Relion 615 series. Transformer Protection and Control RET615 Product Guide

Transcription

1 Relion 615 series Transformer Protection and Control Product Guide

2 Contents 1. Description Standard configurations Protection functions Application Supported ABB solutions Control Measurements Disturbance recorder Event log Recorded data Condition monitoring Trip-circuit supervision Self-supervision Fuse failure supervision 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 Cyber security Terminal diagrams Certificates 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 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. 2 ABB

3 Issued: Revision: K 1. Description is a dedicated transformer protection and control relay for power transformers, unit and step-up transformers including power generator-transformer blocks in utility and industry power distribution systems. is a member of ABB s Relion product family and part of its 615 protection and control product series. The 615 series relays are characterized by their compactness and withdrawable-unit design. Re-engineered from the ground up, the 615 series has been designed to unleash the full potential of the IEC standard for communication and interoperability between substation automation devices. Once the standard configuration relay has been given the application-specific settings, it can directly be put into service. The 615 series relays support a range of communication protocols including IEC with Edition 2 support, process bus according to IEC LE, IEC , Modbus and DNP3. Profibus DPV1 communication protocol is supported by using the protocol converter SPA-ZC Standard configurations is available in eight 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 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. ABB 3

4 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION A PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF 3Ith>T/G/C 49T/G/C 3I> 51P-1 Io 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR Io (HV) 3 6 RTD 2 ma 3I (LV) Io> 51N-1 18 MAP MAP I2> 46 3I>>> 50P/51P 3 Io>> 51N-2 3I> 51P-1 ARC 50L/50NL diolo> 87NL Io 3I>> 51P-2 3dI>T 87T CONDITION MONITORING AND SUPERVISION CBCM CBCM OPTS OPTM 2 TCS TCM CONTROL AND INDICATION 1) Object Ctrl 2) Ind 3) CB 1 - DC 2 3 ES 1 2 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 COMMUNICATION Protocols: IEC Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP MEASUREMENT - HV side: I, Io - LV side: I - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components Analog interface types 1) Current transformer 7 Voltage transformer - 1) Conventional transformer inputs TPOSM 84M REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-C90DE25B-AEC FC8-F4604ACDB769 V2 EN Figure 1. Functionality overview for standard configuration A 4 ABB

5 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION B PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF Io 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR 6 RTD 2 ma Io (LV) 18 MAP MAP Io> 51N-1 Io>> 51N-2 diolo> 87NL Io 3dI>T 87T CONDITION MONITORING AND SUPERVISION CBCM CBCM OPTS OPTM 2 TCS TCM COMMUNICATION Protocols: IEC Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP 3 3I (LV) I2> 46 3I>>> 50P/51P 3 3I> 51P-1 ARC 50L/50NL 3I>> 51P-2 CONTROL AND INDICATION 1) Object Ctrl 2) Ind 3) CB 1 - DC 2 3 ES 1 2 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 MEASUREMENT - HV side: I - LV side: I, Io - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components Analog interface types 1) Current transformer 7 Voltage transformer - 1) Conventional transformer inputs TPOSM 84M REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-C948BC5D FC-B8C3F7BA5BAB V2 EN Figure 2. Functionality overview for standard configuration B ABB 5

6 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION C PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR Io 3 Io (HV) 6 RTD 2 ma 3I (LV) Io> 51N-1 diohi> 87NH 18 MAP MAP I2> 46 3I>>> 50P/51P 3 Io>> 51N-2 3dI>T 87T 3I> 51P-1 Io ARC 50L/50NL 3I>> 51P-2 CONDITION MONITORING AND SUPERVISION CBCM CBCM OPTS OPTM 2 TCS TCM CONTROL AND INDICATION 1) Object Ctrl 2) Ind 3) CB DC ES COMMUNICATION Protocols: IEC Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP MEASUREMENT - HV side: I, Io - LV side: I - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components 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 7 Voltage transformer - 1) Conventional transformer inputs TPOSM 84M REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-F8F3319F-B60D-47EF-A BC683D6C V2 EN Figure 3. Functionality overview for standard configuration C 6 ABB

