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Transcript
Relion® 650 series Generator protection REG650 Product Guide Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Contents 1. 650 series overview..............................................3 11. Logic..................................................................24 2. Application...........................................................3 12. Monitoring.........................................................25 3. Available functions...............................................5 13. Metering............................................................27 4. Differential protection.........................................15 14. Human Machine interface.................................28 5. Impedance protection........................................16 15. Basic IED functions...........................................28 6. Current protection..............................................17 16. Station communication.....................................29 7. Voltage protection..............................................20 17. Hardware description........................................30 8. Frequency protection.........................................22 18. Connection diagrams........................................32 9. Secondary system supervision..........................22 19. Technical data...................................................36 10. Control...............................................................23 20. Ordering............................................................76 Disclaimer The information in this document is subject to change without notice and should not be construed as a commitment by ABB AB. ABB AB assumes no responsibility for any errors that may appear in this document. © Copyright 2011 ABB AB. All rights reserved. Trademarks ABB and Relion are registered trademarks of ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders. 2 ABB Generator protection REG650 Product version: 1.1 1. 650 series overview The 650 series IEDs provide optimum 'off-theshelf', ready-to-use solutions. It is configured with complete protection functionality and default parameters to meet the needs of a wide range of applications for generation transmission and sub-transmission grids. The 650 series IEDs include: • Complete ready-made solutions optimized for a wide range of applications for generation, transmission and subtransmission grids. • Support for user-defined names in the local language for signal and function engineering. • Minimized parameter setting based on default values and ABB's new global base value concept. You only need to set those parameters specific to your own application, such as the line data. • GOOSE messaging for horizontal communication. • Extended HMI functionality with 15 dynamic three-color-indication LEDs per page, on up to three pages, and configurable push-button shortcuts for different actions. • Programmable LED text-based labels. • Settable 1A/5A -rated current inputs. ABB 1MRK 502 036-BEN Issued: February 2011 Revision: - REG670 may be used when more extensive protection systems are required or in combination with REG650 to provide redundant schemes. A wide range of protection functions is available to achieve full and reliable protection for different types of generating plants, for example hydro power plants and thermal power plants. This enables adaptation to the protection requirements of most generating plants. Protection functions are available for detecting and clearing internal faults, such as generator stator short circuits and earth faults, generator rotor earth faults, unit transformer short circuits and earth faults and faults in the external power system, fed from the generating plant. Two packages have been defined for the following applications: • Generator protection IED including generator differential protection (B01) • Generator-transformer unit protection IED including transformer differential protection (B05) In many generating plants, the protection system can be designed with a combination of the two packages, that is, two IEDs of either same type or different types, will give redundant protection for a generating unit (generator and unit transformer) depending on the requirements for the plant design. 2. Application The packages are configured and ready for use. Analogue inputs and binary input/output circuits are pre-defined. REG650 is used for the protection and monitoring of generating plants. The IED is especially suitable for applications in distributed control systems with high demands on reliability. It is intended mainly for small and medium size generation stations. The pre-configured IED can be changed and adapted with the graphical configuration tool. 3 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 110kV HV Substation HV CB A 200/1 Unit Transformer 29MVA 121/11kV YNd5 200/1 Y J 0.11 0.11 kV / / 3 3 3 Y Y Auxiliary Transformer 2500/5 C TRM module with 4I+1I*+5U AIM module with 6I+4U 11 59N 100/5 C MSQI 1) 51 A, B, C or D B 1.6MVA 11/0.4kV Meter. 3Uo> ROV2 PTOV 3I> 49 OC4 PTOC Meter. Ith TR PTTR Generator CB 11 3 50/5 / Y 47 0.11 0.11 kV / 3 3 32Q 81R Q U2> 59N 32 3Uo> 52PD PD 51 CC RPLD 3I> 37 OC4 PTOC RXTTE4 Field CB U I 67N IN> SDE PSDE G IN> EF4 PTOC 3 H P< U</I> AEG GAPC < LEX PDIS 78 Ucos OOS PPAM I2> 49 Ith 21 TR PTTR Z< ZG PDIS f> SA PTOF 81U f< SA PTUF 27 3U< UV2 PTUV 59 3U> OV2 PTOV 24 U/f> OEX PVPH 51V I>/U< VR2 PVOC 60FL SDD RFUF / 0.11 kV 59THD U3d/N 1000 10/1 3Id/I GEN PDIF 46 11 50AE 40 87G 29MVA 11kV 150rpm NS2 PTOC 200/5 CC RBRF Rotor EF protection 64R 67N 81O GOP PDUP 50BF 3I> BF 3) P GOP PDOP ROV2 PTOV 390kVA D 11/0.37kV Dyn11 1600/5 1600/5 df/dt SA PFRC V MSQI Y ~ SC SES RSYN GOP PDOP Excitation Transformer 25 CV MMXN J, G or H 51N IN> EF4 PTOC 87N ¤) IdN STEF PHIZ 59N UN> HZ PDIF REG650-B01 2) ¤) Requires dedicated CT cores, external resistor and metrosil for correct operation Note: 1) Input for independent non-directional OC and overload functions. It can be used for different purposes (e.g. OC protection for either Auxiliary trafo or Excitation trafo or Step-up transformer HV side) 2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection. 3) Input for independent directional (sensitive) EF function. It can be used for different purposes (e.g. as rotor EF with RXTTE4 or stator EF for generators operating in parallel) IEC10000299-1-en.vsd IEC10000299 V1 EN Figure 1. Generator protection IED including generator differential protection (B01) 4 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 110kV HV Substation TRM module with 4I+1I*+5U AIM module with 6I+4U HV CB 52PD 200/1 0.11 0.11 / / kV 3 3 3 Y 2500/5 3I> OC4 PTOC 50BF 3I> BF CC RBRF Meter. CV MMXN Y 200/1 Y 25 J SC SES RSYN Y Auxiliary Transformer 51 CC RPLD 110 Unit Transformer 29MVA 121/11kV YNd5 PD 87T Y 3Id/I T3D PDIF 59N 3Uo> Meter. ROV2 PTOV 100/5 C MSQI 3) E D 1.6MVA 11/0.4kV 51 D or E 3I> OC4 PTOC 49 Meter. Ith CV MMXN TR PTTR GT01 Generator CB 32Q Q 81R GOP PDOP Excitation Transformer 11 3 50/5 / Y 47 0.11 0.11 / kV 3 3 U2> V MSQI Y 59N 3Uo> ROV2 PTOV 390kVA C 11/0.37kV Dyn11 1600/5 32 37 B 50AE RXTTE4 Field CB 1) Rotor EF protection 64R U I 67N IN> SDE PSDE 67N IN> EF4 PTOC 29MVA 11kV 150rpm 1600/5 81O P GOP PDOP P< GOP PDUP ~ A df/dt SA PFRC U</I> AEG GAPC 40 < LEX PDIS 78 Ucos OOS PPAM A or B 46 I2> NS2 PTOC 49 Ith TR PTTR 21 Z< ZG PDIS f> SA PTOF 81U f< SA PTUF 27 3U< UV2 PTUV 59 3U> OV2 PTOV 24 U/f> OEX PVPH 51V I>/U< VR2 PVOC 60FL SDD RFUF 200/5 11 / 0.11 kV 3 G 59THD U3d/N 1000 ¤) 10/1 H J, G or H 51N IN> EF4 PTOC 87N IdN STEF PHIZ 59N UN> HZ PDIF REG650-B05 2) ¤) Requires dedicated CT cores, external resistor and metrosil for correct operation Note: 1) Inputs for independent directional (sensitive) EF function. It can be used for different purposes (e.g. as rotor EF with RXTTE4 or stator EF for generators running in parallel) 2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection. 3) Alternatively step-up transformer HV side open delta VT can be connected here IEC10000300-1-en.vsd IEC10000300 V1 EN Figure 2. Generator-transformer unit protection IED including transformer differential protection (B05) ABB 5 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 3. Available functions Main protection functions REG650 (B05) Gen+Trafo diff Generator REG650 (B01) Gen diff IEC 61850/ ANSI Function description Function block name Differential protection T3WPDIF 87T Transformer differential protection, three winding 1 HZPDIF 87 1Ph High impedance differential protection 1 GENPDIF 87G Generator differential protection 1 1 Impedance protection ZGPDIS 21G Underimpedance protection for generators and transformers 1 1 LEXPDIS 40 Loss of excitation 1 1 OOSPPAM 78 Out-of-step protection 1 1 Load encroachment 1 1 LEPDIS 6 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Back-up protection functions Generator REG650 (B05) Gen+Trafo diff Function description REG650 (B01) Gen diff IEC 61850/ ANSI Function block name Current protection OC4PTOC 51/67 Four step directional phase overcurrent protection 2 2 EF4PTOC 51N/ 67N Four step directional residual overcurrent protection 2 2 SDEPSDE 67N Sensitive directional residual overcurrent and power protection 1 1 TRPTTR 49 Thermal overload protection, two time constants 2 2 CCRBRF 50BF Breaker failure protection 1 1 CCRPLD 52PD Pole discordance protection 1 1 GUPPDUP 37 Directional underpower protection 1 1 GOPPDOP 32 Directional overpower protection 2 2 AEGGAPC 50AE Accidental energizing protection for synchronous generator 1 1 NS2PTOC 46I2 Negative-sequence time overcurrent protection for machines 1 1 VR2PVOC 51V Voltage-restrained time overcurrent protection 1 1 Voltage protection UV2PTUV 27 Two step undervoltage protection 1 1 OV2PTOV 59 Two step overvoltage protection 1 1 ROV2PTOV 59N Two step residual overvoltage protection 2 2 OEXPVPH 24 Overexcitation protection 1 1 STEFPHIZ 59THD 100% Stator earth fault protection, 3rd harmonic based 1 1 Frequency protection ABB 7 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Generator SAPTUF 81 Underfrequency function 4 4 SAPTOF 81 Overfrequency function 4 4 SAPFRC 81 Rate-of-change frequency protection 2 2 8 REG650 (B05) Gen+Trafo diff Function description REG650 (B01) Gen diff IEC 61850/ ANSI Function block name ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Control and monitoring functions Generator REG650 (B05) Gen+Trafo diff ANSI Function description REG650 (B01) Gen diff IEC 61850/ Function block name Control SESRSYN 25 Synchrocheck, energizing check, and synchronizing 1 1 QCBAY Bay control 1 1 LOCREM Handling of LR-switch positions 1 1 LOCREMCTRL LHMI control of Permitted Source To Operate (PSTO) 1 1 SLGGIO Logic Rotating Switch for function selection and LHMI presentation 15 15 VSGGIO Selector mini switch extension 20 20 DPGGIO IEC 61850 generic communication I/O functions double point 16 16 SPC8GGIO Single point generic control 8 signals 5 5 AUTOBITS AutomationBits, command function for DNP3.0 3 3 I103CMD Function commands for IEC60870-5-103 1 1 I103IEDCMD IED commands for IEC60870-5-103 1 1 I103USRCMD Function commands user defined for IEC60870-5-103 4 4 I103GENCMD Function commands generic for IEC60870-5-103 50 50 I103POSCMD IED commands with position and select for IEC60870-5-103 50 50 Secondary system supervision SDDRFUF Fuse failure supervision 1 1 TCSSCBR Breaker close/trip circuit monitoring 3 3 Logic ABB 9 ANSI Function description SMPPTRC 94 Generator REG650 (B01) Gen diff IEC 61850/ Function block name 1MRK 502 036-BEN Issued: February 2011 REG650 (B05) Gen+Trafo diff Generator protection REG650 Product version: 1.1 Tripping logic 6 6 TMAGGIO Trip matrix logic 12 12 OR Configurable logic blocks, OR gate 283 283 INVERTER Configurable logic blocks, Inverter gate 140 140 PULSETIMER Configurable logic blocks, Pulse timer 40 40 GATE Configurable logic blocks, Controllable gate 40 40 XOR Configurable logic blocks, exclusive OR gate 40 40 LOOPDELAY Configurable logic blocks, loop delay 40 40 TIMERSET Configurable logic blocks, timer function block 40 40 AND Configurable logic blocks, AND gate 280 280 SRMEMORY Configurable logic blocks, set-reset memory flip-flop gate 40 40 RSMEMORY Configurable logic blocks, reset-set memory flip-flop gate 40 40 FXDSIGN Fixed signal function block 1 1 B16I Boolean 16 to Integer conversion 16 16 B16IFCVI Boolean 16 to Integer conversion with logic node representation 16 16 IB16A Integer to Boolean 16 conversion 16 16 IB16FCVB Integer to Boolean 16 conversion with logic node representation 16 16 CVMMXN Measurements 6 6 CMMXU Phase current measurement 10 10 VMMXU Phase-phase voltage measurement 6 6 CMSQI Current sequence component measurement 6 6 VMSQI Voltage sequence measurement 6 6 Monitoring 10 ABB ANSI Function description Generator REG650 (B01) Gen diff IEC 61850/ Function block name 1MRK 502 036-BEN Issued: February 2011 ABB REG650 (B05) Gen+Trafo diff Generator protection REG650 Product version: 1.1 VNMMXU Phase-neutral voltage measurement 6 6 CNTGGIO Event counter 5 5 DRPRDRE Disturbance report 1 1 AxRADR Analog input signals 4 4 BxRBDR Binary input signals 6 6 SPGGIO IEC 61850 generic communication I/O functions 64 64 SP16GGIO IEC 61850 generic communication I/O functions 16 inputs 16 16 MVGGIO IEC 61850 generic communication I/O functions 16 16 MVEXP Measured value expander block 66 66 SPVNZBAT Station battery supervision 1 1 SSIMG 63 Insulation gas monitoring function 2 2 SSIML 71 Insulation liquid monitoring function 2 2 SSCBR Circuit breaker condition monitoring 1 1 I103MEAS Measurands for IEC60870-5-103 1 1 I103MEASUSR Measurands user defined signals for IEC60870-5-103 3 3 I103AR Function status auto-recloser for IEC60870-5-103 1 1 I103EF Function status earth-fault for IEC60870-5-103 1 1 I103FLTPROT Function status fault protection for IEC60870-5-103 1 1 I103IED IED status for IEC60870-5-103 1 1 I103SUPERV Supervison status for