ABB RED615 Product Manual

3. Protection functions......................................................12 4. Application................................................................... 12 5. Supported ABB solutions............................................. 14 6. Control......................................................................... 16 7. Measurements............................................................. 17 8. Power quality................................................................17 9. Fault location................................................................17 10. Disturbance recorder...................................................17 11. Event log.....................................................................17 12. Recorded data............................................................ 18 13. Condition monitoring .................................................. 18 14. Trip-circuit supervision.................................................18 15. Self-supervision...........................................................18 16. Current circuit supervision........................................... 18 17. Protection communication and supervision................. 18 18. Access control............................................................ 19 19. Inputs and outputs...................................................... 19 20. Station communication................................................20 21. Technical data.............................................................25 22. Local HMI....................................................................57 23. Mounting methods...................................................... 58 24. Relay case and plug-in unit......................................... 58 25. Selection and ordering data.........................................58 26. Accessories and ordering data.................................... 59 27. Tools...........................................................................59 28. Cyber security............................................................. 60 29. Terminal diagrams.......................................................61 30. Certificates.................................................................. 65 31. References..................................................................65 32. Functions, codes and symbols....................................66 33. Document revision history........................................... 70 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 2015 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 2 ABB

protection and control relay designed for utility and industrial power systems, including radial, looped and meshed distribution networks with or without distributed power generation. RED615 is also designed for the protection of line differential applications with a transformer within the protection zone. RED615 relays communicate between substations over a fiber optic link or a galvanic pilot wire connection. RED615 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 guided by the IEC 61850 standard for communication and interoperability of substation automation equipment. The relay provides unit type main protection for overhead lines and cable feeders in distribution networks. The relay also features current-based protection functions for remote back- up for down-stream protection relays and local back-up for the line differential main protection. Further, standard configurations B and C also include earth-fault protection. Standard configurations D and E include directional overcurrent and voltage based protection functions. The relay is adapted for the protection of overhead line and cable feeders in isolated neutral, resistance earthed, compensated (impedance earthed) and solidly earthed networks. Once the 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 RED615 is available in five 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 utilizing 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 RED615 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 Issued: 2015-10-30 Revision: K ABB 3

Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP CONDITION MONITORING AND SUPERVISION ALSO AVAILABLE - Binary Signal Transfer function (BST) - Disturbance and fault recorder - Event log and recorded data - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI OR AND LINE DIFFERENTIAL PROTECTION AND CONTROL RELAY PROTECTION LOCAL HMI STANDARD CONFIGURATION 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 With in-zone power transformer support RED615 CONTROL AND INDICATION 1) MEASUREMENT Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs 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 1 - 2 3 1 2 - I, Io - Limit value supervision - Load profile record - Symmetrical components 4 - A REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× Sum of phase currents I∑ PCS PCS OPTS OPTM 2× TCS TCM 2× I2> 46 3I>>> 50P/51P 2× Master Trip Lockout relay 94/86 3I>/Io>BF 51BF/51NBF 3I2f> 68 3I> 51P-1 2× 3I>> 51P-2 3dI>L 87L MCS 3I MCS 3I BST BST PHIZ HIZ 18× MAP MAP 3I Io I∑ 3I GUID-78F52211-9D37-4A2F-9527-CD61BDEA68A2 V2 EN Figure 1. Functionality overview for standard configuration A Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 4 ABB

Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP CONDITION MONITORING AND SUPERVISION ALSO AVAILABLE - Binary Signal Transfer function (BST) - Disturbance and fault recorder - Event log and recorded data - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI OR AND LINE DIFFERENTIAL PROTECTION AND CONTROL RELAY PROTECTION LOCAL HMI STANDARD CONFIGURATION 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 With in-zone power transformer support RED615 B 3I>/Io>BF 51BF/51NBF CONTROL AND INDICATION 1) MEASUREMENT Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs 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 1 - 2 3 1 2 - I, Io, Uo - Limit value supervision - Load profile record - Symmetrical components 4 1 O→I 79 REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× 2× I2> 46 I2/I1> 46PD 3Ith>F 49F 3I>>> 50P/51P 2× Master Trip Lockout relay 94/86 2× Io>→ 67N-1 Io>>→ 67N-2 Io>IEF→ 67NIEF 3× Uo> 59G Io>> 51N-2 3I> 51P-1 3I2f> 68 3× Yo>→ 21YN 3× Po>→ 32N OR 2× 3I>> 51P-2 CBCM CBCM OPTS OPTM 2× TCS TCM MCS 3I MCS 3I PCS PCS BST BST 3dI>L 87L Io>HA 51NHA OR PHIZ HIZ 18× MAP MAP 3Ith>T/G/C 49T/G/C 3I Uo Uo Io Io Io 3I GUID-6AB801FF-A43F-40D6-8D70-D27EF2F402B0 V2 EN Figure 2. Functionality overview for standard configuration B Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 5

- Disturbance and fault recorder - Event log and recorded data - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI OR AND LINE DIFFERENTIAL PROTECTION AND CONTROL RELAY PROTECTION LOCAL HMI STANDARD CONFIGURATION REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× 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 With in-zone power transformer support RED615 C CONTROL AND INDICATION 1) MEASUREMENT Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs 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 1 - 2 3 1 2 - I, Io - Limit value supervision - Load profile record - Symmetrical components 4 - O→I 79 2× Master Trip Lockout relay 94/86 Io>> 51N-2 BST BST Io>HA 51NHA 3I>/Io>BF 51BF/51NBF 2× I2> 46 I2/I1> 46PD 3Ith>F 49F 3I>>> 50P/51P 3I> 51P-1 3I2f> 68 2× 3I>> 51P-2 3dI>L 87L SOTF SOTF 18× MAP MAP 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 CONDITION MONITORING AND SUPERVISION OPTS OPTM 2× TCS TCM MCS 3I MCS 3I PCS PCS CBCM CBCM PHIZ HIZ Io>>> 50N/51N 2× Io> 51N-1 3Ith>T/G/C 49T/G/C 3I Io Io Io 3I GUID-C4999021-E1FE-4D55-AB91-FC7C6963501B V2 EN Figure 3. Functionality overview for standard configuration C Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 6 ABB

Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP CONDITION MONITORING AND SUPERVISION ALSO AVAILABLE - Binary Signal Transfer function (BST) - Disturbance and fault recorder - Event log and recorded data - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI OR AND LINE DIFFERENTIAL PROTECTION AND CONTROL RELAY PROTECTION LOCAL HMI STANDARD CONFIGURATION 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 With in-zone power transformer support RED615 D 3I>/Io>BF 51BF/51NBF OPTS OPTM 2× TCS TCM 2× I2> 46 I2/I1> 46PD 3Ith>F 49F 3I>>> 50P/51P 2× Master Trip Lockout relay 94/86 MCS 3I MCS 3I PCS PCS BST BST CBCM CBCM 2× 3I>→ 67-1 3I2f> 68 3I>>→ 67-2 3dI>L 87L CONTROL AND INDICATION 1) 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 1 - 2 3 1 2 REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× MEASUREMENT - I, U, Io, Uo, P, Q, E, pf, f - Limit value supervision - Load profile record - RTD/mA measurement (optional) - Symmetrical components Analog interface types 1) Current transformer Voltage transformer 1) Conventional transformer inputs 2) One of the five inputs is reserved for future applications 2) 4 5 O→I 79 FUSEF 60 PQM3I PQM3I PQM3U PQM3V PQMU PQMV SYNC 25 U12 U12 3Ith>T/G/C 49T/G/C f>/f<, df/dt 81 3× Uo> 59G 3I Uo Uo Io UL1UL2UL3 UL1UL2UL3 18× MAP MAP FLOC 21FL 2xRTD 1xmA SOTF SOTF 2× Io>→ 67N-1 Io>>→ 67N-2 Io>IEF→ 67NIEF Io>> 51N-2 3× Yo>→ 21YN 3× Po>→ 32N OR Io>HA 51NHA OR PHIZ HIZ 3I Io Io 3× 3U< 27 U2> 47O- U1< 47U+ 3× 3U> 59 UL1UL2UL3 RED615 AT REMOTE END 3I 4× PQUUB PQVUB GUID-F76822E6-DDB6-44F2-8704-5A5B3035BAFD V2 EN Figure 4. Functionality overview for standard configuration D Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 7

Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP CONDITION MONITORING AND SUPERVISION ALSO AVAILABLE - Binary Signal Transfer function (BST) - Disturbance and fault recorder - Event log and recorded data - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI OR AND LINE DIFFERENTIAL PROTECTION AND CONTROL RELAY PROTECTION LOCAL HMI CONTROL AND INDICATION 1) 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 1 - 2 3 1 2 STANDARD CONFIGURATION REMARKS Optional function No. of instances Alternative function to be defined when ordering OR Io/Uo Calculated value 3× 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 With in-zone power transformer support RED615 MEASUREMENT Analog interface types 1) Current sensor Voltage sensor 1) Combi sensor inputs with conventional Io input Current transformer 1 3 3 - I, U, Io, Uo, P, Q, E, pf, f - Limit value supervision - Load profile record - Symmetrical components E 3I>/Io>BF 51BF/51NBF OPTS OPTM 2× TCS TCM 2× I2> 46 I2/I1> 46PD 3Ith>F 49F 3I>>> 50P/51P 2× Master Trip Lockout relay 94/86 2× Io>→ 67N-1 Io>>→ 67N-2 Io>IEF→ 67NIEF Io>> 51N-2 MCS 3I MCS 3I PCS PCS BST BST CBCM CBCM 3× Yo>→ 21YN 3× Po>→ 32N OR Io>HA 51NHA OR 2× 3I>→ 67-1 3I2f> 68 3I>>→ 67-2 3dI>L 87L PQM3I PQM3I PQM3U PQM3V PQMU PQMV O→I 79 FUSEF 60 18× MAP MAP FLOC 21FL SOTF SOTF SYNC 25 UL1UL2UL3 3Ith>T/G/C 49T/G/C IEC 61850-9-2LE UL1 UL1UL2UL3 U1< 47U+ 3I Io Io 3I 3I 3× 3U< 27 U2> 47O- 3× 3U> 59 3× Uo> 59G Uo f>/f<, df/dt 81 PQUUB PQVUB 4× Io GUID-D0C7BD80-3FC0-448D-ACD4-D6123319339C V2 EN Figure 5. Functionality overview for standard configuration E Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 8 ABB

Description Std. conf. Line differential protection A Line differential protection with directional earth-fault protection and circuit-breaker condition monitoring B Line differential protection with non-directional earth-fault protection and circuit-breaker condition monitoring C Line differential protection with directional overcurrent and earth-fault protection, voltage and frequency based protection and measurements, synchro-check and circuit-breaker condition monitoring (RTD option, optional power quality and fault locator) D Line differential protection with directional overcurrent and earth-fault protection, voltage and frequency based protection and measurements, and circuit-breaker condition monitoring (sensor inputs, optional power quality, fault locator and synchro-check with IEC 61850-9-2 LE) E Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 9

Function IEC 61850 A B C D E Protection Three-phase non-directional overcurrent protection, low stage PHLPTOC 1 1 1 Three-phase non-directional overcurrent protection, high stage PHHPTOC 2 2 2 Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 1 1 1 1 1 Three-phase directional overcurrent protection, low stage DPHLPDOC 2 2 Three-phase directional overcurrent protection, high stage DPHHPDOC 1 1 Non-directional earth-fault protection, low stage EFLPTOC 2 Non-directional earth-fault protection, high stage EFHPTOC 1 Non-directional earth-fault protection, instantaneous stage EFIPTOC 1 Directional earth-fault protection, low stage DEFLPDEF 2 1) 2 2 2) Directional earth-fault protection, high stage DEFHPDEF 1 1) 1 1 2) Admittance-based earth-fault protection 3) EFPADM (3) 1)3) (3) 3) (3) 2)3) Wattmetric-based earth-fault protection 3) WPWDE (3) 1)3) (3) 3) (3) 2)3) Transient/intermittent earth-fault protection INTRPTEF 1 1)4) 1 4) 1 2)4) Harmonics-based earth-fault protection 3) HAEFPTOC (1)3)4) (1) 3)4) (1) 3)4) (1) 3)4) Non-directional (cross-country) earth-fault protection, using calculated Io EFHPTOC 1 1 1 Negative-sequence overcurrent protection NSPTOC 2 2 2 2 2 Phase discontinuity protection PDNSPTOC 1 1 1 1 Residual overvoltage protection ROVPTOV 3 1) 3 3 2) Three-phase undervoltage protection PHPTUV 3 3 Three-phase overvoltage protection PHPTOV 3 3 Positive-sequence undervoltage protection PSPTUV 1 1 Negative-sequence overvoltage protection NSPTOV 1 1 Frequency protection FRPFRQ 4 4 Three-phase thermal protection for feeders, cables and distribution transformers T1PTTR 1 1 1 1 Three-phase thermal overload protection, two time constants T2PTTR 1 1 1 1 Binary signal transfer BSTGGIO 1 1 1 1 1 Circuit breaker failure protection CCBRBRF 1 5) 1 1 1 1 Three-phase inrush detector INRPHAR 1 1 1 1 1 Switch onto fault CBPSOF 1 1 1 1 1 Master trip TRPPTRC 2 2 2 2 2 Multipurpose protection MAPGAPC 18 18 18 18 18 Fault locator SCEFRFLO (1) (1) Line differential protection with in-zone power transformer LNPLDF 1 1 1 1 1 High-impedance fault detection PHIZ 1 1 1 1 Power quality Current total demand distortion CMHAI (1) 6) (1) 6) Voltage total harmonic distortion VMHAI (1) 6) (1) 6) Voltage variation PHQVVR (1) 6) (1) 6) Voltage unbalance VSQVUB (1) 6) (1) 6) Control Circuit-breaker control CBXCBR 1 1 1 1 1 Disconnector control DCXSWI 2 2 2 2 2 Earthing switch control ESXSWI 1 1 1 1 1 Disconnector position indication DCSXSWI 3 3 3 3 3 Earthing switch indication ESSXSWI 2 2 2 2 2 Autoreclosing DARREC (1) (1) (1) (1) Synchronism and energizing check SECRSYN 1 (1) 7) Condition monitoring and supervision Circuit-breaker condition monitoring SSCBR 1 1 1 1 Trip circuit supervision TCSSCBR 2 2 2 2 2 Current circuit supervision CCSPVC 1 1 1 1 1 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 10 ABB

