S and MicroSCADA Pro/System 800xA 6. Control REV615 integrates functionality for the control of a circuit breaker via the front panel HMI or by means of remote controls. In addition to the circuit breaker control the relay features two control blocks intended for motor-operated control of disconnectors or circuit breaker truck and their position indications. The relay has one control block intended for motor-operated control of one earthing switch control and its position indication. Two physical binary inputs and two physical binary outputs are needed in the relay for each controllable primary device taken into use. The number of unused binary inputs and binary outputs varies, depending on the chosen standard configuration of the relay. Further, some standard configurations offer optional hardware modules that increase the number of available binary inputs and outputs. If the amount of available binary inputs or outputs of the chosen standard configuration is not sufficient, the standard configuration can be modified to release some binary inputs or outputs which have originally been configured for other purposes, when applicable, or an external input or output module, for example, RIO600 can be integrated to the relay. The binary inputs and outputs of the external I/O module can be used for the less time critical binary signals of the application. The integration enables releasing of some initially reserved binary inputs and outputs of the relay in the standard configuration. The suitability of the binary outputs of the relay which have been selected for controlling of primary devices should be carefully verified, for example the make and carry as well as the breaking capacity. If the requirements for the control-circuit of the primary device are not met, the use of external auxiliary relays should be considered. The optional large graphical LCD of the relay's HMI includes a single-line diagram (SLD) with position indication for the relevant primary devices. Interlocking schemes required by the application are configured using the signal matrix or the application configuration functionality of PCM600. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 11

or three-phase unbalance currents (with the natural unbalance current compensated), the symmetrical components of the phase currents and the residual current. The standard configuration B includes voltage measurements. It measures the residual voltage, the phase voltages, the voltage sequence components and frequency. It also measures the capacitor bank unbalance voltage if the Uob is connected and the relay is configured accordingly. This voltage measurement is called residual voltage measurement, instance 2. The relay offers three-phase power and energy measurement including power factor. In addition, the relay calculates the demand value of current over a user-selectable preset time frames, the thermal overload of the protected object, and the phase unbalance value based on the ratio between the negative-sequence and positive- sequence current. The measured values can be accessed via the local HMI or remotely via the communication interface of the relay. The values can also be accessed locally or remotely using the Web HMI. The relay is provided with a load profile recorder. The load profile feature stores the historical load data captured at a periodical time interval (demand interval). The records are in COMTRADE format. 8. Power quality In the EN standards, power quality is defined through the characteristics of the supply voltage. Transients, short-duration and long-duration voltage variations and unbalance and waveform distortions are the key characteristics describing power quality. The distortion monitoring functions are used for monitoring the current total demand distortion and the voltage total harmonic distortion. Power quality monitoring is an essential service that utilities can provide for their industrial and key customers. A monitoring system can provide information about system disturbances and their possible causes. It can also detect problem conditions throughout the system before they cause customer complaints, equipment malfunctions and even equipment damage or failure. Power quality problems are not limited to the utility side of the system. In fact, the majority of power quality problems are localized within customer facilities. Thus, power quality monitoring is not only an effective customer service strategy but also a way to protect a utility's reputation for quality power and service. The protection relay has the following power quality monitoring functions. • Voltage variation • Voltage unbalance • Current harmonics • Voltage harmonics The voltage unbalance and voltage variation functions are used for measuring short-duration voltage variations and monitoring voltage unbalance conditions in power transmission and distribution networks. The voltage and current harmonics functions provide a method for monitoring the power quality by means of the current waveform distortion and voltage waveform distortion. The functions provides a short-term three-second average and a long-term demand for total demand distortion TDD and total harmonic distortion THD. 9. Disturbance recorder The relay is provided with a disturbance recorder featuring up to 12 analog and 64 binary signal channels.The analog channels can be set to record either the waveform or the trend of the currents and voltages measured. The analog channels can be set to trigger the recording function when the measured value falls below or exceeds the set values. The binary signal channels can be set to start a recording either on the rising or the falling edge of the binary signal or on both. By default, the binary channels are set to record external or internal relay signals, for example, the start or trip signals of the relay stages, or external blocking or control signals. Binary relay signals, such as protection start and trip signals, or an external relay control signal via a binary input, can be set to trigger the recording. Recorded information is stored in a nonvolatile memory and can be uploaded for subsequent fault analysis. 10. Event log To collect sequence-of-events information, the relay has a non- volatile memory capable of storing 1024 events with the associated time stamps. The non-volatile memory retains its data even if the relay temporarily loses its auxiliary supply. The event log facilitates detailed pre- and post-fault analyses of feeder faults and disturbances. The considerable capacity to process and store data and events in the relay facilitates meeting the growing information demand of future network configurations. The sequence-of-events information can be accessed either via local HMI or remotely via the communication interface of the relay. The information can also be accessed locally or remotely using the Web HMI. 11. Recorded data The relay has the capacity to store the records of the 128 latest fault events. The records can be used to analyze the power system events. Each record includes, for example, current, Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 12 ABB

can be triggered by the start or the trip signal of a protection block, or by both. The available measurement modes include DFT, RMS and peak-to-peak. Fault records store relay measurement values at the moment when any protection function starts. In addition, the maximum demand current with time stamp is separately recorded. The records are stored in the non-volatile memory. 1024 PROCESS LEVEL USER LEVEL Fault summary; Trip timestamp, Function, Currents, Voltages, etc. BASIC FUNCTIONS IEC 61850-8-1 Modbus IEC 103 DNP3 LHMI WHMI PCM600 Process events (FIFO) 128 Fault records (FIFO) System and security-related events; Configuration changes, Control, Login, etc. 2048 Audit trail events (FIFO) n…100 Disturbance records ...7 yrs Load profile record Historical load data captured at a periodical time interval (Demand interval 1 ...180min) Function specific data Min/max demand currents, Operation counters, etc. History view GUID-CDF1DC16-AF90-406F-B21B-EF6C7F60BCCA V1 EN Figure 8. Recording and event capabilities overview 12. Condition monitoring The condition monitoring functions of the relay constantly monitor the performance and the condition of the circuit breaker. The monitoring comprises the spring charging time, SF6 gas pressure, the travel time and the inactivity time of the circuit breaker. The monitoring functions provide operational circuit breaker history data, which can be used for scheduling preventive circuit breaker maintenance. In addition, the relay includes a runtime counter for monitoring of how many hours a protected device has been in operation thus enabling scheduling of time-based preventive maintenance of the device. 13. Trip-circuit supervision The trip-circuit supervision continuously monitors the availability and operability of the trip circuit. It provides open- circuit monitoring both when the circuit breaker is in its closed and in its open position. It also detects loss of circuit-breaker control voltage. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 13

monitors the state of the relay hardware and the operation of the relay software. Any fault or malfunction detected is used for alerting the operator. A permanent relay fault blocks the protection functions to prevent incorrect operation. 15. Fuse failure supervision In the standard configuration B, the relay includes fuse failure supervision functionality. The fuse failure supervision detects failures between the voltage measurement circuit and the relay. The failures are detected either by the negative sequence- based algorithm or by the delta voltage and delta current algorithm. Upon the detection of a failure, the fuse failure supervision function activates an alarm and blocks voltage- dependent protection functions from unintended operation. 16. Current circuit supervision The relay includes current circuit supervision. Current circuit supervision is used for detecting faults in the current transformer secondary circuits. On detecting of a fault the current circuit supervision function activates an alarm LED and blocks certain protection functions to avoid unintended operation. The current circuit supervision function calculates the sum of the phase currents from the protection cores and compares the sum with the measured single reference current from a core balance current transformer or from separate cores in the phase current transformers. 17. Access control To protect the relay from unauthorized access and to maintain information integrity, the relay is provided with a four-level, role- based authentication system with administrator-programmable individual passwords for the viewer, operator, engineer and administrator levels. The access control applies to the local HMI, the Web HMI and PCM600. 18. Inputs and outputs The relay is equipped with three phase-current inputs, three unbalance-current inputs and one residual-current input for non-directional earth-fault protection. In the standard configuration B, the relay is additionally equipped with three phase-voltage inputs, one residual voltage input for directional earth-fault protection and one voltage input (Uob) that can be used for voltage based unbalance protection. The rated level of the current inputs is 1/5 A and selectable in the relay software. The three phase-voltage inputs and the residual-voltage inputs cover the rated voltages 60-210 V. Both phase-to-phase voltages and phase-to-earth voltages can be connected. The binary input thresholds 16…176 V DC are selected by adjusting the relay’s parameter settings. All binary input and output contacts are freely configurable with the signal matrix or application configuration functionality of PCM600. See the Input/output overview table and the terminal diagrams for more information about the inputs and outputs. Optionally, a binary input and output module can be selected. It has three high speed binary outputs (HSO) and it decreases the total operate time with typically 4...6 ms compared to the normal power outputs. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 14 ABB