IEC60870-5-103 1 1 I103USRDEF Status for user defined signals for IEC60870-5-103 20 20 11 ANSI Function description Generator REG650 (B01) Gen diff IEC 61850/ Function block name 1MRK 502 036-BEN Issued: February 2011 REG650 (B05) Gen+Trafo diff Generator protection REG650 Product version: 1.1 Metering PCGGIO Pulse counter logic 16 16 ETPMMTR Function for energy calculation and demand handling 3 3 12 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Designed to communicate Generator REG650 (B05) Gen+Trafo diff ANSI Function description REG650 (B01) Gen diff IEC 61850/ Function block name IEC 61850 communication protocol, LAN1 1 1 DNP3.0 for TCP/IP communication protocol, LAN1 1 1 IEC61870-5-103 IEC60870-5-103 serial communication via ST 1 1 GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59 59 GOOSEBINRCV GOOSE binary receive 4 4 GOOSEDPRCV GOOSE function block to receive a double point value 32 32 GOOSEINTRCV GOOSE function block to receive an integer value 32 32 GOOSEMVRCV GOOSE function block to receive a mesurand value 16 16 GOOSESPRCV GOOSE function block to receive a single point value 64 64 Station communication ABB 13 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Basic IED functions IEC 61850/ Function block name Function description Basic functions included in all products INTERRSIG Self supervision with internal event list 1 SELFSUPEVLST Self supervision with internal event list 1 SNTP Time synchronization 1 TIMESYNCHGEN Time synchronization 1 DTSBEGIN, DTSEND, TIMEZONE Time synchronization, daylight saving 1 IRIG-B Time synchronization 1 SETGRPS Setting group handling 1 ACTVGRP Parameter setting groups 1 TESTMODE Test mode functionality 1 CHNGLCK Change lock function 1 TERMINALID IED identifiers 1 PRODINF Product information 1 PRIMVAL Primary system values 1 SMAI_20_1-12 Signal matrix for analog inputs 2 3PHSUM Summation block 3 phase 12 GBASVAL Global base values for settings 6 ATHSTAT Authority status 1 ATHCHCK Authority check 1 FTPACCS FTP access with password 1 DOSFRNT Denial of service, frame rate control for front port 1 DOSLAN1 Denial of service, frame rate control for LAN1 1 DOSSCKT Denial of service, socket flow control 1 14 ABB Generator protection REG650 Product version: 1.1 4. Differential protection Transformer differential protection T2WPDIF/T3WPDIF The Transformer differential protection, twowinding (T2WPDIF) and Transformer differential protection, three-winding (T3WPDIF) are provided with internal CT ratio matching and vector group compensation and settable, zero sequence current elimination. The function can be provided with two or three-phase sets of current inputs. All current inputs are provided with percentage bias restraint features, making the IED suitable for two- or three-winding transformer arrangements. Two-winding applications xx05000048.vsd two-winding power transformer IEC05000048 V1 EN Three-winding applications xx05000052.vsd three-winding power transformer with all three windings connected IEC05000052 V1 EN xx05000049.vsd IEC05000049 V1 EN three-winding power transformer with unconnected delta tertiary winding Figure 3. CT group arrangement for differential protection and other protections The setting facilities cover for applications of the differential protection to all types of power transformers and auto-transformers with or without load tap changer as well as for shunt reactors or and local feeders within ABB 1MRK 502 036-BEN Issued: February 2011 the station. An adaptive stabilizing feature is included for heavy through-faults. Stabilization is included for inrush currents as well as for overexcitation condition. Adaptive stabilization is also included for system recovery inrush and CT saturation for external faults. A high set unrestrained differential current protection is included for a very high speed tripping at a high internal fault currents. An innovative sensitive differential protection feature, based on the theory of symmetrical components, offers the best possible coverage for power transformer winding turnto-turn faults. 1Ph High impedance differential protection HZPDIF The 1Ph High impedance differential protection HZPDIF function can be used when the involved CT cores have the same turn ratio and similar magnetizing characteristics. It utilizes an external summation of the currents in the interconnected CTs and a series resistor and a voltage dependent resistor externally to the IED. HZPDIF can be used as high impedance REF protection. Generator differential protection GENPDIF Short circuit between the phases of the stator windings causes normally very large fault currents. The short circuit gives risk of damages on insulation, windings and stator iron core. The large short circuit currents cause large forces, which can cause damage even to other components in the power plant, such as turbine and generator-turbine shaft. The task of Generator differential protection GENPDIF is to determine whether a fault is within the protected zone, or outside the protected zone. If the fault is internal, the faulty generator must be quickly tripped, that is, disconnected from the network, the field 15 Generator protection REG650 Product version: 1.1 breaker tripped and the power to the prime mover interrupted. To limit the damage due to stator winding short circuits, the fault clearance must be as fast as possible (instantaneous). If the generator block is connected to the power system close to other generating blocks, the fast fault clearance is essential to maintain the transient stability of the non-faulted generators. Normally, the short circuit fault current is very large, that is, significantly larger than the generator rated current. There is a risk that a short circuit can occur between phases close to the neutral point of the generator, thus causing a relatively small fault current. The fault current can also be limited due to low excitation of the generator. Therefore, it is desired that the detection of generator phaseto-phase short circuits shall be relatively sensitive, detecting small fault currents. It is also of great importance that the generator differential protection does not trip for external faults, with large fault currents flowing from the generator. To combine fast fault clearance, as well as sensitivity and selectivity, the generator differential protection is normally the best choice for phase-to-phase generator short circuits. A negative-sequence-current-based internalexternal fault discriminator can be used to determine whether a fault is internal or external. The internal-external fault discriminator not only positively discriminates between internal and external faults, but can independently detect minor faults which may not be felt (until they develop into more serious faults) by the "usual" differential protection based on operate-restrain characteristic. An open CT circuit condition creates unexpected operations for Generator differential protection under the normal load conditions. It is also possible to damage secondary equipment due to high voltage produced from open CT circuit outputs. Therefore, it may be a requirement from security and reliability points of view to have 16 1MRK 502 036-BEN Issued: February 2011 open CT detection function to block Generator differential protection function in case of open CT conditions and at the same time produce the alarm signal to the operational personal to make quick remedy actions to correct the open CT condition. Generator differential protection GENPDIF is also well suited to generate fast, sensitive and selective fault clearance, if used to protect shunt reactors or small busbars 5. Impedance protection Underimpedance protection for generators and transformers ZGPDIS The underimpedance protection for generators and transformers ZGPDIS, has the offset mho characteristic as a three zone backup protection for detection of short circuits in transformers and generators. The three zones have independent measuring and settings that gives high flexibility for all types of applications. Load encroachment characteristic is available for third zone as shown in figure 4. jX Operation area Operation area R Operation area No operation area No operation area en07000117.vsd IEC07000117 V1 EN Figure 4. Load encroachment influence on the offset mho characteristic ABB Generator protection REG650 Product version: 1.1 Loss of excitation LEXPDIS There are limits for the low excitation of a synchronous machine. A reduction of the excitation current weakens the coupling between the rotor and the stator. The machine may lose the synchronism and start to operate like an induction machine. Then, the reactive power consumption will increase. Even if the machine does not loose synchronism it may not be acceptable to operate in this state for a long time. Reduction of excitation increases the generation of heat in the end region of the synchronous machine. The local heating may damage the insulation of the stator winding and the iron core. To prevent damages to the generator it should be tripped when excitation becomes too low. Out-of-step protection OOSPPAM Out-of-step protection (OOSPPAM) function in the IED can be used both for generator protection application as well as, line protection applications. The main purpose of the OOSPPAM function is to detect, evaluate, and take the required action during pole slipping occurrences in the power system. The OOSPPAM function detects pole slip conditions and trips the generator as fast as possible, that is after the first pole-slip if the centre of oscillation is found to be in zone 1 which normally includes the generator and its step-up power transformer. If the centre of oscillation is found to be further out in the power system, that is, in zone 2, more than one pole-slip is usually allowed before the generator-transformer unit is disconnected. If there are several out-of-step relays in the power system, then one which finds the centre of oscillation in its zone 1 shall operate first. Load encroachment LEPDIS Heavy load transfer is common in many power networks and may make fault ABB 1MRK 502 036-BEN Issued: February 2011 resistance coverage difficult to achieve. In such a case, Load encroachment (LEPDIS) function can be used to enlarge the resistive setting of the underimpedance measuring zones without interfering with the load. 6. Current protection Four step phase overcurrent protection OC4PTOC The four step phase overcurrent protection function OC4PTOC has an inverse or definite time delay independent for step 1 and 4 separately. Step 2 and 3 are always definite time delayed. All IEC and ANSI time delayed characteristics are available. The directional function is voltage polarized with memory. The function can be set to be directional or non-directional independently for each of the steps. Four step residual overcurrent protection EF4PTOC The four step residual overcurrent protection (EF4PTOC) has a settable inverse or definite time delay independent for step 1 and 4 separately. Step 2 and 3 are always definite time delayed. All IEC and ANSI time delayed characteristics are available. The directional function is voltage polarized, current polarized or dual polarized. EF4PTOC can be set directional or nondirectional independently for each of the steps. A second harmonic blocking can be set individually for each step. Sensitive directional residual overcurrent and power protection SDEPSDE In isolated networks or in networks with high impedance earthing, the earth fault current is significantly smaller than the short 17 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 circuit currents. In addition to this, the magnitude of the fault current is almost independent on the fault location in the network. The protection can be selected to use either the residual current or residual power component 3U0·3I0·cos j, for operating quantity. There is also available one non-directional 3I0 step and one nondirectional 3U0 overvoltage tripping step. A contact check criteria can be used where the fault current through the breaker is small. Thermal overload protection, two time constant TRPTTR CCRBRF function can be programmed to give a three-phase re-trip of the own breaker to avoid unnecessary tripping of surrounding breakers at an incorrect initiation due to mistakes during testing. If a power transformer or generator reaches very high temperatures the equipment might be damaged. The insulation within the transformer/generator will have forced ageing. As a consequence of this the risk of internal phase-to-phase or phase-to-earth faults will increase. High temperature will degrade the quality of the transformer/ generator insulation. The thermal overload protection estimates the internal heat content of the transformer/ generator (temperature) continuously. This estimation is made by using a thermal model of the transformer/generator with two time constants, which is based on current measurement. Two warning levels are available. This enables actions in the power system to be done before dangerous temperatures are reached. If the temperature continues to increase to the trip value, the protection initiates a trip of the protected transformer/ generator. Breaker failure protection CCRBRF Breaker failure protection (CCRBRF) ensures fast back-up tripping of surrounding breakers in case the own breaker failure to open. CCRBRF can be current based, contact based, or an adaptive combination of these two principles. A current check with extremely short reset time is used as check criterion to achieve a high security against unnecessary operation. 