Function IEC 61850 A B C D E Fuse failure supervision SEQSPVC 1 1 Protection communication supervision PCSITPC 1 1 1 1 1 Runtime counter for machines and devices MDSOPT 1 1 1 1 1 Measurement Disturbance recorder RDRE 1 1 1 1 1 Load profile record LDPRLRC 1 1 1 1 1 Fault record FLTRFRC 1 1 1 1 1 Three-phase current measurement CMMXU 1 1 1 1 1 Sequence current measurement CSMSQI 1 1 1 1 1 Residual current measurement RESCMMXU 1 1 1 1 Three-phase voltage measurement VMMXU 2 1 (1) 7) Residual voltage measurement RESVMMXU 1 1 Sequence voltage measurement VSMSQI 1 1 Three-phase power and energy measurement PEMMXU 1 1 RTD/mA measurement XRGGIO130 (1) Frequency measurement FMMXU 1 1 IEC 61850-9-2 LE sampled value sending 7)8) SMVSENDER (1) (1) IEC 61850-9-2 LE sampled value receiving (voltage sharing) 7)8) SMVRCV (1) (1) Other Minimum pulse timer (2 pcs) TPGAPC 4 4 4 4 4 Minimum pulse timer (2 pcs, second resolution) TPSGAPC 1 1 1 1 1 Minimum pulse timer (2 pcs, minute resolution) TPMGAPC 1 1 1 1 1 Pulse timer (8 pcs) PTGAPC 2 2 2 2 2 Time delay off (8 pcs) TOFGAPC 4 4 4 4 4 Time delay on (8 pcs) TONGAPC 4 4 4 4 4 Set-reset (8 pcs) SRGAPC 4 4 4 4 4 Move (8 pcs) MVGAPC 2 2 2 2 2 Generic control point (16 pcs) SPCGAPC 2 2 2 2 2 Analog value scaling (4 pcs) SCA4GAPC 4 4 4 4 4 Integer value move (4 pcs) MVI4GAPC 1 1 1 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) "Uo measured" is always used. 2) "Uo calculated" is always used. 3) One of the following can be ordered as an option: admittance-based E/F, wattmetric-based E/F or harmonics-based E/F. 4) "Io measured" is always used. 5) "Io calculated" is always used. 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 11

The relay offers two-stage phase-segregated line differential protection, phase overcurrent protection, negative-sequence overcurrent protection and circuit breaker failure protection. Depending on the chosen standard configuration, the basic functionality can be extended by thermal overload protection, non-directional or directional overcurrent protection, directional or non-directional earth-fault protection, sensitive earth-fault protection, phase discontinuity protection, transient/ intermittent earth-fault protection, residual overvoltage protection, phase-voltage and frequency based protection and three-pole multishot autoreclosing functions for overhead line feeders. For standard configurations B, D and E, admittance- based, wattmetric-based or harmonics-based earth-fault protection is offered as an option in addition to the directional earth-fault protection. The line differential protection function includes a stabilized low stage and an instantaneous high stage. The stabilized low stage provides sensitive differential protection and remains stable during, for example, current transformer saturation conditions. The low-stage operation can be restrained using second harmonic detection if an out-of-zone power transformer is to be energized. The instantaneous high stage offers less sensitive differential protection but enables fast operation during high fault currents. If there is an in-zone transformer in the protection zone, the vector group is automatically compensated based on the winding types and clock number setting values. The operating time characteristic for the low stage can be set to definite time or inverse definite time mode. The direct intertrip function ensures that both ends are always simultaneously tripped, independent of the fault current contribution. 4. Application RED615 can be used in a variety of applications requiring an absolutely selective unit type protection system. The zone-of- protection of a line differential protection system is the feeder section defined by the location of the current transformers in the local and the remote substation. RED615 can also be used for line differential protection if there is an in-zone transformer in the protected feeder section. Combining horizontal GOOSE communication over a station bus and binary signal transfer over the protection communication link offers new application possibilities beyond traditional line differential protection. One interesting application based on inter-substation signal transfer is loss-of- mains (LOM) protection in networks with distributed generation. The performance of the combination of binary signal transfer and horizontal GOOSE communication performance as to speed, selectivity and reliability are hard to match with conventional loss-of-mains protection. RED615 is the ideal relay for the protection of feeders in network configurations containing closed loops. Under normal operating conditions the feeder loop is closed. The aim of the closed loop is to secure the availability of power for the end users. As a result of the closed loop configuration, any fault spot in the system will be fed with fault current from two directions. Using plain overcurrent protection, either directional or non-directional, it is difficult to obtain fast and selective short circuit protection. With RED615 line differential protection relays the faulty part of the network can be selectively isolated, thus securing power distribution to the healthy part of the network. The standard configuration E includes one conventional residual current (Io) input and three combi-sensor inputs for phase currents and phase voltages. The connection of the three combi-sensors is made with RJ-45 type of connectors. Sensors offer certain benefits compared to conventional current and voltage instrument transformers. For example, current sensors do not saturate at high currents, they consume less energy and they weigh less. In voltage sensors the risk of ferro-resonance is eliminated. The sensor inputs also enable the use of the relay in compact medium voltage switchgears, such as ABB’s UniGear Digital, SafeRing and SafePlus, with limited space for conventional measuring transformers, thus requiring the use of sensor technology. Further, the adapters also enable the use of sensors with Twin-BNC connectors. Under certain operational circumstances, such as maintenance of primary equipment or substation extension projects there will be a need to interconnect network parts, which normally are separated. To avoid major re-parameterization of the protection devices of the network when the network topology is changed, line differential protection relays can be used to obtain absolutely selective feeder protection in looped networks. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 12 ABB

P 0.00 kW Q 0.00 kVAr IL2 0 A A RED615 Std. conf. ANSI IEC 46 50P/51P 51BF/51NBF 51P-1/51P-2 87L BST MCS 3I I2> 3I>>> 3I>/Io>BF 3I>/3I>> 3ΔI> BST MCS 3I A I∑ Protection communication I∑ R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A GUID-28763BDA-8E54-4716-9CDD-F2A208E79E25 V1 EN Figure 6. Line differential protection for an interconnecting feeder between two primary distribution substations using standard configuration A Figure 6 illustrates line differential protection for an interconnecting feeder between two primary distribution substations using standard configuration A. Additionally, protection is offered for a in-zone power transformer, when available and located in the protection zone. Io 3I 3I RED615 Std. conf. ANSI IEC 46 49F/49T 50P/51P 51BF/51NBF 51N 87L BST MCS 3I I2> 3Ith>F/3Ith>T 3I>>> 3I>/Io>BF Io> 3ΔI> BST MCS 3I B/C RED615 Std. conf. ANSI IEC 46 47O-/59 47U+/27 50P/51P 51BF/51NBF 67N-1/67N-2 87L BST MCS 3I I2> U2>/3U> U1>> 3I>/Io>BF Io>→/Io>>→ 3ΔI> BST MCS 3I D 3U Uo R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A Protection communication Io R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A GUID-3084D6C6-6067-4827-AA10-DAC1A772077C V1 EN Figure 7. Line differential protection of a feeder using the standard configurations D and B or C Line differential protection of a feeder using the standard configurations D and B or C is shown in Figure 7. Additionally, protection is offered for an in-zone power transformer, when available and located in the protection zone. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 13

P 0.00 kW Q 0.00 kVAr IL2 0 A A 3U R L Clear ESC I O U12 0. 0 kV P 0.00 kW Q 0.00 kVAr IL2 0 A A GUID-6802EC2A-DC22-44E6-8BD2-DF7DCEAAEBA0 V1 EN Figure 8. Line differential protection of a feeder using the standard configuration E Figure 8 illustrates line differential protection of a feeder using the standard configuration E, in which current sensors (Rogowski coil) and voltage sensors (voltage divider) are used for the measurements. Additionally, protection is offered for an in-zone power transformer, when available and located in the protection zone. The standard configuration E has been pre- configured especially for ABB switchgears, for example, UniGear Digital. However, the use of this configuration is not restricted for this purpose only. Standard configurations D and E are not designed for using all the available functionality content in one relay at the same time. Frequency protection functions and third instances of voltage protection functions must be added with the Application Configuration tool. To ensure the performance of the relay, the user-specific configuration load is verified with the Application Configuration tool in PCM600. 5. Supported ABB solutions ABB’s 615 series protection and control relays together with the Substation Automation Unit COM600 constitute a genuine IEC 61850 solution for reliable power distribution in utility and industrial power systems. To facilitate and streamline 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 also includes event and parameter lists. With the connectivity packages, the relays can be readily configured using PCM600 and integrated with the Substation Automation Unit COM600 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 integrity of the protection and communication system, 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, COM600 uses the data content of the bay- level devices to enhance substation level functionality. COM600 features a Web browser-based HMI, which provides a customizable graphical display for visualizing single-line mimic Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 14 ABB

especially useful when 615 series relays without the optional single-line diagram feature are used. The Web HMI of COM600 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, COM600 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 COM600. The history data can be used for accurate monitoring of process and equipment performance, using calculations based on both real-time and history values. A better understanding of the process dynamics is achieved by combining time-based process measurements with production and maintenance events. COM600 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 COM600 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 Automation Unit COM600 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 15