Std. conf. Order code digit Analog channels Binary channels 5-6 7-8 CT VT BI BO RTD mA A BA BA 7 - 8 4 PO + 6 SO - - BB 7 - 14 4 PO + 9 SO - - FD 7 - 8 4 PO + 2 SO + 3 HSO - - FF 7 - 14 4 PO + 5 SO + 3 HSO - - BG BA 7 - 8 4 PO + 6 SO 6 2 FD 7 - 8 4 PO + 2 SO + 3 HSO 6 2 B BC AD 7 5 12 4 PO + 6 SO - - FE 7 5 12 4 PO + 2 SO + 3 HSO - - BE BA 7 5 8 4 PO + 6 SO 2 1 FD 7 5 8 4 PO + 2 SO + 3 HSO 2 1 As an option for standard configuration B, the relay has two RTD inputs and 1 mA input. The relay measures signals such as temperature via the two RTD inputs and mA inputs using a transducer. The values can, apart from measuring and monitoring purposes, be used for tripping and alarm purposes using the multipurpose protection functions. The temperature signal can also be used for ambient temperature information for the thermal protection function. 19. Station communication The relay supports a range of communication protocols including IEC 61850 Edition 2, IEC 61850-9-2 LE, IEC 60870-5-103, Modbus® and DNP3. Profibus DPV1 communication protocol is supported with using the protocol converter SPA-ZC 302. Operational information and controls are available through these protocols. However, some communication functionality, for example, horizontal communication between the relays, is only enabled by the IEC 61850 communication protocol. The IEC 61850 protocol is a core part of the relay as the protection and control application is fully based on standard modelling. The relay supports Edition 2 and Edition 1 versions of the standard. With Edition 2 support, the relay has the latest functionality modelling for substation applications and the best interoperability for modern substations. It incorporates also the full support of standard device mode functionality supporting different test applications. Control applications can utilize the new safe and advanced station control authority feature. The IEC 61850 communication implementation supports monitoring and control functions. Additionally, parameter settings, disturbance recordings and fault records can be accessed using the IEC 61850 protocol. Disturbance recordings are available to any Ethernet-based application in the standard COMTRADE file format. The relay supports simultaneous event reporting to five different clients on the station bus. The relay can exchange data with other devices using the IEC 61850 protocol. The relay can send binary and analog signals to other devices using the IEC 61850-8-1 GOOSE (Generic Object Oriented Substation Event) profile. Binary GOOSE messaging can, for example, be employed for protection and interlocking-based protection schemes. The relay meets the GOOSE performance requirements for tripping applications in distribution substations, as defined by the IEC 61850 standard (<10 ms data exchange between the devices). The relay also supports the sending and receiving of analog values using GOOSE messaging. Analog GOOSE messaging enables easy transfer of analog measurement values over the station bus, thus facilitating for example the sending of measurement values between the relays when controlling parallel running transformers. The relay also supports IEC 61850 process bus by sending sampled values of analog currents and voltages and by receiving sampled values of voltages. With this functionality the galvanic interpanel wiring can be replaced with Ethernet communication. The measured values are transferred as sampled values using IEC 61850-9-2 LE protocol. The intended Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 15

series relays, having voltage based functions and 9-2 support. 615 relays with process bus based applications use IEEE 1588 for high accuracy time synchronization. For redundant Ethernet communication, the relay offers either two optical or two galvanic Ethernet network interfaces. A third port with galvanic Ethernet network interface is also available. The third Ethernet interface provides connectivity for any other Ethernet device to an IEC 61850 station bus inside a switchgear bay, for example connection of a Remote I/O. Ethernet network redundancy can be achieved using the high-availability seamless redundancy (HSR) protocol or the parallel redundancy protocol (PRP) or a with self-healing ring using RSTP in managed switches. Ethernet redundancy can be applied to Ethernet-based IEC 61850, Modbus and DNP3 protocols. The IEC 61850 standard specifies network redundancy which improves the system availability for the substation communication. The network redundancy is based on two complementary protocols defined in the IEC 62439-3 standard: PRP and HSR protocols. Both the protocols are able to overcome a failure of a link or switch with a zero switch-over time. In both the protocols, each network node has two identical Ethernet ports dedicated for one network connection. The protocols rely on the duplication of all transmitted information and provide a zero switch-over time if the links or switches fail, thus fulfilling all the stringent real-time requirements of substation automation. In PRP, each network node is attached to two independent networks operated in parallel. The networks are completely separated to ensure failure independence and can have different topologies. The networks operate in parallel, thus providing zero-time recovery and continuous checking of redundancy to avoid failures. Ethernet switch IEC 61850 PRP Ethernet switch SCADA COM600 GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V2 EN Figure 9. Parallel redundancy protocol (PRP) solution HSR applies the PRP principle of parallel operation to a single ring. For each message sent, the node sends two frames, one through each port. Both the frames circulate in opposite directions over the ring. Every node forwards the frames it receives from one port to another to reach the next node. When the originating sender node receives the frame it sent, the sender node discards the frame to avoid loops. The HSR ring with 615 series relays supports the connection of up to 30 relays. If more than 30 relays are to be connected, it is recommended to split the network into several rings to guarantee the performance for real-time applications. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 16 ABB

Redundancy Box Redundancy Box REF615 REF620 RET620 REM620 REF615 SCADA Devices not supporting HSR COM600 GUID-7996332D-7FC8-49F3-A4FE-FB4ABB730405 V1 EN Figure 10. High availability seamless redundancy (HSR) solution The choice between the HSR and PRP redundancy protocols depends on the required functionality, cost and complexity. The self-healing Ethernet ring solution enables a cost-efficient communication ring controlled by a managed switch with standard Rapid Spanning Tree Protocol (RSTP) support. The managed switch controls the consistency of the loop, routes the data and corrects the data flow in case of a communication switch-over. The relays in the ring topology act as unmanaged switches forwarding unrelated data traffic. The Ethernet ring solution supports the connection of up to 30 615 series relays. If more than 30 relays are to be connected, it is recommended to split the network into several rings. The self-healing Ethernet ring solution avoids single point of failure concerns and improves the reliability of the communication. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 17

with RSTP support Managed Ethernet switch with RSTP support Client B Client A Network A Network B GUID-AB81C355-EF5D-4658-8AE0-01DC076E519C V4 EN Figure 11. Self-healing Ethernet ring solution All communication connectors, except for the front port connector, are placed on integrated optional communication modules. The relay can be connected to Ethernet-based communication systems via the RJ-45 connector (100Base-TX) or the fiber optic LC connector (100Base-FX). If connection to serial bus is required, the 9-pin RS-485 screw-terminal can be used. An optional serial interface is available for RS-232 communication. Modbus implementation supports RTU, ASCII and TCP modes. Besides standard Modbus functionality, the relay supports retrieval of time-stamped events, changing the active setting group and uploading of the latest fault records. If a Modbus TCP connection is used, five clients can be connected to the relay simultaneously. Further, Modbus serial and Modbus TCP can be used in parallel, and if required both IEC 61850 and Modbus protocols can be run simultaneously. The IEC 60870-5-103 implementation supports two parallel serial bus connections to two different masters. Besides basic standard functionality, the relay supports changing of the active setting group and uploading of disturbance recordings in IEC 60870-5-103 format. Further, IEC 60870-5-103 can be used at the same time with the IEC 61850 protocol. DNP3 supports both serial and TCP modes for connection up to five masters. Changing of the active setting and reading fault records are supported. DNP serial and DNP TCP can be used in parallel. If required, both IEC 61850 and DNP protocols can be run simultaneously. 615 series supports Profibus DPV1 with support of SPA-ZC 302 Profibus adapter. If Profibus is required the relay must be ordered with Modbus serial options. Modbus implementation includes SPA-protocol emulation functionality. This functionality enables connection to SPA-ZC 302. When the relay uses the RS-485 bus for the serial communication, both two- and four wire connections are supported. Termination and pull-up/down resistors can be configured with jumpers on the communication card so external resistors are not needed. The relay supports the following time synchronization methods with a time-stamping resolution of 1 ms. Ethernet-based • SNTP (Simple Network Time Protocol) With special time synchronization wiring • IRIG-B (Inter-Range Instrumentation Group - Time Code Format B) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 18 ABB

synchronization method with a time-stamping resolution of 4 µs required especially in process bus applications. • PTP (IEEE 1588) v2 with Power Profile The IEEE 1588 support is included in all variants having a redundant Ethernet communication module. IEEE 1588 v2 features • Ordinary Clock with Best Master Clock algorithm • One-step Transparent Clock for Ethernet ring topology • 1588 v2 Power Profile • Receive (slave): 1-step/2-step • Transmit (master): 1-step • Layer 2 mapping • Peer to peer delay calculation • Multicast operation Required accuracy of grandmaster clock is +/-1 µs. The relay can work as a master clock per BMC algorithm if the external grandmaster clock is not available for short term. The IEEE 1588 support is included in all variants having a redundant Ethernet communication module. In addition, the relay supports time synchronization via Modbus, DNP3 and IEC 60870-5-103 serial communication protocols. Table 5. Supported station communication interfaces and protocols Interfaces/Protocols Ethernet Serial 100BASE-TX RJ-45 100BASE-FX LC RS-232/RS-485 Fiber optic ST IEC 61850-8-1 ● ● - - IEC 61850-9-2 LE ● ● - - MODBUS RTU/ASCII - - ● ● MODBUS TCP/IP ● ● - - DNP3 (serial) - - ● ● DNP3 TCP/IP ● ● - - IEC 60870-5-103 - - ● ● ● = Supported Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 19