7 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION D PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF Io 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR 6 RTD 2 ma Io (LV) 18 MAP MAP diohi> 87NH Io> 51N-1 3dI>T 87T Io>> 51N-2 CONDITION MONITORING AND SUPERVISION CBCM CBCM OPTS OPTM 2 TCS TCM COMMUNICATION Protocols: IEC Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP Io CONTROL AND INDICATION 1) MEASUREMENT 3 3I (LV) I2> 46 3I>>> 50P/51P 3 3I> 51P-1 ARC 50L/50NL 3I>> 51P-2 Object Ctrl 2) Ind 3) CB 1 - DC 2 3 ES 1 2 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 - HV side: I - LV side: I, Io - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components Analog interface types 1) Current transformer 7 Voltage transformer - 1) Conventional transformer inputs TPOSM 84M REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-422AE187-3E2A-4A20-BBE2-2B8A840DC1FA V2 EN Figure 4. Functionality overview for standard configuration D ABB 7

8 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control Uo U L1 U L2 U L3 TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION E PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR Io 3 Io (HV) 2xRTD 1xmA Io> 51N-1 18 MAP MAP I2> 46 3 Io>> 51N-2 ARC 50L/50NL diolo> 87NL Io 3dI>T 87T 3I (HV) CONDITION MONITORING AND SUPERVISION 2 FUSEF 60 TCS TCM CBCM CBCM OPTS OPTM CONTROL AND INDICATION 1) COMMUNICATION Protocols: IEC /9-2LE Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP MEASUREMENT 3I (LV) 3I>>> 50P/51P 3I> 51P-1 3I>> 51P-2 Object Ctrl 2) Ind 3) CB DC ES HV side: I, Io, U, Uo, P, Q, E, pf, f - LV side: I - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components U L1 U L2 U L3 2 3U< U> 59 U L1 U L2 U L3 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 7 Voltage transformer 2) 5 1) Conventional transformer inputs Uo 2 Uo> 59G TPOSM 84M 2) One of the five inputs is reserved for future applications REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-DC590CA4-DF86-499D-8B77-3DE0CB2997F0 V2 EN Figure 5. Functionality overview for standard configuration E 8 ABB

9 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control Uo U L1 U L2 U L3 TRANSFORMER PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION F PROTECTION LOCAL HMI ALSO AVAILABLE 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF Io 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR 2 RTD 1 ma Io (LV) 18 MAP MAP Io> 51N-1 Io>> 51N-2 diolo> 87NL Io 3dI>T 87T 3I (HV) CONDITION MONITORING AND SUPERVISION 2 FUSEF 60 TCS TCM CBCM CBCM OPTS OPTM COMMUNICATION Protocols: IEC /9-2LE Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP 3 3I (LV) I2> 46 3I>>> 50P/51P 3 3I> 51P-1 ARC 50L/50NL 3I>> 51P-2 CONTROL AND INDICATION 1) Object Ctrl 2) Ind 3) CB DC ES MEASUREMENT - HV side: I, U, Uo, P, Q, E, pf, f - LV side: I, Io - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components U L1 U L2 U L3 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 7 Voltage transformer 2) 5 1) Conventional transformer inputs U L1 U L2 U L3 2 3U< U> 59 2 Uo> 59G TPOSM 84M 2) One of the five inputs is reserved for future applications Uo REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-7F2F76A7-E9D A C V2 EN Figure 6. Functionality overview for standard configuration F ABB 9

10 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control Uo U L1 U L2 U L3 PROTECTION TRANSFORMER PROTECTION AND CONTROL RELAY LOCAL HMI STANDARD CONFIGURATION ALSO AVAILABLE G 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR Io 2xRTD 1xmA Io (HV) Io> 51N-1 diohi> 87NH 18 MAP MAP Io>> 51N-2 3dI>T 87T 3I (HV) CONDITION MONITORING AND SUPERVISION 2 FUSEF 60 TCS TCM CBCM CBCM OPTS OPTM COMMUNICATION Protocols: IEC /9-2LE Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP 3 3I (LV) I2> 46 3I>>> 50P/51P 3 3I> 51P-1 Io ARC 50L/50NL 3I>> 51P-2 U L1 U L2 U L3 CONTROL AND INDICATION 1) Object Ctrl 2) Ind 3) CB 1 - DC 2 3 ES 1 2 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 MEASUREMENT - HV side: I, Io, U, Uo, P, Q, E, pf, f - LV side: I - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components Analog interface types 1) Current transformer 7 Voltage transformer 5 1) Conventional transformer inputs U L1 U L2 U L3 2 3U< U> 59 2 Uo> 59G TPOSM 84M Uo REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-D133822F-DB95-4CF6-B971-9D67054A5731 V2 EN Figure 7. Functionality overview for standard configuration G 10 ABB