Industry: OPC COM600 Web HMI ABB MicroSCADA Pro/ System 800xA Analog and binary horizontal GOOSE communication IEC 61850 PCM600 Ethernet switch COM600 Web HMI Analog and binary horizontal GOOSE communication IEC 61850 GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V2 EN Figure 9. ABB power system example using Relion relays, Substation Automation Unit COM600 and MicroSCADA Pro/System 800xA 6. Control RED615 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 which are intended for motor-operated control of disconnectors or circuit breaker truck and for their position indications. Further, the relay offers one control block which is 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. Further, some standard configurations also 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 such as 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 the releasing of some initially reserved binary inputs and outputs of the relay in the standard configuration. The suitability of the relay's binary outputs 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 should be considered. In case 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 16 ABB

symmetrical components of the currents and the residual current. If the relay includes voltage measurements, it also measures the residual voltage. The relay also calculates the demand value of the current over a user-selectable, pre-set time frame, the thermal overload of the protected object, and the phase unbalance based on the ratio between the negative- sequence and positive-sequence current. Furthermore, the relay monitors the phase differential, bias and remote-end phase currents. The values measured can be accessed locally via the user interface on the relay's front panel or remotely via the communication interface of the relay. The values can also be accessed locally or remotely using the Web browser-based user interface. 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. Not only can a monitoring system 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 3-second average and a long- term demand for total demand distortion TDD and total harmonic distortion THD. 9. Fault location RED615 features an optional impedance-measuring fault location function suitable for locating short-circuits in radial distribution systems. Earth faults can be located in effectively and low-resistance earthed networks. Under circumstances where the fault current magnitude is at least of the same order of magnitude or higher than the load current, earth faults can also be located in isolated neutral distribution networks. The fault location function identifies the type of the fault and then calculates the distance to the fault point. An estimate of the fault resistance value is also calculated. The estimate provides information about the possible fault cause and the accuracy of the estimated distance to the fault point. 10. Disturbance recorder The relay is provided with a disturbance recorder with 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 non-volatile memory and can be uploaded for subsequent fault analysis. 11. Event log To collect sequence-of-events information, the relay has a non- volatile memory with a capacity of storing 1024 events with associated time stamps. The non-volatile memory retains its data also in case the relay temporarily loses its auxiliary supply. The event log facilitates detailed pre- and post-fault analyses of feeder faults and disturbances. The increased capacity to process and store data and events in the relay offers prerequisites to support the growing information demand of future network configurations. The sequence-of-events information can be accessed either locally via the user interface on the relay's front panel, or remotely via the communication interface of the relay. The Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 17

based user interface, either locally or remotely. 12. Recorded data The relay has the capacity to store the records of the 128 latest fault events. The records enable the user to analyze the power system events. Each record includes the phase, differential and bias current values, time stamp, and so on. The fault recording can be triggered by the start signal 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. 13. 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. 14. 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. 15. Self-supervision The relay’s built-in self-supervision system continuously 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. 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 the line differential protection and negative-sequence overcurrent 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. Protection communication and supervision The communication between the relays is enabled by means of a dedicated fiber optic communication channel. 1310 nm multi- mode or single-mode fibers with LC connectors are used for line differential communication. The channel is used for transferring the phase segregated current value data between the relays. The current phasors from the two relays, geographically located apart from each other, must be time coordinated so that the current differential algorithm can be executed correctly. The so called echo method is used for time synchronization. No external devices such as GPS clocks are thereby needed for the line differential protection communication. As an option to the fiber optic communication link a galvanic connection over a pilot wire link composed of a twisted pair cable and RPW600 link-end communication modems can be established. The optional pilot wire communication link is also an ideal and cost efficient retrofit solution for electromechanical line differential protection installations. Compared to conventional combined sequence line differential protection solutions with analog pilot wire communication, RED615 relays in combination with RPW600 communication modems offer a modern phase-segregated line differential protection solution over existing pilot wire cables. The pilot wire link supports the same protection and communication functionality as the fiber optic link. The quality of service (QoS) is indicated by the modems and the communication link is continuously supervised by the relay. The RPW600 modem offers a 5 kV (RMS) level of isolation between the pilot wire terminals and ground. The RPW600 modems (master and follower) are galvanically connected to either end of the pilot wire and optically connected to the relays using short optical single-mode cables. Using 0.8 mm2 twisted pair cables pilot wire link distances up to 8 km are typically supported. However, twisted pair pilot wire cables in good conditions may support even longer distances to be covered. The length of the supported pilot wire link also depends on the noise environment in the installation. Should the need arise to replace the pilot wire cables with fiber optic cables, the single mode fiber optic LC connectors of the relays can be utilized for direct connection of the fiber optic communication link. Apart from the continued protection communication, the communication channel can also be used for binary signal transfer (BST) that is, transferring of user configurable binary information between the relays. There are a total of eight BST signals available for user definable purposes. The BST signals can originate from the relay’s binary inputs or internal logics, Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 18 ABB

logics. The protection communication supervision continuously monitors the protection communication link. The relay immediately blocks the line differential protection function in case that severe interference in the communication link, risking the correct operation of the function, is detected. An alarm signal will eventually be issued if the interference, indicating permanent failure in the protection communication, persists. The two high-set stages of the overcurrent protection are further by default released. RED615 RED615 Fibre-optic line differential communication link Protection communication and supervision Binary signal transfer GUID-8CE71CC9-F0EA-4BE9-B693-173CAEA9FA58 V2 EN Figure 10. Fiber optic protection communication link RED615 RED615 Pilot wire line differential communication link Protection communication and supervision Binary signal transfer RPW600 modem RPW600 modem GUID-12C57326-6CB9-4FA9-B9F4-3D8F21015DCF V2 EN Figure 11. Pilot wire protection communication link 18. 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 level. The access control applies to the front- panel user interface, the Web browser-based user interface and PCM600. 19. Inputs and outputs Depending on the standard configuration selected, the relay is equipped with three phase-current inputs and one residual- current input for non-directional earth-fault protection and current circuit supervision, or three phase-current inputs, one residual-current input and one residual voltage input for directional earth-fault protection and current circuit supervision. The standard configuration E includes one conventional residual current (Io 0.2/1 A) input and three sensor inputs for the direct connection of three combi-sensors with RJ-45 connectors. As an alternative to combi-sensors, separate current and voltage sensors can be utilized using adapters. Furthermore, the adapters also enable the use of sensors with Twin-BNC connectors. The phase-current inputs are rated 1/5 A. Two optional residual-current inputs are available, that is, 1/5 A or 0.2/1 A. The 0.2/1 A input is normally used in applications requiring sensitive earth-fault protection and featuring core-balance current transformers. The residual-voltage input covers the rated voltages 60...210 V. The phase-current input 1 A or 5 A, the residual-current input 1 A or 5 A, alternatively 0.2 A or 1 A, and the rated voltage of the residual voltage input are selected in the relay software. In Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 19