Table 6. Dimensions Description Value Width Frame 177 mm Case 164 mm Height Frame 177 mm (4U) Case 160 mm Depth 201 mm (153 + 48 mm) Weight Complete protection relay 4.1 kg Plug-in unit only 2.1 kg Table 7. Power supply Description Type 1 Type 2 Nominal auxiliary voltage Un 100, 110, 120, 220, 240 V AC, 50 and 60 Hz 24, 30, 48, 60 V DC 48, 60, 110, 125, 220, 250 V DC Maximum interruption time in the auxiliary DC voltage without resetting the relay 50 ms at Un Auxiliary voltage variation 38...110% of Un (38...264 V AC) 50...120% of Un (12...72 V DC) 80...120% of Un (38.4...300 V DC) Start-up threshold 19.2 V DC (24 V DC × 80%) Burden of auxiliary voltage supply under quiescent (Pq)/operating condition DC <13.0 W (nominal)/<18.0 W (max.) AC <16.0 W (nominal)/<21.0 W (max.) DC <13.0 W (nominal)/<18.0 W (max.) Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 Hz) Fuse type T4A/250 V Table 8. Energizing inputs Description Value Rated frequency 50/60 Hz Current inputs Rated current, In 0.2/1 A1) 1/5 A2) Thermal withstand capability: • Continuously 4 A 20 A • For 1 s 100 A 500 A Dynamic current withstand: • Half-wave value 250 A 1250 A Input impedance <100 mΩ <20 mΩ Voltage inputs Rated voltage 60...210 V AC Voltage withstand: • Continuous 240 V AC • For 10 s 360 V AC Burden at rated voltage <0.05 VA 1) Ordering option for residual current input 2) Residual current and/or phase current Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 20 ABB

Description Value Operating range ±20% of the rated voltage Rated voltage 24...250 V DC Current drain 1.6...1.9 mA Power consumption 31.0...570.0 mW Threshold voltage 16...176 V DC Reaction time <3 ms Table 10. RTD/mA measurement (XRGGIO130) Description Value RTD inputs Supported RTD sensors 100 Ω platinum 250 Ω platinum 100 Ω nickel 120 Ω nickel 250 Ω nickel 10 Ω copper TCR 0.00385 (DIN 43760) TCR 0.00385 TCR 0.00618 (DIN 43760) TCR 0.00618 TCR 0.00618 TCR 0.00427 Supported resistance range 0...2 kΩ Maximum lead resistance (three- wire measurement) 25 Ω per lead Isolation 2 kV (inputs to protective earth) Response time <4 s RTD/resistance sensing current Maximum 0.33 mA rms Operation accuracy Resistance Temperature ± 2.0% or ±1 Ω ±1°C 10 Ω copper: ±2°C mA inputs Supported current range 0…20 mA Current input impedance 44 Ω ± 0.1% Operation accuracy ±0.5% or ±0.01 mA Table 11. Signal output X100: SO1 Description Value Rated voltage 250 V AC/DC Continuous contact carry 5 A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at 48/110/220 V DC 1 A/0.25 A/0.15 A Minimum contact load 100 mA at 24 V AC/DC Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 21

Description Value Rated voltage 250 V AC/DC Continuous contact carry 5 A Make and carry for 3.0 s 10 A Make and carry 0.5 s 15 A Breaking capacity when the control-circuit time constant L/R<40 ms, at 48/110/220 V DC 1 A/0.25 A/0.15 A Minimum contact load 10 mA at 5 V AC/DC Table 13. Double-pole power output relays with TCS function Description Value Rated voltage 250 V AC/DC Continuous contact carry 8 A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at 48/110/220 V DC (two contacts connected in series) 5 A/3 A/1 A Minimum contact load 100 mA at 24 V AC/DC Trip-circuit supervision (TCS): • Control voltage range 20...250 V AC/DC • Current drain through the supervision circuit ~1.5 mA • Minimum voltage over the TCS contact 20 V AC/DC (15...20 V) Table 14. Single-pole power output relays Description Value Rated voltage 250 V AC/DC Continuous contact carry 8 A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at 48/110/220 V DC 5 A/3 A/1 A Minimum contact load 100 mA at 24 V AC/DC Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 22 ABB

Description Value Rated voltage 250 V AC/DC Continuous contact carry 6 A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R <40 ms, at 48/110/220 V DC 5 A/3 A/1 A Operate time <1 ms Reset <20 ms, resistive load Table 16. Front port Ethernet interfaces Ethernet interface Protocol Cable Data transfer rate Front TCP/IP protocol Standard Ethernet CAT 5 cable with RJ-45 connector 10 MBits/s Table 17. IRIG-B Description Value IRIG time code format B004, B0051) Isolation 500V 1 min Modulation Unmodulated Logic level 5 V TTL Current consumption <4 mA Power consumption <20 mW 1) According to the 200-04 IRIG standard Table 18. Degree of protection of flush-mounted protection relay Description Value Front side IP 54 Rear side, connection terminals IP 20 Table 19. Environmental conditions Description Value Operating temperature range -25...+55ºC (continuous) Short-time service temperature range -40...+85ºC (<16h)1)2) Relative humidity <93%, non-condensing Atmospheric pressure 86...106 kPa Altitude Up to 2000 m Transport and storage temperature range -40...+85ºC 1) Degradation in MTBF and HMI performance outside the temperature range of -25...+55 ºC 2) For relays with an LC communication interface the maximum operating temperature is +70 ºC Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 23

Description Type test value Reference 1 MHz/100 kHz burst disturbance test IEC 61000-4-18 IEC 60255-26, class III IEEE C37.90.1-2002 • Common mode 2.5 kV • Differential mode 2.5 kV 3 MHz, 10 MHz and 30 MHz burst disturbance test IEC 61000-4-18 IEC 60255-26, class III • Common mode 2.5 kV Electrostatic discharge test IEC 61000-4-2 IEC 60255-26 IEEE C37.90.3-2001 • Contact discharge 8 kV • Air discharge 15 kV Radio frequency interference test 10 V (rms) f = 150 kHz...80 MHz IEC 61000-4-6 IEC 60255-26, class III 10 V/m (rms) f = 80...2700 MHz IEC 61000-4-3 IEC 60255-26, class III 10 V/m f = 900 MHz ENV 50204 IEC 60255-26, class III 20 V/m (rms) f = 80...1000 MHz IEEE C37.90.2-2004 Fast transient disturbance test IEC 61000-4-4 IEC 60255-26 IEEE C37.90.1-2002 • All ports 4 kV Surge immunity test IEC 61000-4-5 IEC 60255-26 • Communication 1 kV, line-to-earth • Other ports 4 kV, line-to-earth 2 kV, line-to-line Power frequency (50 Hz) magnetic field immunity test IEC 61000-4-8 • Continuous • 1...3 s 300 A/m 1000 A/m Pulse magnetic field immunity test 1000 A/m 6.4/16 µs IEC 61000-4-9 Damped oscillatory magnetic field immunity test IEC 61000-4-10 • 2 s 100 A/m • 1 MHz 400 transients/s Voltage dips and short interruptions 30%/10 ms 60%/100 ms 60%/1000 ms >95%/5000 ms IEC 61000-4-11 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 24 ABB

Description Type test value Reference Power frequency immunity test Binary inputs only IEC 61000-4-16 IEC 60255-26, class A • Common mode 300 V rms • Differential mode 150 V rms Conducted common mode disturbances 15 Hz...150 kHz Test level 3 (10/1/10 V rms) IEC 61000-4-16 Emission tests EN 55011, class A IEC 60255-26 CISPR 11 CISPR 12 • Conducted 0.15...0.50 MHz <79 dB (µV) quasi peak <66 dB (µV) average 0.5...30 MHz <73 dB (µV) quasi peak <60 dB (µV) average • Radiated 30...230 MHz <40 dB (µV/m) quasi peak, measured at 10 m distance 230...1000 MHz <47 dB (µV/m) quasi peak, measured at 10 m distance 1…3 GHz <76 dB (µV/m) peak <56 dB (µV/m) average, measured at 3 m distance 3…6 GHz <80 dB (µV/m) peak <60 dB (µV/m) average, measured at 3 m distance Table 21. Insulation tests Description Type test value Reference Dielectric tests 2 kV, 50 Hz, 1 min 500 V, 50 Hz, 1 min, communication IEC 60255-27 Impulse voltage test 5 kV, 1.2/50 μs, 0.5 J 1 kV, 1.2/50 μs, 0.5 J, communication IEC 60255-27 Insulation resistance measurements >100 MΩ, 500 V DC IEC 60255-27 Protective bonding resistance <0.1 Ω, 4 A, 60 s IEC 60255-27 Table 22. Mechanical tests Description Requirement Reference Vibration tests (sinusoidal) Class 2 IEC 60068-2-6 (test Fc) IEC 60255-21-1 Shock and bump test Class 2 IEC 60068-2-27 (test Ea shock) IEC 60068-2-29 (test Eb bump) IEC 60255-21-2 Seismic test Class 2 IEC 60255-21-3 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 25