11 U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear Configuration System HMI Time Authorization ESC A Clear Transformer Protection and Control Uo U L1 U L2 U L3 PROTECTION TRANSFORMER PROTECTION AND CONTROL RELAY LOCAL HMI STANDARD CONFIGURATION ALSO AVAILABLE H 3I (HV) I2> 46 3I>/Io>BF 51BF/51NBF Io 3Ith>T/G/C 49T/G/C 3I> 51P-1 3I>>> 50P/51P 3I>> 51P-2 I O R L I O R L - Disturbance and fault recorders - Event log and recorded data - High-Speed Output module (optional) - Local/Remote push button on LHMI - Self-supervision - Time synchronization: IEEE 1588 v2, SNTP, IRIG-B - User management - Web HMI AND OR 2 RTD 1 ma Io (LV) 18 MAP MAP diohi> 87NH Io> 51N-1 3dI>T 87T Io>> 51N-2 3I (HV) CONDITION MONITORING AND SUPERVISION 2 FUSEF 60 TCS TCM CBCM CBCM OPTS OPTM COMMUNICATION Protocols: IEC /9-2LE Modbus IEC DNP3 Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232 Redundant protocols: HSR PRP RSTP Io CONTROL AND INDICATION 1) MEASUREMENT 3 3I (LV) I2> 46 3I>>> 50P/51P 3 3I> 51P-1 ARC 50L/50NL 3I>> 51P-2 U L1 U L2 U L3 Object Ctrl 2) Ind 3) CB 1 - DC 2 3 ES 1 2 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 - HV side: I, U, Uo, P, Q, E, pf, f - LV side: I, Io - Limit value supervision - Load profile record - RTD/mA measurement, optional - Symmetrical components Analog interface types 1) Current transformer 7 Voltage transformer 5 1) Conventional transformer inputs U L1 U L2 U L3 2 3U< U> 59 2 Uo> 59G TPOSM 84M Uo REMARKS 2 Master trip Lockout relay 94/86 3 Master Trip Lockout relay 94/86 Optional function 3 No. of instances Calculated value Io/Uo OR Alternative function to be defined when ordering GUID-8C9FE17B C-BE D23FC744 V2 EN Figure 8. Functionality overview for standard configuration H ABB 11

12 Table 1. Standard configurations Description Transformer differential with low-impedance restricted earth-fault protection on the HV side Transformer differential with low-impedance restricted earth-fault protection on the LV side Transformer differential with high-impedance restricted earth-fault protection on the HV side Transformer differential with high-impedance restricted earth-fault protection on the LV side Transformer differential with voltage protection and measurements, and low-impedance restricted earth-fault protection on the HV side Transformer differential with voltage protection and measurements, and low-impedance restricted earth-fault protection on the LV side Transformer differential with voltage protection and measurements, and high-impedance restricted earth-fault protection on the HV side Transformer differential with voltage protection and measurements, and high-impedance restricted earth-fault protection on the LV side Std. conf. A B C D E F G H 12 ABB

