RELION PRODUCT FAMILY Grid Automation Recloser Protection and Control RER615 Product Guide

Transcription

1 RELION PRODUCT FAMILY Recloser Protection and Control RER615 Product Guide

2 Contents 1. Description Standard configurations Protection functions Application Supported ABB solutions Control Measurement Fault location Disturbance recorder Event log Fault recorder Condition monitoring Trip-circuit supervision Self-supervision Fuse failure supervision Autoreclosing Hot line tag Access control Inputs and outputs Station communication Technical data Local HMI Mounting methods Relay case and plug-in unit Selection and ordering data Accessories and ordering data Tools Connection diagrams References Functions, codes and symbols Document revision history Disclaimer The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for any errors that may appear in this document. Copyright 2018 ABB. All rights reserved. Trademarks ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders. 2 ABB

3 Issued: Revision: E 1. Description RER615 is a recloser controller designed for remote control and monitoring, protection, fault indication, power quality analysis and automation in medium-voltage secondary distribution systems, including radial, looped and meshed distribution networks, with or without distributed power generation. RER615 is a member of the Relion product family. The relay has inherited features from the 615 series relays that are characterized by their compactness as well as environmentally friendly (RoHS compliance) and withdrawable-unit design. Reengineered from the ground up, the relays have been designed to unleash the full potential of the IEC standard for communication and interoperability between substation automation devices. With RER615, grid reliability can be enhanced, ranging from basic, non-directional overload protection to extended protection functionality with power quality analyses. RER615 meets today s requirements for smart grids and supports the protection of overhead lines in isolated neutral, resistanceearthed, compensated and solidly earthed networks. RER615 is freely programmable with horizontal GOOSE communication, thus enabling sophisticated interlocking functions. RER615 includes sophisticated protection functionality to detect, isolate and restore power in all types of networks but especially in compensated networks (including recloser tripping curves). As part of an ABB smart grid solution, the relay provides superior fault location, isolation and restoration (FLIR) to lower the frequency and shorten the duration of faults. The adaptable standard configurations allow the relay to be taken into use right after the application-specific parameters have been set, thus enabling rapid commissioning. RER615 supports the same configuration tools as the other relays in the Relion product family. The freely programmable relay contains six easily manageable setting groups. Via the relay's front panel HMI or a remote control system, one recloser can be controlled. The relay's large, easy-to-read LCD screen with single-line diagram offers local control and parametrization possibilities with dedicated push buttons for safe operation. Easy Web-based parametrization tool is also available with download possibility. To protect the relay from unauthorized access and to maintain the integrity of information, the relay is provided with a fourlevel, role-based user authentication system, with individual passwords for the viewer, operator, engineer and administrator levels. The access control system applies to the front panel HMI, embedded Web browser-based HMI and Protection and Control IED Manager PCM600. In addition, the relay also includes cyber security features such as audit trail. RER615 supports a variety of communication protocols for remote communication, such as IEC /104, DNP3 level 2 and Modbus, simultaneously also supporting IEC with GOOSE messaging for high-speed protection, fault isolation and restoration. 2. Standard configurations RER615 is available in three standard configurations. An example configuration suitable for recloser applications is delivered with each standard configuration. This minimizes the required amount of engineering, allowing fast commissioning by just parametrizing the protection functions. For applications where the example configuration is not suitable, the standard signal configuration can be easily altered using the application configuration or signal matrix functionality of the Protection and Control IED Manager PCM600. The application configuration functionality of PCM600 also supports the creation of multilayer logic functions using various logical elements. By combining protection functions with logic function blocks, the relay configuration can be adapted to user-specific application requirements. Standard configuration A supports traditional current and voltage transformers. The residual current for the earth-fault protection is derived from the phase currents in a Holmgren connection. Alternatively, the core balance current transformers can be used for measuring the residual current, especially when sensitive earth-fault protection is required. Standard configuration D supports a combination of traditional current and voltage transformers or alternatively voltage sensors. The residual current for the earth-fault protection is derived from the phase currents in a Holmgren connection. Alternatively, the core balance current transformers can be used for measuring the residual current, especially when sensitive earth-fault protection is required. The sensor inputs are highly flexible and are type-tested to support both ABB's capacitive and resistive voltage sensors. ABB 3

4 Source RER615 Version 2.0 RECLOSER PROTECTION AND CONTROL STANDARD CONFIGURATION A 3I PROTECTION I2> 46 3I2f> 68 Master Trip Lockout relay 94/86 I2/I1> 46PD 3Ith>F 49F 3I>/Io>BF 51BF/51NBF 3I> 51P-1 OR 3I>> 51P-2 3I>>> 50P/51P OR 3I> I>> I LOCAL HMI ALSO AVAILABLE Disturbance and fault recorder Event log Load profile Relay self-supervision Local/Remote push-button on LHMI 4 programmable push-buttons with LED indication 11 programmable bi-color LED Time synchronization: SNTP, IRIG-B, /-104, DNP3, IEEE 1588 v2 User management Web HMI Graphic programmable logics, counter and timer AND OR I O 3x Yo> 21YN OR 3x Po> 32N OR Io> 51N-1 Io>> 51N-2 Io>>> 50N/ 51N Io>HA 51NHA OR OR OR Io> 67N-1 Io>> 67N-2 Io> IEF 67NIEF Io> Y 67YN CONDITION MONITORING AND SUPERVISION FUSEF 60 I1 32P CBCM CBCM PHSVPR PHSVPR TCS TCM OPTS OPTM CONTROL AND INDICATION 1) Object Ctrl 2) Ind. 3) CB 2 DC 8 2 COMMUNICATION Protocols IEC IEC & -104, Modbus, DNP3 Level 2 Interfaces Ethernet: TX (RJ-45), FX (LC) Serial: Serial glass fiber (ST) RS485, RS232/485, IRIG-B Redundant protocols HSR PRP MEASUREMENT I, U, Io, Uo, P, Q, E, pf, f Limit value supervision Load profile record Power Quality function (optional) U L1 U L2 U L3 Uo> 59G 3x 3U< 27 U1< 47U+ U O U L1 U L2 U L3 ES 8 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 Analog interface types 1) Current transformer 4 Voltage transformer 3 1) Conventional transformer inputs PQM3I PQM3I PQM3U PQM3V PQMU PQMV 3x 3U> 59 U2> 47O- f>/f<, df/dt 81 O I 79 ATSABTC ATSABTC PQUUB PQUUV (With REC615 optional) FLOC 21FL UFLS/R 81LSH REMARKS Load 6x MAP MAP 8x MV MV 1 SCA4 SCA4 MVI4 MVI4 Optional function No. of instances Calculated value OR Alternative function defined when ordering GUID-7BCC1E2C-B ACDE-8354FE V3 EN Figure 1. Functionality overview of standard configuration A 4 ABB

5 Source U L1B U L2B U L3B RER615 Version 2.0 RECLOSER PROTECTION AND CONTROL STANDARD CONFIGURATION D 3I PROTECTION I2> 46 3I2f> 68 Master Trip Lockout relay 94/86 I2/I1> 46PD 3Ith>F 49F 3I>/Io>BF 51BF/51NBF 3I> 51P-1 OR 3I>> 51P-2 3I>>> 50P/51P OR 3I> I>> I LOCAL HMI ALSO AVAILABLE Disturbance and fault recorder Event log Load profile Relay self-supervision Local/Remote push-button on LHMI 4 programmable push-buttons with LED indication 11 programmable bi-color LED Time synchronization: SNTP, IRIG-B, /-104, DNP3, IEEE 1588 v2 User management Web HMI Graphic programmable logics, counter and timer AND OR I O Io> 51N-1 Io>> 51N-2 Io>>> 50N/ 51N OR OR Io> 67N-1 Io>> 67N-2 Io> IEF 67NIEF CONDITION MONITORING AND SUPERVISION FUSEF 60 I1 32P CBCM CBCM PHSVPR PHSVPR * ) TCS TCM OPTS OPTM PHSVPR PHSVPR ** ) COMMUNICATION Protocols IEC IEC & -104, Modbus, DNP3 Level 2 Interfaces Ethernet: TX (RJ-45), FX (LC) Serial: Serial glass fiber (ST) RS485, RS232/485, IRIG-B Redundant protocols HSR PRP 3x Yo> 21YN OR 3x Po> 32N OR Io>HA 51NHA OR Io> Y 67YN CONTROL AND INDICATION 1) Object Ctrl 2) Ind. 3) CB 2 DC 8 2 MEASUREMENT I, U, Io, Uo, P, Q, E, pf, f Limit value supervision Load profile record Power Quality function (optional) U L1 U L2 U L3 3U< 27 * ) 3U> 59 * ) Uo> 59G U1< 47U+ U O U2> 47O- f>/f<, df/dt 81 U L1 U L2 U L3 ES 8 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 SYNC 25 ATSABTC ATSABTC 1) Analog interface types Current transformer 4 Voltage sensor 6 1) Conventional transformer and voltage sensor inputs PQM3I PQM3I PQUUB PQUUV PQM3U PQM3V PQMU PQMV U L1B U L2B U L3B 3U< 27 ** ) 3U> U 59 OB ** ) Uo> 59G O I 79 (With REC615 optional) FLOC 21FL UFLS/R 81LSH * ) Instance 1 and 2 ** ) Instance 3 REMARKS Load 6x MAP MAP 8x MV MV 1 SCA4 SCA4 MVI4 MVI4 Optional function No. of instances Calculated value OR Alternative function defined when ordering GUID-D0D32AE3-D6A0-45C3-82FE-2CDE8432F2B9 V3 EN Figure 2. Functionality overview of standard configuration D ABB 5