by adjusting the relay’s parameter settings. All binary inputs and outputs contacts are freely configurable with the signal matrix or application configuration functionality of PCM600. Please refer to the Input/output overview table and the terminal diagrams for more detailed information about the inputs and outputs. Table 4. Input/output overview Std. conf. Order code digit Analog channels Binary channels 5-6 7-8 CT VT Combi sensor BI BO RTD mA A AC AD 4 - - 12 4 PO + 6 SO - - AF 4 - - 18 4 PO + 9 SO - - B AA / AB AC 4 1 - 11 4 PO + 6 SO - - AE 4 1 - 17 4 PO + 9 SO - - C AC AD 4 - - 12 4 PO + 6 SO - - AF 4 - - 18 4 PO + 9 SO - - D FE / FF AD 4 5 - 12 4 PO + 6 SO 2 1 AE / AF AG 4 5 - 16 4 PO + 6 SO - - E DA AH 1 - 3 8 4 PO + 6 SO - - 20. 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 application for sampled values shares the voltages to other 615 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 20 ABB

optical Ethernet network interfaces. 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. All communication card variants support self-healing ring based Ethernet redundancy. Communication card variants with two optical interfaces for station bus communication have support for HSR and PRP redundancy protocols. These variants include also support for IEEE 1588 based time synchronization. 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 REF615 REF620 RET620 REM620 REF615 SCADA COM600 GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V1 EN Figure 12. 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 21

Redundancy Box Redundancy Box REF615 REF620 RET620 REM620 REF615 SCADA Devices not supporting HSR COM600 GUID-7996332D-7FC8-49F3-A4FE-FB4ABB730405 V1 EN Figure 13. 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. The self-healing Ethernet ring solution avoids single point of failure concerns and improves the reliability of the communication. The solution can be applied for the Ethernet- based IEC 61850, Modbus and DNP3 protocols. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 22 ABB

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 14. 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). 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) Remote-end station time reference • Line differential Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 23

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-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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 24 ABB

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 <12.0 W (nominal)/<18.0 W (max) AC <16.0 W (nominal)/<21.0 W (max) DC <12.0 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 A 1/5 A1) 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) Residual current and/or phase current Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 25

Description Value Current sensor input Rated current voltage (in secondary side) 75 mV...9000 mV1) Continuous voltage withstand 125 V Input impedance at 50/60 Hz 2...3 MΩ2) Voltage sensor input Rated voltage 6 kV...30 kV3) Continuous voltage withstand 50 V Input impedance at 50/60 Hz 3 MΩ 1) Equals the current range of 40...4000 A with a 80 A, 3 mV/Hz Rogowski 2) Depending on the used nominal current (hardware gain) 3) This range is covered (up to 2*rated) with sensor division ratio of 10 000:1 Table 10. Binary inputs 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 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 1 A/0.25 A/0.15 A Minimum contact load 100 mA at 24 V AC/DC Table 12. Signal outputs and IRF output 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 26 ABB

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 8A 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 Table 15. High-speed output HSO with BIO0007 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 27

Connector Fibre type Wave length Typical max. length1) Permitted path attenuation2) LC MM 62.5/125 or 50/125 μm 1300 nm 2 km <8 dB LC SM 9/125 μm3) 1300 nm 20 km <8 dB 1) Maximum length depends on the cable attenuation and quality, the amount of splices and connectors in the path. 2) Maximum allowed attenuation caused by connectors and cable altogether 3) Use single-mode fiber with recommended minimum length of 3 m to connect RED615 to the pilot wire modem RPW600. Table 18. 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 19. Degree of protection of flush-mounted protection relay Description Value Front side IP 54 Rear side, connection terminals IP 20 Table 20. Environmental conditions Description Value Operating temperature range -25...+55ºC (continuous) Short-time service temperature range -40...+70ºC (<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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 28 ABB

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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 29

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 22. 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 23. Mechanical tests Description Reference Requirement Vibration tests (sinusoidal) IEC 60068-2-6 (test Fc) IEC 60255-21-1 Class 2 Shock and bump test IEC 60068-2-27 (test Ea shock) IEC 60068-2-29 (test Eb bump) IEC 60255-21-2 Class 2 Seismic test IEC 60255-21-3 Class 2 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 30 ABB

Description Type test value Reference Dry heat test • 96 h at +55ºC • 16 h at +70ºC1) 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 1) For relays with an LC communication interface the maximum operating temperature is +70oC Table 25. Product safety Description Reference LV directive 2006/95/EC Standard EN 60255-27 (2013) EN 60255-1 (2009) Table 26. EMC compliance Description Reference EMC directive 2004/108/EC Standard EN 60255-26 (2013) Table 27. RoHS compliance Description Complies with RoHS directive 2002/95/EC Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 31

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 x 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 32 ABB

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 0.05...15.00 0.01 PHHPTOC 0.05...15.00 0.01 Operate delay time PHLPTOC 40...200000 ms 10 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 Operation characteristics table Table 30. Three-phase directional overcurrent protection (DPHxPDOC) Characteristic Value Operation accuracy Depending on the frequency of the current/voltage measured: fn ±2 Hz DPHLPDOC 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° DPHHPDOC 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 time1)2) Minimum Typical Maximum IFault = 2.0 × set Start value 39 ms 43 ms 47 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 ms3) Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Measurement mode and Pol quantity = default, current before fault = 0.0 × In, voltage before fault = 1.0 × Un, 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) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5 to 20 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 33

Parameter Function Value (Range) Step Start value DPHLPDOC 0.05...5.00 × In 0.01 DPHHPDOC 0.10...40.00 × In 0.01 Time multiplier DPHxPDOC 0.05...15.00 0.01 Operate delay time DPHxPDOC 40...200000 ms 10 Directional mode DPHxPDOC 1 = Non-directional 2 = Forward 3 = Reverse Characteristic angle DPHxPDOC -179...180° 1 Operating curve type1) DPHLPDOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 DPHHPDOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 1) For further reference, refer to the Operating characteristics table Table 32. Non-directional earth-fault protection (EFxPTOC) 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 34 ABB

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 0.05...15.00 0.01 EFHPTOC 0.05...15.00 0.01 Operate delay time EFLPTOC 40...200000 ms 10 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 Operation characteristics table Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 35

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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 36 ABB

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 60...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 DEFLPDEF and DEFHPDEF 1 = Phase angle 2 = IoSin 3 = IoCos 4 = Phase angle 80 5 = Phase angle 88 1) For further reference, refer to the Operating characteristics table Table 36. Admittance-based earth-fault protection (EFPADM) Characteristic Value Operation accuracy1) At the frequency f = fn ±1.0% or ±0.01 mS (In range of 0.5...100 mS) Start time2) Minimum Typical Maximum 56 ms 60 ms 64 ms Reset time 40 ms Operate time accuracy ±1.0% of the set value of ±20 ms Suppression of harmonics -50 dB at f = n × fn, where n = 2, 3, 4, 5,… 1) Uo = 1.0 × Un 2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000 measurements. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 37