13 Table 2. Supported functions Function IEC A B C D E F G H Protection Three-phase non-directional overcurrent protection, low stage PHLPTOC1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV PHLPTOC2 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV Three-phase non-directional overcurrent protection, high stage Three-phase non-directional overcurrent protection, instantaneous stage PHHPTOC1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV PHHPTOC2 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV PHIPTOC1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV PHIPTOC2 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV Non-directional earth-fault protection, low stage EFLPTOC1 1 HV 1 HV 1) 1 HV 1 HV 1) EFLPTOC2 1 LV 1 LV 2) 1 LV 1 LV 2) Non-directional earth-fault protection, high stage EFHPTOC1 1 HV 1 HV 1) 1 HV 1 HV 1) EFHPTOC2 1 LV 1 LV 2) 1 LV 1 LV 2) Negative-sequence overcurrent protection NSPTOC1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV NSPTOC2 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV Residual overvoltage protection ROVPTOV 2 HV 2 HV 2 HV 2 HV Three-phase undervoltage protection PHPTUV 2 HV 2 HV 2 HV 2 HV Three-phase overvoltage protection PHPTOV 2 HV 2 HV 2 HV 2 HV Three-phase thermal overload protection, two time constants Stabilized and instantaneous differential protection for two-winding transformers Numerically stabilized low-impedance restricted earth-fault protection High-impedance based restricted earth-fault protection T2PTTR 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV TR2PTDF LREFPNDF 1 HV 1 LV 1 HV 1 LV HREFPDIF 1 HV 1 LV 3) 1 HV 1 LV 3) Circuit breaker failure protection CCBRBRF 1 HV 1) 1 HV 1) 1 HV 1) 1 HV 1) 1 HV 1) 1 HV 1) 1 HV 1) 1 HV 1) Master trip TRPPTRC 2 (3) 4) 2 (3) 4) 2 (3) 4) 2 (3) 4) 2 (3) 4) 2 (3) 4) 2 (3) 4) 2 (3) 4) Arc protection ARCSARC (3) LV 5) (3) LV 5) (3) LV 5) (3) LV 5) (3) LV 5) (3) LV 5) (3) LV 5) (3) LV 5) Multipurpose protection MAPGAPC Control Circuit-breaker control CBXCBR 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV Disconnector control DCXSWI Earthing switch control ESXSWI Disconnector position indication DCSXSWI Earthing switch indication ESSXSWI Tap changer position indication TPOSYLTC Condition monitoring and supervision Circuit-breaker condition monitoring SSCBR 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV Trip circuit supervision TCSSCBR Fuse failure supervision SEQSPVC Runtime counter for machines and devices MDSOPT Measurement Disturbance recorder RDRE Load profile record LDPRLRC Fault record FLTRFRC Three-phase current measurement CMMXU1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV CMMXU2 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV 1 LV Sequence current measurement CSMSQI1 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV 1 HV Residual current measurement RESCMMXU1 1 HV 1 HV 1 HV 1 HV RESCMMXU2 1 LV 1 LV 1 LV 1 LV Three-phase voltage measurement VMMXU 1 HV 1 HV 1 HV 1 HV Residual voltage measurement RESVMMXU 1 HV 1 HV 1 HV 1 HV Sequence voltage measurement VSMSQI 1 HV 1 HV 1 HV 1 HV Three-phase power and energy measurement PEMMXU 1 HV 1 HV 1 HV 1 HV ABB 13

14 Table 2. Supported functions, continued Function IEC A B C D E F G H RTD/mA measurement XRGGIO130 (1) (1) (1) (1) (1) (1) (1) (1) Frequency measurement FMMXU IEC LE sampled value sending 6)7) SMVSENDER (1) (1) (1) (1) IEC LE sampled value receiving SMVRCV (1) (1) (1) (1) (voltage sharing) 6)7) Other Minimum pulse timer (2 pcs) TPGAPC Minimum pulse timer (2 pcs, second resolution) TPSGAPC Minimum pulse timer (2 pcs, minute resolution) TPMGAPC Pulse timer (8 pcs) PTGAPC Time delay off (8 pcs) TOFGAPC Time delay on (8 pcs) TONGAPC Set-reset (8 pcs) SRGAPC Move (8 pcs) MVGAPC Generic control point (16 pcs) SPCGAPC Analog value scaling (4 pcs) SCA4GAPC Integer value move (4 pcs) MVI4GAPC , 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 HV = The function block is to be used on the high-voltage side in the application. LV = The function block is to be used on the low-voltage side in the application. 1) "Io calculated" is always used. 2) IoB calculated is always used. 3) "IoB measured" is always used. 4) Master trip is included and connected to the corresponding HSO in the configuration only when the BIO0007 module is used. If additionally the ARC option is selected, ARCSARC is connected in the configuration to the corresponding master trip input. 5) "IoB calculated" and "3IB" are always used. 6) Available only with IEC ) Available only with COM Protection functions The relay features three-phase, multi-slope stabilized (biased) stage transformer differential protection and an instantaneous stage to provide fast and selective protection for phase-tophase short circuit, winding interturn fault and bushing flashover protection. Besides second harmonic restraint, an advanced waveform-based blocking algorithm ensures stability at transformer energization and a fifth harmonic restraint function ensures good protection stability at moderate overexcitation of power transformers. Sensitive restricted earth-fault protection completes the overall differential protection providing detection of even single phase-to-earth faults close to the neutral earthing point of the transformer. Either the conventional high-impedance scheme or a numerical low-impedance scheme can be selected for protection of the transformer windings. When low-impedance restricted earthfault protection is used neither stabilizing resistors nor varistors are needed and as a further benefit the transforming ratio of the neutral earthing CTs can differ from those of the phase current transformers. Due to its unit protection character and absolute selectivity restricted earth fault does not need to be timegraded with other protection schemes, and therefore high speed fault clearance can be achieved. The relay also incorporates a thermal overload protection function, which supervises the thermal stress of the transformer windings to prevent premature aging of the insulation of the windings. Multiple stages of short circuit, phase overcurrent, negative-sequence and earth-fault backup protection are separately available for both sides of the power transformer. Earth-fault protection based on the measured or calculated residual voltage is also available. Depending on the chosen standard configuration the relay also features three-phase overvoltage protection, three-phase undervoltage protection and residual overvoltage protection. Further, the relay also offers circuit breaker failure protection. Enhanced with optional hardware and software, the relay also features three light detection channels for arc fault protection of the circuit breaker, busbar and cable compartment of metalenclosed indoor switchgear. The arc-fault protection sensor interface is available on the optional communication module. Fast tripping increases staff safety and security and limits material damage in an arc fault situation. A binary input and output module can be selected as an option - having three high speed binary outputs (HSO) it further decreases the total operate time with typically ms compared to the normal power outputs. 14 ABB