6 Source U L1B U L2B U L3B RER615 Version 2.0 RECLOSER PROTECTION AND CONTROL STANDARD CONFIGURATION E 3I PROTECTION I2> 46 3I2f> 68 Master Trip Lockout relay 94/86 I2/I1> 46PD 3Ith>F 49F 3I>/Io>BF 51BF/51NBF 3I> 51P-1 OR 3I>> 51P-2 3I>>> 50P/51P OR 3I> I>> I LOCAL HMI ALSO AVAILABLE Disturbance and fault recorder Event log Load profile Relay self-supervision Local/Remote push-button on LHMI 4 programmable push-buttons with LED indication 11 programmable bi-color LED Time synchronization: SNTP, IRIG-B, /-104, DNP3, IEEE 1588 v2 User management Web HMI Graphic programmable logics, counter and timer AND OR I O Io> 51N-1 Io>> 51N-2 Io>>> 50N/ 51N OR OR Io> 67N-1 Io>> 67N-2 Io> IEF 67NIEF CONDITION MONITORING AND SUPERVISION FUSEF 60 I1 32P CBCM CBCM PHSVPR PHSVPR TCS TCM OPTS OPTM PHSVPR PHSVPR COMMUNICATION Protocols IEC IEC & -104, Modbus, DNP3 Level 2 Interfaces Ethernet: TX (RJ-45), FX (LC) Serial: Serial glass fiber (ST) RS485, RS232/485, IRIG-B Redundant protocols HSR PRP 3x Yo> 21YN OR 3x Po> 32N OR Io>HA 51NHA OR Io> Y 67YN CONTROL AND INDICATION 1) Object Ctrl 2) Ind. 3) CB 2 DC 8 2 MEASUREMENT I, U, Io, Uo, P, Q, E, pf, f Limit value supervision Load profile record Power Quality function (optional) U L1 U L2 U L3 Uo> 59G 3U< 27 3U> 59 U1< 47U+ U O U2> 47O- f>/f<, df/dt 81 U L1 U L2 U L3 ES 8 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 SYNC 25 ATSABTC ATSABTC Analog interface types Current sensor 3 Voltage sensor 6 PQM3I PQM3I PQUUB PQUUV PQM3U PQM3V PQMU PQMV U L1B U L2B U L3B 3U< 27 3U> 59 U OB Uo> 59G O I 79 (With REC615 optional) FLOC 21FL UFLS/R 81LSH REMARKS Load 6x MAP MAP 8x MV MV 1 SCA4 SCA4 MVI4 MVI4 Optional function No. of instances Calculated value OR Alternative function defined when ordering GUID-0AE B-4AC6-9A1A-BEE9A11AD115 V1 EN Figure 3. Functionality overview of standard configuration E 6 ABB

7 Table 1. Standard configurations Description Sectionalizer/Midpoint recloser application to be used with conventional transformers supporting reclosing function, directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions, voltage protection, frequency and load-shedding protection, condition monitoring: Phase voltage inputs based on conventional VTs Phase current inputs based on conventional CTs Residual current input based on conventional CT Tie point recloser application to be used with mixed transformers supporting reclosing function, directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions, voltage protection, frequency and load-shedding protection, synchrocheck, condition monitoring: Phase voltage inputs based on conventional VTs/voltage sensors Phase current inputs based on conventional CTs Residual current input based on conventional CT Remote monitoring and control to be used with combi-sensor and additional voltage sensor supporting reclosing function, directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions, voltage protection, frequency and load-shedding protection, synchrocheck, condition monitoring: Phase voltage inputs based on voltage sensors Phase current inputs based on current sensors (Rogowsky coil) Std. conf. A D E ABB 7

8 Table 2. Supported functions Function IEC IEC IEC-ANSI A D E Protection Three-phase non-directional overcurrent protection, low stage Three-phase non-directional overcurrent protection, high stage Three-phase non-directional overcurrent protection, instantaneous stage Three-phase directional overcurrent protection, low stage Three-phase directional overcurrent protection, high stage PHLPTOC 3I> 51P-1 (1) (1) (1) FPHLPTOC F3I> F51P-1 (1) (1) (1) PHHPTOC 3I>> 51P-2 (1) (1) (1) PHIPTOC 3I>>> 50P/51P DPHLPDOC 3I> -> 67-1 (2) (2) (2) FDPHLPDOC F3I> -> F67-1 (2) (2) (2) DPHHPDOC 3I>> -> 67-2 (1) (1) (1) Non-directional earth-fault protection, low stage EFLPTOC Io> 51N-1 (1) (1) (1) 1) FEFLPTOC FIo> F51N-1 (1) (1) (1) 1) Non-directional earth-fault protection, high stage EFHPTOC Io>> 51N-2 (1) (1) (1) 1) Non-directional earth-fault protection, instantaneous stage EFIPTOC Io>>> 50N/51N ) Directional earth-fault protection, low stage DEFLPDEF Io> -> 67N-1 (2) 2) (2) 2) (2) 1)2) FDEFLPDEF FIo> -> F67N-1 (2) 2) (2) 2) (2) 1)2) Directional earth-fault protection, high stage DEFHPDEF Io>> -> 67N-2 (1) 2) (1) 2) (1) 1)2) Transient / intermittent earth-fault protection INTRPTEF Io> -> IEF 67NIEF (1) 2) (1) 2) (1) 1)2) Admittance-based earth-fault protection EFPADM Yo> -> 21YN (3) 2) (3) 2) (3) 1)2) Wattmetric-based earth-fault protection WPWDE Po> -> 32N (3) 2) (3) 2) (3) 1)2) Harmonics-based earth-fault protection HAEFPTOC Io>HA 51NHA (1) (1) (1) 1) Multifrequency admittance-based earth-fault protection MFADPSDE Io> -> Y 67YN (1) 2) (1) 2) (1) 1)2) Negative-sequence overcurrent protection NSPTOC I2> Phase discontinuity protection PDNSPTOC I2/I1> 46PD Residual overvoltage protection ROVPTOV Uo> 59G (1) 2) (2) 3)4) (2) 3)4) Three-phase undervoltage protection PHPTUV 3U< 27 (3) (3) 5) (3) 5) Three-phase overvoltage protection PHPTOV 3U> 59 (3) (3) 5) (3) 5) Positive-sequence undervoltage protection PSPTUV U1< 47U+ (1) (1) (1) Negative-sequence overvoltage protection NSPTOV U2> 47O- (1) (1) (1) Frequency protection FRPFRQ f>/f<,df/dt 81 (2) (2) (2) Three-phase thermal protection for feeders, cables and distribution transformers T1PTTR 3Ith>F 49F Circuit breaker failure protection CCBRBRF 3I>/Io>BF 51BF/51NBF ) Three-phase inrush detector INRPHAR 3I2f> Master trip TRPPTRC Master Trip 94/ Multipurpose protection MAPGAPC MAP MAP ABB

9 Table 2. Supported functions, continued Function IEC IEC IEC-ANSI A D E Load-shedding and restoration LSHDPFRQ UFLS/R 81LSH (1) (1) (1) Fault locator SCEFRFLO FLOC 21FL (1) (1) (1) Three-phase power directional element DPSRDIR I1-> 32P Power quality Current total demand distortion CMHAI PQM3I PQM3I (1) (1) (1) Voltage total harmonic distortion VMHAI PQM3U PQM3V (1) (1) (1) Voltage variation PHQVVR PQMU PQMV (1) (1) (1) Voltage unbalance VSQVUB PQUUB PQVUB (1) (1) (1) Control Circuit-breaker control CBXCBR I <-> O CB I <-> O CB Disconnector control DCXSWI I <-> O DCC I <-> O DCC Disconnector position indication DCSXSWI I <-> O DC I <-> O DC Earthing switch indication ESSXSWI I <-> O ES I <-> O ES Autoreclosing DARREC O -> I Synchronism and energizing check SECRSYN SYNC Automatic transfer switch ATSABTC ATSABTC1 ATSABTC1 (1) (1) (1) Condition monitoring Circuit-breaker condition monitoring SSCBR CBCM CBCM Trip circuit supervision TCSSCBR TCS TCM Fuse failure supervision SEQSPVC FUSEF Runtime counter for machines and devices MDSOPT OPTS OPTM Voltage presence PHSVPR PHSVPR PHSVPR 1 2 6) 2 6) Measurement Three-phase current measurement CMMXU 3I 3I Sequence current measurement CSMSQI I1, I2, I0 I1, I2, I Residual current measurement RESCMMXU Io In 1 1 Three-phase voltage measurement VMMXU 3U 3V 1 2 6) 2 6) Sequence voltage measurement VSMSQI U1, U2, U0 V1, V2, V ) 2 6) Three-phase power and energy measurement PEMMXU P, E P, E Single-phase power and energy measurement SPEMMXU SP, SE SP, SE Frequency measurement FMMXU f f 1 2 6) 2 6) Load profile record LDPRLRC LOADPROF LOADPROF Other Minimum pulse timer (2 pcs) TPGAPC TP TP Minimum pulse timer (2 pcs, second resolution) TPSGAPC TPS TPS Minimum pulse timer (2 pcs, minute resolution) TPMGAPC TPM TPM Pulse timer (8 pcs) PTGAPC PT PT ABB 9