18 Breaker failure protection (CCRBRF) current criteria can be fulfilled by one or two phase currents, or one phase current plus residual current. When those currents exceed the user defined settings, the function is activated. These conditions increase the security of the back-up trip command. Pole discordance protection CCRPLD Circuit breakers and disconnectors can end up with the poles in different positions (closeopen), due to electrical or mechanical failures. This can cause negative and zero sequence currents which cause thermal stress on rotating machines and can cause unwanted operation of zero sequence or negative sequence current functions. Normally the own breaker is tripped to correct such a situation. If the situation persists the surrounding breakers should be tripped to clear the unsymmetrical load situation. The pole discordance function operates based on information from the circuit breaker logic with additional criteria from unsymmetrical phase currents when required. Directional over/underpower protection GOPPDOP/GUPPDUP The directional over-/under-power protection GOPPDOP/GUPPDUP can be used wherever a high/low active, reactive or apparent power protection or alarming is required. The functions can alternatively be used to check the direction of active or reactive power flow in the power system. There are a number of applications where such functionality is needed. Some of them are: ABB Generator protection REG650 Product version: 1.1 • detection of reversed active power flow • detection of high reactive power flow Each function has two steps with definite time delay. Reset times for both steps can be set as well. Accidental energizing protection for synchronous generator AEGGAPC Inadvertent or accidental energizing of offline generators has occurred often enough due to operating errors, breaker head flashovers, control circuit malfunctions, or a combination of these causes. Inadvertently energized generator operates as induction motor drawing a large current from the system. The voltage supervised overcurrent protection is used to protect the inadvertently energized generator. Accidental energizing protection for synchronous generator (AEGGAPC) takes the maximum phase current input from the generator terminal side or from generator neutral side and maximum phase to phase voltage inputs from the terminal side. AEGGAPC is armed when the terminal voltage drops below the specified voltage level for the preset time. Negative sequence time overcurrent protection for machines NS2PTOC Negative-sequence time overcurrent protection for machines NS2PTOC is intended primarily for the protection of generators against possible overheating of the rotor caused by negative sequence component in the stator current. The negative sequence currents in a generator may, among others, be caused by: • Unbalanced loads • Line to line faults • Line to earth faults • Broken conductors • Malfunction of one or more poles of a circuit breaker or a disconnector 1MRK 502 036-BEN Issued: February 2011 the event line protections or circuit breakers fail to clear unbalanced system faults. To provide an effective protection for the generator for external unbalanced conditions, NS2PTOC is able to directly measure the negative sequence current. NS2PTOC also has a time delay characteristic which matches the heating characteristic of the generator I 22t = K as defined in standard. where: I2 is negative sequence current expressed in per unit of the rated generator current t is operating time in seconds K is a constant which depends of the generators size and design NS2PTOC has a wide range of K settings and the sensitivity and capability of detecting and tripping for negative sequence currents down to the continuous capability of a generator. A separate output is available as an alarm feature to warn the operator of a potentially dangerous situation. Voltage-restrained time overcurrent protection VR2PVOC Voltage-restrained time overcurrent protection (VR2PVOC) function is recommended as a backup protection for generators. The overcurrent protection feature has a settable current level that can be used either with definite time or inverse time characteristic. Additionally, it can be voltage controlled/restrained. One undervoltage step with definite time characteristic is also available with the function in order to provide funcionality for overcurrent protection with undervoltage sealin. NS2PTOC can also be used as a backup protection, that is, to protect the generator in ABB 19 Generator protection REG650 Product version: 1.1 7. Voltage protection Two step undervoltage protection UV2PTUV Undervoltages can occur in the power system during faults or abnormal conditions. Two step undervoltage protection (UV2PTUV) function can be used to open circuit breakers to prepare for system restoration at power outages or as long-time delayed back-up to primary protection. UV2PTUV has two voltage steps, where step 1 is settable as inverse or definite time delayed. Step 2 is always definite time delayed. Two step overvoltage protection OV2PTOV Overvoltages may occur in the power system during abnormal conditions such as sudden power loss, tap changer regulating failures, open line ends on long lines etc. OV2PTOV has two voltage steps, where step 1 can be set as inverse or definite time delayed. Step 2 is always definite time delayed. OV2PTOV has an extremely high reset ratio to allow settings close to system service voltage. Two step residual overvoltage protection ROV2PTOV Residual voltages may occur in the power system during earth faults. Two step residual overvoltage protection ROV2PTOV function calculates the residual voltage from the three-phase voltage input transformers or measures it from a single voltage input transformer fed from an open delta or neutral point voltage transformer. ROV2PTOV has two voltage steps, where step 1 can be set as inverse or definite time delayed. Step 2 is always definite time delayed. Overexcitation protection OEXPVPH When the laminated core of a power transformer or generator is subjected to a 20 1MRK 502 036-BEN Issued: February 2011 magnetic flux density beyond its design limits, stray flux will flow into non-laminated components not designed to carry flux and cause eddy currents to flow. The eddy currents can cause excessive heating and severe damage to insulation and adjacent parts in a relatively short time. The function has settable inverse operating curves and independent alarm stages. 95% and 100% Stator earth fault protection based on 3rd harmonic STEFPHIZ Stator earth fault is a fault type having relatively high fault rate. The generator systems normally have high impedance earthing, that is, earthing via a neutral point resistor. This resistor is normally dimensioned to give an earth fault current in the range 3 – 15 A at a solid earth-fault directly at the generator high voltage terminal. The relatively small earth fault currents give much less thermal and mechanical stress on the generator, compared to the short circuit case, which is between conductors of two phases. Anyhow, the earth faults in the generator have to be detected and the generator has to be tripped, even if longer fault time compared to internal short circuits, can be allowed. In normal non-faulted operation of the generating unit the neutral point voltage is close to zero, and there is no zero sequence current flow in the generator. When a phaseto-earth fault occurs the neutral point voltage will increase and there will be a current flow through the neutral point resistor. To detect an earth fault on the windings of a generating unit one may use a neutral point overvoltage protection, a neutral point overcurrent protection, a zero sequence overvoltage protection or a residual differential protection. These protections are simple and have served well during many years. However, at best these simple schemes protect only 95% of the stator winding. They leave 5% close to the neutral end unprotected. Under unfavorable conditions ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 the blind zone may extend up to 20% from the neutral. The 95% stator earth fault protection measures the fundamental frequency voltage component in the generator star point and it operates when it exceeds the preset value. By applying this principle approximately 95% of the stator winding can be protected. In order to protect the last 5% of the stator winding close to the neutral end the 3rd harmonic voltage measurement can be performed. In 100% Stator E/F 3rd harmonic protection either the 3rd harmonic voltage differential principle, the neutral point 3rd harmonic undervoltage principle or the terminal side 3rd harmonic overvoltage principle can be applied. However, differential principle is strongly recommended. Combination of these two measuring principles provides coverage for entire stator winding against earth faults. CB 1 may not exist stator winding N x E3 (1- x) E3 RN uN Samples of the neutral voltage from which the fundamental and 3rd harmonic voltages are filtered out T CB 1 Transformer Rf x CB 2 uT 1- x 1 or 100 % Neutral point fundamental frequency over-voltage protection 5% - 100% over- voltage protection 10%– 100% 3rd harmonic Differential differential 0% – 30% 0% - 30% Samples of the terminal voltage from which the 3rd harmonic voltage is filtered out IEC10000202-1-en.vsd IEC10000202 V1 EN Figure 5. Protection principles for STEFPHIZ function Rotor earth fault protection 64R Generator rotor winding and its associated dc supply electric circuit is typically fully insulated from the earth (that is, ground). Therefore single connection of this circuit to earth will not cause flow of any substantial current. However if second earth fault appears in this circuit circumstances can be quit serious. Depending on the location of these two faults such operating condition may cause: ABB • Partial or total generator loss of field • Large dc current flow through rotor magnetic circuit • Rotor vibration • Rotor displacement sufficient to cause stator mechanical damage Therefore practically all bigger generators have some dedicated protection which is capable to detect the first earth fault in the rotor circuit and then, depending on the fault resistance, either just to give an alarm to the operating personnel or actually to give stop command to the machine. Requires injection unit for rotor earth fault protection (RXTTE4) and a protective resistor on plate for correct operation. 21 Generator protection REG650 Product version: 1.1 8. Frequency protection Underfrequency protection SAPTUF Underfrequency occurs as a result of lack of generation in the network. Underfrequency protection SAPTUF is used for load shedding systems, remedial action schemes, gas turbine startup and so on. SAPTUF is provided with an undervoltage blocking. Overfrequency protection SAPTOF Overfrequency protection function SAPTOF is applicable in all situations, where reliable detection of high fundamental power system frequency is needed. Overfrequency occurs at sudden load drops or shunt faults in the power network. Close to the generating plant, generator governor problems can also cause over frequency. SAPTOF is used mainly for generation shedding and remedial action schemes. It is also used as a frequency stage initiating load restoring. 1MRK 502 036-BEN Issued: February 2011 9. Secondary system supervision Fuse failure supervision SDDRFUF The aim of the fuse failure supervision function (SDDRFUF) is to block voltage measuring functions at failures in the secondary circuits between the voltage transformer and the IED in order to avoid unwanted operations that otherwise might occur. The fuse failure supervision function basically has three different algorithms, negative sequence and zero sequence based algorithms and an additional delta voltage and delta current algorithm. The negative sequence detection algorithm is recommended for IEDs used in isolated or high-impedance earthed networks. It is based on the negative-sequence measuring quantities, a high value of voltage 3U2 without the presence of the negativesequence current 3I2. Rate-of-change frequency protection SAPFRC The zero sequence detection algorithm is recommended for IEDs used in directly or low impedance earthed networks. It is based on the zero sequence measuring quantities, a high value of voltage 3U0 without the presence of the residual current 3I0. Rate-of-change frequency protection function (SAPFRC) gives an early indication of a main disturbance in the system. SAPFRC can be used for generation shedding, load shedding and remedial action schemes. SAPFRC can discriminate between positive or negative change of frequency. A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure, which in practice is more associated with voltage transformer switching during station operations. SAPFRC is provided with an undervoltage blocking. For better adaptation to system requirements, an operation mode setting has been introduced which makes it possible to select the operating conditions for negative sequence and zero sequence based function. The selection of different operation modes SAPTOF is provided with an undervoltage blocking. 22 ABB Generator protection REG650 Product version: 1.1 makes it possible to choose different interaction possibilities between the negative sequence and zero sequence based algorithm. Breaker close/trip circuit monitoring TCSSCBR The trip circuit supervision function TCSSCBR is designed to supervise the control circuit of the circuit breaker. The invalidity of a control circuit is detected by using a dedicated output contact that contains the supervision functionality. The function operates after a predefined operating time and resets when the fault disappears. 