15 I U kv P 0.00 kw Q 0.00 kvar IL2 0 A ESC A Clear R L Transformer Protection and Control 4. Application provides main protection for two-winding power transformers and power generator-transformer blocks. The eight standard configurations offer comprehensive protection functions for detection and elimination of operational disturbance conditions and power transformer faults. The standard configurations A, C, E and G are intended for power transformers with earthed HV side neutrals. The A and E configuration features low-impedance REF protection while the C and G configurations offer high-impedance REF protection. The B, D, F and H configurations fit transformers with solidlyearthed LV side neutral or the LV side with a neutral earthing resistor. The B, D, F and H configurations also fit applications including a separate earthing transformer located within the area of protection. The A, B, E, and F configurations also suit applications, where the turns ratio of the CT of the neutral earthing circuit differs from the turns ratio of the line CTs. The C, D, G and H configurations require that the turns ratios of the CTs are equal. Standard configurations E, F, G and H include phase-voltage protection and measurement functions which provide twostage power transformer overvoltage and undervoltage protection and/or supervision. Two optional RTD/mA modules are available. The optional RTD/mA module offered for the standard configurations A-D allows up to eight analog signals to be measured via the six RTD inputs and the two ma inputs using transducers. The RTD and ma inputs can be used for measuring the oil temperature at the bottom and top of the transformer. Furthermore, the RTD/mA inputs can be used for measuring the ambient air temperature. The RTD inputs also offer thermal protection of dry-type power transformers fitted with Pt-100 temperature sensors. Temperature measurement over the RTD/mA inputs extends the function of the three-phase thermal overload protection of the relay. Further, one of the RTD inputs can also be used as a direct resistance measuring input for position information of the on-load tap changer. Alternatively, the tap changer position indication can be obtained via a ma-transducer. The optional RTD/mA module offered for the standard configurations E-H allows up to three analog signals to be measured via the two RTD inputs and the one ma input using transducers. The RTD inputs can be used for measuring the oil temperature and the ambient air temperature. Temperature measurement over the RTD inputs extends the function of the three-phase thermal overload protection of the relay. For onload tap changer, the tap changer position indication can be obtained via a ma transducer. If required, the analog temperature or tap changer position values can be sent to other devices using analog horizontal GOOSE messaging. Analog values can also be received from other devices over the station bus, thus improving the extent of relevant information. 3I (HV) O Std. conf. ANSI 49T 50L/50NL 50P/51P 51P/51N 87NL 87T A IEC Io (HV) 3Ith>T ARC 3I>>> 3I/Io diolo> 3dI>T RTD 3I (LV) GUID-6657E450-7FB D-E896064D04A3 V1 EN Figure 9. Protection of a two-winding power transformer with standard configuration A Figure 9 illustrates the protection of a two-winding power transformer with standard configuration A. The main protection used in this application example is transformer differential protection. Additionally, restricted earth-fault protection with numerical low-impedance principle is applied on the transformer's HV side. ABB 15