10 Table 2. Supported functions, continued Function IEC IEC IEC-ANSI A D E Time delay off (8 pcs) TOFGAPC TOF TOF Time delay on (8 pcs) TONGAPC TON TON Set-reset (8 pcs) SRGAPC SR SR Move (8 pcs) MVGAPC MV MV Generic control point (16 pcs) SPCGAPC SPC SPC Remote generic control points SPCRGAPC SPCR SPCR Local generic control points SPCLGAPC SPCL SPCL Generic up-down counters UDFCNT UDCNT UDCNT Analog value scaling SCA4GAPC SCA4 SCA Integer value move MVI4GAPC MVI4 MVI Daily timer function DTMGAPC DTMGAPC1 DTMGAPC Programmable buttons (4 buttons) FKEY4GGIO FKEY4GGIO1 FKEY4GGIO Logging functions Disturbance recorder RDRE DR DFR Fault record FLTRFRC FAULTREC FAULTREC , 2,... = number of included instances () = optional 1) Io calculated is always used 2) Uo calculated is always used 3) Uo calculated is always used with the first instance 4) UoB calculated is always used with the second instance 5) Voltage group B is always used with the third instance 6) Voltage group B is always used with the second instance 3. Protection functions To allow the customers to customize the relay according to their requirements, it can be ordered as a basic relay or enhanced with selected protection functions. The selection depends on the application, whether it is a compensated network, and whether the compensated network is with distributed generation or closed-loop feeders. As a standard offering, the relay includes non-directional overcurrent and non-directional earth-fault functions, as well as other protection functions commonly accepted as a means to significantly improve the grid reliability in recloser applications, such as breaker failure and negative-sequence overcurrent protection to detect a broken conductor. Alternatively, a more sensitive phase-discontinuity protection is available. Thermal protection, which is used for protecting feeders, cables and distribution transformers, is also included. The optional functionalities of the relay include more advanced methods to detect the earth faults in various distribution networks. On top of the permanent earth faults, the relay can be equipped with algorithms that can be used to detect intermittent and transient temporary faults. This can be used to localize possible future problem points in the distribution network, even before they develop to a fault that causes interruption in the power distribution seen by the end users. A syncrocheck function is offered with standard configuration D. The synchrocheck function ensures that the voltage, phase angle and frequency on either side of an open circuit breaker meet the conditions for a safe interconnection of two networks. Some advanced protection functions are optionally available in RER Application The recloser protection and control relay RER615 is suitable for a variety of applications, ranging from basic applications on the line recloser to sophisticated applications including distributed generation and demanding interlocking applications. Because of the large number of protection functions, the illustrated applications are only example applications which can be extended to meet tomorrow's requirements. 10 ABB

11 I I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A A Clear R L Clear R L I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC I A U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC Clear R L A Clear R L I I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A A Clear R L Clear R L I I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A A Clear R L Clear R L I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L I I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A A Clear R L Clear R L O 3I RER615 3U O Std. conf. ANSI IEC A 67NIEF 46PD 49F 50P/51P 67/67N 79 Io> >IEF I2/I1> 3Ith>F 3I>>> 3I /Io O I GUID-DFFEAC20-C31D-4D65-9E2A-0B C8 V2 EN Figure 4. Selective protection in radial feeder Figure 4 illustrates selective protection in a radial feeder with autoreclosing functionality and advanced admittance-based earth-fault protection. Additionally, directional overcurrent protection for distributed generation applications is included. IEC and GOOSE IEC and GOOSE RER615 RER615 RER615 RER615 O O O O Fault RER615 RER615 RER615 RER615 RER615 RER615 O O O O O O Pre-fault state Post-fault state GUID-2B2034FA-A359-4FE7-B166-21CD9B V1 EN Figure 5. Fault detection, isolation and restoration in radial feeder Exact earth-fault and overcurrent protection enables autonomous fault detection, isolation and restoration, and can be achieved through IEC and GOOSE communication as illustrated in Figure 5. In the pre-fault state, the closed loop network is of radial type with one normal open point (NOP). The fault is accurately located between two circuit breakers, isolating the faulty part and allowing NOP to be closed. ABB 11

12 I I I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A A A Clear R L Clear R L Clear R L I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L IEC and GOOSE O O 3I DG 3Ub 3U RER615 Std. conf. D O O ANSI IEC 21YN 1) 25 47O-/59 47U+/27 49F 50P/51P 67/67N Yo> 1) SYNC U2>/3U> U1</3U< 3Ith>F 3I>>> 3I /Io O I f</f>,df/dt 1) or 51NHA (Io>HA), 32N (Po> ) GUID-15D B19-49EA-95DF-4698B923C9CE V1 EN Figure 6. Protection of distributed generation plant The advanced protection functionality of RER615 ensures secure protection of distributed generation against faults, and early indication of loss-of-mains through IEC and GOOSE communication as seen in Figure 6. Safe reconnection is enabled by using the synchrocheck functionality. 5. Supported ABB solutions RER615 integrates fully with other ABB products such as COM600S, MicroSCADA, SYS600, DMS600, and with ABB's secure, reliable and tested communication solutions, ARG600 and the ARM600 gateway. ABB offers a solution which meets the demanding customer requirements regarding smart grids, and which also contributes to faster engineering. To facilitate the system engineering, ABB's relays are supplied with connectivity packages. The connectivity packages include a compilation of software and relay-specific information, including single-line diagram templates and a full relay data model. The data model includes event and parameter lists. With the connectivity packages, the relays can be readily configured using PCM600 and integrated with COM600S or the network control and management system MicroSCADA Pro. 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 substation automation standard, are fast communication capability, continuous supervision of the protection and communication system's integrity, and an inherent flexibility regarding reconfiguration and upgrades. At substation level, COM600S uses the data content of the baylevel devices to enhance substation level functionality. COM600S features a Web browser-based HMI, which provides a customizable graphical display for visualizing single-line mimic diagrams for switchgear bay solutions. The Web HMI of COM600S also provides an overview of the whole substation, including relay-specific single-line diagrams, which makes information easily accessible. Substation devices and processes can also be remotely accessed through the Web HMI, which improves personnel safety. In addition, COM600S can be used as a local data warehouse for the substation's technical documentation and for the network data collected by the devices. The collected network data facilitates extensive reporting and analyzing of network fault situations by using the data historian and event handling features of COM600S. The historical data can be used for accurate monitoring of process and equipment performance, using calculations based on both real-time and historical values. A better understanding of the process dynamics is achieved by combining time-based process measurements with production and maintenance events. COM600S can also function as a gateway and provide seamless connectivity between the substation devices and network-level control and management systems, such as MicroSCADA Pro and System 800xA. 12 ABB

13 Table 3. Supported ABB solutions Product Substation Management Unit COM600S MicroSCADA Pro SYS 600 System 800xA Version 4.0 SP1 or later 9.4 or later 5.1 or later 6. Control Two circuit breakers can be controlled via the front panel HMI of RER615 or via a remote system.the relay also provides position indication for two disconnectors and two earthing switches. If the amount of available binary inputs or outputs of the chosen standard configuration is not sufficient, the configuration can be modified to release some binary inputs or outputs originally configured for other purposes. In this case, an external input/ output module, for example, RIO600, can be integrated with the relay and its binary inputs and outputs used for the less timecritical binary signals of the application. The suitability of the relay's binary outputs selected for controlling primary devices should be carefully verified, for example, regarding the make and carry and the breaking capacity. If the requirements for the control circuit of the primary device are not met, the use of external auxiliary relays should be considered. The optional, large, graphical LCD of the relay's HMI includes a single-line diagram with position indication for the relevant primary devices. Interlocking schemes required by the application are configured using the signal matrix or the application configuration function of PCM600. Depending on the standard configuration, the relay also has a synchrocheck function to ensure that the voltage, phase angle and frequency on either side of an open circuit breaker meet the conditions for a safe interconnection of two networks. Furthermore, the relay offers three-phase power and energy measurement including power factor. The measured values can be accessed via the local HMI or remotely via the communication interface of the relay. The values can also be accessed locally or remotely using the Web HMI. 8. Fault location The relay 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. 9. Disturbance recorder The relay is provided with a disturbance recorder featuring up to 12 analog and 64 binary signal channels.the analog channels can be set to record either the waveform or the trend of the currents and voltages measured. 7. Measurement The relay continuously measures the phase currents and voltages, the symmetrical components of the currents, and the residual current. The relay additionally offers frequency measurement. 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. Active and reactive power as well as residual voltage are also calculated. Power quality measurement, such as total harmonic values for both current and voltage, voltage sags and swells, and voltage unbalance, is supported. The analog channels can be set to trigger the recording function when the measured value falls below or exceeds the set values. The binary signal channels can be set to start a recording either on the rising or the falling edge of the binary signal or on both. By default, the binary channels are set to record external or internal relay signals, for example, the start or trip signals of the relay stages, or external blocking or control signals. Binary relay signals, such as protection start and trip signals, or an external relay control signal via a binary input, can be set to trigger the recording. Recorded information is stored in a nonvolatile memory and can be uploaded for subsequent fault analysis. 10. Event log To collect sequence-of-events information, the relay has a nonvolatile memory capable of storing 1024 events with the associated time stamps. The non-volatile memory retains its ABB 13