10. Control Synchrocheck, energizing check, and synchronizing SESRSYN The Synchronizing function allows closing of asynchronous networks at the correct moment including the breaker closing time, which improves the network stability. Synchrocheck, energizing check, and synchronizing (SESRSYN) function checks that the voltages on both sides of the circuit breaker are in synchronism, or with at least one side dead to ensure that closing can be done safely. SESRSYN function includes a built-in voltage selection scheme for double bus arrangements. Manual closing as well as automatic reclosing can be checked by the function and can have different settings. For systems which are running asynchronous a synchronizing function is provided. The main purpose of the synchronizing function is to provide controlled closing of circuit breakers when two asynchronous systems are going to be connected. It is used for slip frequencies that are larger than those for synchrocheck and lower than a set maximum level for the synchronizing function. ABB 1MRK 502 036-BEN Issued: February 2011 Bay control QCBAY The Bay control QCBAY function is used together with Local remote and local remote control functions is used to handle the selection of the operator place per bay. QCBAY also provides blocking functions that can be distributed to different apparatuses within the bay. Local remote LOCREM /Local remote control LOCREMCTRL The signals from the local HMI or from an external local/remote switch are applied via the function blocks LOCREM and LOCREMCTRL to the Bay control (QCBAY) function block. A parameter in function block LOCREM is set to choose if the switch signals are coming from the local HMI or from an external hardware switch connected via binary inputs. Logic rotating switch for function selection and LHMI presentation SLGGIO The logic rotating switch for function selection and LHMI presentation function (SLGGIO) (or the selector switch function block) is used to get a selector switch functionality similar to the one provided by a hardware selector switch. Hardware selector switches are used extensively by utilities, in order to have different functions operating on pre-set values. Hardware switches are however sources for maintenance issues, lower system reliability and an extended purchase portfolio. The logic selector switches eliminate all these problems. Selector mini switch VSGGIO The Selector mini switch VSGGIO function block is a multipurpose function used for a variety of applications, as a general purpose switch. VSGGIO can be controlled from the menu or from a symbol on the single line diagram (SLD) on the local HMI. 23 Generator protection REG650 Product version: 1.1 IEC 61850 generic communication I/O functions DPGGIO The IEC 61850 generic communication I/O functions (DPGGIO) function block is used to send double indications to other systems or equipment in the substation. It is especially used in the interlocking and reservation station-wide logics. Single point generic control 8 signals SPC8GGIO The Single point generic control 8 signals (SPC8GGIO) function block is a collection of 8 single point commands, designed to bring in commands from REMOTE (SCADA) to those parts of the logic configuration that do not need extensive command receiving functionality (for example, SCSWI). In this way, simple commands can be sent directly to the IED outputs, without confirmation. Confirmation (status) of the result of the commands is supposed to be achieved by other means, such as binary inputs and SPGGIO function blocks. The commands can be pulsed or steady. AutomationBits AUTOBITS The Automation bits function (AUTOBITS) is used to configure the DNP3 protocol command handling. 11. Logic Tripping logic SMPPTRC A function block for protection tripping is provided for each circuit breaker involved in the tripping of the fault. It provides the pulse prolongation to ensure a trip pulse of sufficient length, as well as all functionality necessary for correct co-operation with autoreclosing functions. The trip function block includes functionality for breaker lock-out. 24 1MRK 502 036-BEN Issued: February 2011 Trip matrix logic TMAGGIO Trip matrix logic TMAGGIO function is used to route trip signals and other logical output signals to different output contacts on the IED. TMAGGIO output signals and the physical outputs allows the user to adapt the signals to the physical tripping outputs according to the specific application needs. Configurable logic blocks A number of logic blocks and timers are available for the user to adapt the configuration to the specific application needs. • OR function block. • INVERTER function blocks that inverts the input signal. • PULSETIMER function block can be used, for example, for pulse extensions or limiting of operation of outputs. • GATE function block is used for whether or not a signal should be able to pass from the input to the output. • XOR function block. • LOOPDELAY function block used to delay the output signal one execution cycle. • TIMERSET function has pick-up and dropout delayed outputs related to the input signal. The timer has a settable time delay. • AND function block. • SRMEMORY function block is a flip-flop that can set or reset an output from two inputs respectively. Each block has two outputs where one is inverted. The memory setting controls if the block should be reset or return to the state before the interruption, after a power interruption. Set input has priority. • RSMEMORY function block is a flip-flop that can reset or set an output from two inputs respectively. Each block has two ABB Generator protection REG650 Product version: 1.1 outputs where one is inverted. The memory setting controls if the block should be reset or return to the state before the interruption, after a power interruption. Reset input has priority. Boolean 16 to Integer conversion B16I Boolean 16 to integer conversion function (B16I) is used to transform a set of 16 binary (logical) signals into an integer. Boolean 16 to Integer conversion with logic node representation B16IFCVI Boolean 16 to integer conversion with logic node representation function (B16IFCVI) is used to transform a set of 16 binary (logical) signals into an integer. Integer to Boolean 16 conversion IB16A Integer to boolean 16 conversion function (IB16A) is used to transform an integer into a set of 16 binary (logical) signals. Integer to Boolean 16 conversion with logic node representation IB16FCVB Integer to boolean conversion with logic node representation function (IB16FCVB) is used to transform an integer to 16 binary (logic) signals. IB16FCVB function can receive remote values over IEC61850 depending on the operator position input (PSTO). 12. Monitoring Measurements CVMMXN, CMMXU, VNMMXU, VMMXU, CMSQI, VMSQI The measurement functions are used to get online information from the IED. These service values make it possible to display on-line ABB 1MRK 502 036-BEN Issued: February 2011 information on the local HMI and on the Substation automation system about: • measured voltages, currents, frequency, active, reactive and apparent power and power factor • primary and secondary phasors • current sequence components • voltage sequence components Event counter CNTGGIO Event counter (CNTGGIO) has six counters which are used for storing the number of times each counter input has been activated. Disturbance report DRPRDRE Complete and reliable information about disturbances in the primary and/or in the secondary system together with continuous event-logging is accomplished by the disturbance report functionality. Disturbance report DRPRDRE, always included in the IED, acquires sampled data of all selected analog input and binary signals connected to the function block that is, maximum 40 analog and 96 binary signals. The Disturbance report functionality is a common name for several functions: • Event list • Indications • Event recorder • Trip value recorder • Disturbance recorder The Disturbance report function is characterized by great flexibility regarding configuration, starting conditions, recording times, and large storage capacity. A disturbance is defined as an activation of an input to the AxRADR or BxRBDR function blocks, which are set to trigger the disturbance recorder. All signals from start of pre-fault time to the end of post-fault time will be included in the recording. Every disturbance report recording is saved in the IED in the standard Comtrade format. The same applies to all events, which are continuously saved in a ring-buffer. The local 25 Generator protection REG650 Product version: 1.1 HMI is used to get information about the recordings. The disturbance report files may be uploaded to PCM600 for further analysis using the disturbance handling tool. Event list DRPRDRE Continuous event-logging is useful for monitoring the system from an overview perspective and is a complement to specific disturbance recorder functions. The event list logs all binary input signals connected to the Disturbance report function. The list may contain up to 1000 time-tagged events stored in a ring-buffer. Indications DRPRDRE 1MRK 502 036-BEN Issued: February 2011 The event recorder information is available for the disturbances locally in the IED. The event recording information is an integrated part of the disturbance record (Comtrade file). Trip value recorder DRPRDRE Information about the pre-fault and fault values for currents and voltages are vital for the disturbance evaluation. The Trip value recorder calculates the values of all selected analog input signals connected to the Disturbance report function. The result is magnitude and phase angle before and during the fault for each analog input signal. To get fast, condensed and reliable information about disturbances in the primary and/or in the secondary system it is important to know, for example binary signals that have changed status during a disturbance. This information is used in the short perspective to get information via the local HMI in a straightforward way. The trip value recorder information is available for the disturbances locally in the IED. There are three LEDs on the local HMI (green, yellow and red), which will display status information about the IED and the Disturbance report function (trigged). The Disturbance recorder function supplies fast, complete and reliable information about disturbances in the power system. It facilitates understanding system behavior and related primary and secondary equipment during and after a disturbance. Recorded information is used for different purposes in the short perspective (for example corrective actions) and long perspective (for example functional analysis). The Indication list function shows all selected binary input signals connected to the Disturbance report function that have changed status during a disturbance. Event recorder DRPRDRE Quick, complete and reliable information about disturbances in the primary and/or in the secondary system is vital, for example, time-tagged events logged during disturbances. This information is used for different purposes in the short term (for example corrective actions) and in the long term (for example functional analysis). The event recorder logs all selected binary input signals connected to the Disturbance report function. Each recording can contain up to 150 time-tagged events. 26 The trip value recorder information is an integrated part of the disturbance record (Comtrade file). Disturbance recorder DRPRDRE The Disturbance recorder acquires sampled data from selected analog- and binary signals connected to the Disturbance report function (maximum 40 analog and 96 binary signals). The binary signals available are the same as for the event recorder function. The function is characterized by great flexibility and is not dependent on the operation of protection functions. It can record disturbances not detected by protection functions. The disturbance recorder information for the last 100 disturbances are saved in the IED ABB Generator protection REG650 Product version: 1.1 and the local HMI is used to view the list of recordings. Measured value expander block MVEXP The current and voltage measurements functions (CVMMXN, CMMXU, VMMXU and VNMMXU), current and voltage sequence measurement functions (CMSQI and VMSQI) and IEC 61850 generic communication I/O functions (MVGGIO) are provided with measurement supervision functionality. All measured values can be supervised with four settable limits: low-low limit, low limit, high limit and high-high limit. The measure value expander block has been introduced to enable translating the integer output signal from the measuring functions to 5 binary signals: below low-low limit, below low limit, normal, above high-high limit or above high limit. The output signals can be used as conditions in the configurable logic or for alarming purpose. Station battery supervision SPVNZBAT The station battery supervision function SPVNZBAT is used for monitoring battery terminal voltage. SPVNZBAT activates the start and alarm outputs when the battery terminal voltage exceeds the set upper limit or drops below the set lower limit. A time delay for the overvoltage and undervoltage alarms can be set according to definite time characteristics. In the definite time (DT) mode, SPVNZBAT operates after a predefined operate time and resets when the battery undervoltage or overvoltage condition disappears. Insulation gas monitoring function SSIMG Insulation gas monitoring function (SSIMG) is used for monitoring the circuit breaker condition. Binary information based on the gas pressure in the circuit breaker is used as input signals to the function. In addition, the function generates alarms based on received information. ABB 1MRK 502 036-BEN Issued: February 2011 Insulation liquid monitoring function SSIML Insulation liquid monitoring function (SSIML) is used for monitoring the circuit breaker condition. Binary information based on the oil level in the circuit breaker is used as input signals to the function. In addition, the function generates alarms based on received information. Circuit breaker monitoring SSCBR The circuit breaker condition monitoring function SSCBR is used to monitor different parameters of the circuit breaker. The breaker requires maintenance when the number of operations has reached a predefined value. The energy is calculated from the measured input currents as a sum of Iyt values. Alarms are generated when the calculated values exceed the threshold settings. The function contains a blocking functionality. It is possible to block the function outputs, if desired. 