Parameter Function Value (Range) Step Voltage start value EFPADM 0.01...2.00 × Un 0.01 Directional mode EFPADM 1 = Non-directional 2 = Forward 3 = Reverse Operation mode EFPADM 1 = Yo 2 = Go 3 = Bo 4 = Yo, Go 5 = Yo, Bo 6 = Go, Bo 7 = Yo, Go, Bo Operate delay time EFPADM 60...200000 ms 10 Circle radius EFPADM 0.05...500.00 mS 0.01 Circle conductance EFPADM -500.00...500.00 mS 0.01 Circle susceptance EFPADM -500.00...500.00 mS 0.01 Conductance forward EFPADM -500.00...500.00 mS 0.01 Conductance reverse EFPADM -500.00...500.00 mS 0.01 Conductance tilt Ang EFPADM -30...30° 1 Susceptance forward EFPADM -500.00...500.00 mS 0.01 Susceptance reverse EFPADM -500.00...500.00 mS 0.01 Susceptance tilt Ang EFPADM -30...30° 1 Table 38. Wattmetric-based earth-fault protection (WPWDE) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz Current and voltage: ±1.5% of the set value or ±0.002 × In Power: ±3% of the set value or ±0.002 × Pn Start time 1)2) Typically 63 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in IDMT mode ±5.0% of the set value or ±20 ms Suppression of harmonics -50 dB at f = n × fn, where n = 2,3,4,5,… 1) Io varied during the test. Uo = 1.0 × Un = phase to earth voltage during earth fault in compensated or un-earthed network. The residual power value before fault = 0.0 pu, fn = 50 Hz, results based on statistical distribution of 1000 measurement. 2) Includes the delay of the signal output contact. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 38 ABB

Parameter Function Value (Range) Step Directional mode WPWDE 2 = Forward 3 = Reverse Current start value WPWDE 0.010...5.000 × In 0.001 Voltage start value WPWDE 0.010...1.000 × Un 0.001 Power start value WPWDE 0.003...1.000 × Pn 0.001 Reference power WPWDE 0.050...1.000 × Pn 0.001 Characteristic angle WPWDE -179...180° 1 Time multiplier WPWDE 0.05...2.00 0.01 Operating curve type WPWDE Definite or inverse time Curve type: 5, 15, 20 Operate delay time WPWDE 60...200000 ms 10 Min operate current WPWDE 0.010...1.000 × In 0.001 Min operate voltage WPWDE 0.01...1.00 × Un 0.01 Table 40. 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 41. 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 (voltage start value for transient EF) INTRPTEF 0.01...0.50 × Un 0.01 Operation mode INTRPTEF 1=Intermittent EF 2=Transient EF - Peak counter limit (Min requirement for peak counter before start in IEF mode) INTRPTEF 2...20 - Min operate current INTRPTEF 0.01...1.00 × In 0.01 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 39

Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz ±5% of the set value or ±0.004 × In Start time 1)2) Typically 77 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Operate time accuracy in IDMT mode 3) ±5.0% of the set value or ±20 ms Suppression of harmonics -50 dB at f = fn -3 dB at f = 13 × fn 1) Fundamental frequency current = 1.0 × In. Harmonics current before fault = 0.0 × In, harmonics fault current 2.0 × Start value. Results based on statistical distribution of 1000 measurement. 2) Includes the delay of the signal output contact 3) Maximum Start value = 2.5 × In, Start value multiples in range of 2...20 Table 43. Harmonics-based earth-fault protection (HAEFPTOC) main settings Parameter Function Value (Range) Step Start value HAEFPTOC 0.05...5.00 × In 0.01 Time multiplier HAEFPTOC 0.05...15.00 0.01 Operate delay time HAEFPTOC 100...200000 ms 10 Minimum operate time HAEFPTOC 100...200000 ms 10 Operating curve type HAEFPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 Table 44. Negative-sequence overcurrent protection (NSPTOC) 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 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 20ms 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 40 ABB

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 Operation characteristics table Table 46. Phase discontinuity protection (PDNSPTOC) Characteristic Value Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz ±2% of the set value Start time <70 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,… Table 47. Phase discontinuity protection (PDNSPTOC) main settings Parameter Function Value (Range) Step Start value (Current ratio setting I2/ I1) PDNSPTOC 10...100% 1 Operate delay time PDNSPTOC 100...30000 ms 1 Min phase current PDNSPTOC 0.05...0.30 × In 0.01 Table 48. 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 41

Parameter Function Value (Range) Step Start value ROVPTOV 0.010...1.000 × Un 0.001 Operate delay time ROVPTOV 40...300000 ms 1 Table 50. 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 51. 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 Operation characteristics table Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 42 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 of 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 53. 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 Operation characteristics table Table 54. 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 of 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 43

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...1.0 × Un 0.01 Table 56. Negative-sequence overvoltage protection (NSPTOV) 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 = 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 57. 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 58. Frequency protection (FRPFRQ) Characteristic Value Operation accuracy f>/f< ±5 mHz df/dt ±50 mHz/s (in range |df/dt| <5 Hz/s) ±2.0% of the set value (in range 5 Hz/s < |df/dt| < 15 Hz/s) Start time f>/f< <80 ms df/dt <120 ms Reset time <150 ms Operate time accuracy ±1.0% of the set value or ±30 ms Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 44 ABB

Parameter Function Value (Range) Step Operation mode FRPFRQ 1 = Freq< 2 = Freq> 3 = df/dt 4 = Freq< + df/dt 5 = Freq> + df/dt 6 = Freq< OR df/dt 7 = Freq> OR df/dt Start value Freq> FRPFRQ 0.9000...1.2000 × fn 0.0001 Start value Freq< FRPFRQ 0.8000...1.1000 × fn 0.0001 Start value df/dt FRPFRQ -0.200...0.200 × fn/s 0.005 Operate Tm Freq FRPFRQ 80...200000 ms 10 Operate Tm df/dt FRPFRQ 120...200000 ms 10 Table 60. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR) 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 × In (at currents in the range of 0.01...4.00 × In) Operate time accuracy1) ±2.0% of the theoretical value or ±0.50 s 1) Overload current > 1.2 × Operate level temperature Table 61. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR) main settings Parameter Function Value (Range) Step Env temperature Set (Ambient temperature used when the AmbSens is set to Off) T1PTTR -50...100°C 1 Current multiplier (Current multiplier when function is used for parallel lines) T1PTTR 1...5 1 Current reference T1PTTR 0.05...4.00 × In 0.01 Temperature rise (End temperature rise above ambient) T1PTTR 0.0...200.0°C 0.1 Time constant (Time constant of the line in seconds) T1PTTR 60...60000 s 1 Maximum temperature (temperature level for operate) T1PTTR 20.0...200.0°C 0.1 Alarm value (Temperature level for start (alarm) T1PTTR 20.0...150.0°C 0.1 Reclose temperature (Temperature for reset of block reclose after operate) T1PTTR 20.0...150.0°C 0.1 Initial temperature (Temperature raise above ambient temperature at startup) T1PTTR -50.0...100.0°C 0.1 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 45

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 Table 63. Three-phase thermal overload protection, two time constants (T2PTTR) main settings 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 Weighting factor p T2PTTR 0.00...1.00 0.01 Short time constant T2PTTR 6...60000 s 1 Current reference T2PTTR 0.05...4.00 × In 0.01 Operation T2PTTR Off On - Table 64. Binary signal transfer (BSTGGIO) Characteristic Value Signalling delay Fiber optic link <5 ms Galvanic pilot wire link <10 ms Table 65. 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 time1) Typically 40 ms Retardation time <20 ms 1) Trip pulse time defines the minimum pulse length Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 46 ABB

Parameter Function Value (Range) Step Current value (Operating phase current) CCBRBRF 0.05...1.00 × In 0.05 Current value Res (Operating residual current) CCBRBRF 0.05...1.00 × In 0.05 CB failure mode (Operating mode of function) 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 Table 67. Three-phase inrush detector (INRPHAR) Characteristic Value Operation accuracy At the frequency f = fn Current measurement: ±1.5% of the set value or ±0.002 × In Ratio I2f/I1f measurement: ±5.0% of the set value Reset time +35 ms / -0 ms Reset ratio Typically 0.96 Operate time accuracy +35 ms / -0 ms Table 68. Three-phase inrush detector (INRPHAR) main settings Parameter Function Value (Range) Step Start value (Ratio of the 2nd to the 1st harmonic leading to restraint) INRPHAR 5...100% 1 Operate delay time INRPHAR 20...60000 ms 1 Table 69. Switch onto fault (CBPSOF) Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 70. Switch onto fault (CBPSOF) main settings Parameter Function Value (Range) Step SOTF reset time CBPSOF 0...60000 ms 1 Table 71. Multipurpose protection (MAPGAPC) Characteristic Value Operation accuracy ±1.0% of the set value or ±20 ms Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 47