Description Type test value Reference Dry heat test • 96 h at +55ºC IEC 60068-2-2 Dry cold test • 96 h at -25ºC • 16 h at -40ºC IEC 60068-2-1 Damp heat test • 6 cycles (12 h + 12 h) at +25°C…+55°C, humidity >93% IEC 60068-2-30 Change of temperature test • 5 cycles (3 h + 3 h) at -25°C...+55°C IEC60068-2-14 Storage test • 96 h at -40ºC • 96 h at +85ºC IEC 60068-2-1 IEC 60068-2-2 Table 24. Product safety Description Reference LV directive 2006/95/EC Standard EN 60255-27 (2013) EN 60255-1 (2009) Table 25. EMC compliance Description Reference EMC directive 2004/108/EC Standard EN 60255-26 (2013) Table 26. RoHS compliance Description Complies with RoHS directive 2002/95/EC Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 26 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz PHLPTOC ±1.5% of the set value or ±0.002 × In PHHPTOC and PHIPTOC ±1.5% of set value or ±0.002 × In (at currents in the range of 0.1…10 × In) ±5.0% of the set value (at currents in the range of 10…40 × In) Start time 1)2) Minimum Typical Maximum PHIPTOC: IFault = 2 × set Start value IFault = 10 × set Start value 16 ms 11 ms 19 ms 12 ms 23 ms 14 ms PHHPTOC and PHLPTOC: IFault = 2 × set Start value 23 ms 26 ms 29 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <30 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3) Suppression of harmonics RMS: No suppression DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… Peak-to-Peak: No suppression P-to-P+backup: No suppression 1) Set Operate delay time = 0,02 s, Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Includes the delay of the heavy-duty output contact Table 28. Three-phase non-directional overcurrent protection (PHxPTOC) main settings Parameter Function Value (Range) Step Start value PHLPTOC 0.05...5.00 × In 0.01 PHHPTOC 0.10...40.00 × In 0.01 PHIPTOC 1.00...40.00 × In 0.01 Time multiplier PHLPTOC and PHHPTOC 0.05...15.00 0.01 Operate delay time PHLPTOC and PHHPTOC 40...200000 ms 10 PHIPTOC 20...200000 ms 10 Operating curve type1) PHLPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 PHHPTOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 PHIPTOC Definite time 1) For further reference, see the Operation characteristics table Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 27

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz EFLPTOC ±1.5% of the set value or ±0.002 × In EFHPTOC and EFIPTOC ±1.5% of set value or ±0.002 × In (at currents in the range of 0.1…10 × In) ±5.0% of the set value (at currents in the range of 10…40 × In) Start time 1)2) Minimum Typical Maximum EFIPTOC: IFault = 2 × set Start value IFault = 10 × set Start value 16 ms 11 ms 19 ms 12 ms 23 ms 14 ms EFHPTOC and EFLPTOC: IFault = 2 × set Start value 23 ms 26 ms 29 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <30 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3) Suppression of harmonics RMS: No suppression DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… Peak-to-Peak: No suppression 1) Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20 Table 30. Non-directional earth-fault protection (EFxPTOC) main settings Parameter Function Value (Range) Step Start value EFLPTOC 0.010...5.000 × In 0.005 EFHPTOC 0.10...40.00 × In 0.01 EFIPTOC 1.00...40.00 × In 0.01 Time multiplier EFLPTOC and EFHPTOC 0.05...15.00 0.01 Operate delay time EFLPTOC and EFHPTOC 40...200000 ms 10 EFIPTOC 20...200000 ms 10 Operating curve type1) EFLPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 EFHPTOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 EFIPTOC Definite time 1) For further reference, see the Operation characteristics table Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 28 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz DEFLPDEF Current: ±1.5% of the set value or ±0.002 × In Voltage ±1.5% of the set value or ±0.002 × Un Phase angle: ±2° DEFHPDEF Current: ±1.5% of the set value or ±0.002 × In (at currents in the range of 0.1…10 × In) ±5.0% of the set value (at currents in the range of 10…40 × In) Voltage: ±1.5% of the set value or ±0.002 × Un Phase angle: ±2° Start time 1)2) Minimum Typical Maximum DEFHPDEF IFault = 2 × set Start value 42 ms 46 ms 49 ms DEFLPDEF IFault = 2 × set Start value 58 ms 62 ms 66 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <30 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3) Suppression of harmonics RMS: No suppression DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… Peak-to-Peak: No suppression 1) Set Operate delay time = 0.06 s,Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 29

Parameter Function Value (Range) Step Start value DEFLPDEF 0.010...5.000 × In 0.005 DEFHPDEF 0.10...40.00 × In 0.01 Directional mode DEFLPDEF and DEFHPDEF 1 = Non-directional 2 = Forward 3 = Reverse - Time multiplier DEFLPDEF 0.05...15.00 0.01 DEFHPDEF 0.05...15.00 0.01 Operate delay time DEFLPDEF 50...200000 ms 10 DEFHPDEF 40...200000 ms 10 Operating curve type1) DEFLPDEF Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 DEFHPDEF Definite or inverse time Curve type: 1, 3, 5, 15, 17 Operation mode DEFxPDEF 1 = Phase angle 2 = IoSin 3 = IoCos 4 = Phase angle 80 5 = Phase angle 88 - 1) For further reference, see the Operating characteristics table Table 33. Transient/intermittent earth-fault protection (INTRPTEF) Characteristic Value Operation accuracy (Uo criteria with transient protection) Depending on the frequency of the measured current: fn ±2 Hz ±1.5% of the set value or ±0.002 × Uo Operate time accuracy ±1.0% of the set value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5 Table 34. Transient/intermittent earth-fault protection (INTRPTEF) main settings Parameter Function Value (Range) Step Directional mode INTRPTEF 1 = Non-directional 2 = Forward 3 = Reverse - Operate delay time INTRPTEF 40...1200000 ms 10 Voltage start value INTRPTEF 0.05...0.50 × Un 0.01 Operation mode INTRPTEF 1 = Intermittent EF 2 = Transient EF - Peak counter limit INTRPTEF 2...20 1 Min operate current INTRPTEF 0.01...1.00 × In 0.01 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 30 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±1.5% of the set value or ±0.002 × In Start time 1)2) Minimum Typical Maximum IFault = 2 × set Start value IFault = 10 × set Start value 23 ms 15 ms 26 ms 18 ms 28 ms 20 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3) Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Negative sequence current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20 Table 36. Negative-sequence overcurrent protection (NSPTOC) main settings Parameter Function Value (Range) Step Start value NSPTOC 0.01...5.00 × In 0.01 Time multiplier NSPTOC 0.05...15.00 0.01 Operate delay time NSPTOC 40...200000 ms 10 Operating curve type1) NSPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 1) For further reference, see the Operation characteristics table Table 37. Residual overvoltage protection (ROVPTOV) Characteristic Value Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz ±1.5% of the set value or ±0.002 × Un Start time1)2) Minimum Typical Maximum UFault = 2 × set Start value 48 ms 51 ms 54 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Residual voltage before fault = 0.0 × Un, fn = 50 Hz, residual voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 31

Parameter Function Value (Range) Step Start value ROVPTOV 0.010...1.000 × Un 0.001 Operate delay time ROVPTOV 40...300000 ms 1 Table 39. Three-phase undervoltage protection (PHPTUV) Characteristic Value Operation accuracy Depending on the frequency of the voltage measured: fn ±2 Hz ±1.5% of the set value or ±0.002 × Un Start time1)2) Minimum Typical Maximum UFault = 0.9 × set Start value 62 ms 66 ms 70 ms Reset time Typically 40 ms Reset ratio Depends on the set Relative hysteresis Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms3) Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Start value = 1.0 × Un, Voltage before fault = 1.1 × Un, fn = 50 Hz, undervoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Minimum Start value = 0.50, Start value multiples in range of 0.90...0.20 Table 40. Three-phase undervoltage protection (PHPTUV) main settings Parameter Function Value (Range) Step Start value PHPTUV 0.05...1.20 × Un 0.01 Time multiplier PHPTUV 0.05...15.00 0.01 Operate delay time PHPTUV 60...300000 ms 10 Operating curve type1) PHPTUV Definite or inverse time Curve type: 5, 15, 21, 22, 23 1) For further reference, see the Operation characteristics table Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 32 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz ±1.5% of the set value or ±0.002 × Un Start time1)2) Minimum Typical Maximum UFault = 1.1 × set Start value 23 ms 27 ms 31 ms Reset time Typically 40 ms Reset ratio Depends on the set Relative hysteresis Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms3) Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Start value = 1.0 × Un, Voltage before fault = 0.9 × Un, fn = 50 Hz, overvoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Maximum Start value = 1.20 × Un, Start value multiples in range of 1.10...2.00 Table 42. Three-phase overvoltage protection (PHPTOV) main settings Parameter Function Value (Range) Step Start value PHPTOV 0.05...1.60 × Un 0.01 Time multiplier PHPTOV 0.05...15.00 0.01 Operate delay time PHPTOV 40...300000 ms 10 Operating curve type1) PHPTOV Definite or inverse time Curve type: 5, 15, 17, 18, 19, 20 1) For further reference, see the Operation characteristics table Table 43. Positive-sequence undervoltage protection (PSPTUV) Characteristic Value Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz ±1.5% of the set value or ±0.002 × Un Start time1)2) Minimum Typical Maximum UFault = 0.99 × set Start value UFault = 0.9 × set Start value 52 ms 44 ms 55 ms 47 ms 58 ms 50 ms Reset time Typically 40 ms Reset ratio Depends on the set Relative hysteresis Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Start value = 1.0 × Un, positive-sequence voltage before fault = 1.1 × Un, fn = 50 Hz, positive sequence undervoltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 33