16 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 Transformer Protection and Control 3I (HV) O Std. conf. D ANSI IEC 49T 3Ith>T RTD 50L/50NL ARC 50P/51P 3I>>> Io (LV) 51P/51N 87NH 3I/Io diohi> 87T 3dI>T 3I (LV) GUID-46A1FCF8-F2EC EA8-636E4AEF84FC V1 EN Figure 10. Protection of a two-winding power transformer with standard configuration D Figure 10 illustrates the protection of a two-winding power transformer with standard configuration D. The main protection used in this application example is transformer differential protection. Additionally, restricted earth-fault protection with high-impedance principle is applied on the transformer's LV side. 3U Uo 3I (HV) O Std. conf. E ANSI IEC RTD Io (HV) 27/59 49T 50L/50NL 50P/51P 51P/51N 59G 87NL 87T 3U</3U> 3Ith>T ARC 3I>>> 3I/Io Uo> diolo> 3dI>T 3I (LV) GUID-3C760FFC-6D6B-4860-A198-4BA4273B32D9 V1 EN Figure 11. Protection of a two-winding power transformer with standard configuration E Figure 11 illustrates the protection of a two-winding power transformer with standard configuration E. The main protection used in this application example is transformer differential protection. Additionally, restricted earth-fault protection with numerical low-impedance principle and voltage based protection are applied on the transformer's HV side. 16 ABB

17 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 A Clear R L Transformer Protection and Control 3U Uo 3I (HV) O Std. conf. ANSI IEC E RTD Io (HV) 27/59 49T 50L/50NL 50P/51P 51P/51N 87NL 87T 3U</3U> 3Ith>T ARC 3I>>> 3I/Io diolo> 3dI>T 3U 3I (LV) O REU615 Std. conf. B ANSI IEC 27/59 50P/51P 51P/51N 84M 90V 3U</3U> 3I>>> 3I/Io TPOSM COLTC GUID-AB31C909-F38E-4885-AFEE-E2EEE V4 EN Figure 12. Protection of a two-winding power transformer with standard configuration E Figure 12 illustrates the protection of a two-winding power transformer with standard configuration. The main protection used in this application example is transformer differential protection. Restricted earth-fault protection with numerical low-impedance principle is applied on the transformer's HV side. The RTD inputs of are utilized for monitoring the oil temperature and oil level of the transformer. Additionally, REU615 with the standard configuration B is used as automatic voltage regulator for the on-load tap changer of the transformer. ABB 17

18 5. Supported ABB solutions ABB s 615 series protection and control relays together with the Substation Automation Unit COM600 constitute a genuine IEC 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 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 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 Edition 2 features. At substation level, COM600 uses the data content of the baylevel devices to enhance substation level functionality. COM600 features a Web browser-based HMI, which provides a customizable graphical display for visualizing single-line mimic diagrams for switchgear bay solutions. The SLD feature is especially useful when 615 series relays without the optional single-line diagram feature are used. The Web HMI of 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 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 Substation Automation Unit COM600 Version 4.0 SP1 or later 4.1 or later (Edition 2) MicroSCADA Pro SYS FP2 or later 9.4 or later (Edition 2) System 800xA 5.1 or later 18 ABB

19 ABB MicroSCADA Pro/ System 800xA Utility: IEC Industry: OPC COM600 Web HMI COM600 Web HMI Ethernet switch PCM600 Ethernet switch PCM600 Analog and binary horizontal GOOSE communication IEC Analog and binary horizontal GOOSE communication IEC GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V2 EN Figure 13. ABB power system example using Relion relays, Substation Automation Unit COM600 and MicroSCADA Pro/System 800xA 6. Control 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. Depending on the chosen standard configuration of the relay the number of unused binary inputs and binary outputs varies. 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, for example, RIO600 can be integrated to the relay. The binary inputs and outputs of the external I/O module can be used for the less time critical binary signals of the application. The integration enables releasing of some initially reserved binary inputs and outputs of the relay in the standard configuration. The suitability of the binary outputs of the relay which have been selected for controlling of primary devices should be carefully verified, for example the make and carry as well as the breaking capacity. In case the requirements for the control-circuit of the primary device are not met, the use of external auxiliary relays should to 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. ABB 19