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 Over Under - Table 73. Fault locator (SCEFRFLO) Characteristic Value Measurement accuracy At the frequency f = fn Impedance: ±2.5% or ±0.25 Ω Distance: ±2.5% or ±0.16 km/0.1 mile XC0F_CALC: ±2.5% or ±50 Ω IFLT_PER_ILD: ±5% or ±0.05 Table 74. Fault locator (SCEFRFLO) main settings Parameter Function Value (Range) Step Z Max phase load SCEFRFLO 1.0...10000.00 Ω 0.1 Ph leakage Ris SCEFRFLO 20...1000000 Ω 1 Ph capacitive React SCEFRFLO 10...1000000 Ω 1 R1 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001 X1 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001 R0 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001 X0 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001 Line Len section A SCEFRFLO 0.000...1000.000 pu 0.001 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 48 ABB

Characteristics Value Operation accuracy 1) Depending on the frequency of the measured current: fn ±2 Hz Low stage ±2.5% of the set value High stage ±2.5% of the set value Minimum Typical Maximum High stage, operate time 2)3) 22 ms 25 ms 29 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time (Low stage) <40 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 set value or ±20 ms 4) 1) With the symmetrical communication channel (as when using dedicated fiber optic). 2) Without additional delay in the communication channel (as when using dedicated fiber optic). 3) Including the delay of the output contact. When differential current = 2 × High operate value and fn = 50 Hz with galvanic pilot wire link + 5 ms. 4) Low operate value multiples in range of 1.5...20. Table 76. Line differential protection with in-zone power transformer (LNPLDF) main settings Parameter Function Value (Range) Description High operate value LNPLDF 200...4000 % In Instantaneous stage operate value Low operate value LNPLDF 10...200 % In Basic setting for the stabilized stage start Operate delay time LNPLDF 45...200000 ms Operate delay time for stabilized stage Operate curve type LNPLDF 1=ANSI Ext. inv. 3=ANSI Norm. inv. 5=ANSI Def. Time 9=IEC Norm. inv. 10=IEC Very inv. 12=IEC Ext. inv. 15=IEC Def. Time Selection of time delay curve for stabilized stage Time multiplier LNPLDF 0.05...15.00 Time multiplier in IDMT curves Start value 2.H LNPLDF 10...50 % The ratio of the 2. harmonic component to fundamental component required for blocking CT ratio correction LNPLDF 0.200...5.000 Remote phase current transformer ratio correction Table 77. High-impedance fault detection (PHIZ) main settings Parameter Function Value (Range) Step Security Level PHIZ 1...10 1 System type PHIZ 1=Grounded 2=Ungrounded Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 49

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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 50 ABB

Table 79. 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 80. Voltage unbalance (VSQVUB) Characteristic Value Operation accuracy ±1.5% of the set value or ±0.002 × Un Reset ratio Typically 0.96 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 51

Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 82. Synchronism and energizing check (SECRSYN) Characteristic Value Operation accuracy Depending on the frequency of the voltage measured: fn ±1 Hz Voltage: ±3.0% of the set value or ±0.01 × Un Frequency: ±10 mHz Phase angle: ±3° Reset time <50 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms Table 83. Synchronism and energizing check (SECRSYN) main settings Parameter Function Value (Range) Step Live dead mode SECRSYN -1 = Off 1 = Both Dead 2 = Live L, Dead B 3 = Dead L, Live B 4 = Dead Bus, L Any 5 = Dead L, Bus Any 6 = One Live, Dead 7 = Not Both Live Difference voltage SECRSYN 0.01...0.50 × Un 0.01 Difference frequency SECRSYN 0.001...0.100 × fn 0.001 Difference angle SECRSYN 5...90° 1 Synchrocheck mode SECRSYN 1 = Off 2 = Synchronous 3 = Asynchronous Control mode SECRSYN 1 = Continuous 2 = Command Dead line value SECRSYN 0.1...0.8 × Un 0.1 Live line value SECRSYN 0.2...1.0 × Un 0.1 Close pulse SECRSYN 200...60000 ms 10 Max energizing V SECRSYN 0.50...1.15 × Un 0.01 Phase shift SECRSYN -180...180° 1 Minimum Syn time SECRSYN 0...60000 ms 10 Maximum Syn time SECRSYN 100...6000000 ms 10 Energizing time SECRSYN 100...60000 ms 10 Closing time of CB SECRSYN 40...250 ms 10 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 52 ABB

Table 84. Circuit-breaker condition monitoring (SSCBR) Characteristic Value Current measuring accuracy ±1.5% or ±0.002 x In (at currents in the range of 0.1…10 x In) ±5.0% (at currents in the range of 10…40 x In) Operate time accuracy ±1.0% of the set value or ±20 ms Travelling time measurement +10 ms / -0 ms Table 85. Current circuit supervision (CCSPVC) Characteristic Value Operate time 1) <30 ms 1) Including the delay of the output contact Table 86. Current circuit supervision (CCSPVC) main settings Parameter Function Value (Range) Step Start value CCSPVC 0.05...0.20 × In 0.01 Maximum operate current CCSPVC 1.00...5.00 × In 0.01 Table 87. 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 88. 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. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 53

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 90. 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 91. 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 92. 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 93. Residual voltage measurement (RESVMMXU) Characteristic Value Operation accuracy Depending on the frequency of the measured current: 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 54 ABB

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 95. 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 96. Frequency measurement (FMMXU) Characteristic Value Operation accuracy ±10 mHz (in measurement range 35...75 Hz) Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 55

Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 98. Time delay off (8 pcs) (TOFPAGC) Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Table 99. Time delay on (8 pcs) (TONGAPC) Characteristic Value Operate time accuracy ±1.0% of the set value or ±20 ms Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 56 ABB

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 15. Small display IECA070901 V3 EN Figure 16. Large display Table 100. Small display Character size1) Rows in the view Characters per row Small, mono-spaced (6x12 pixels) 5 20 Large, variable width (13x14 pixels) 3 8 or more 1) Depending on the selected language Table 101. Large display Character size1) Rows in the view Characters per row Small, mono-spaced (6x12 pixels) 10 20 Large, variable width (13x14 pixels) 7 8 or more 1) Depending on the selected language Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 57

By means of appropriate mounting accessories the standard relay case for the 615 series relay 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 relay can be mounted in 19” instrument cabinets by means of 4U Combiflex equipment frames. For the 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 a 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 17. Flush mounting 98 177 160 186 103 IECA070903 V4 EN Figure 18. Semi-flush mounting 230 107 25° 133 190 IECA070902 V4 EN Figure 19. Semi-flush with a 25º tilt 24. Relay case and 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 current measuring relay units from being inserted into a relay case for a voltage measuring relay unit and vice versa, that is, the relay cases are assigned to a certain type of plug-in unit. 25. Selection and ordering data Use the ABB Library to access the selection and ordering information and to generate the order number. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 58 ABB