Parameter Function Value (Range) Step Start value PSPTUV 0.010...1.200 × Un 0.001 Operate delay time PSPTUV 40...120000 ms 10 Voltage block value PSPTUV 0.01...1.00 × Un 0.01 Table 45. Negative-sequence overvoltage protection (NSPTOV) Characteristic Value Operation accuracy Depending on the frequency of the voltage measured: fn ±1.5% of the set value or ±0.002 × Un Start time1)2) Minimum Typical Maximum UFault = 1.1 × set Start value UFault = 2.0 × set Start value 33 ms 24 ms 35 ms 26 ms 37 ms 28 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Negative-sequence voltage before fault = 0.0 × Un, fn = 50 Hz, negative-sequence overvoltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Table 46. Negative-sequence overvoltage protection (NSPTOV) main settings Parameter Function Value (Range) Step Start value NSPTOV 0.010...1.000 × Un 0.001 Operate delay time NSPTOV 40...120000 ms 1 Table 47. Three-phase thermal overload protection, two time constants (T2PTTR) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz Current measurement: ±1.5% of the set value or ±0.002 x In (at currents in the range of 0.01...4.00 x In) Operate time accuracy1) ±2.0% of the theoretical value or ±0.50 s 1) Overload current > 1.2 x Operate level temperature Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 34 ABB

Parameter Function Value (Range) Step Temperature rise T2PTTR 0.0...200.0°C 0.1 Max temperature T2PTTR 0.0...200.0°C 0.1 Operate temperature T2PTTR 80.0...120.0% 0.1 Short time constant T2PTTR 6...60000 s 1 Weighting factor p T2PTTR 0.00...1.00 0.01 Current reference T2PTTR 0.05...4.00 × In 0.01 Operation T2PTTR 1 = on 5 = off - Table 49. Circuit breaker failure protection (CCBRBRF) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz ±1.5% of the set value or ±0.002 × In Operate time accuracy ±1.0% of the set value or ±20 ms Reset time Typically 40 ms Retardation time <20 ms Table 50. Circuit breaker failure protection (CCBRBRF) main settings Parameter Function Value (Range) Step Current value CCBRBRF 0.05...2.00 × In 0.05 Current value Res CCBRBRF 0.05...2.00 × In 0.05 CB failure mode CCBRBRF 1 = Current 2 = Breaker status 3 = Both - CB fail trip mode CCBRBRF 1 = Off 2 = Without check 3 = Current check - Retrip time CCBRBRF 0...60000 ms 10 CB failure delay CCBRBRF 0...60000 ms 10 CB fault delay CCBRBRF 0...60000 ms 10 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 35

Characteristic Value Operation accuracy ±3% of the set value or ±0.01 × In Operate time Minimum Typical Maximum Operation mode = "Light +current"1)2) 9 ms3) 4 ms4) 12 ms3) 6 ms4) 15 ms 3) 9 ms4) Operation mode = "Light only"2) 9 ms3) 4 ms4) 10 ms3) 6 ms4) 12 ms3) 7 ms4) Reset time Typically 40 ms Reset ratio Typically 0.96 1) Phase start value = 1.0 × In, current before fault = 2.0 × set Phase start value, fn = 50 Hz, fault with nominal frequency, results based on statistical distribution of 200 measurements 2) Includes the delay of the heavy-duty output contact 3) Normal power output 4) High-speed output Table 52. Arc protection (ARCSARC) main settings Parameter Function Value (Range) Step Phase start value ARCSARC 0.50...40.00 × In 0.01 Ground start value ARCSARC 0.05...8.00 × In 0.01 Operation mode ARCSARC 2 = Light only 3 = BI controlled - Table 53. Multipurpose protection (MAPGAPC) Characteristic Value Operation accuracy ±1.0% of the set value or ±20 ms Table 54. Multipurpose protection (MAPGAPC) main settings Parameter Function Value (Range) Step Start value MAPGAPC -10000.0...10000.0 0.1 Operate delay time MAPGAPC 0...200000 ms 100 Operation mode MAPGAPC 1 = Over 2 = Under - Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 36 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz, and no harmonics 5% of the set value or 0.002 × In Start time for overload stage1)2) Typically 75 ms Start time for under current stage2)3) Typically 26 ms Reset time for overload and alarm stage Typically 60 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode 1% of the set value or ±20 ms Operate time accuracy in inverse time mode 10% of the theoretical value or ±20 ms Suppression of harmonics for under current stage DFT: -50 dB at f = n × fn, where n = 2,3,4,5,.. 1) Harmonics current before fault = 0.5 × In, harmonics fault current 1.5 × Start value, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Harmonics current before fault = 1.2 × In, harmonics fault current 0.8 × Start value, results based on statistical distribution of 1000 measurements Table 56. Three-phase overload protection for shunt capacitor banks (COLPTOC) main settings Parameter Function Value (Range) Step Start value overload COLPTOC 0.30...1.50 × In 0.01 Alarm start value COLPTOC 80...120% 1 Start value Un Cur COLPTOC 0.10...0.70 × In 0.01 Time multiplier COLPTOC 0.05...2.00 0.01 Alarm delay time COLPTOC 500...6000000 ms 100 Un Cur delay time COLPTOC 100...120000 ms 100 Table 57. Current unbalance protection for shunt capacitor banks (CUBPTOC) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz 1.5% of the set value or 0.002 × In Start time1)2) Typically 26 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode 1% of the theoretical value or ±20 ms Operate time accuracy in inverse definite minimum time mode 5% of the theoretical value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2,3,4,5,.. 1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 37

Parameter Function Value (Range) Step Alarm mode CUBPTOC 1 = Normal 2 = Element counter - Start value CUBPTOC 0.01...1.00 × In 0.01 Alarm start value CUBPTOC 0.01...1.00 × In 0.01 Time multiplier CUBPTOC 0.05...15.00 0.01 Operating curve type1) CUBPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 Operate delay time CUBPTOC 50...200000 ms 10 Alarm delay time CUBPTOC 50...200000 ms 10 1) For further reference, refer to the Operating characteristics table Table 59. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz 1.5% of the set value or 0.002 × In Start time1)2) Typically 26 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode 1% of the theoretical value or ±20 ms Operate time accuracy in IDMT mode 5% of the theoretical value or ±20 ms Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2,3,4,5,.. 1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Table 60. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC) main settings Parameter Function Value (Range) Step Start value HCUBPTOC 0.01...1.00 × In 0.01 Alarm start value HCUBPTOC 0.01...1.00 × In 0.01 Time multiplier HCUBPTOC 0.05...15.00 0.01 Operating curve type 1) HCUBPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 Operate delay time HCUBPTOC 40...200000 ms 10 Alarm delay time HCUBPTOC 40...200000 ms 10 1) For further reference, refer to the Operating characteristics table Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 38 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz Operate value accuracy: ±3% of the set value or ±0.002 × In (for 2nd order Harmonics) ±1.5% of the set value or ±0.002 × In (for 3rd order < Harmonics < 10th order) ±6% of the set value or ±0.004 × In (for Harmonics >= 10th order) Reset time Typically 45 ms or maximum 50 ms Retardation time Typically 0.96 Retardation time <35 ms Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Suppression of harmonics -50 dB at f = fn Table 62. Shunt capacitor bank switching resonance protection, current based (SRCPTOC) main settings Parameter Function Value (Range) Step Alarm start value SRCPTOC 0.03...0.50 × In 0.01 Start value SRCPTOC 0.03...0.50 × In 0.01 Tuning harmonic Num SRCPTOC 1...11 1 Operate delay time SRCPTOC 120...360000 ms 1 Alarm delay time SRCPTOC 120...360000 ms 1 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 39