14 data even if the relay temporarily loses its auxiliary supply. The event log facilitates detailed pre- and post-fault analyses of feeder faults and disturbances. The considerable capacity to process and store data and events in the relay facilitates meeting the growing information demand of future network configurations. The sequence-of-events information can be accessed either via local HMI or remotely via the communication interface of the relay. The information can also be accessed locally or remotely using the Web HMI. 11. Fault recorder The relay has the capacity to store the records of the 128 latest fault events. The records can be used to analyze the power system events. The fault recording can be triggered by the start or the trip signal of a protection block, or by both. The available measurement modes include DFT, RMS and peak-to-peak. Fault records store relay measurement values at the moment when any protection function starts. In addition, the maximum demand current with time stamp is separately recorded. The records are stored in the non-volatile memory. the relay software. Any fault or malfunction detected is used for alerting the operator. A permanent relay fault blocks the protection functions to prevent incorrect operation. 15. Fuse failure supervision The fuse failure supervision detects failures between the voltage measurement circuit and the relay. The failures are detected either by the negative sequence-based algorithm or by the delta voltage and delta current algorithm. Upon the detection of a failure, the fuse failure supervision function activates an alarm and blocks voltage-dependent protection functions from unintended operation. 16. Autoreclosing The relay includes a powerful and flexible multi-shot autoreclosing function. The autoreclosing function provides up to five programmable autoreclosing sequences, which can perform one to five successive autoreclosing shots of desired type and duration. Furthermore, the relay includes a load profile recorder capable of storing measurement values into the relay's memory. The selected measurement values averaged over the selected period, ranging from one minute to three hours, are stored in a non-volatile memory. Depending on the selected measurements and averaging period, the overall length of the load profile recording ranges from some days to several months, even a year, making this feature suitable for monitoring long-time load behavior for the interested loads. 12. Condition monitoring The condition monitoring functions of the relay constantly monitor the performance and the condition of the circuit breaker. The monitoring comprises the spring charging time, SF6 gas pressure, the travel time and the inactivity time of the circuit breaker. The monitoring functions provide operational circuit breaker history data, which can be used for scheduling preventive circuit breaker maintenance. 13. Trip-circuit supervision The trip-circuit supervision continuously monitors the availability and operability of the trip circuit. It provides opencircuit monitoring both when the circuit breaker is in its closed and in its open position. It also detects loss of circuit-breaker control voltage. 14. Self-supervision The relay s built-in self-supervision system continuously monitors the state of the relay hardware and the operation of 17. Hot line tag Standard configurations of the RER615 are delivered with the hot line tag security functionality that will block the close operation of recloser or breaker when enabled. Hot line tag functionality can be enabled either from the local HMI of the RER615 or from the external signal. 18. Access control To protect the relay from unauthorized access and to maintain information integrity, the relay is provided with a four-level, rolebased authentication system with administrator-programmable individual passwords for the viewer, operator, engineer and administrator levels. The access control applies to the local HMI, the Web HMI and PCM Inputs and outputs Depending on the selected standard configuration, the relay is equipped with different analog input channels. Standard configuraton A provides three phase-current inputs, one residual current input and three voltage inputs. Standard configuration D provides three phase-current inputs, one residual current input and six sensor voltage inputs or voltage transformers. The phase-current inputs are rated 1/5 A and the residual current input 0.2/1 A. The residual current is suitable for applications requiring sensitive earth-fault protection and which have core balance current transformers. As the residual current is usually limited to small values, it can also be used in applications where even the phase current is 5A. The three phase voltage inputs and the residual voltage input cover the rated voltages V. Both phase-to-phase voltages and phase-to-earth voltages can be connected. 14 ABB

15 The nominal secondary voltage of voltage sensor inputs is userprogrammable, supporting both capacitive and resistive voltage sensors from 5 kv up to 38 kv. The phase current input 1 A or 5 A, the residual current input 0.2 A or 1 A and the rated voltage of the residual voltage input are selected in the relay software. In addition, the binary input thresholds V DC are selected by adjusting the relay's parameter settings. All the binary input and output contacts are freely configurable with the Application Configuration or Signal Matrix tool in PCM600. Table 4. Number of physical connections in standard configurations Std. conf. Order code digit Analog channels Binary channels CT VT Combi-sensor BI BO A AA N A D AD N 4 6 1) E AE N - 3 2) ) Support for phase voltage sensors or phase voltage transformer with the SIM0001 module 2) Support for three combi-sensors and three voltage sensors with the SIM0904 module ABB 15

16 20. Station communication The relay supports a variety of communication protocols, including IEC and the most common remote control protocols IEC , IEC Modbus and DNP3. Operational information and controls are available through these protocols. However, some communication functionality, for example horizontal communication between the relays, is only possible through the IEC communication protocol. The IEC communication implementation supports all the monitoring and control functions. Additionally, parameter settings, disturbance recordings and fault records can be accessed using the IEC protocol. Disturbance recordings are available for any Ethernet-based application in the standard COMTRADE file format. The relay supports simultaneous event reporting to five different clients over the station bus. The relay can send binary signals to other devices (so-called horizontal communication) using the IEC GOOSE profile. Binary GOOSE messaging can, for example, be used 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 standard. Furthermore, the relay supports the sending and receiving of analog values using GOOSE messaging. Analog GOOSE messaging enables fast transfer of the analog measurement values over the station bus. This facilitates, for example, the sharing of RTD input values, such as surrounding temperature, with other relay applications. All communication connectors, except for the front port connector, are placed on integrated optional communication modules. Modbus implementation supports RTU, ASCII and TCP modes. In addition to the standard Modbus functionality, the relay supports retrieval of timestamped events, changing the active setting group and uploading the latest fault records. If a Modbus TCP connection is used, four clients can be connected to the relay at the same time. Modbus serial and Modbus TCP can also be used in parallel and IEC and Modbus simultaneously, if required. In addition to the basic standard functionality, the relay supports changing of the active setting group and uploading of disturbance recordings in the IEC /104 format. DNP3 supports both serial and TCP modes for connection to one master. Changing of the active setting group is also supported. When the relay uses the RS-485 bus for serial communication, both 2-wire and 4-wire connections are supported. Termination and pull-up/down resistors can be configured with jumpers on the communication card, therefore no external resistors are required. The relay supports several time synchronization methods with a time-stamping resolution of 1 ms. SNTP and IEC can be used in Ethernet based time synchronization and IRIG-B is available with special time synchronization wiring. In addition, the relay supports time synchronization via the serial communication protocols Modbus, DNP3 and IEC ABB

17 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L DC + A F M P M USB LA POWER DC IN CONSOLE/RS1 RS OFF ON CONSOLE/RS1 ø 1 0 LAN 1 Primary Switchgear Control center IEC COM600 IEC Fiber optic NCC I I O O REF615 REF615 Secondary Switchgear Public GPRS VPN Tunnel VPN Tunnel M2M gateway 3I I IEC O RER615 ARG600 GUID-CAE7C34B-3E89-42EE-94CE-401B01AC540F V2 EN Figure 7. System overview of utility communication Table 5. Supported station communication interfaces and protocols Interfaces/Protocols Ethernet Serial 100BASE-TX RJ BASE-FX LC RS-232/RS-485 Fibre-optic ST IEC MODBUS RTU/ASCII - - MODBUS TCP/IP - - DNP3 (serial) - - DNP3 TCP/IP - - IEC IEC = Supported ABB 17

18 21. Technical data Table 6. Dimensions Description Width Frame 177 mm Case 164 mm Height Frame 177 mm (4U) Case 160 mm Depth 201 mm ( 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 U n 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 U n Auxiliary voltage variation % of U n ( V AC) % of U n ( V DC) % of U n ( V DC) Start-up threshold 19.2 V DC (24 V DC 80%) Burden of auxiliary voltage supply under quiescent (P q )/operating condition DC <13.0 W (nominal)/<18.0 W (max.) AC <16.0 W (nominal)/<21.0 W (max.) DC <13.0 W (nominal)/<18.0 W (max.) Ripple in the DC auxiliary voltage Fuse type Max 15% of the DC value (at frequency of 100 Hz) T4A/250 V The protection relay does not include any batteries as backup power when the auxiliary power goes down. However, the relay configuration and settings, events, disturbance recordings and any critical data stay in the relay's memory because those are saved to a nonvolatile memory. Also, the relay's real-time clock is kept running via a 48-hour capacitor backup. 18 ABB