Table 102. Pilot wire communication Item Order number Pilot Wire communication package including two Pilot Wire modems: RPW600AM (master) and RPW600AF (follower) RPW600AMF Diagnostics kit including the RPW-diagnostic tool, a diagnostic cable and a CD with necessary drivers and information RPW600ADP 3.0 meter LC-LC single-mode fiber optic patch cable for connecting one Pilot Wire modem to the RED615 relay1) 1MRS120547-3 1) Please note that two patch cables are required for connecting the Pilot Wire communication package (RPW600AMF). Table 103. 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 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 27. Tools The protection relay is delivered as a pre-configured unit. The default parameter setting values can be changed from the front- panel user interface, the Web browser-based user interface (Web HMI) or the PCM600 tool in combination with the relay- specific connectivity package. The Protection and Control IED Manager PCM600 offers extensive relay configuration functions such as relay signal configuration, application configuration, graphical display configuration including single line diagram configuration, and IEC 61850 communication configuration including horizontal GOOSE communication. When the Web browser-based user interface is used, the protection relay can be accessed either locally or remotely using a Web browser (Internet Explorer). For security reasons, the Web browser-based user interface is disabled by default but it can be enabled via the front-panel user interface. 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 enable 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 Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 59

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 104. Tools Configuration and setting tools Version PCM600 2.6 (Rollup 20150626) or later Web browser-based user interface IE 8.0, IE 9.0, IE 10.0 or IE 11.0 RED615 Connectivity Package 5.1 or later Table 105. Supported functions 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 28. 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 desired system setup. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 60 ABB

GUID-FBFA9940-E37D-4C32-A083-0367AAEDE267 V2 EN Figure 20. Terminal diagram for configuration A and C Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 61

Figure 21. Terminal diagram for configuration B Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 62 ABB

X2 LAN IRIG-B - IRIG-B + AGND 1) 3) X12 RX TX 1) 3) 1) 4) 1) 5) B/- A/+ 1) Optional 2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached 3) 100BaseFx / LC or 100BaseTx / RJ-45 4) RS-485 serial bus 5) Fibre Optic (ST) Serial Bus 6) AIM0006 (5U+4BI) Alternative Module AIM0003 (5U+2RTD+1mA) GUID-EE704FD2-E4A7-4745-B84D-95033D4DC5AA V2 EN Figure 22. Terminal diagram for configuration D Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 63

X2 LAN IRIG-B - IRIG-B + AGND 1) 3) X12 RX TX 1) 3) 1) 4) 1) 5) B/- A/+ 1) Optional 2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached 3) 100BaseFx / LC or 100BaseTx / RJ-45 4) RS-485 serial bus 5) Fibre Optic (ST) Serial Bus X130 1 2 X131 4 5 IL1 7 8 U1 X132 4 5 IL2 7 8 U2 X133 4 5 IL3 7 8 U3 Io 0,2/1A N GUID-33733308-95B9-4B59-B5DC-E15AFA16E05E V1 EN Figure 23. Terminal diagram for configuration E Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 64 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. 31. References The www.abb.com/substationautomation portal provides information on the entire range of distribution automation products and services. You will find the latest relevant information on the RED615 protection and control relay on the product page. Scroll down the page to find and download the related documentation. For information regarding the RPW600 modems please refer to the RPW600 User’s Guide, document id 6621-2260. The document is available for download on the RED615 product page. Scroll down the page to find and download the related documentation. Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 65

Table 106. 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) Three-phase directional overcurrent protection, low stage DPHLPDOC1 3I> -> (1) 67-1 (1) DPHLPDOC2 3I> -> (2) 67-1 (2) Three-phase directional overcurrent protection, high stage DPHHPDOC1 3I>> -> (1) 67-2 (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) Admittance-based earth-fault protection EFPADM1 Yo> -> (1) 21YN (1) EFPADM2 Yo> -> (2) 21YN (2) EFPADM3 Yo> -> (3) 21YN (3) Wattmetric-based earth-fault protection WPWDE1 Po> -> (1) 32N (1) WPWDE2 Po> -> (2) 32N (2) WPWDE3 Po> -> (3) 32N (3) Transient/intermittent earth-fault protection INTRPTEF1 Io> -> IEF (1) 67NIEF (1) Harmonics-based earth-fault protection HAEFPTOC1 Io>HA (1) 51NHA (1) Non-directional (cross-country) earth-fault protection, using calculated Io EFHPTOC1 Io>> (1) 51N-2 (1) Negative-sequence overcurrent protection NSPTOC1 I2> (1) 46 (1) NSPTOC2 I2> (2) 46 (2) Phase discontinuity protection PDNSPTOC1 I2/I1> (1) 46PD (1) 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) PHPTUV3 3U< (3) 27 (3) Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 66 ABB

Function IEC 61850 IEC 60617 IEC-ANSI Three-phase overvoltage protection PHPTOV1 3U> (1) 59 (1) PHPTOV2 3U> (2) 59 (2) PHPTOV3 3U> (3) 59 (3) Positive-sequence undervoltage protection PSPTUV1 U1< (1) 47U+ (1) Negative-sequence overvoltage protection NSPTOV1 U2> (1) 47O- (1) Frequency protection FRPFRQ1 f>/f<,df/dt (1) 81 (1) FRPFRQ2 f>/f<,df/dt (2) 81 (2) FRPFRQ3 f>/f<,df/dt (3) 81 (3) FRPFRQ4 f>/f<,df/dt (4) 81 (4) Three-phase thermal protection for feeders, cables and distribution transformers T1PTTR1 3Ith>F (1) 49F (1) Three-phase thermal overload protection, two time constants T2PTTR1 3Ith>T/G/C (1) 49T/G/C (1) Binary signal transfer BSTGGIO1 BST (1) BST (1) Circuit breaker failure protection CCBRBRF1 3I>/Io>BF (1) 51BF/51NBF (1) Three-phase inrush detector INRPHAR1 3I2f> (1) 68 (1) Switch onto fault CBPSOF1 SOTF (1) SOTF (1) Master trip TRPPTRC1 Master Trip (1) 94/86 (1) TRPPTRC2 Master Trip (2) 94/86 (2) 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) Fault locator SCEFRFLO1 FLOC (1) 21FL (1) Line differential protection with in-zone power transformer LNPLDF1 3Id/I> (1) 87L (1) Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 67

Function IEC 61850 IEC 60617 IEC-ANSI High-impedance fault detection PHIZ1 HIF (1) HIZ (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) Earthing switch indication ESSXSWI1 I <-> O ES (1) I <-> O ES (1) ESSXSWI2 I <-> O ES (2) I <-> O ES (2) Autoreclosing DARREC1 O -> I (1) 79 (1) Synchronism and energizing check SECRSYN1 SYNC (1) 25 (1) 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) Protection communication supervision PCSITPC1 PCS (1) PCS (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) VMMXU2 3U (2) 3V (2) Residual voltage measurement RESVMMXU1 Uo (1) Vn (1) 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) Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 68 ABB

Function IEC 61850 IEC 60617 IEC-ANSI 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) 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) Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 ABB 69

Document revision/date Product version History A/2008-10-03 1.1 First release B/2009-07-03 2.0 Content updated to correspond to the product version C/2010-06-11 3.0 Content updated to correspond to the product version D/2010-06-29 3.0 Terminology updated E/2010-09-07 3.0 Content updated F/2012-05-11 4.0 Content updated to correspond to the product version G/2013-02-21 4.0 FP1 Content updated to correspond to the product version H/2014-01-24 5.0 Content updated to correspond to the product version K/2015-10-30 5.0 FP1 Content updated to correspond to the product version Line Differential Protection and Control 1MRS756500 K RED615 Product version: 5.0 FP1 70 ABB

Distribution Automation P.O. Box 699 FI-65101 VAASA, Finland Phone +358 10 22 11 Fax +358 10 22 41094 www.abb.com/mediumvoltage www.abb.com/substationautomation ABB India Limited, Distribution Automation Maneja Works Vadodara-390013, India Phone +91 265 6724402 Fax +91 265 6724423 www.abb.com/mediumvoltage www.abb.com/substationautomation 1MRS756500 K © Copyright 2015 ABB. All rights reserved.