13. Metering Pulse counter logic PCGGIO Pulse counter (PCGGIO) function counts externally generated binary pulses, for instance pulses coming from an external energy meter, for calculation of energy consumption values. The pulses are captured by the BIO (binary input/output) module and then read by the PCGGIO function. A scaled service value is available over the station bus. Function for energy calculation and demand handling ETPMMTR Outputs from the Measurements (CVMMXN) function can be used to calculate energy consumption. Active as well as reactive values are calculated in import and export direction. Values can be read or generated as 27 Generator protection REG650 Product version: 1.1 pulses. Maximum demand power values are also calculated by the function. 14. Human Machine interface Local HMI 1MRK 502 036-BEN Issued: February 2011 the main unit. The units are connected with the Ethernet cable included in the delivery. The LHMI is simple and easy to understand. The whole front plate is divided into zones, each with a well-defined functionality: • Status indication LEDs • Alarm indication LEDs which can indicate three states with the colors green, yellow and red, with user printable label. All LEDs are configurable from the PCM600 tool • Liquid crystal display (LCD) • Keypad with push buttons for control and navigation purposes, switch for selection between local and remote control and reset • Five user programmable function buttons • An isolated RJ45 communication port for PCM600 15. Basic IED functions GUID-23A12958-F9A5-4BF1-A31B-F69F56A046C7 V2 EN Figure 6. Local human-machine interface The LHMI of the IED contains the following elements: • Display (LCD) • Buttons • LED indicators • Communication port The LHMI is used for setting, monitoring and controlling . The Local human machine interface, LHMI includes a graphical monochrome LCD with a resolution of 320x240 pixels. The character size may vary depending on selected language. The amount of characters and rows fitting the view depends on the character size and the view that is shown. The LHMI can be detached from the main unit. The detached LHMI can be wall mounted up to a distance of five meters from 28 Self supervision with internal event list The Self supervision with internal event list (INTERRSIG and SELFSUPEVLST) function reacts to internal system events generated by the different built-in self-supervision elements. The internal events are saved in an internal event list. Time synchronization Use time synchronization to achieve a common time base for the IEDs in a protection and control system. This makes comparison of events and disturbance data between all IEDs in the system possible. Time-tagging of internal events and disturbances are an excellent help when evaluating faults. Without time synchronization, only the events within the IED can be compared to one another. With time synchronization, events and disturbances within the entire station, and ABB Generator protection REG650 Product version: 1.1 even between line ends, can be compared at evaluation. Authority status ATHSTAT In the IED, the internal time can be synchronized from a number of sources: Authority status (ATHSTAT) function is an indication function block for user log-on activity. • SNTP • IRIG-B • DNP • IEC60870-5-103 Parameter setting groups ACTVGRP Use the four sets of settings to optimize the IED operation for different system conditions. Creating and switching between fine-tuned setting sets, either from the local HMI or configurable binary inputs, results in a highly adaptable IED that can cope with a variety of system scenarios. Test mode functionality TESTMODE The protection and control IEDs have many included functions. To make the testing procedure easier, the IEDs include the feature that allows individual blocking of a single-, several-, or all functions. There are two ways of entering the test mode: • By configuration, activating an input signal of the function block TESTMODE • By setting the IED in test mode in the local HMI While the IED is in test mode, all functions are blocked. Any function can be unblocked individually regarding functionality and event signaling. This enables the user to follow the operation of one or several related functions to check functionality and to check parts of the configuration, and so on. Change lock function CHNGLCK Change lock function (CHNGLCK) is used to block further changes to the IED configuration and settings once the commissioning is complete. The purpose is to block inadvertent IED configuration changes beyond a certain point in time. ABB 1MRK 502 036-BEN Issued: February 2011 Authority check ATHCHCK To safeguard the interests of our customers, both the IED and the tools that are accessing the IED are protected, by means of authorization handling. The authorization handling of the IED and the PCM600 is implemented at both access points to the IED: • local, through the local HMI • remote, through the communication ports 16. Station communication IEC 61850-8-1 communication protocol The IED supports the communication protocols IEC 61850-8-1 and DNP3 over TCP/ IP. All operational information and controls are available through these protocols. However, some communication functionality, for example, horizontal communication (GOOSE) between the IEDs, is only enabled by the IEC 61850-8-1 communication protocol. The IED is equipped with an optical Ethernet rear port for the substation communication standard IEC 61850-8-1. IEC 61850-8-1 protocol allows intelligent electrical devices (IEDs) from different vendors to exchange information and simplifies system engineering. Peer-to-peer communication according to GOOSE is part of the standard. Disturbance files uploading is provided. Disturbance files are accessed using the IEC 61850-8-1 protocol. Disturbance files are available to any Ethernet based application via FTP in the standard Comtrade format. Further, the IED can send and receive binary 29 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 values, double point values and measured values (for example from MMXU functions), together with their quality, using the IEC 61850-8-1 GOOSE profile. The IED meets the GOOSE performance requirements for tripping applications in substations, as defined by the IEC 61850 standard. The IED interoperates with other IEC 61850-compliant IEDs, tools, and systems and simultaneously reports events to five different clients on the IEC 61850 station bus. The event system has a rate limiter to reduce CPU load. The event channel has a quota of 10 events/second. If the quota is exceeded the event channel transmission is blocked until the event changes is below the quota, no event is lost. All communication connectors, except for the front port connector, are placed on integrated communication modules. The IED is connected to Ethernet-based communication systems via the fibre-optic multimode LC connector (100BASE-FX). The IED supports SNTP and IRIG-B time synchronization methods with a timestamping resolution of 1 ms. • Ethernet based: SNTP and DNP3 • With time synchronization wiring: IRIG-B The IED supports IEC 60870-5-103 time synchronization methods with a time stamping resolution of 5 ms. Horizontal communication via GOOSE for interlocking GOOSE communication can be used for exchanging information between IEDs via the IEC 61850-8-1 station communication bus. This is typically used for sending apparatus position indications for interlocking or reservation signals for 1-of-n control. GOOSE can also be used to exchange any boolean, integer, double point and analog measured values between IEDs. DNP3 protocol DNP3 (Distributed Network Protocol) is a set of communications protocols used to communicate data between components in process automation systems. For a detailed description of the DNP3 protocol, see the DNP3 Communication protocol manual. IEC 60870-5-103 communication protocol IEC 60870-5-103 is an unbalanced (masterslave) protocol for coded-bit serial communication exchanging information with a control system, and with a data transfer rate up to 38400 bit/s. In IEC terminology, a primary station is a master and a secondary station is a slave. The communication is based on a point-to-point principle. The master must have software that can interpret IEC 60870-5-103 communication messages. Table 1. Supported communication interface and protocol alternatives Interfaces/ Protocols Ethernet 100BASEFX LC IEC 61850-8-1 ● DNP3 ● IEC 60870-5-103 ● = Supported 30 ST connector 17. Hardware description Layout and dimensions Mounting alternatives The following mounting alternatives are available (IP40 protection from the front): ● • 19” rack mounting kit • Wall mounting kit • Flush mounting kit • 19" dual rack mounting kit ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 See ordering for details about available mounting alternatives. Rack mounting the IED Flush mounting the IED K A H B D C IJ E D E F G C A B IEC09000672.ai IEC09000676.ai IEC09000672 V1 EN IEC09000676 V1 EN Figure 7. Flush mounting the IED into a panel cut-out A 240 mm G 21.55 mm B 21.55 mm H 220 mm C 227 mm I 265.9 mm D 228.9 mm J 300 mm E 272 mm K 254 mm F ∅6 mm Figure 9. Rack mounted IED A 224 mm + 12 mm with ring-lug connector B 25.5 mm C 482.6 mm (19") D 265.9 mm (6U) E 13 mm A E B D A B C IEC09000677.ai C IEC09000677 V1 EN Figure 10. Two rack mounted IEDs side by side IEC09000673.ai IEC09000673 V1 EN Figure 8. Flush mounted IED ABB A 222 mm B 27 mm C 13 mm A 224 mm + 12 mm with ring-lug connector B 25.5 mm C 482.6 mm (19") D 13 mm E 265.9 mm (6U) 31 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Wall mounting the IED A B F C D E G IEC09000678.ai IEC09000678 V1 EN Figure 11. Wall mounting the IED A 270 mm E 190.5 mm B 252.5 mm F 296 mm C ∅6.8 mm G 13 mm D 268.9 mm 32 GUID-5C185EAC-13D0-40BD-8511-58CA53EFF7DE V1 EN Figure 12. Main unit and detached LHMI display A 25.5 mm E 258.6 mm B 220 mm F 265.9 mm C 13 mm G 224 mm D 265.9 mm ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 18. Connection diagrams Module Slot Rear Position COM pCOM X0, X1, X4, X9,X304 PSM pPSM X307, X309, X410 TRM p2 X101, X102 AIM p4 X103, X104 BIO p5 X331, X334 BIO p6 X336, X339 1MRK006501-NB 2 PG 1.1 IEC V1 EN Figure 13. Designation for 6U, 1/2x19" casing with 1 TRM and 1 AIM ABB 33 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Connection diagrams for REG650 B01 1MRK006501-NB 5 PG 1.1 IEC V1 EN Figure 16. Power supply module (PSM), 110-250V DC 1MRK006501-NB 3 PG 1.1 IEC V1 EN Figure 14. Communication module (COM) 1MRK006501-NB 6 PG 1.1 IEC V1 EN Figure 17. Transformer module (TRM) 1MRK006501-NB 4 PG 1.1 IEC V1 EN Figure 15. Power supply module (PSM) 48-125V DC 34 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Connection diagrams for REG650 B05 1MRK006501-NB 7 PG 1.1 IEC V1 EN Figure 18. Analog input module (AIM) 1MRK006501-PB 3 PG 1.1 IEC V1 EN Figure 20. Communication module (COM) 1MRK006501-NB 8 PG 1.1 IEC V1 EN Figure 19. Binary input/output (BIO) option (Terminal X331, X334) ABB 1MRK006501-PB 4 PG 1.1 IEC V1 EN Figure 21. Power supply module (PSM) 48-125V DC 35 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 1MRK006501-PB 5 PG 1.1 IEC V1 EN Figure 22. Power supply module (PSM), 110-250V DC 1MRK006501-PB 7 PG 1.1 IEC V1 EN Figure 24. Analog input module (AIM) 1MRK006501-PB 6 PG 1.1 IEC V1 EN Figure 23. Transformer module (TRM) 1MRK006501-PB 8 PG 1.1 IEC V1 EN Figure 25. Binary input/output (BIO) option (Terminal X331, X334) 36 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 19. Technical data General Definitions Reference value The specified value of an influencing factor to which are referred the characteristics of the equipment Nominal range The range of values of an influencing quantity (factor) within which, under specified conditions, the equipment meets the specified requirements Operative range The range of values of a given energizing quantity for which the equipment, under specified conditions, is able to perform its intended functions according to the specified requirements Energizing quantities, rated values and limits ABB 37 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Analog inputs Table 2. Energizing inputs Description Value Rated frequency 50/60 Hz Operating range Rated frequency ± 5 Hz Current inputs Rated current, In 0.1/0.5 A1) 1/5 A2) • Continuously 4A 20 A • For 1 s 100 A 500 A • For 10 s 20 A 100 A • Half-wave value 250 A 1250 A Input impedance <100 mΩ <20 mΩ Rated voltage, Un 100 V AC/ 110 V AC/ 115 V AC/ 120 V AC Thermal withstand capability: Dynamic current withstand: Voltage inputs Voltage withstand: • Continuous 420 V rms • For 10 s 450 V rms Burden at rated voltage <0.05 VA 1) Residual current 2) Phase currents or residual current 38 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Auxiliary DC voltage Table 3. Power supply Description Type 1 Type 2 Uauxnominal 100, 110, 120, 220, 240 V AC, 50 and 60 Hz 48, 60, 110, 125 V DC 110, 125, 220, 250 V DC Uauxvariation 85...110% of Un (85...264 V AC) 80...120% of Un (38.4...150 V DC) 80...120% of Un (88...300 V DC) Maximum load of auxiliary voltage supply 35 W Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 Hz) Maximum interruption time in the auxiliary DC voltage without resetting the IED 50 ms at Uaux Binary inputs and outputs Table 4. Binary inputs ABB Description Value Operating range Maximum input voltage 300 V DC Rated voltage 24...250 V DC Current drain 1.6...1.8 mA Power consumption/input <0.3 W Threshold voltage 15...221 V DC (parametrizable in the range in steps of 1% of the rated voltage) 39 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 5. Signal output and IRF output IRF relay change over - type signal output relay Description Value Rated voltage 250 V AC/DC Continuous contact carry 5A Make and carry for 3.0 s 10 A Make and carry 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at U< 48/110/220 V DC ≤0.5 A/≤0.1 A/≤0.04 A Table 6. Power output relays without TCS function Description Value Rated voltage 250 V AC/DC Continuous contact carry 8A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at U< 48/110/220 V DC ≤1 A/≤0.3 A/≤0.1 A Table 7. Power output relays with TCS function Description Value Rated voltage 250 V DC Continuous contact carry 8A Make and carry for 3.0 s 15 A Make and carry for 0.5 s 30 A Breaking capacity when the control-circuit time constant L/R<40 ms, at U< 48/110/220 V DC ≤1 A/≤0.3 A/≤0.1 A Control voltage range 20...250 V DC Current drain through the supervision circuit ~1.0 mA Minimum voltage over the TCS contact 20 V DC 40 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 8. Ethernet interfaces Ethernet interface Protocol Cable Data transfer rate LAN/HMI port (X0)1) - CAT 6 S/FTP or better 100 MBits/s LAN1 (X1) TCP/IP protocol Fibre-optic cable with LC connector 100 MBits/s 1) Only available for the external HMI option. Table 9. Fibre-optic communication link Wave length Fibre type Connector Permitted path attenuation1) Distance 1300 nm MM 62.5/125 μm glass fibre core LC <8 dB 2 km 1) Maximum allowed attenuation caused by connectors and cable together Table 10. X4/IRIG-B interface Type Protocol Cable Screw terminal, pin row header IRIG-B Shielded twisted pair cable Recommended: CAT 5, Belden RS-485 (98419844) or Alpha Wire (Alpha 6222-6230) Table 11. Serial rear interface Type Counter connector Serial port (X9) Optical serial port, type ST for IEC 60870-5-103 Influencing factors Table 12. Degree of protection of flush-mounted IED Description Value Front side IP 40 Rear side, connection terminals IP 20 Table 13. Degree of protection of the LHMI ABB Description Value Front and side IP 42 41 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 14. Environmental conditions Description Value Operating temperature range -25...