19 Table 8. Energizing inputs Description Rated frequency 50/60 Hz Current inputs Rated current, I n 0.2/1 A 1) 1/5 A 2) Thermal withstand capability Continuously 4 A 1) 20 A For 1 s 100 A 1) 500 A Dynamic current withstand Half-wave value 250 A 1) 1250 A Input impedance <100 mω 1) <20 mω Voltage inputs Rated voltage V AC Voltage withstand Continuous For 10 s Burden at rated voltage 240 V AC 360 V AC <0.05 VA 1) Ordering option for residual current input 2) Residual current and/or phase current Table 9. Energizing inputs of SIM0001 Description Voltage sensor input Rated voltage 5 kv...38 kv 1) Continuous voltage withstand 125 V AC 2) Input impedance at 50/60 Hz 1 MΩ 3) Voltage inputs Rated voltage V AC Voltage withstand Continuous For 10 s Burden at rated voltage 240 V AC 360 V AC <0.05 VA 1) This range is covered with a sensor division ratio of :1 if the input type is set as CVD sensor. 2) Test to this voltage 3) Neutral input impedance is close to zero ABB 19

20 Table 10. Energizing inputs of SIM0002/SIM0904 Description Current sensor input Rated current voltage (in secondary side) Continuous voltage withstand 75 mv mv 1) 125 V Input impedance at 50/60 Hz MΩ 2) Voltage sensor input Rated voltage 6 kv...30 kv 3) Continuous voltage withstand Input impedance at 50/60 Hz 50 V 3 MΩ 1) Equals the current range of 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 :1 Table 11. Binary inputs Description Operating range Rated voltage Current drain Power consumption Threshold voltage Reaction time ±20% of the rated voltage V DC ma mw V DC 3 ms Table 12. Signal output with high make and carry Description 1) Rated voltage Continuous contact carry Make and carry for 3.0 s Make and carry for 0.5 s Breaking capacity when the control-circuit time constant L/R <40 ms Minimum contact load 250 V AC/DC 5 A 15 A 30 A 1 A/0.25 A/0.15 A 100 ma at 24 V AC/DC 1) X100: SO1 X110: SO1, SO2 Table 13. Signal outputs and IRF output Description 1) Rated voltage Continuous contact carry Make and carry for 3.0 s Make and carry 0.5 s Breaking capacity when the control-circuit time constant L/R <40 ms, at 48/110/220 V DC Minimum contact load 250 V AC/DC 5 A 10 A 15 A 1 A/0.25 A/0.15 A 10 ma at 5 V AC/DC 1) X100: IRF,SO2 X110: SO3, SO4 20 ABB

21 Table 14. Double-pole power outputs with TCS function X100: PO3 and PO4 Description Rated voltage Continuous contact carry Make and carry for 3.0 s Make and carry for 0.5 s Breaking capacity when the control-circuit time constant L/R <40 ms, at 48/110/220 V DC (two contacts connected in a series) Minimum contact load 250 V AC/DC 8 A 15 A 30 A 5 A/3 A/1 A 100 ma at 24 V AC/DC Trip-circuit monitoring (TCS) Control voltage range Current drain through the monitoring circuit V AC/DC ~1.5 ma Minimum voltage over the TCS contact 20 V AC/DC ( V) Table 15. Single-pole power output relays X100: PO1 and PO2 Description Rated voltage Continuous contact carry Make and carry for 3.0 s Make and carry for 0.5 s Breaking capacity when the control-circuit time constant L/R <40 ms, at 48/110/220 V DC Minimum contact load 250 V AC/DC 8 A 15 A 30 A 5 A/3 A/1 A 100 ma at 24 V AC/DC Table 16. Front port Ethernet interfaces Ethernet interface Protocol Cable Data transfer rate Front TCP/IP protocol Standard Ethernet CAT 5 cable with RJ-45 connector 10 MBits/s Table 17. Station communication link, fibre-optic Connector Fibre type 1) Wave length Max. distance Permitted path attenuation 2) LC ST MM 62.5/125 or 50/125 μm glass fibre core MM 62.5/125 or 50/125 μm glass fibre core 1300 nm 2 km <8 db nm 1 km <11 db 1) (MM) multi-mode fibre, (SM) single-mode fibre 2) Maximum allowed attenuation caused by connectors and cable together ABB 21

22 Table 18. IRIG-B Description IRIG time code format B004, B005 1) Isolation Modulation Logic level Current consumption Power consumption 500V 1 min Unmodulated TTL level ma mw 1) According to the IRIG standard Table 19. Degree of protection of flush-mounted protection relay Description Front side IP 54 Rear side, connection terminals IP 20 Table 20. Environmental conditions Description Operating temperature range ºC (continuous) Short-time service temperature range ºC (<16h) 1)2) Relative humidity Atmospheric pressure Altitude Transport and storage temperature range <93%, non-condensing kpa Up to 2000 m ºC 1) Degradation in MTBF and HMI performance outside the temperature range of ºC 2) For relays with an LC communication interface the maximum operating temperature is +70 ºC 22 ABB

23 Table 21. Electromagnetic compatibility tests Description Type test value Reference 1 MHz/100 khz burst disturbance test IEC IEC IEEE C Common mode 2.5 kv Differential mode 2.5 kv 3 MHz, 10 MHz and 30 MHz burst disturbance test IEC IEC , class III Common mode 2.5 kv Electrostatic discharge test IEC IEC IEEE C Contact discharge 8 kv Air discharge 15 kv Radio frequency interference test 10 V (rms) f = 150 khz...80 MHz 10 V/m (rms) f = MHz 10 V/m f = 900 MHz 20 V/m (rms) f = MHz IEC IEC , class III IEC IEC , class III ENV IEC , class III IEEE C Fast transient disturbance test IEC IEC IEEE C All ports 4 kv Surge immunity test IEC IEC 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 Continuous s Pulse magnetic field immunity test 300 A/m 1000 A/m 1000 A/m 6.4/16 µs IEC Damped oscillatory magnetic field immunity test IEC s 100 A/m 1 MHz 400 transients/s Power frequency immunity test Binary inputs only IEC IEC , class A Common mode 300 V rms Differential mode 150 V rms ABB 23

24 Table 21. Electromagnetic compatibility tests, continued Description Type test value Reference Emission tests EN 55011, class A IEC CISPR 11 CISPR 22 Conducted MHz <79 db (µv) quasi peak <66 db (µv) average MHz <73 db (µv) quasi peak <60 db (µv) average Radiated MHz <40 db (µv/m) quasi peak, measured at 10 m distance MHz <47 db (µv/m) quasi peak, measured at 10 m distance Table 22. Insulation tests Description Type test value Reference Dielectric tests Impulse voltage test 2 kv, 50 Hz, 1 min 500 V, 50 Hz, 1 min, communication 5 kv, 1.2/50 μs, 0.5 J 1 kv, 1.2/50 μs, 0.5 J, communication IEC IEC Insulation resistance measurements >100 MΩ, 500 V DC IEC Protective bonding resistance <0.1 Ω, 4 A, 60 s IEC Table 23. Mechanical tests Description Requirement Reference Vibration tests (sinusoidal) Class 2 IEC (test Fc) IEC Shock and bump test Class 2 IEC (test Ea shock) IEC (test Eb bump) IEC Seismic test Class 2 IEC ABB

25 Table 24. Environmental tests Description Type test value Reference Dry heat test 96 h at +55ºC IEC h at +85ºC 1) Cold test Damp heat test 96 h at -25ºC 16 h at -40ºC 6 cycles (12 h + 12 h) at +25 C +55 C, humidity >93% IEC IEC Change of temperature test 5 cycles (3 h + 3 h) at -25 C C IEC Storage test Mixed gas corrosion 2) 96 h at -40ºC 96 h at +85ºC Test parameters according to GR-63-CORE (outdoor): Temp: 30 C ±1 RH: 70% ±2 H2S: 100 ±15 ppb Cl2: 20 ±3 ppb NO2: 200 ±30 ppb SO2: 200 ±30 ppb IEC IEC IEC , test procedure 2 Salt mist test 2) Severity level 2 IEC , Test Kb 1) For relays with an LC communication interface the maximum operating temperature is +70 o C 2) For relays with optional conformal coating (the chosen coating is recognized by Underwriters Laboratories (UL) and compliant with the US military specification MIL-I-46058C, IPC-CC-830 (Institute of Printed Circuits) and the RoHS (Restriction of Hazardous Substances) directive 2002/95/EC) Table 25. Product safety Description LV directive Reference 2006/95/EC Standard EN (2013) EN (2009) Table 26. EMC compliance Description EMC directive Reference 2004/108/EC Standard EN (2013) Table 27. RoHS compliance Description Complies with RoHS directive 2002/95/EC ABB 25

26 Protection functions Table 28. Three-phase non-directional overcurrent protection ((F)PHxPTOC) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz (F)PHLPTOC PHHPTOC and PHIPTOC ±1.5% of the set value or ±0.002 I n ±1.5% of set value or ±0.002 I n (at currents in the range of I n ) ±5.0% of the set value (at currents in the range of I n ) Start time 1)2) Minimum Typical Maximum PHIPTOC: I Fault = 2 set Start value 16 ms 19 ms 23 ms I Fault = 10 set Start value 11 ms 12 ms 14 ms PHHPTOC and (F)PHLPTOC: I Fault = 2 set Start value 23 ms 26 ms 29 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode <30 ms ±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) ±5.0% of the theoretical value or ±40 ms 3)4) Suppression of harmonics RMS: No suppression DFT: -50 db at f = n f n, 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 4) Valid for FPHLPTOC 26 ABB