Parameter Value (Range) Operating curve type 1 = ANSI Ext. inv. 2 = ANSI Very. inv. 3 = ANSI Norm. inv. 4 = ANSI Mod inv. 5 = ANSI Def. Time 6 = L.T.E. inv. 7 = L.T.V. inv. 8 = L.T. inv. 9 = IEC Norm. inv. 10 = IEC Very inv. 11 = IEC inv. 12 = IEC Ext. inv. 13 = IEC S.T. inv. 14 = IEC L.T. inv 15 = IEC Def. Time 17 = Programmable 18 = RI type 19 = RD type Operating curve type (voltage protection) 5 = ANSI Def. Time 15 = IEC Def. Time 17 = Inv. Curve A 18 = Inv. Curve B 19 = Inv. Curve C 20 = Programmable 21 = Inv. Curve A 22 = Inv. Curve B 23 = Programmable Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 40 ABB

Table 64. Voltage variation (PHQVVR) Characteristic Value Operation accuracy ±1.5% of the set value or ±0.2% of reference voltage Reset ratio Typically 0.96 (Swell), 1.04 (Dip, Interruption) Table 65. Voltage unbalance (VSQVUB) Characteristic Value Operation accuracy ±1.5% of the set value or ±0.002 × Un Reset ratio Typically 0.96 Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 41

Table 66. Circuit-breaker condition monitoring (SSCBR) Characteristic Value Current measuring accuracy ±1.5% or ±0.002 × In (at currents in the range of 0.1…10 × In) ±5.0% (at currents in the range of 10…40 × In) Operate time accuracy ±1.0% of the set value or ±20 ms Travelling time measurement +10 ms / -0 ms Table 67. Current circuit supervision (CCSPVC) Characteristic Value Operate time 1) <30 ms 1) Including the delay of the output contact Table 68. Current circuit supervision (CCSPVC) main settings Parameter Function Value (Range) Step Start value CCSPVC 0.05...0.20 × In 0.01 Max operate current CCSPVC 1.00...5.00 × In 0.01 Table 69. Fuse failure supervision (SEQSPVC) Characteristic Value Operate time1) NPS function UFault = 1.1 × set Neg Seq voltage Lev <33 ms UFault = 5.0 × set Neg Seq voltage Lev <18 ms Delta function ΔU = 1.1 × set Voltage change rate <30 ms ΔU = 2.0 × set Voltage change rate <24 ms 1) Includes the delay of the signal output contact, fn = 50 Hz, fault voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements Table 70. Runtime counter for machines and devices (MDSOPT) Description Value Motor runtime measurement accuracy1) ±0.5% 1) Of the reading, for a stand-alone relay, without time synchronization Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 42 ABB

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz ±0.5% or ±0.002 × In (at currents in the range of 0.01...4.00 × In) Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… RMS: No suppression Table 72. Sequence current measurement (CSMSQI) Characteristic Value Operation accuracy Depending on the frequency of the measured current: f/fn = ±2 Hz ±1.0% or ±0.002 × In at currents in the range of 0.01...4.00 × In Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… Table 73. Residual current measurement (RESCMMXU) Characteristic Value Operation accuracy Depending on the frequency of the current measured: f/fn = ±2 Hz ±0.5% or ±0.002 × In at currents in the range of 0.01...4.00 × In Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… RMS: No suppression Table 74. Three-phase voltage measurement (VMMXU) Characteristic Value Operation accuracy Depending on the frequency of the voltage measured: fn ±2 Hz At voltages in range 0.01…1.15 × Un ±0.5% or ±0.002 × Un Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… RMS: No suppression Table 75. Residual voltage measurement (RESVMMXU) Characteristic Value Operation accuracy Depending on the frequency of the measured voltage: f/fn = ±2 Hz ±0.5% or ±0.002 × Un Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… RMS: No suppression Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 43

Characteristic Value Operation accuracy Depending on the frequency of the voltage measured: fn ±2 Hz At voltages in range 0.01…1.15 × Un ±1.0% or ±0.002 × Un Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… Table 77. Three-phase power and energy measurement (PEMMXU) Characteristic Value Operation accuracy At all three currents in range 0.10…1.20 × In At all three voltages in range 0.50…1.15 × Un At the frequency fn ±1 Hz ±1.5% for apparent power S ±1.5% for active power P and active energy1) ±1.5% for reactive power Q and reactive energy2) ±0.015 for power factor Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) |PF| >0.5 which equals |cosφ| >0.5 2) |PF| <0.86 which equals |sinφ| >0.5 Table 78. RTD/mA measurement (XRGGIO130) Description Value RTD inputs Supported RTD sensors 100 Ω platinum 250 Ω platinum 100 Ω nickel 120 Ω nickel 250 Ω nickel 10 Ω copper TCR 0.00385 (DIN 43760) TCR 0.00385 TCR 0.00618 (DIN 43760) TCR 0.00618 TCR 0.00618 TCR 0.00427 Supported resistance range 0...2 kΩ Maximum lead resistance (three- wire measurement) 25 Ω per lead Isolation 2 kV (inputs to protective earth) Response time <4 s RTD/resistance sensing current Maximum 0.33 mA rms Operation accuracy Resistance Temperature ± 2.0% or ±1 Ω ±1°C 10 Ω copper: ±2°C mA inputs Supported current range 0…20 mA Current input impedance 44 Ω ± 0.1% Operation accuracy ±0.5% or ±0.01 mA Table 79. Frequency measurement (FMMXU) Characteristic Value Operation accuracy ±5 mHz (in measurement range 35...75 Hz) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 44 ABB

Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 81. Time delay off (8 pcs) (TOFPAGC) Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 82. Time delay on (8 pcs) (TONGAPC) Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 45

The relay is available with two optional displays, a large one and a small one. The large display is suited for relay installations where the front panel user interface is frequently used and a single line diagram is required. The small display is suited for remotely controlled substations where the relay is only occasionally accessed locally via the front panel user interface. Both LCD displays offer front-panel user interface functionality with menu navigation and menu views. However, the large display offers increased front-panel usability with less menu scrolling and improved information overview. In addition, the large display includes a user-configurable single line diagram (SLD) with position indication for the associated primary equipment. Depending on the chosen standard configuration, the relay displays the related measuring values, apart from the default single line diagram. The SLD view can also be accessed using the Web browser-based user interface. The default SLD can be modified according to user requirements by using the Graphical Display Editor in PCM600. The user can create up to 10 SLD pages. The local HMI includes a push button (L/R) for local/remote operation of the relay. When the relay is in the local mode, it can be operated only by using the local front panel user interface. When the relay is in the remote mode, it can execute commands sent from a remote location. The relay supports the remote selection of local/remote mode via a binary input. This feature facilitates, for example, the use of an external switch at the substation to ensure that all relays are in the local mode during maintenance work and that the circuit breakers cannot be operated remotely from the network control center. IECA070904 V3 EN Figure 12. Small display IECA070901 V3 EN Figure 13. Large display Table 83. Small display Character size1) Rows in the view Characters per row Small, mono-spaced (6 × 12 pixels) 5 20 Large, variable width (13 × 14 pixels) 3 8 or more 1) Depending on the selected language Table 84. Large display Character size1) Rows in the view Characters per row Small, mono-spaced (6 × 12 pixels) 10 20 Large, variable width (13 × 14 pixels) 7 8 or more 1) Depending on the selected language Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 46 ABB

By means of appropriate mounting accessories, the standard relay case can be flush mounted, semi-flush mounted or wall mounted. The flush mounted and wall mounted relay cases can also be mounted in a tilted position (25°) using special accessories. Further, the relays can be mounted in any standard 19” instrument cabinet by means of 19” mounting panels available with cut-outs for one or two relays.Alternatively, the relays can be mounted in 19” instrument cabinets by means of 4U Combiflex equipment frames. For routine testing purposes, the relay cases can be equipped with test switches, type RTXP 18, which can be mounted side by side with the relay cases. Mounting methods • Flush mounting • Semi-flush mounting • Semi-flush mounting in a 25° tilt • Rack mounting • Wall mounting • Mounting to a 19" equipment frame • Mounting with an RTXP 18 test switch to a 19" rack Panel cut-out for flush mounting • Height: 161.5 ±1 mm • Width: 165.5 ±1 mm 48 177 160 177 153 164 IECA070900 V4 EN Figure 14. Flush mounting 98 177 160 186 103 IECA070903 V4 EN Figure 15. Semi-flush mounting 230 107 25° 133 190 IECA070902 V4 EN Figure 16. Semi-flush mounting in a 25º tilt 23. Relay case and plug-in unit The relay cases are assigned to a certain type of plug-in unit. For safety reasons, the relay cases for current measuring relays are provided with automatically operating contacts for short- circuiting the CT secondary circuits when a relay unit is withdrawn from its case. The relay case is further provided with a mechanical coding system preventing the current measuring relay units from being inserted into relay cases intended for voltage measuring relay units. 24. Selection and ordering data Use ABB Library to access the selection and ordering information and to generate the order number. Product Selection Tool (PST), a Next-Generation Order Number Tool, supports order code creation for ABB Distribution Automation IEC products with emphasis on, but not exclusively for, the Relion product family. PST is an easy-to-use, online tool always containing the latest product information. The complete order code can be created with detailed specification and the result can be printed and mailed. Registration is required. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 47