+55ºC (continuous) Short-time service temperature range -40...+70ºC (<16h) Note: Degradation in MTBF and HMI performance outside the temperature range of -25...+55ºC Relative humidity <93%, non-condensing Atmospheric pressure 86...106 kPa Altitude up to 2000 m Transport and storage temperature range -40...+85ºC Table 15. Environmental tests Description Cold tests Type test value Reference operation 96 h at -25ºC 16 h at -40ºC IEC 60068-2-1 storage 96 h at -40ºC Dry heat tests operation Damp heat tests 42 16 h at +70ºC IEC 60068-2-2 storage 96 h at +85ºC steady state 240 h at +40ºC humidity 93% IEC 60068-2-78 cyclic 6 cycles at +25 to +55ºC humidity 93...95% IEC 60068-2-30 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Type tests according to standards Table 16. Electromagnetic compatibility tests Description Type test value 100 kHz and 1 MHz burst disturbance test Reference IEC 61000-4-18 IEC 60255-22-1, level 3 • Common mode 2.5 kV • Differential mode 1.0 kV Electrostatic discharge test IEC 61000-4-2 IEC 60255-22-2, level 4 • Contact discharge 8 kV • Air discharge 15 kV Radio frequency interference tests • Conducted, common mode 10 V (emf), f=150 kHz...80 MHz IEC 61000-4-6 IEC 60255-22-6, level 3 • Radiated, amplitudemodulated 20 V/m (rms), f=80...1000 MHz and f=1.4...2.7 GHz IEC 61000-4-3 IEC 60255-22-3, level 3 Fast transient disturbance tests IEC 61000-4-4 IEC 60255-22-4, class A • Communication ports 2 kV • Other ports 4 kV Surge immunity test IEC 61000-4-5 IEC 60255-22-5, level 3/2 • Communication 1 kV line-to-earth • Other ports 2 kV line-to-earth, 1 kV lineto-line Power frequency (50 Hz) magnetic field ABB IEC 61000-4-8, level 5 •3s 1000 A/m • Continuous 100 A/m 43 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 16. Electromagnetic compatibility tests, continued Description Power frequency immunity test • Common mode Type test value Reference 300 V rms IEC 60255-22-7, class A IEC 61000-4-16 150 V rms • Differential mode Voltage dips and short interruptions Dips: 40%/200 ms 70%/500 ms Interruptions: 0-50 ms: No restart 0...∞ s : Correct behaviour at power down Electromagnetic emission tests IEC 60255-11 IEC 61000-4-11 EN 55011, class A IEC 60255-25 • Conducted, RF-emission (mains terminal) 0.15...0.50 MHz < 79 dB(µV) quasi peak < 66 dB(µV) average 0.5...30 MHz < 73 dB(µV) quasi peak < 60 dB(µV) average • Radiated RF-emission 30...230 MHz < 40 dB(µV/m) quasi peak, measured at 10 m distance 230...1000 MHz < 47 dB(µV/m) quasi peak, measured at 10 m distance 44 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 17. Insulation tests Description Type test value Dielectric tests: • Test voltage IEC 60255-5 2 kV, 50 Hz, 1 min 1 kV, 50 Hz, 1 min, communication Impulse voltage test: • Test voltage IEC 60255-5 5 kV, unipolar impulses, waveform 1.2/50 μs, source energy 0.5 J 1 kV, unipolar impulses, waveform 1.2/50 μs, source energy 0.5 J, communication Insulation resistance measurements • Isolation resistance IEC 60255-5 >100 MΏ, 500 V DC Protective bonding resistance • Resistance Reference IEC 60255-27 <0.1 Ώ (60 s) Table 18. Mechanical tests Description Reference Requirement Vibration response tests (sinusoidal) IEC 60255-21-1 Class 2 Vibration endurance test IEC60255-21-1 Class 1 Shock response test IEC 60255-21-2 Class 1 Shock withstand test IEC 60255-21-2 Class 1 Bump test IEC 60255-21-2 Class 1 Seismic test IEC 60255-21-3 Class 2 Product safety Table 19. Product safety ABB Description Reference LV directive 2006/95/EC Standard EN 60255-27 (2005) 45 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 EMC compliance Table 20. EMC compliance Description Reference EMC directive 2004/108/EC Standard EN 50263 (2000) EN 60255-26 (2007) 46 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Differential protection Table 21. Transformer differential protection T2WPDIF, T3WPDIF ABB Function Range or value Accuracy Operating characteristic Adaptable ± 1.0% of Ir for I < Ir ± 1.0% of Ir for I > Ir Reset ratio >94% - Unrestrained differential current limit (1.00-50.00)xIBase on high voltage winding ± 1.0% of set value Base sensitivity function (0.05 - 0.60) x IBase ± 1.0% of Ir Minimum negative sequence current (0.02 - 0.20) x IBase ± 1.0% of Ir Operate angle, negative sequence (30.0 - 90.0) degrees ± 1.0 degrees Second harmonic blocking (5.0-100.0)% of ± 2.0% of Ir fundamental differential current Fifth harmonic blocking (5.0-100.0)% of ± 12.0% of Ir fundamental differential current Connection type for each of the windings Y or D - Phase displacement between high voltage winding, W1 and each of the windings, W2 and W3. Hour notation 0–11 - Operate time, restrained function 25 ms typically at 0 to 5 x Ib - Reset time, restrained function 25 ms typically at 5 to 0 x Ib - Operate time, unrestrained function 20 ms typically at 0 to 5 x Ib - Reset time, unrestrained function 25 ms typically at 5 to 0 x Ib - 47 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 22. 1Ph High impedance differential protection HZPDIF Function Range or value Accuracy Operate voltage (20-400) V I=U/R ± 1.0% of Ir Reset ratio >95% - Maximum continuous voltage U>Trip2/series resistor ≤200 W - Operate time 15 ms typically at 0 to 10 x Ud - Reset time 90 ms typically at 10 to 0 x Ud - Critical impulse time 2 ms typically at 0 to 10 x Ud - Table 23. Generator differential protection GENPDIF Function Range or value Accuracy Reset ratio > 90% - Unrestrained differential current limit (1-50)p.u. of IBase ± 1.0% of set value Base sensitivity function (0.05–1.00)p.u. of IBase ± 1.0% of Ir Negative sequence current level (0.02–0.2)p.u. of IBase ± 1.0% of Ir Operate time, restrained function 40 ms typically at 0 to 2 x set level - Reset time, restrained function 40 ms typically at 2 to 0 x set level - Operate time, unrestrained function 20 ms typically at 0 to 5 x set level - Reset time, unrestrained function 40 ms typically at 5 to 0 x set level - Operate time, negative sequence unrestrained function 15 ms typically at 0 to 5 x set level - Critical impulse time, unrestrained 2 ms typically at 0 function to 5 x set level 48 - ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Impedance protection Table 24. Underimpedance protection for generators and transformers ZGPDIS Function Range or value Accuracy Number of zones 3 - Forward positive sequence impedance (0.005-3000.000) Ω/phase ± 2.0% static accuracy Conditions: • Voltage range: (0.1-1.1) x Ur • Current range: (0.5-30) x Ir • Angle: at 0 degrees and 85 degrees Reverse positive sequence impedance (0.005-3000.000) Ω/phase - Angle for positive sequence impedance, (10-90) degrees - Timers (0.000-60.000) s ± 0.5% ± 10 ms Operate time 55 ms typically - Reset ratio 105% typically - Table 25. Loss of excitation LEXPDIS ABB Function Range or value Accuracy X offset of Mho top point (–1000.00–1000.00)% of ZBase ± 2.0% of Ur/Ir Diameter of Mho circle (0.00–3000.00)% of ZBase ± 2.0% of Ur/Ir Timers (0.00–6000.00) s ± 0.5% ± 25 ms 49 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 26. Out-of-step OOSPPAM Function Range or value Accuracy Remark VOLTAGE 0.1 – 2.0 UBase Better than ±1.5 % of true value or 1 % of rated, whichever is greater Better than ±0.5 % at nominal voltage CURRENT 0.1 – 5.0 IBase Better than ±1.0 % of true value or 1 % of rated, whichever is greater Better than ±0.5 % at nominal current X 0.1 – 2.0 UBase, 0.1 – 5.0 IBase Better than ±3.0 % of true value or 3.0 % of Zbase, whichever is greater Better than ±1 % at nominal current and voltage R 0.1 – 2.0 UBase, 0.1 – 5.0 IBase Better than ±3.0 % of true value or 3.0 % of Zbase, whichever is greater Better than ±1 % at nominal current and voltage P 0.1 – 2.0 UBase, 0.1 – 5.0 IBase Better than ±3.0 % of true value or ±3 % of rated S, whichever is greater Better than ±1 % at nominal current and voltage Q 0.1 – 2.0 UBase, 0.1 – 5.0 IBase Better than ±3.0 % of true value or ±3 % of rated S, whichever is greater Better than ±1 % at nominal current and voltage Better than ±6 degrees Better than ±3 deg at nominal current and voltage Under steady-state conditions with constant slip ROTORANG SLIPFREQ 0.1 – 10 Hz Better than ±50 mHz UCOSPHI 0.1 – 2.0 UBase, 0.1 – 5.0 IBase Better than ±3.0 % of true value or 3.0 % of UBase, whichever is greater Table 27. Load enchroachment LEPDIS Function Load encroachment criteria: Load resistance, forward and reverse Safety load impedance angle Reset ratio 50 Range or value (1.00–3000.00) Ω/phase (5-85) degrees 105% typically Accuracy ± 5.0% static accuracy ± 2.0 degrees static angular accuracy Conditions: Voltage range: (0.1-1.1) x Ur Current range: (0.5-30) x Ir Angle: at 0 degrees and 85 degrees - ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Current protection Table 28. Four step phase overcurrent protection OC4PTOC Function Setting range Accuracy Operate current (5-2500)% of lBase ± 1.0% of Ir at I ≤ Ir ± 1.0% of I at I > Ir ABB Reset ratio > 95% - Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I ≤ Ir ±1.0% of I at I > Ir Independent time delay (0.000-60.000) s ± 0.5% ±25 ms Minimum operate time for inverse characteristics (0.000-60.000) s ± 0.5% ±25ms Inverse characteristics, see table 68, table 69 and table 70 17 curve types See table 68, table 69 and table 70 Operate time, nondirectional start function 20 ms typically at 0 to 2 x Iset - Reset time, nondirectional 30 ms typically at 2 to 0 x Iset start function - Operate time, directional start function 30 ms typically at 0 to 2 x Iset - Reset time, directional start funciton 25 ms typically at 2 to 0 x Iset - Critical impulse time 10 ms typically at 0 to 2 x Iset - Impulse margin time 15 ms typically - 51 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 29. Four step residual overcurrent protection EF4PTOC Function Range or value Accuracy Operate current (1-2500)% of lBase ± 1.0% of Ir at I £ Ir ± 1.0% of I at I > Ir Reset ratio > 95% - Operate current for directional comparison (1–100)% of lBase ± 1.0% of Ir Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I < Ir ± 1.0% of I at I < Ir Minimum operate time for inverse characteristics (0.000-60.000) s ± 0.5% ± 25 ms Timers (0.000-60.000) s ± 0.5% ±25 ms Inverse characteristics, see table 68, table 69 and table 70 17 curve types See table 68, table 69 and table 70 Minimum polarizing voltage (1–100)% of UBase ± 0.5% of Ur Minimum polarizing current (2-100)% of IBase ±1.0% of Ir Real part of source Z used for current polarization (0.50-1000.00) W/phase - Imaginary part of source Z used for current polarization (0.50–3000.00) W/phase - Operate time, nondirectional start function 30 ms typically at 0.5 to 2 x Iset - Reset time, nondirectional start function 30 ms typically at 2 to 0.5 x Iset - Operate time, directional start function 30 ms typically at 0,5 to 2 x IN - Reset time, directional start function 30 ms typically at 2 to 0,5 x IN - 52 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 30. Sensitive directional residual overcurrent and power protection SDEPSDE Function Range or value Accuracy Operate level for 3I0·cosj directional residual overcurrent (0.25-200.00)% of lBase ± 1.0% of Ir at I £ Ir Operate level for 3I0·3U0 · cosj directional residual power Operate level for 3I0 and j residual overcurrent Operate level for nondirectional overcurrent At low setting: (2.5-10) mA (10-50) mA (0.25-200.00)% of SBase At low setting: (0.25-5.00)% of SBase (0.25-200.00)% of lBase At low setting: (2.5-10) mA (10-50) mA (1.00-400.00)% of lBase At low setting: (10-50) mA Operate level for nondirectional residual overvoltage (1.00-200.00)% of UBase Residual release current for all directional modes (0.25-200.00)% of lBase ±0.5 mA ±1.0 mA ± 1.0% of Sr at S £ Sr ± 1.0% of S at S > Sr ± 10% of set value ± 1.0% of Ir at £ Ir ± 1.0% of I at I > Ir ±0.5 mA ±1.0 mA ± 1.0% of Ir at I £ Ir ± 1.0% of I at I > Ir ± 1.0 mA ± 0.5% of Ur at U£Ur ± 0.5% of U at U > Ur At low setting: (2.5-10) mA (10-50) mA ABB ± 1.0% of I at I > Ir ± 1.0% of Ir at I £ Ir ± 1.0% of I at I > Ir ±0.5 mA ± 1.0 mA ± 0.5% of Ur at U£Ur Residual release voltage for all directional modes (1.00 - 300.00)% of UBase Reset ratio > 95% - Timers (0.000-60.000) s ± 0.5% ±25 ms Inverse characteristics, see table 68, table 69 and table 70 17 curve types See table 68, table 69 and table 70 Class 5 + 150 ms Relay characteristic angle RCA (-179 to 180) degrees ± 2.0 degrees Relay open angle ROA (0-90) degrees ± 2.0 degrees ± 0.5% of U at U > Ur 53 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 30. Sensitive directional residual overcurrent and power protection SDEPSDE, continued Function Range or value Accuracy Operate time, nondirectional residual over current 80 ms typically at 0.5 to 2 x Iset - Reset time, nondirectional residual over current 90 ms typically at 1.2 to 0.5 x Iset - Operate time, nondirectional residual overvoltage 70 ms typically at 0.8 to 1.5 x Uset - Reset time, nondirectional residual overvoltage 120 ms typically at 1.2 to 0.8 x Uset - Operate time, directional residual over current 260 ms typically at 0.5 to 2 x Iset - Reset time, directional residual over current 170 ms typically at 2 to 0.5 x Iset - Critical impulse time non- 100 ms typically at 0 to 2 x Iset directional residual over 20 ms typically at 0 to 10 x Iset current - Impulse margin time non- 25 ms typically directional residual over current - 54 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 31. Thermal overload protection, two time constants TRPTTR Function Range or value Accuracy Base current 1 and 2 (30–250)% of IBase ± 1.0% of Ir Operate time: Ip = load current before overload occurs Time constant τ = (1–500) minutes IEC 60255–8, class 5 + 200 ms Alarm level 1 and 2 (50–99)% of heat content trip value ± 2.0% of heat content trip Operate current (50–250)% of IBase ± 1.0% of Ir Reset level temperature (10–95)% of heat content trip ± 2.0% of heat content trip æ I 2 - I p2 t = t × ln ç 2 ç I - Ib 2 è EQUATION1356 V1 EN ö ÷ ÷ ø (Equation 1) I = Imeasured Table 32. Breaker failure protection CCRBRF Function Range or value Accuracy Operate phase current (5-200)% of lBase ± 1.0% of Ir at I £ Ir ± 1.0% of I at I > Ir Reset ratio, phase current > 95% - Operate residual current (2-200)% of lBase ± 1.0% of Ir at I £ Ir ± 1.0% of I at I > Ir ABB Reset ratio, residual current > 95% - Phase current level for blocking of contact function (5-200)% of lBase ± 1.0% of Ir at I £ Ir Reset ratio > 95% - Timers (0.000-60.000) s ± 0.5% ±10 ms Operate time for current detection 35 ms typically - Reset time for current detection 10 ms maximum - ± 1.0% of I at I > Ir 55 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 33. Pole discordance protection CCRPLD Function Range or value Accuracy Operate value, current asymmetry level (0-100) % ± 1.0% of Ir Reset ratio >95% - Time delay (0.000-60.000) s ± 0.5% ± 25 ms Table 34. Directional over/underpower protection GOPPDOP, GUPPDUP Function Range or value Accuracy Power level (0.0–500.0)% of SBase ± 1.0% of Sr at S < Sr ± 1.0% of S at S > Sr1) (1.0-2.0)% of SBase < ± 50% of set value 2) (2.0-10)% of SBase < ± 20% of set value 3) Characteristic angle (-180.0–180.0) degrees 2 degrees Timers (0.010 - 6000.000) s ± 0.5% ± 25 ms 1) 2) 3) 56 Accuracy valid for 50 Hz. At 60 Hz both accuracies are ±2.0% Accuracy valid for 50 Hz. At 60 Hz the accuracy is -50/+100% Accuracy valid for 50 Hz. At 60 Hz the accuracy is ±40% ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 35. Accidental energizing protection for synchronous generator AEGGAPC ABB Function Range or value Accuracy Operate value, overcurrent (2-900)% of IBase ± 1,0% of Ir at I<Ir ± 1.0% of I at I>Ir Reset ratio, overcurrent >95% - Transient overreach, overcurrent function <20% at τ = 100 ms - Critical impulse time, overcurrent 10 ms typically at 0 to 2 x Iset - Impulse margin time, overcurrent 15 ms typically - Operate value, undervoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur ± 0.5% of U at U>Ur Critical impulse time, undervoltage 10 ms typically at 2 to 0 x Uset - Impulse margin time, undervoltage 15 ms typically - Operate value, overvoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur ± 0.5% of U at U>Ur Timers (0.000-60.000) s ± 0.5% ± 25 ms 57 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 36. Negative sequence time overcurrent protection for machines NS2PTOC Function Range or value Accuracy Operate value, step 1 and 2, negative sequence overcurrent (3-500)% of IBase ± 1.0% of Ir at I < Ir ± 1.0% of I at I > Ir Reset ratio, step 1 and 2 >95% - Operate time, start 30 ms typically at 0 to 2 x Iset 20 ms typically at 0 to 10 x Iset - Reset time, start 40 ms typically at 2 to 0 x Iset - Time characteristics Definite or Inverse - Inverse time characteristic K=1.0-99.0 Class 5 + 40 ms K=0.01-20.00 Class 10 + 40 ms Maximum trip delay, step 1 IDMT (0.00-6000.00) s ± 0.5% ± 25 ms Minimum trip delay, step 1 IDMT (0.000-60.000) s ± 0.5% ± 25 ms Timers (0.00-6000.00) s ± 0.5% ± 25 ms 2 step 1, I 2 t = K Reset time, inverse characteristic step 1, I 22t = K 58 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 37. Voltage-restrained time overcurrent protection VR2PVOC ABB Function Range or value Accuracy Start overcurrent (2 - 5000)% of IBase ± 1.0% of Ir at I<Ir ± 1.0% of I at I>Ir Definite time delay (0.00 - 6000.00) s ± 0.5% ± 25 ms Inverse characteristics, see 17 curves type table 68, table 69 and table 70 See table 68, table 69 and table70 Operate time start overcurrent 30 ms typically at 0 to 2 x Iset 20 ms typically at 0 to 10 x Iset - Reset time start overcurrent 40 ms typically at 2 to 0 x Iset - Start undervoltage (2.0 - 100.0)% of UBase ± 0.5 % of Ur Operate time start undervoltage 30 ms typically 2 to 0 x Uset - Reset time start undervoltage 40 ms typically at 0 to 2 x Uset - High voltage limit, voltage dependent operation (30 - 100)% of UBase ± 1.0 % of Ur Reset ratio, overcurrent > 95% - Reset ratio, undervoltage < 105% - Overcurrent: Critical impulse time Impulse margin time 10 ms typically at 0 to 2 x Iset 15 ms typically - 59 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Voltage protection Table 38. Two step undervoltage protection UV2PTUV Function Range or value Accuracy Operate voltage, low and high step (1–100)% of UBase ± 0.5% of Ur Reset ratio <105% - Inverse time characteristics for low and high step, see table 72 - See table 72 Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms Definite time delays, step 2 (0.000-60.000) s ± 0.5% ±25 ms Minimum operate time, inverse characteristics (0.000–60.000) s ± 0.5% ± 25 ms Operate time, start function 30 ms typically at 2 to 0.5 x Uset - Reset time, start function 40 ms typically at 0.5 to 2 x Uset - Critical impulse time 10 ms typically at 2 to 0 x Uset - Impulse margin time 15 ms typically - Table 39. Two step overvoltage protection OV2PTOV Function Range or value Accuracy Operate voltage, low and high step (1-200)% of UBase ± 0.5% of Ur at U < Ur ± 0.5% of U at U > Ur Reset ratio >95% - Inverse time characteristics for low and high step, see table 71 - See table 71 Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms Definite time delays, step 2 (0.000-60.000) s ± 0.5% ± 25 ms Minimum operate time, Inverse characteristics (0.000-60.000) s ± 0.5% ± 25 ms Operate time, start function 30 ms typically at 0 to 2 x Uset - Reset time, start function 40 ms typically at 2 to 0 x Uset - Critical impulse time 10 ms typically at 0 to 2 x Uset - Impulse margin time 15 ms typically - 60 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 40. Two step residual overvoltage protection ROV2PTOV Function Range or value Accuracy Operate voltage, step 1 (1-200)% of UBase ± 0.5% of Ur at U < Ur ± 0.5% of U at U > Ur Operate voltage, step 2 (1–100)% of UBase ± 0.5% of Ur at U < Ur ± 0.5% of U at U > Ur Reset ratio >95% - Inverse time characteristics for low and high step, see table 73 - See table 73 Definite time setting, step 1 (0.00–6000.00) s ± 0.5% ± 25 ms Definite time setting, step 2 (0.000–60.000) s ± 0.5% ± 25 ms Minimum operate time for step 1 inverse characteristic (0.000-60.000) s ± 0.5% ± 25 ms Operate time, start function 30 ms typically at 0 to 2 x Uset - Reset time, start function 40 ms typically at 2 to 0 x Uset - Critical impulse time 10 ms typically at 0 to 2 x Uset - Impulse margin time 15 ms typically - Table 41. Overexcitation protection OEXPVPH Function Range or value Accuracy Operate value, start (100–180)% of (UBase/frated) ± 0.5% of U Operate value, alarm (50–120)% of start level ± 0.5% of Ur at U ≤ Ur ± 0.5% of U at U > Ur Operate value, high level (100–200)% of (UBase/frated) ± 0.5% of U Curve type IEEE Class 5 + 40 ms IEEE : t = (0.18 × k ) ( M - 1) 2 EQUATION1319 V1 EN (Equation 2) where M = (E/f)/(Ur/fr) ABB Minimum time delay for inverse function (0.000–60.000) s ± 0.5% ± 25 ms Alarm time delay (0.000–60.000) s ± 0.5% ± 25 ms 61 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 42. 100% Stator E/F 3rd harmonic STEFPHIZ Function Range or value Accuracy Fundamental frequency level UN (95% Stator EF) (1.0–50.0)% of UBase ± 0.5% of Ur Third harmonic differential level (0.5–10.0)% of UBase ± 5.0% of Ur Third harmonic differential block level (0.1–10.0)% of UBase ± 5.0% of Ur Timers (0.020–60.000) s ± 0.5% ± 25 ms Filter characteristic: Fundamental Third harmonic Reject third harmonic by 1–40 Reject fundamental harmonic by 1–40 Frequency protection Table 43. Under frequency protection SAPTUF Function Range or value Accuracy Operate value, start function (35.00-75.00) Hz ± 2.0 mHz Operate value, restore frequency (45 - 65) Hz ± 2.0 mHz Operate time, start function At 50 Hz: 200 ms typically at fset +0.5 Hz to fset -0.5 Hz At 60 Hz: 170 ms typically at fset +0.5 Hz to fset -0.5 Hz - Reset time, start function At 50 Hz: 60 ms typically at fset -0.5 Hz to fset +0.5 Hz At 60 Hz: 50 ms typically at fset -0.5 Hz to fset +0.5 Hz - Operate time delay (0.000-60.000)s <250 ms Restore time delay (0.000-60.000)s <150 ms 62 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 44. Overfrequency protection SAPTOF Function Range or value Accuracy Operate value, start function (35.00-75.00) Hz ± 2.0 mHz at symmetrical three-phase voltage Operate time, start function At 50 Hz: 200 ms typically at fset -0.5 Hz to fset +0.5 Hz At 60 Hz: 170 ms at fset -0.5 Hz to fset +0.5 Hz - Reset time, start function At 50 and 60 Hz: 55 ms typically at fset +0.5 Hz to fset-0.5 Hz - Timer (0.000-60.000)s <250 ms Table 45. Rate-of-change frequency protection SAPFRC ABB Function Range or value Accuracy Operate value, start function (-10.00-10.00) Hz/s ± 10.0 mHz/s Operate value, restore enable frequency (45.00 - 65.00) Hz ± 2.0 mHz Timers (0.000 - 60.000) s <130 ms Operate time, start function At 50 Hz: 100 ms typically At 60 Hz: 80 ms typically 63 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Secondary system supervision Table 46. Fuse failure supervision SDDRFUF Function Range or value Accuracy Operate voltage, zero sequence (1-100)% of UBase ± 1.0% of Ur Operate current, zero sequence (1–100)% of IBase ± 1.0% of Ir Operate voltage, negative sequence (1–100)% of UBase ± 0.5% of Ur Operate current, negative sequence (1–100)% of IBase ± 1.0% of Ir Operate voltage change level (1–100)% of UBase ± 5.0% of Ur Operate current change level (1–100)% of IBase ± 5.0% of Ir Operate phase voltage (1-100)% of UBase ± 0.5% of Ur Operate phase current (1-100)% of IBase ± 1.0% of Ir Operate phase dead line voltage (1-100)% of UBase ± 0.5% of Ur Operate phase dead line current (1-100)% of IBase ± 1.0% of Ir Table 47. Breaker close/trip circuit monitoring TCSSCBR Function Range or value Accuracy Operate time delay (0.020 - 300.000) s ± 0,5% ± 110 ms 64 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Control Table 48. Synchronizing, synchrocheck and energizing check SESRSYN Function Range or value Accuracy Phase shift, jline - jbus (-180 to 180) degrees - Voltage ratio, Ubus/Uline 0.2 to 5.0 - Frequency difference limit between bus and line (0.003-1.000) Hz ± 2.0 mHz Phase angle difference limit between bus and line (5.0-90.0) degrees ± 2.0 degrees Voltage difference limit between bus and line ± 0.5% of Ur Time delay output for synchrocheck (0.000-60.000) s ± 0.5% ± 25 ms Time delay for energizing check (0.000-60.000) s ± 0.5% ± 25 ms Closing time for the circuit breaker (0.000-60.000) s ± 0.5% ± 25 ms Logic Table 49. Tripping logic SMPPTRC ABB Function Range or value Accuracy Trip action 3-ph - Timers (0.000-60.000) s ± 0.5% ± 10 ms 65 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 50. Configurable logic blocks Logic block Quantity with cycle time Range or value Accuracy 5 ms 20 ms 100 ms AND 60 60 160 - - OR 60 60 160 - - XOR 10 10 20 - - INVERTER 30 30 80 - - SRMEMORY 10 10 20 - - RSMEMORY 10 10 20 - - GATE 10 10 20 - - PULSETIMER 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms TIMERSET 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms LOOPDELAY 10 10 20 Monitoring Table 51. Measurements CVMMXN Function Range or value Accuracy Voltage (0.1-1.5) ×Ur ± 0.5% of Ur at U£Ur ± 0.5% of U at U > Ur Connected current (0.2-4.0) × Ir ± 0.5% of Ir at I £ Ir ± 0.5% of I at I > Ir Active power, P 0.1 x Ur< U < 1.5 x Ur 0.2 x Ir < I < 4.0 x Ir ± 1.0% of Sr at S ≤ Sr ± 1.0% of S at S > Sr 1) Reactive power, Q 0.1 x Ur< U < 1.5 x Ur 0.2 x Ir < I < 4.0 x Ir ± 1.0% of Sr at S ≤ Sr ± 1.0% of S at S > Sr 1) Apparent power, S 0.1 x Ur < U < 1.5 x Ur 0.2 x Ir< I < 4.0 x Ir ± 1.0% of Sr at S ≤ Sr ± 1.0% of S at S > Sr Apparent power, S Three phase settings cos phi = 1 ± 0.5% of S at S > Sr ± 0.5% of Sr at S ≤ Sr Power factor, cos (φ) 0.1 x Ur < U < 1.5 x Ur 0.2 x Ir< I < 4.0 x Ir < 0.02 1) 2) 66 2) Accuracy valid for 50 Hz. At 60 Hz both accuracies are ±2.0% Accuracy valid for 50 Hz. At 60 Hz the accuracy is <0.04. ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 52. Event counter CNTGGIO ABB Function Range or value Accuracy Counter value 0-10000 - Max. count up speed 10 pulses/s - 67 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 53. Disturbance report DRPRDRE Function Range or value Accuracy Current recording - ± 1,0% of Ir at I ≤ Ir ± 1,0% of I at I > Ir Voltage recording - ± 1,0% of Ur at U ≤ Ur ± 1,0% of U at U > Ur Pre-fault time (0.05–3.00) s - Post-fault time (0.1–10.0) s - Limit time (0.5–8.0) s - Maximum number of recordings 100, first in - first out - Time tagging resolution 1 ms See time synchronization technical data Maximum number of analog inputs 30 + 10 (external + internally derived) - Maximum number of binary inputs 96 - Maximum number of phasors in the Trip Value recorder per recording 30 - Maximum number of indications in a disturbance report 96 - Maximum number of events in the Event recording per recording 150 - Maximum number of events in the Event list 1000, first in - first out - Maximum total recording time (3.4 s recording time and maximum number of channels, typical value) 340 seconds (100 recordings) at 50 Hz, 280 seconds (80 recordings) at 60 Hz - Sampling rate 1 kHz at 50 Hz 1.2 kHz at 60 Hz - Recording bandwidth (5-300) Hz - 68 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 54. Event list DRPRDRE Function Buffer capacity Value Maximum number of events in the list 1000 Resolution 1 ms Accuracy Depending on time synchronizing Table 55. Indications DRPRDRE Function Buffer capacity Value Maximum number of indications presented for single disturbance 96 Maximum number of recorded disturbances 100 Table 56. Event recorder DRPRDRE Function Buffer capacity Value Maximum number of events in disturbance report 150 Maximum number of disturbance reports 100 Resolution 1 ms Accuracy Depending on time synchronizing Table 57. Trip value recorder DRPRDRE Function Buffer capacity ABB Value Maximum number of analog inputs 30 Maximum number of disturbance reports 100 69 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 58. Disturbance recorder DRPRDRE Function Buffer capacity Value Maximum number of analog inputs 40 Maximum number of binary inputs 96 Maximum number of disturbance reports 100 Maximum total recording time (3.4 s recording time and maximum number of channels, typical value) 340 seconds (100 recordings) at 50 Hz 280 seconds (80 recordings) at 60 Hz Table 59. Station battery supervision SPVNZBAT Function Range or value Accuracy Lower limit for the battery terminal voltage (60-140) % of Ubat ± 1.0% of set battery voltage Reset ratio, lower limit <105 % - Upper limit for the battery terminal voltage (60-140) % of Ubat ± 1.0% of set battery voltage Reset ratio, upper limit >95 % - Timers (0.000-60.000) s ± 0.5% ± 110 ms Table 60. Insulation gas monitoring function SSIMG Function Range or value Accuracy Pressure alarm 0.00-25.00 - Pressure lockout 0.00-25.00 - Temperature alarm -40.00-200.00 - Temperature lockout -40.00-200.00 - Timers (0.000-60.000) s ± 0.5% ± 110 ms Table 61. Insulation liquid monitoring function SSIML Function Range or value Accuracy Alarm, oil level 0.00-25.00 - Oil level lockout 0.00-25.00 - Temperature alarm -40.00-200.00 - Temperature lockout -40.00-200.00 - Timers (0.000-60.000) s ± 0.5% ± 110 ms 70 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 62. Circuit breaker condition monitoring SSCBR Function Range or value Accuracy Alarm levels for open and close travel time (0-200) ms ± 0.5% ± 25 ms Alarm levels for number of operations (0 - 9999) - Setting of alarm for spring charging time (0.00-60.00) s ± 0.5% ± 25 ms Time delay for gas pressure alarm (0.00-60.00) s ± 0.5% ± 25 ms Time delay for gas pressure lockout (0.00-60.00) s ± 0.5% ± 25 ms Metering Table 63. Pulse counter PCGGIO Function Setting range Accuracy Cycle time for report of counter value (1–3600) s - Table 64. Function for energy calculation and demand handling ETPMMTR Function Range or value Accuracy Energy metering MWh Export/Import, MVArh Export/Import Input from MMXU. No extra error at steady load Hardware IED Table 65. Degree of protection of flush-mounted IED Description Value Front side IP 40 Rear side, connection terminals IP 20 Table 66. Degree of protection of the LHMI ABB Description Value Front and side IP 42 71 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Dimensions Table 67. Dimensions Description Value Width 220 mm Height 265.9 mm (6U) Depth 249.5 mm Weight box <10 kg (6U) Weight LHMI 1.3 kg (6U) Inverse time characteristics Table 68. ANSI Inverse time characteristics Function Range or value Accuracy Operating characteristic: k = (0.05-999) in steps of 0.01 unless otherwise stated - ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0 ANSI Very inverse A=19.61, B=0.491, P=2.0 ANSI/IEEE C37.112, class 5 + 40 ms ANSI Normal Inverse A=0.0086, B=0.0185, P=0.02, tr=0.46 ANSI Moderately Inverse A=0.0515, B=0.1140, P=0.02 ANSI Long Time Extremely Inverse A=64.07, B=0.250, P=2.0 ANSI Long Time Very Inverse A=28.55, B=0.712, P=2.0 ANSI Long Time Inverse k=(0.05-999) in steps of 0.01 A=0.086, B=0.185, P=0.02 t = æ A ç P ç ( I - 1) è ö ÷ ø + B÷ × k EQUATION1249-SMALL V1 EN I = Imeasured/Iset 72 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 69. IEC Inverse time characteristics Function Range or value Accuracy Operating characteristic: k = (0.05-999) in steps of 0.01 - IEC Normal Inverse A=0.14, P=0.02 IEC Very inverse A=13.5, P=1.0 IEC 60255-151, class 5 + 40 ms IEC Inverse A=0.14, P=0.02 IEC Extremely inverse A=80.0, P=2.0 IEC Short time inverse A=0.05, P=0.04 IEC Long time inverse A=120, P=1.0 t = æ A ö ç P ÷×k ç ( I - 1) ÷ è ø EQUATION1251-SMALL V1 EN I = Imeasured/Iset Table 70. RI and RD type inverse time characteristics Function Range or value Accuracy RI type inverse characteristic k = (0.05-999) in steps of 0.01 IEC 60255-151, class 5 + 40 ms k = (0.05-999) in steps of 0.01 IEC 60255-151, class 5 + 40 ms 1 t = 0.339 - ×k 0.236 I EQUATION1137-SMALL V1 EN I = Imeasured/Iset RD type logarithmic inverse characteristic æ è t = 5.8 - ç 1.35 × In ö ÷ kø I EQUATION1138-SMALL V1 EN I = Imeasured/Iset ABB 73 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 71. Inverse time characteristics for overvoltage protection Function Range or value Accuracy Type A curve: k = (0.05-1.10) in steps of 0.01 unless otherwise stated Class 5 +40 ms t = k æU -U >ö ç ÷ è U> ø EQUATION1436-SMALL V1 EN U> = Uset U = Umeasured Type B curve: t = k = (0.05-1.10) in steps of 0.01 unless otherwise stated k × 480 æ 32 × U - U > - 0.5 ö ç ÷ U > è ø 2.0 - 0.035 EQUATION1437-SMALL V1 EN Type C curve: t = k = (0.05-1.10) in steps of 0.01 unless otherwise stated k × 480 æ 32 × U - U > - 0.5 ö ç ÷ U > è ø 3.0 - 0.035 EQUATION1438-SMALL V1 EN 74 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 72. Inverse time characteristics for undervoltage protection Function Range or value Accuracy Type A curve: k = (0.05-1.10) in steps of 0.01 unless otherwise stated Class 5 +40 ms t = k æ U < -U ö ç ÷ è U< ø EQUATION1431-SMALL V1 EN U< = Uset U = UVmeasured Type B curve: t = k = (0.05-1.10) in steps of 0.01 unless otherwise stated k × 480 æ 32 × U < -U - 0.5 ö ç ÷ U < è ø 2.0 + 0.055 EQUATION1432-SMALL V1 EN U< = Uset U = Umeasured ABB 75 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Table 73. Inverse time characteristics for residual overvoltage protection Function Range or value Accuracy Type A curve: k = (0.05-1.10) in steps of 0.01 Class 5 +40 ms t = k æU -U >ö ç ÷ è U> ø EQUATION1436-SMALL V1 EN U> = Uset U = Umeasured Type B curve: t = k = (0.05-1.10) in steps of 0.01 k × 480 æ 32 × U - U > - 0.5 ö ç ÷ U > è ø 2.0 - 0.035 EQUATION1437-SMALL V1 EN Type C curve: t = k = (0.05-1.10) in steps of 0.01 k × 480 æ 32 × U - U > - 0.5 ö ç ÷ U > è ø 3.0 - 0.035 EQUATION1438-SMALL V1 EN 76 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 20. Ordering Guidelines Carefully read and follow the set of rules to ensure problem-free order management. Please refer to the available functions table for included application functions. To obtain the complete ordering code, please combine code from the tables, as given in the example below. Exemple code: REG650*1.1-B01X00-X00-B1A5-B-A-SA-AB1-RA3B1-AX-E. Using the code of each position #1-11 specified as REG650*1-2 2-3-4 4-5-6-7 7-8 8-9 9 9-10 10 10 10-11 # 1 - 3 - 4 - 5 - - - - 6 - 7 - 8 - 9 - 10 - 1 1 - - - - - Position REG650* - 2 SOFTWARE #1 Notes and Rules Version number 1.1 Version no Selection for position #1. Configuration alternatives 1.1 #2 Generator protection, IEC B01 Generator-Transformer protection, IEC B05 Notes and Rules ACT configuration ABB standard configuration X00 Selection for position #2. X00 Software options #3 No option Notes and Rules X00 Selection for postition #3 First HMI language X00 #4 English IEC Notes and Rules B1 Selection for position #4. Additional HMI language #4 No second HMI language X0 Chinese A5 Selection for position #4. B1 Casing #5 Rack casing, 6 U 1/2 x 19" B Selection for position #5. ABB Notes and Rules B 77 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Mounting details with IP40 of protection from the front #6 No mounting kit included X Rack mounting kit for 6 U 1/2 x 19" A Wall mounting kit for 6U 1/2 x 19" D Flush mounting kit for 6U 1/2 x 19" E Wall mounting bracket 6U 1/2 x 19" G Notes and Rules Selection for position #6. Connection type for Power supply, Input/output and Communication modules #7 Compression terminals S Ringlug terminals R Notes and Rules pPSM Power supply Slot position: 100-240V AC, 110-250V DC, 9BO A 48-125V DC, 9BO B Selection for position #7. Human machine interface #8 Local human machine interface, OL3000, IEC 6U 1/2 x 19", Basic Notes and Rules A Detached LHMI No detached mounting of LHMI X0 Detached mounting of LHMI incl. Ethernet cable, 1m B1 Detached mounting of LHMI incl. Ethernet cable, 2m B2 Detached mounting of LHMI incl. Ethernet cable, 3m B3 Detached mounting of LHMI incl. Ethernet cable, 4m B4 Detached mounting of LHMI incl. Ethernet cable, 5m B5 Selection for position #8. A Connection type for Analog modules #9 Compression terminals S Ringlug terminals R Notes and Rules Transformer module, 4I, 1/5A+1I, 0.1/0.5A+5U, 100/220V A3 Slot position: p4 Slot position: p2 Analog system Analog input module, 6I + 4U, 1/5A, 100/220V B1 Selection for position #9. 78 A3 B1 ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Notes and Rules p6 #10 p5 Binary input/output module No board in slot X X Binary input/output module 9 BI, 3 NO Trip, 5 NO Signal, 1 CO Signal A Slot position (rear view) Available slots in 1/2 case Selection for position #10. AIM in p4 p5 basic, p6 optional A #11 Notes and Rules pCOM Communication and processing module Slot position (rear view) 14BI, IRIG-B, Ethernet, LC, ST B Selection for position #11. B Accessories Rack mounting kit for 2 x 6U 1/2 x 19" Quantity: 1KHL400240R0001 External resistor unit High impedance resistor unit 1-ph with resistor and voltage dependent resistor for 20-100V operating voltage Quantity: RK795101-MA High impedance resistor unit 1-ph with resistor and voltage dependent resistor for 100-400V operating voltage Quantity: RK795101-CB Configuration and monitoring tools Front connection cable between LCD-HMI and PC Quantity: 1MRK 001 665-CA LED Label special paper A4, 1 pc Quantity: 1MRK 002 038-CA LED Label special paper Letter, 1 pc Quantity: 1MRK 002 038-DA Injection unit for Rotor earth fault protection (RXTTE 4) Quantity: 1MRK 002 108-BA Protective resistor on plate Quantity: RK795102-AD External interface units for Rotor earth fault protection ABB 79 Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Manuals Note: One (1) IED Connect CD containing user documentation (Operation manual, Technical manual, Installation manual, Commissioning manual, Application manual, Communication protocol manual, DNP, Communication protocol manual, IEC61850, Communication protocol manual, IEC60870-5-103, Type test certificate, Engineering manual and Point list manual, DNP3, Connectivity packages and LED label template is always included for each IED. Rule: Specify additional quantity of IED Connect CD requested User documentation Quantity: 1MRK 003 500-AA Rule: Specify the number of printed manuals requested Operation manual IEC Quantity: 1MRK 500 093-UEN Technical manual IEC Quantity: 1MRK 502 034-UEN Commissioning manual IEC Quantity: 1MRK 502 035-UEN Application manual IEC Quantity: 1MRK 502 033-UEN Communication protocol manual, DNP3 IEC Quantity: 1MRK 511 241-UEN Communication protocol manual, IEC 61850 IEC Quantity: 1MRK 511 242-UEN Communication protocol manual, IEC 60870-5-103 IEC Quantity: 1MRK 511 243-UEN Engineering manual IEC Quantity: 1MRK 511 245-UEN Installation manual IEC Quantity: 1MRK 514 014-UEN Point list manual, DNP3 IEC Quantity: 1MRK 511 244-UEN Reference information For our reference and statistics we would be pleased to be provided with the following application data: Country: End user: Station name: Voltage level: 80 kV ABB Generator protection REG650 Product version: 1.1 1MRK 502 036-BEN Issued: February 2011 Related documents ABB Documents related to REG650 Identity number Application manual 1MRK 502 033-UEN Technical manual 1MRK 502 034-UEN Commissioning manual 1MRK 502 035-UEN Product Guide 1MRK 502 036-BEN Type test certificate 1MRK 502 036-TEN Rotor Earth Fault Protection with Injection Unit RXTTE4 and REG670 1MRG001910 650 series manuals Identity number Communication protocol manual, DNP3 1MRK 511 241-UEN Communication protocol manual, IEC 61850 1MRK 511 242-UEN Communication protocol manual, IEC 60870-5-103 1MRK 511 243-UEN Point list manual, DNP3 1MRK 511 244-UEN Engineering manual 1MRK 511 245-UEN Operation manual 1MRK 500 093-UEN Installation manual 1MRK 514 014-UEN 81 82 ABB AB Substation Automation Products SE-721 59 Västerås, Sweden Phone +46 (0) 21 32 50 00 Fax +46 (0) 21 14 69 18 www.abb.com/substationautomation 1MRK 502 036-BEN - © Copyright 2011 ABB. 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