27 Table 29. Three-phase non-directional overcurrent protection ((F)PHxPTOC) main settings Parameter Function (Range) Step Start value (F)PHLPTOC I n 0.01 PHHPTOC I n 0.01 PHIPTOC I n 0.01 Time multiplier (F)PHLPTOC PHHPTOC Operate delay time (F)PHLPTOC ms 10 PHHPTOC ms 10 PHIPTOC ms 10 Operating curve type 1) (F)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, -1, -2, -3, -4, -5, -6, -7, -8, -9, -10, -11, -12, -13, -14, -15, -16, -17, -18, -19, -20, -21, -22, -23, -24, -25, -26, -27, -28, -29, -30, -31, -32, -33, -34, -35, -36, -37, -38, -39 PHHPTOC PHIPTOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 Definite time 1) For further reference, see the Operation characteristics table ABB 27

28 Table 30. Three-phase directional overcurrent protection ((F)DPHxPDOC) Operation accuracy Depending on the frequency of the current/voltage measured: f n ±2 Hz (F)DPHLPDOC DPHHPDOC Current: ±1.5% of the set value or ±0.002 I n Voltage: ±1.5% of the set value or ±0.002 U n Phase angle: ±2 Current: ±1.5% of the set value or ±0.002 I n (at currents in the range of I n ) ±5.0% of the set value (at currents in the range of I n ) Voltage: ±1.5% of the set value or ±0.002 U n Phase angle: ±2 Start time 1)2) Minimum Typical Maximum I Fault = 2.0 set Start value 39 ms 43 ms 47 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode <35 ms ±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) ±5.0% of the theoretical value or ±40 ms 3)4) Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, 1) Measurement mode and Pol quantity = default, current before fault = 0.0 I n, voltage before fault = 1.0 U n, f n = 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 I n, Start value multiples in range of ) Valid for (F)DPHLPDOC 28 ABB

29 Table 31. Three-phase directional overcurrent protection ((F)DPHxPDOC) main settings Parameter Function (Range) Step Start value (F)DPHLPDOC I n 0.01 DPHHPDOC I n 0.01 Time multiplier DPHxPDOC Operate delay time DPHxPDOC ms 10 Directional mode DPHxPDOC 1 = Non-directional 2 = Forward 3 = Reverse - angle DPHxPDOC Operating curve type 1) (F)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, -1, -2, -3, -4, -5, -6, -7, -8, -9, -10, -11, -12, -13, -14, -15, -16, -17, -18, -19, -20, -21, -22, -23, -24, -25, -26, -27, -28, -29, -30, -31, -32, -33, -34, -35, -36, -37, -38, -39 DPHHPDOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 1) For further reference, see the Operating characteristics table Table 32. Non-directional earth-fault protection ((F)EFxPTOC) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz (F)EFLPTOC EFHPTOC and EFIPTOC ±1.5% of the set value or ±0.002 I n ±1.5% of set value or ±0.002 I n (at currents in the range of I n ) ±5.0% of the set value (at currents in the range of I n ) Start time 1)2) Minimum Typical Maximum EFIPTOC: I Fault = 2 set Start value I Fault = 10 set Start value 16 ms 11 ms 19 ms 12 ms 23 ms 14 ms EFHPTOC and (F)EFLPTOC: I Fault = 2 set Start value 23 ms 26 ms 29 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode <30 ms ±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) ±5.0% of the theoretical value or ±40 ms 3)4) Suppression of harmonics RMS: No suppression DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, Peak-to-Peak: No suppression 1) Measurement mode = default (depends on stage), current before fault = 0.0 I n, f n = 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 I n, Start value multiples in range of ) Valid for FEFLPTOC ABB 29

30 Table 33. Non-directional earth-fault protection ((F)EFxPTOC) main settings Parameter Function (Range) Step Start value (F)EFLPTOC I n EFHPTOC I n 0.01 EFIPTOC I n 0.01 Time multiplier (F)EFLPTOC and EFHPTOC Operate delay time (F)EFLPTOC and EFHPTOC ms 10 EFIPTOC ms 10 Operating curve type 1) (F)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, -1, -2, -3, -4, -5, -6, -7, -8, -9, -10, -11, -12, -13, -14, -15, -16, -17, -18, -19, -20, -21, -22, -23, -24, -25, -26, -27, -28, -29, -30, -31, -32, -33, -34, -35, -36, -37, -38, -39 EFHPTOC EFIPTOC Definite or inverse time Curve type: 1, 3, 5, 9, 10, 12, 15, 17 Definite time 1) For further reference, see the Operation characteristics table 30 ABB

31 Table 34. Directional earth-fault protection ((F)DEFxPDEF) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz (F)DEFLPDEF DEFHPDEF Current: ±1.5% of the set value or ±0.002 I n Voltage ±1.5% of the set value or ±0.002 U n Phase angle: ±2 Current: ±1.5% of the set value or ±0.002 I n (at currents in the range of I n ) ±5.0% of the set value (at currents in the range of I n ) Voltage: ±1.5% of the set value or ±0.002 U n Phase angle: ±2 Start time 1)2) Minimum Typical Maximum DEFHPDEF I Fault = 2 set Start value 42 ms 46 ms 49 ms (F)DEFLPDEF I Fault = 2 set Start value 58 ms 62 ms 66 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode <30 ms ±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) ±5.0% of the theoretical value or ±40 ms 3)4) Suppression of harmonics RMS: No suppression DFT: -50 db at f = n f n, 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 I n, f n = 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 I n, Start value multiples in range of ) Valid for FDEFLPDEF ABB 31

32 Table 35. Directional earth-fault protection ((F)DEFxPDEF) main settings Parameter Function (Range) Step Start value (F)DEFLPDEF I n DEFHPDEF I n 0.01 Directional mode (F)DEFxPDEF 1 = Non-directional 2 = Forward 3 = Reverse - Time multiplier (F)DEFLPDEF DEFHPDEF Operate delay time (F)DEFLPDEF ms 10 DEFHPDEF ms 10 Operating curve type 1) (F)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, -1, -2, -3, -4, -5, -6, -7, -8, -9, -10, -11, -12, -13, -14, -15, -16, -17, -18, -19, -20, -21, -22, -23, -24, -25, -26, -27, -28, -29, -30, -31, -32, -33, -34, -35, -36, -37, -38, -39 DEFHPDEF Definite or inverse time Curve type: 1, 3, 5, 15, 17 Operation mode (F)DEFxPDEF 1 = Phase angle 2 = IoSin 3 = IoCos 4 = Phase angle 80 5 = Phase angle 88-1) For further reference, see the Operating characteristics table Table 36. Transient/intermittent earth-fault protection (INTRPTEF) Operation accuracy (Uo criteria with transient protection) Depending on the frequency of the measured current: f n ±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 f n, where n = 2, 3, 4, 5 Table 37. Transient/intermittent earth-fault protection (INTRPTEF) main settings Parameter Function (Range) Step Directional mode INTRPTEF 1 = Non-directional 2 = Forward 3 = Reverse - Operate delay time INTRPTEF ms 10 Voltage start value INTRPTEF U n 0.01 Operation mode INTRPTEF 1 = Intermittent EF 2 = Transient EF - Peak counter limit INTRPTEF Min operate current INTRPTEF I n ABB

33 Table 38. Admittance-based earth-fault protection (EFPADM) Operation accuracy 1) At the frequency f = f n ±1.0% or ±0.01 ms (In range of ms) Start time 2) Minimum Typical Maximum 56 ms 60 ms 64 ms Reset time Operate time accuracy Suppression of harmonics 40 ms ±1.0% of the set value of ±20 ms -50 db at f = n f n, 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 Table 39. Admittance-based earth-fault protection (EFPADM) main settings Parameter Function (Range) Step Voltage start value EFPADM U n 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 ms 10 Circle radius EFPADM ms 0.01 Circle conductance EFPADM ms 0.01 Circle susceptance EFPADM ms 0.01 Conductance forward EFPADM ms 0.01 Conductance reverse EFPADM ms 0.01 Susceptance forward EFPADM ms 0.01 Susceptance reverse EFPADM ms 0.01 Conductance tilt Ang EFPADM Susceptance tilt Ang EFPADM ABB 33

34 Table 40. Wattmetric-based earth-fault protection (WPWDE) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz Current and voltage: ±1.5% of the set value or ±0.002 I n Power: ±3% of the set value or ±0.002 P n Start time 1)2) Reset time Typically 63 ms Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode Operate time accuracy in IDMT mode Suppression of harmonics ±1.0% of the set value or ±20 ms ±5.0% of the set value or ±20 ms -50 db at f = n f n, where n = 2,3,4,5, 1) Io varied during the test, Uo = 1.0 U n = phase-to-earth voltage during earth fault in compensated or unearthed network, the residual power value before fault = 0.0 pu, f n = 50 Hz, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact Table 41. Wattmetric-based earth-fault protection (WPWDE) main settings Parameter Function (Range) Step Directional mode WPWDE 2 = Forward 3 = Reverse - Current start value WPWDE I n Voltage start value WPWDE U n Power start value WPWDE P n Reference power WPWDE P n angle WPWDE Time multiplier WPWDE Operating curve type 1) WPWDE Definite or inverse time Curve type: 5, 15, 20 Operate delay time WPWDE ms 10 Min operate current WPWDE I n Min operate voltage WPWDE U n ) For further reference, refer to the Operating characteristics table 34 ABB