Table 85. Cables Item Order number Optical sensor for arc protection, cable length 1.5 m 1MRS120534-1.5 Optical sensor for arc protection, cable length 3.0 m 1MRS120534-3 Optical sensor for arc protection, cable length 5.0 m 1MRS120534-5 Optical sensor for arc protection, cable length 7.0 m 1MRS120534-7 Optical sensor for arc protection, cable length 10.0 m 1MRS120534-10 Optical sensor for arc protection, cable length 15.0 m 1MRS120534-15 Optical sensor for arc protection, cable length 20.0 m 1MRS120534-20 Optical sensor for arc protection, cable length 25.0 m 1MRS120534-25 Optical sensor for arc protection, cable length 30.0 m 1MRS120534-30 Table 86. Mounting accessories Item Order number Semi-flush mounting kit 1MRS050696 Wall mounting kit 1MRS050697 Inclined semi-flush mounting kit 1MRS050831 19” rack mounting kit with cut-out for one relay 1MRS050694 19” rack mounting kit with cut-out for two relays 1MRS050695 Mounting bracket for one relay with test switch RTXP in 4U Combiflex (RHGT 19” variant C) 2RCA022642P0001 Mounting bracket for one relay in 4U Combiflex (RHGT 19” variant C) 2RCA022643P0001 19” rack mounting kit for one relay and one RTXP18 test switch (the test switch is not included in the delivery) 2RCA021952A0003 19” rack mounting kit for one relay and one RTXP24 test switch (the test switch is not included in the delivery) 2RCA022561A0003 Functional earthing flange for RTD modules1) 2RCA036978A0001 Replacement kit for a Strömberg SP_J40 series relay (cut-out in the center of the installation plate) 2RCA027871A0001 Replacement kit for a Strömberg SP_J40 series relay (cut-out on the left or the right of the installation plate) 2RCA027874A0001 Replacement kit for two Strömberg SP_J3 series relays 2RCA027880A0001 19” rack replacement kit for Strömberg SP_J3/J6 series relays (one cut-out) 2RCA027894A0001 19” rack replacement kit for Strömberg SP_J3/J6 series relays (two cut-outs) 2RCA027897A0001 Replacement kit for a Strömberg SP_J6 series relay 2RCA027881A0001 Replacement kit for three BBC S_ series relays 2RCA027882A0001 Replacement kit for a SPA 300 series relay 2RCA027885A0001 1) Cannot be used when the protection relay is mounted with the Combiflex 19" equipment frame (2RCA032826A0001) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 48 ABB

default parameter setting values can be changed from the front- panel user interface (local HMI), the Web browser-based user interface (Web HMI) or Protection and Control IED Manager PCM600 in combination with the relay-specific connectivity package. PCM600 offers extensive relay configuration functions. For example, depending on the protection relay, the relay signals, application, graphical display and single-line diagram, and IEC 61850 communication, including horizontal GOOSE communication, can be modified with PCM600. When the Web HMI is used, the protection relay can be accessed either locally or remotely using a Web browser (Internet Explorer). For security reasons, the Web HMI is disabled by default but it can be enabled via the local HMI. The Web HMI functionality can be limited to read-only access. The relay connectivity package is a collection of software and specific relay information, which enables system products and tools to connect and interact with the protection relay. The connectivity packages reduce the risk of errors in system integration, minimizing device configuration and setup times. Further, the connectivity packages for protection relays of this product series include a flexible update tool for adding one additional local HMI language to the protection relay. The update tool is activated using PCM600, and it enables multiple updates of the additional HMI language, thus offering flexible means for possible future language updates. Table 87. Tools Description Version PCM600 2.6 (Rollup 20150626) or later Web browser IE 8.0, IE 9.0, IE 10.0 or IE 11.0 REV615 Connectivity Package 5.1 or later Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 49

Function Web HMI PCM600 Relay parameter setting ● ● Saving of relay parameter settings in the relay ● ● Signal monitoring ● ● Disturbance recorder handling ● ● Alarm LED viewing ● ● Access control management ● ● Relay signal configuration (Signal Matrix) - ● Modbus® communication configuration (communication management) - ● DNP3 communication configuration (communication management) - ● IEC 60870-5-103 communication configuration (communication management) - ● Saving of relay parameter settings in the tool - ● Disturbance record analysis - ● XRIO parameter export/import ● ● Graphical display configuration - ● Application configuration - ● IEC 61850 communication configuration, GOOSE (communication configuration) - ● Phasor diagram viewing ● - Event viewing ● ● Saving of event data on the user's PC ● ● Online monitoring - ● ● = Supported 27. Cyber security The relay supports role based user authentication and authorization. It can store 2048 audit trail events to a non- volatile memory. The non-volatile memory is based on a memory type which does not need battery backup or regular component exchange to maintain the memory storage. FTP and Web HMI use TLS encryption with a minimum of 128 bit key length protecting the data in transit. In this case the used communication protocols are FTPS and HTTPS. All rear communication ports and optional protocol services can be deactivated according to the required system setup. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 50 ABB

REV615 X13 Light sensor input 1 1) X14 Light sensor input 2 1) X15 Light sensor input 3 1) 1) Optional 2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached 3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO) 4) BIO0006 Module (6BI+3BO) Alternative Module RTD0001 (6RTD+2mA) 16 17 19 18 X100 6 7 8 9 10 11 12 13 15 14 2 1 3 4 5 22 21 23 24 SO2 TCS2 PO4 SO1 TCS1 PO3 PO2 PO1 IRF + - Uaux 20 X110 3 4 5 6 7 8 9 10 BI 6 BI 5 BI 4 BI 3 BI 2 BI 8 BI 7 12 13 11 BI 1 1 2 X110 16 14 15 19 17 18 22 20 21 SO3 SO2 SO1 23 SO4 24 2) X120 1 2 3 4 5 6 7 8 9 10 11 12 13 14 IL1unb 1/5A N IL2unb IL1 IL2 IL3 Io 1/5A N 1/5A N 1/5A N 1/5A N 1/5A N 1/5A N IL3unb 3) 3) X130 1 2 3 4 5 6 BI 4 BI 3 BI 2 BI 1 BI 6 BI 5 8 9 7 X130 12 10 11 15 13 14 18 16 17 SO3 SO2 SO1 4) 4) GUID-E075C9E1-5D32-4556-ADD7-8B64EF861FA8 V1 EN Figure 17. Terminal diagram for standard configuration A Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 51

X14 Light sensor input 2 1) X15 Light sensor input 3 1) 1) Optional 2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached 3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO) 4) AIM0006 Module (5U+4BI) Alternative Module AIM0003 (5U+2RTD+1mA) 16 17 19 18 X100 6 7 8 9 10 11 12 13 15 14 2 1 3 4 5 22 21 23 24 SO2 TCS2 PO4 SO1 TCS1 PO3 PO2 PO1 IRF + - Uaux 20 X110 3 4 5 6 7 8 9 10 BI 6 BI 5 BI 4 BI 3 BI 2 BI 8 BI 7 12 13 11 BI 1 1 2 X110 16 14 15 19 17 18 22 20 21 SO3 SO2 SO1 23 SO4 24 2) X120 1 2 3 4 5 6 7 8 9 10 11 12 13 14 IL1unb 1/5A N IL2unb IL1 IL2 IL3 Io 1/5A N 1/5A N 1/5A N 1/5A N 1/5A N 1/5A N IL3unb 3) 3) X130 1 2 3 4 5 6 BI 4 BI 3 BI 2 BI 1 8 7 9 10 11 12 UoB 13 14 U1 15 16 U2 17 18 U3 Uo N N N N 60 - N 210V 60 - 210V 60 - 210V 60 - 210V 60 - 210V 4) GUID-71A7F7FA-9605-46FE-A7EF-B53142C4EE9F V1 EN Figure 18. Terminal diagram for standard configuration B Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 52 ABB

for Relion® 615 series. Certificate number: 7410570I-OPE/INC 15-1136. DNV GL has issued an IEC 61850 Edition 1 Certificate Level A1 for Relion® 615 series. Certificate number: 74105701-OPE/INC 15-1145. Additional certificates can be found on the product page. 30. References The www.abb.com/substationautomation portal provides information on the entire range of distribution automation products and services. The latest relevant information on the REV615 protection and control relay is found on the product page. Scroll down the page to find and download the related documentation. Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 53