20 7. Measurements The relay continuously measures the high voltage (HV) side and the low voltage (LV) side phase currents and the neutral current of the protected transformer. In addition, the relay calculates the symmetrical components of the currents and voltages, maximum current demand value over a user-selectable pre-set time frame, the active and reactive power, the power factor, and the active and reactive energy values. Calculated values are also obtained from the protection and condition monitoring functions of the relay. Depending on the standard configuration, the relay also measures the phase voltages, the residual voltage and the voltage sequence components. For standard configuration A, B, C and D RTD/mA inputs are offered as an option. By means of the optional RTD/mA module the relay can measure up to eight analog signals such as temperature, pressure and tap changer position values via the six RTD inputs or the two ma inputs using transducers. For standard configuration E, F, G and H RTD/mA inputs are offered as an option. By means of these inputs the relay can measure up to three analog signals such as temperature, pressure and tap changer position values via the two RTD inputs or the one ma inputs using transducers. 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. 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. 9. Event log To collect sequence-of-events information, the relay has a nonvolatile 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 information can also be accessed using the Web browserbased user interface, either locally or remotely. 10. 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 current, voltage and angle 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. 11. 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. 12. 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. 20 ABB

21 13. 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. 14. Fuse failure supervision Depending on the chosen standard configuration, the relay includes fuse failure supervision functionality. The fuse failure supervision detects failures between the voltage measurement circuit and the relay. The failures are detected either by the negative sequence-based algorithm or by the delta voltage and delta current algorithm. Upon the detection of a failure, the fuse failure supervision function activates an alarm and blocks voltage-dependent protection functions from unintended operation. 15. 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 level. The access control applies to the frontpanel user interface, the Web browser-based user interface and PCM Inputs and outputs The relay is equipped with six phase-current inputs and one neutral-current input or six phase-current inputs, one neutralcurrent input, three phase-voltage inputs and one residual voltage input. The rated level of the current inputs is 1/5 A and selectable in the relay software. The three phase-voltage inputs and the residual-voltage input covers the rated voltages V. Both phase-to-phase voltages and phase-to-earth voltages can be connected. In addition, the binary input thresholds V DC are selected 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. As an option for standard configurations A, B, C and D, the relay offers six RTD inputs and two ma inputs. By means of the optional RTD/mA module the relay can measure up to eight analog signals such as temperature, pressure and tap changer position values via the six RTD inputs or the two ma inputs using transducers. The values can, apart from measuring and monitoring purposes, be used for tripping and alarm purposes using the offered optional multipurpose protection functions. As an option for standard configurations E, F, G and H, the relay offers two RTD inputs and one ma input. As an option a binary input and output module can be selected, having three high speed binary outputs (HSO), decreasing further the total operate time with typically ms compared to the normal power outputs. 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 CT VT BI BO RTD ma BB PO + 9 SO - - A B C D E F G H BA BG BC BE FF PO + 5 SO + 3 HSO - - BA PO + 6 SO 6 2 FD PO + 2 SO + 3 HSO 6 2 AD PO + 6 SO - - FE PO + 2 SO + 3 HSO - - BA PO + 6 SO 2 1 FD PO + 2 SO + 3 HSO 2 1 ABB 21

22 17. Station communication The relay supports a range of communication protocols including IEC Edition 2, IEC LE, IEC , 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 communication protocol. The IEC 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 communication implementation supports monitoring and control functions. Additionally, parameter settings, disturbance recordings and fault records can be accessed using the IEC 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 protocol. The relay can send binary and analog signals to other devices using the IEC 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 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 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 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. For redundant Ethernet communication, the relay offers either two optical or two galvanic Ethernet network interfaces. A third port with galvanic Ethernet network interface is also available. The third Ethernet interface provides connectivity for any other Ethernet device to an IEC station bus inside a switchgear bay, for example connection of a Remote I/O. Ethernet network redundancy can be achieved using the high-availability seamless redundancy (HSR) protocol or the parallel redundancy protocol (PRP) or a with self-healing ring using RSTP in managed switches. Ethernet redundancy can be applied to Ethernet-based IEC 61850, Modbus and DNP3 protocols. The IEC 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 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. 22 ABB