35 Table 42. Harmonics-based earth-fault protection (HAEFPTOC) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz ±5% of the set value or ±0.004 I n Start time 1)2) Reset time Typically 77 ms Typically 40 ms Reset ratio Typically 0.96 Operate time accuracy in definite time mode Operate time accuracy in IDMT mode 3) Suppression of harmonics ±1.0% of the set value or ±20 ms ±5.0% of the set value or ±20 ms -50 db at f = f n -3 db at f = 13 f n 1) Fundamental frequency current = 1.0 I n, harmonics current before fault = 0.0 I n, harmonics fault current 2.0 Start value, results based on statistical distribution of 1000 measurements 2) Includes the delay of the signal output contact 3) Maximum Start value = 2.5 I n, Start value multiples in range of Table 43. Harmonics-based earth-fault protection (HAEFPTOC) main settings Parameter Function (Range) Step Start value HAEFPTOC I n 0.01 Time multiplier HAEFPTOC Operate delay time HAEFPTOC ms 10 Operating curve type 1) 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 Minimum operate time HAEFPTOC ms 10 1) For further reference, see Operation characteristics table Table 44. Multifrequency admittance-based earth-fault protection (MFADPSDE) Operation accuracy Depending on the frequency of the measured voltage: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Start time 1) Reset time Operate time accuracy Typically 35 ms Typically 40 ms ±1.0% of the set value or ±20 ms 1) Includes the delay of the signal output contact, results based on statistical distribution of 1000 measurements ABB 35

36 Table 45. Multifrequency admittance-based earth-fault protection (MFADPSDE) main settings Parameter Function (Range) Step Directional mode MFADPSDE 2 = Forward 3 = Reverse - Voltage start value MFADPSDE U n 0.01 Operate delay time MFADPSDE ms 10 Operating quantity MFADPSDE 1 = Adaptive 2 = Amplitude 3 = Resistive - Min operate current MFADPSDE I n Operation mode MFADPSDE 1 = Intermittent EF 3 = General EF 4 = Alarming EF - Peak counter limit MFADPSDE Table 46. Negative-sequence overcurrent protection (NSPTOC) Operation accuracy Depending on the frequency of the measured current: f n ±1.5% of the set value or ±0.002 I n Start time 1)2) Minimum Typical Maximum I Fault = 2 set Start value I Fault = 10 set Start value 23 ms 15 ms 26 ms 18 ms 28 ms 20 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode <35 ms ±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 f n, where n = 2, 3, 4, 5, 1) Negative sequence current before fault = 0.0, f n = 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 I n, Start value multiples in range of Table 47. Negative-sequence overcurrent protection (NSPTOC) main settings Parameter Function (Range) Step Start value NSPTOC I n 0.01 Time multiplier NSPTOC Operate delay time NSPTOC ms 10 Operating curve type 1) NSPTOC Definite or inverse time Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19 1) For further reference, see the Operation characteristics table 36 ABB

37 Table 48. Phase discontinuity protection (PDNSPTOC) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz ±2% of the set value Start time Reset time <70 ms Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode Suppression of harmonics <35 ms ±1.0% of the set value or ±20 ms DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, Table 49. Phase discontinuity protection (PDNSPTOC) main settings Parameter Function (Range) Step Start value PDNSPTOC % 1 Operate delay time PDNSPTOC ms 1 Min phase current PDNSPTOC I n 0.01 Table 50. Residual overvoltage protection (ROVPTOV) Operation accuracy Depending on the frequency of the measured voltage: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Start time 1)2) Minimum Typical Maximum U Fault = 2 set Start value 48 ms 51 ms 54 ms Reset time Typically 40 ms Reset ratio Typically 0.96 Retardation time Operate time accuracy in definite time mode Suppression of harmonics <35 ms ±1.0% of the set value or ±20 ms DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, 1) Residual voltage before fault = 0.0 U n, f n = 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 Table 51. Residual overvoltage protection (ROVPTOV) main settings Parameter Function (Range) Step Start value ROVPTOV U n Operate delay time ROVPTOV ms 1 ABB 37

38 Table 52. Three-phase undervoltage protection (PHPTUV) Operation accuracy Depending on the frequency of the voltage measured: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Start time 1)2) Minimum Typical Maximum U Fault = 0.9 set Start value 62 ms 66 ms 70 ms Reset time Reset ratio Retardation time Operate time accuracy in definite time mode Typically 40 ms Depends on the set Relative hysteresis <35 ms ±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 f n, where n = 2, 3, 4, 5, 1) Start value = 1.0 U n, Voltage before fault = 1.1 U n, f n = 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 Table 53. Three-phase undervoltage protection (PHPTUV) main settings Parameter Function (Range) Step Start value PHPTUV U n 0.01 Time multiplier PHPTUV Operate delay time PHPTUV ms 10 Operating curve type 1) PHPTUV Definite or inverse time Curve type: 5, 15, 21, 22, 23 1) For further reference, see the Operation characteristics table Table 54. Three-phase overvoltage protection (PHPTOV) Operation accuracy Depending on the frequency of the measured voltage: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Start time 1)2) Minimum Typical Maximum U Fault = 1.1 set Start value 23 ms 27 ms 31 ms Reset time Reset ratio Retardation time Operate time accuracy in definite time mode Typically 40 ms Depends on the set Relative hysteresis <35 ms ±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 f n, where n = 2, 3, 4, 5, 1) Start value = 1.0 U n, Voltage before fault = 0.9 U n, f n = 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 U n, Start value multiples in range of ABB

39 Table 55. Three-phase overvoltage protection (PHPTOV) main settings Parameter Function (Range) Step Start value PHPTOV U n 0.01 Time multiplier PHPTOV Operate delay time PHPTOV ms 10 Operating curve type 1) PHPTOV Definite or inverse time Curve type: 5, 15, 17, 18, 19, 20 1) For further reference, see the Operation characteristics table Table 56. Positive-sequence undervoltage protection (PSPTUV) Operation accuracy Depending on the frequency of the measured voltage: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Start time 1)2) Minimum Typical Maximum U Fault = 0.99 set Start value U Fault = 0.9 set Start value 52 ms 44 ms 55 ms 47 ms 58 ms 50 ms Reset time Reset ratio Retardation time Operate time accuracy in definite time mode Suppression of harmonics Typically 40 ms Depends on the set Relative hysteresis <35 ms ±1.0% of the set value or ±20 ms DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, 1) Start value = 1.0 U n, positive-sequence voltage before fault = 1.1 U n, f n = 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 Table 57. Positive-sequence undervoltage protection (PSPTUV) main settings Parameter Function (Range) Step Start value PSPTUV U n Operate delay time PSPTUV ms 10 Voltage block value PSPTUV U n 0.01 ABB 39

40 Table 58. Negative-sequence overvoltage protection (NSPTOV) Operation accuracy Depending on the frequency of the voltage measured: f n ±1.5% of the set value or ±0.002 U n Start time 1)2) Minimum Typical Maximum U Fault = 1.1 set Start value U Fault = 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 Operate time accuracy in definite time mode Suppression of harmonics <35 ms ±1.0% of the set value or ±20 ms DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, 1) Negative-sequence voltage before fault = 0.0 U n, f n = 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 59. Negative-sequence overvoltage protection (NSPTOV) main settings Parameter Function (Range) Step Start value NSPTOV U n Operate delay time NSPTOV ms 1 Table 60. Frequency protection (FRPFRQ) 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 Operate time accuracy <150 ms ±1.0% of the set value or ±30 ms 40 ABB

41 Table 61. Frequency protection (FRPFRQ) main settings Parameter Function (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 f n Start value Freq< FRPFRQ f n Start value df/dt FRPFRQ f n /s Operate Tm Freq FRPFRQ ms 10 Operate Tm df/dt FRPFRQ ms 10 Table 62. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz Current measurement: ±1.5% of the set value or ±0.002 I n (at currents in the range of I n ) Operate time accuracy 1) ±2.0% of the theoretical value or ±0.50 s 1) Overload current > 1.2 Operate level temperature Table 63. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR) main settings Parameter Function (Range) Step Env temperature Set T1PTTR C 1 Current reference T1PTTR I n 0.01 Temperature rise T1PTTR C 0.1 Time constant T1PTTR s 1 Maximum temperature T1PTTR C 0.1 Alarm value T1PTTR C 0.1 Reclose temperature T1PTTR C 0.1 Current multiplier T1PTTR Initial temperature T1PTTR C 0.1 Table 64. Circuit breaker failure protection (CCBRBRF) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz ±1.5% of the set value or ±0.002 I n Operate time accuracy Reset time Retardation time ±1.0% of the set value or ±20 ms Typically 40 ms <20 ms ABB 41