Table 89. Functions included in the relay Function IEC 61850 IEC 60617 IEC-ANSI Protection Three-phase non-directional overcurrent protection, low stage PHLPTOC1 3I> (1) 51P-1 (1) Three-phase non-directional overcurrent protection, high stage PHHPTOC1 3I>> (1) 51P-2 (1) PHHPTOC2 3I>> (2) 51P-2 (2) Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC1 3I>>> (1) 50P/51P (1) Non-directional earth-fault protection, low stage EFLPTOC1 Io> (1) 51N-1 (1) EFLPTOC2 Io> (2) 51N-1 (2) Non-directional earth-fault protection, high stage EFHPTOC1 Io>> (1) 51N-2 (1) Non-directional earth-fault protection, instantaneous stage EFIPTOC1 Io>>> (1) 50N/51N (1) Directional earth-fault protection, low stage DEFLPDEF1 Io> -> (1) 67N-1 (1) DEFLPDEF2 Io> -> (2) 67N-1 (2) Directional earth-fault protection, high stage DEFHPDEF1 Io>> -> (1) 67N-2 (1) Transient/intermittent earth-fault protection INTRPTEF1 Io> -> IEF (1) 67NIEF (1) Negative-sequence overcurrent protection NSPTOC1 I2> (1) 46 (1) NSPTOC2 I2> (2) 46 (2) Residual overvoltage protection ROVPTOV1 Uo> (1) 59G (1) ROVPTOV2 Uo> (2) 59G (2) ROVPTOV3 Uo> (3) 59G (3) Three-phase undervoltage protection PHPTUV1 3U< (1) 27 (1) PHPTUV2 3U< (2) 27 (2) Three-phase overvoltage protection PHPTOV1 3U> (1) 59 (1) PHPTOV2 3U> (2) 59 (2) Positive-sequence undervoltage protection PSPTUV1 U1< (1) 47U+ (1) Negative-sequence overvoltage protection NSPTOV1 U2> (1) 47O- (1) Three-phase thermal overload protection, two time constants T2PTTR1 3Ith>T/G/C (1) 49T/G/C (1) Circuit breaker failure protection CCBRBRF1 3I>/Io>BF (1) 51BF/51NBF (1) Master trip TRPPTRC1 Master Trip (1) 94/86 (1) TRPPTRC2 Master Trip (2) 94/86 (2) TRPPTRC3 Master Trip (3) 94/86 (3) TRPPTRC4 Master Trip (4) 94/86 (4) TRPPTRC5 Master Trip (5) 94/86 (5) Arc protection ARCSARC1 ARC (1) 50L/50NL (1) ARCSARC2 ARC (2) 50L/50NL (2) ARCSARC3 ARC (3) 50L/50NL (3) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 54 ABB

Function IEC 61850 IEC 60617 IEC-ANSI Multipurpose protection MAPGAPC1 MAP (1) MAP (1) MAPGAPC2 MAP (2) MAP (2) MAPGAPC3 MAP (3) MAP (3) MAPGAPC4 MAP (4) MAP (4) MAPGAPC5 MAP (5) MAP (5) MAPGAPC6 MAP (6) MAP (6) MAPGAPC7 MAP (7) MAP (7) MAPGAPC8 MAP (8) MAP (8) MAPGAPC9 MAP (9) MAP (9) MAPGAPC10 MAP (10) MAP (10) MAPGAPC11 MAP (11) MAP (11) MAPGAPC12 MAP (12) MAP (12) MAPGAPC13 MAP (13) MAP (13) MAPGAPC14 MAP (14) MAP (14) MAPGAPC15 MAP (15) MAP (15) MAPGAPC16 MAP (16) MAP (16) MAPGAPC17 MAP (17) MAP (17) MAPGAPC18 MAP (18) MAP (18) Three-phase overload protection for shunt capacitor banks COLPTOC1 3I> 3I< (1) 51C/37 (1) Current unbalance protection for shunt capacitor banks CUBPTOC1 dI>C (1) 51NC-1 (1) Three-phase current unbalance protection for shunt capacitor banks HCUBPTOC1 3dI>C (1) 51NC-2 (1) Shunt capacitor bank switching resonance protection, current based SRCPTOC1 TD> (1) 55TD (1) Power quality Current total demand distortion CMHAI1 PQM3I (1) PQM3I (1) Voltage total harmonic distortion VMHAI1 PQM3U (1) PQM3V (1) Voltage variation PHQVVR1 PQMU (1) PQMV (1) Voltage unbalance VSQVUB1 PQUUB (1) PQVUB (1) Control Circuit-breaker control CBXCBR1 I <-> O CB (1) I <-> O CB (1) Disconnector control DCXSWI1 I <-> O DCC (1) I <-> O DCC (1) DCXSWI2 I <-> O DCC (2) I <-> O DCC (2) Earthing switch control ESXSWI1 I <-> O ESC (1) I <-> O ESC (1) Disconnector position indication DCSXSWI1 I <-> O DC (1) I <-> O DC (1) DCSXSWI2 I <-> O DC (2) I <-> O DC (2) DCSXSWI3 I <-> O DC (3) I <-> O DC (3) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 55

Function IEC 61850 IEC 60617 IEC-ANSI Earthing switch indication ESSXSWI1 I <-> O ES (1) I <-> O ES (1) ESSXSWI2 I <-> O ES (2) I <-> O ES (2) Condition monitoring and supervision Circuit-breaker condition monitoring SSCBR1 CBCM (1) CBCM (1) Trip circuit supervision TCSSCBR1 TCS (1) TCM (1) TCSSCBR2 TCS (2) TCM (2) Current circuit supervision CCSPVC1 MCS 3I (1) MCS 3I (1) Fuse failure supervision SEQSPVC1 FUSEF (1) 60 (1) Runtime counter for machines and devices MDSOPT1 OPTS (1) OPTM (1) Measurement Disturbance recorder RDRE1 DR (1) DFR (1) Load profile record LDPRLRC1 LOADPROF (1) LOADPROF (1) Fault record FLTRFRC1 FAULTREC (1) FAULTREC (1) Three-phase current measurement CMMXU1 3I (1) 3I (1) Sequence current measurement CSMSQI1 I1, I2, I0 (1) I1, I2, I0 (1) Residual current measurement RESCMMXU1 Io (1) In (1) Three-phase voltage measurement VMMXU1 3U (1) 3V (1) Residual voltage measurement RESVMMXU1 Uo (1) Vn (1) RESVMMXU2 Uo (2) Vn (2) Sequence voltage measurement VSMSQI1 U1, U2, U0 (1) V1, V2, V0 (1) Three-phase power and energy measurement PEMMXU1 P, E (1) P, E (1) RTD/mA measurement XRGGIO130 X130 (RTD) (1) X130 (RTD) (1) Frequency measurement FMMXU1 f (1) f (1) IEC 61850-9-2 LE sampled value sending SMVSENDER SMVSENDER SMVSENDER IEC 61850-9-2 LE sampled value receiving (voltage sharing) SMVRCV SMVRCV SMVRCV Other Minimum pulse timer (2 pcs) TPGAPC1 TP (1) TP (1) TPGAPC2 TP (2) TP (2) TPGAPC3 TP (3) TP (3) TPGAPC4 TP (4) TP (4) Minimum pulse timer (2 pcs, second resolution) TPSGAPC1 TPS (1) TPS (1) Minimum pulse timer (2 pcs, minute resolution) TPMGAPC1 TPM (1) TPM (1) Pulse timer (8 pcs) PTGAPC1 PT (1) PT (1) PTGAPC2 PT (2) PT (2) Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 56 ABB

Function IEC 61850 IEC 60617 IEC-ANSI Time delay off (8 pcs) TOFGAPC1 TOF (1) TOF (1) TOFGAPC2 TOF (2) TOF (2) TOFGAPC3 TOF (3) TOF (3) TOFGAPC4 TOF (4) TOF (4) Time delay on (8 pcs) TONGAPC1 TON (1) TON (1) TONGAPC2 TON (2) TON (2) TONGAPC3 TON (3) TON (3) TONGAPC4 TON (4) TON (4) Set-reset (8 pcs) SRGAPC1 SR (1) SR (1) SRGAPC2 SR (2) SR (2) SRGAPC3 SR (3) SR (3) SRGAPC4 SR (4) SR (4) Move (8 pcs) MVGAPC1 MV (1) MV (1) MVGAPC2 MV (2) MV (2) Generic control point (16 pcs) SPCGAPC1 SPC (1) SPC (1) SPCGAPC2 SPC (2) SPC (2) Analog value scaling SCA4GAPC1 SCA4 (1) SCA4 (1) SCA4GAPC2 SCA4 (2) SCA4 (2) SCA4GAPC3 SCA4 (3) SCA4 (3) SCA4GAPC4 SCA4 (4) SCA4 (4) Integer value move MVI4GAPC1 MVI4 (1) MVI4 (1) 32. Document revision history Document revision/date Product version History A/2014-01-24 5.0 First release B/2015-10-30 5.0 FP1 Content updated to correspond to the product version C/2016-05-20 5.0 FP1 Content updated D/2018-12-20 5.0 FP1 Content updated Capacitor Bank Protection and Control 1MRS757952 D REV615 Product version: 5.0 FP1 ABB 57

Distribution Automation P.O. Box 699 FI-65101 VAASA, Finland Phone +358 10 22 11 ABB Distribution Automation Maneja Works Vadodara-390013, India Phone +91 265 2604386 Fax +91 265 2638922 www.abb.com/mediumvoltage www.abb.com/relion www.abb.com/substationautomation — © Copyright 2018 ABB. All rights reserved. 1MRS757952 D