42 Table 65. Circuit breaker failure protection (CCBRBRF) main settings Parameter Function (Range) Step Current value CCBRBRF I n 0.01 Current value Res CCBRBRF I n 0.01 CB failure mode CCBRBRF 1 = Current 2 = Breaker status 3 = Both CB fail trip mode CCBRBRF 1 = Off 2 = Without check 3 = Current check - - Retrip time CCBRBRF ms 10 CB failure delay CCBRBRF ms 10 CB fault delay CCBRBRF ms 10 Table 66. Three-phase inrush detector (INRPHAR) Operation accuracy At the frequency f = f n Current measurement: ±1.5% of the set value or ±0.002 I n 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 67. Three-phase inrush detector (INRPHAR) main settings Parameter Function (Range) Step Start value INRPHAR % 1 Operate delay time INRPHAR ms 1 Table 68. Multipurpose protection (MAPGAPC) Operation accuracy ±1.0% of the set value or ±20 ms Table 69. Multipurpose protection (MAPGAPC) main settings Parameter Function (Range) Step Start value MAPGAPC Operate delay time MAPGAPC ms 100 Operation mode MAPGAPC 1 = Over 2 = Under - 42 ABB

43 Table 70. Load-shedding and restoration (LSHDPFRQ) Operation accuracy f< ±5 mhz df/dt ±100 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< <80 ms df/dt <120 ms Reset time Operate time accuracy <150 ms ±1.0% of the set value or ±30 ms Table 71. Load-shedding and restoration (LSHDPFRQ) main settings Parameter Function (Range) Step Load shed mode LSHDPFRQ 1 = Freq< 6 = Freq< OR df/dt 8 = Freq< AND df/dt Restore mode LSHDPFRQ 1 = Disabled 2 = Auto 3 = Manual - - Start value Freq LSHDPFRQ f n Start value df/dt LSHDPFRQ f n /s Operate Tm Freq LSHDPFRQ ms 10 Operate Tm df/dt LSHDPFRQ ms 10 Restore start Val LSHDPFRQ f n Restore delay time LSHDPFRQ ms 10 Table 72. Fault locator (SCEFRFLO) Measurement accuracy At the frequency f = f n 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 ABB 43

44 Table 73. Fault locator (SCEFRFLO) main settings Parameter Function (Range) Step Z Max phase load SCEFRFLO Ω 0.1 Ph leakage Ris SCEFRFLO Ω 1 Ph capacitive React SCEFRFLO Ω 1 R1 line section A SCEFRFLO Ω/pu X1 line section A SCEFRFLO Ω/pu R0 line section A SCEFRFLO Ω/pu X0 line section A SCEFRFLO Ω/pu Line Len section A SCEFRFLO pu Table 74. Operation characteristics Parameter Operating curve type Operating curve type (voltage protection) (Range) 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 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 44 ABB

45 Power quality functions Table 75. Voltage variation (PHQVVR) Operation accuracy Reset ratio ±1.5% of the set value or ±0.2% of reference voltage Typically 0.96 (Swell), 1.04 (Dip, Interruption) Table 76. Voltage variation (PHQVVR) main settings Parameter Function (Range) Step Voltage dip set 1 PHQVVR % 0.1 Voltage dip set 2 PHQVVR % 0.1 Voltage dip set 3 PHQVVR % 0.1 Voltage swell set 1 PHQVVR % 0.1 Voltage swell set 2 PHQVVR % 0.1 Voltage swell set 3 PHQVVR % 0.1 Voltage Int set PHQVVR % 0.1 VVa Dur Max PHQVVR ms 100 Table 77. Voltage unbalance (VSQVUB) Operation accuracy ±1.5% of the set value or ±0.002 U n Reset ratio Typically 0.96 Table 78. Voltage unbalance (VSQVUB) main settings Parameter Function (Range) Step Operation VSQVUB 1 = on 5 = off Unb detection method VSQVUB 1 = Neg Seq 2 = Zero Seq 3 = Neg to Pos Seq 4 = Zero to Pos Seq 5 = Ph vectors Comp - - ABB 45

46 Control functions Table 79. Autoreclosing (DARREC) Operate time accuracy ±1.0% of the set value or ±20 ms Table 80. Synchronism and energizing check (SECRSYN) Operation accuracy Depending on the frequency of the voltage measured: f n ±1 Hz Voltage: ±3.0% of the set value or ±0.01 U n 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 81. Synchronism and energizing check (SECRSYN) main settings Parameter Function (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 U n 0.01 Difference frequency SECRSYN f n Difference angle SECRSYN Synchrocheck mode SECRSYN 1 = Off 2 = Synchronous 3 = Asynchronous - Dead line value SECRSYN U n 0.1 Live line value SECRSYN U n 0.1 Max energizing V SECRSYN U n 0.01 Control mode SECRSYN 1 = Continuous 2 = Command - Close pulse SECRSYN ms 10 Phase shift SECRSYN Minimum Syn time SECRSYN ms 10 Maximum Syn time SECRSYN ms 10 Energizing time SECRSYN ms 10 Closing time of CB SECRSYN ms ABB

47 Table 82. Automatic transfer switch (ATSABTC) Operation time accuracy ±1.0% of the set value or ±20 ms Table 83. Automatic transfer switch (ATSABTC) main settings Parameter Function (Range) Step Operation ATSABTC 1=on 5=off Main bus priority ATSABTC 1=Bus 1 2=Bus 2 Operate delay CB tr ATSABTC ms 10 ms Transfer dead time ATSABTC ms 10 ms Reconnection delay ATSABTC ms 10 ms ABB 47

48 Condition monitoring functions Table 84. Circuit breaker condition monitoring (SSCBR) Current measuring accuracy At the frequency f = f n ±1.5% or ±0.002 I n (at currents in the range of I n ) ±5.0% (at currents in the range of I n ) Operate time accuracy Traveling time measurement ±1.0% of the set value or ±20 ms ±10 ms Table 85. Fuse failure supervision (SEQSPVC) Operate time 1) NPS function U Fault = 1.1 set Neg Seq voltage Lev U Fault = 5.0 set Neg Seq voltage Lev <33 ms <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, f n = 50 Hz, fault voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements Table 86. Runtime counter for machines and devices (MDSOPT) Description Motor runtime measurement accuracy 1) ±0.5% 1) Of the reading, for a stand-alone relay, without time synchronization Table 87. Voltage presence (PHSVPR) Operation accuracy Depending on the frequency of the measured voltage: f n ±2 Hz ±1.5% of the set value or ±0.002 U n Operation time accuracy ±1.0% of the set value or ±20 ms Table 88. Voltage presence (PHSVPR) main settings Parameter Function (Range) Step Num of phases PHSVPR 1=1 out of 3 2=2 out of 3 3=3 out of 3 V live value PHSVPR U n 0.1 V live time PHSVPR ms 1 ms V dead value PHSVPR U n 0.1 V dead time PHSVPR ms 1 ms 48 ABB

49 Measurement functions Table 89. Three-phase current measurement (CMMXU) Operation accuracy Depending on the frequency of the measured current: f n ±2 Hz ±0.5% or ±0.002 I n (at currents in the range of I n ) Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, RMS: No suppression Table 90. Sequence current measurement (CSMSQI) Operation accuracy Depending on the frequency of the measured current: f/f n = ±2 Hz ±1.0% or ±0.002 I n at currents in the range of I n Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, Table 91. Residual current measurement (RESCMMXU) Operation accuracy Depending on the frequency of the current measured: f/f n = ±2 Hz ±0.5% or ±0.002 I n at currents in the range of I n Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, RMS: No suppression Table 92. Three-phase voltage measurement (VMMXU) Operation accuracy Depending on the frequency of the voltage measured: f n ±2 Hz At voltages in range U n ±0.5% or ±0.002 U n Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, RMS: No suppression Table 93. Sequence voltage measurement (VSMSQI) Operation accuracy Depending on the frequency of the voltage measured: f n ±2 Hz At voltages in range U n ±1.0% or ±0.002 U n Suppression of harmonics DFT: -50 db at f = n f n, where n = 2, 3, 4, 5, ABB 49

50 Table 94. Three-phase power and energy measurement (PEMMXU) Operation accuracy At all three currents in range I n At all three voltages in range U n At the frequency f n ±1 Hz ±1.5% for apparent power S ±1.5% for active power P and active energy 1) ±1.5% for reactive power Q and reactive energy 2) ±0.015 for power factor Suppression of harmonics DFT: -50 db at f = n f n, 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 95. Single-phase power and energy measurement (SPEMMXU) Operation accuracy At all three currents in range x I n At all three voltages in range x U n At the frequency f n ±1 Hz Active power and energy in range PF > 0.71 Reactive power and energy in range PF < 0.71 ±1.5% for power (S, P and Q) ±0.015 for power factor ±1.5% for energy Suppression of harmonics DFT: -50 db at f = n x f n, where n = 2, 3, 4, 5, Table 96. Frequency measurement (FMMXU) Operation accuracy ±10 mhz (in measurement range Hz) 50 ABB

51 22. Local HMI The relay is available with one large display. The LCD display offers 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 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. Further, it offers four functional user-configurable push buttons. These buttons can be used, for example, to change setting groups and the non-reclose mode or to block protection functions. REC615 F1 F2 F3 F4 READY START PICKUP TRIP Switch closed Switch open Switch earthed Counter logic enabled Switch mode enabled SF6 gas pressure Condition monitoring Overcurrent Earth-fault 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. ESC CLOSE OPEN GUID-A0F138E8-2A A266-25F29CF50491 V1 EN Figure 8. Large display CLEAR MENU R L HELP Table 97. Large display Character size 1) Rows in the view Characters per row Small, mono-spaced (6 12 pixels) Large, variable width (13 14 pixels) 7 8 or more 1) Depending on the selected language ABB 51