CSC-161 Line Protection IED Product Guide

Transcription

1 CSC-161 Line Protection IED Product Guide

2 Version V1.10 Doc. Code: 0SF (E) Issued Date Copyright owner: Beijing Sifang Automation Co., Ltd. Note: The company keeps the right to perfect the instruction. If equipments do not agree with the instruction at anywhere, please contact our company in time. We will provide you with corresponding service. is registered trademark of Beijing Sifang Automation Co., Ltd. We reserve all rights to this document, even in the event that a patent is issued and a different commercial proprietary right is registered. Improper use, in particular reproduction and dissemination to third parties, is not permitted. This document has been carefully checked. If the user nevertheless detects any errors, he is asked to notify us as soon as possible. The data contained in this manual is intended solely for the IED description and is not to be deemed to be a statement of guaranteed properties. In the interests of our customers, we constantly seek to ensure that our products are developed to the latest technological standards as a result; it is possible that there may be some differences between the hardware/software product and this information product. Manufacturer: Beijing Sifang Automation Co., Ltd.

3 Overview CSC-161 is selective, reliable and high speed comprehensive transmission line protection IED (Intelligent Electronic Device) for overhead lines, cables or combination of them. It is a proper solution for following applications: Subtransmission network and distribution network, with solidly earthed (grounded), low-resistance earthed, isolated or compensated neutral point All type of station arrangement, such as 1.5 breakers arrangement, double bus arrangement, etc. Short lines Heavily loaded lines Communication with station automation system The IED provides a highly sensitive and reliable distance protection with innovative and proven quadrilateral characteristic. In addition to separated zone extension functionality, five distance zones have fully independent measuring and setting values which gives high flexibility for all types of lines and fault resistances. Many other functions are integrated to provide a complete backup protection library. The wide application flexibility makes the IED an excellent choice for both new installations and retrofitting of the existing stations For three pole operated circuit breaker. 1

4 Feature Protection and monitoring IED with extensive functional library, user configuration possibility and expandable hardware design to meet with user s special requirements Redundant A/D sampling channels guarantee the high security and reliability of the IED Three tripping/reclosing Highly sensitive startup elements, which enhance the IED sensitivity in all disturbance conditions and avoid maloperation Current sudden-change startup element Zero sequence current startup element Over current startup element Undervoltage startup element for weak-infeed end of line directional element Impedance directional element Full scheme phase-to-phase and phase-to-earth distance protection with five quadrilateral protection zones and additional extension zone characteristic (21, 21N) Power swing function (68) Proven and reliable principle of power swing logic Unblock elements during power swing All useful types of tele-protection scheme (85) Permissive Underreach Transfer Trip (PUTT) scheme Permissive Overreach Transfer Trip (POTT) scheme Blocking scheme Three kinds of faulty phase selectors are combined to guarantee the correction of phase selection: Current sudden-change phase selector Zero sequence and negative sequence phase selector Under voltage phase selector Inter-tripping scheme Particular logic for tele-protection scheme Current reversal Weak-infeed end Evolving fault logic Sequence tripping logic Four kinds of directional elements cooperate each other so as to determine the fault direction correctly and promptly: Memory voltage directional element Zero sequence component directional element Negative sequence component A complete protection functions library, include: Distance protection with quadrilateral characteristic (21,21N) Power swing function (68) Tele-protection scheme based on 2

5 Feature distance protection (85-21,21N) Tele-protection scheme based on dedicated earth fault protection (85-67N) Overcurrent protection (50, 51, 67) Complete IED information recording: tripping reports, alarm reports, startup reports and general operation reports. Any kinds of reports can be stored up to 2000 and be memorized in case of power disconnection Earth fault protection (50N, 51N, 67N) Emergency/backup overcurrent protection (50, 51) Emergency/backup earth fault protection (50N, 51N) Switch-onto-fault protection (50SOTF) Overload protection (50OL) Overvoltage protection (59) Undervoltage protection (27) Circuit breaker failure protection (50BF) Poles discordance protection (50PD) Dead zone protection (50DZ) STUB protection (50STUB) Synchro-check and energizing check (25) Auto-reclosing function for singleand/or three-phase reclosing (79) Voltage transformer secondary circuit supervision (97FF) Current transformer secondary circuit supervision Self-supervision to all modules in the IED Remote communication Tele-protection contacts for power line carrier protection interface Up to two fiber optical remote communication ports for protection function, like tele-protection, used up to 100kM single mode optical fiber cable External optical/electrical converter, which support communication through SDH or PCM, for G.703 (64kbit/s) and G.703E1 (2048kbit/s) Up to three electric /optical Ethernet ports can be selected to communicate with substation automation system by IEC61850 or IEC protocols Up to two electric RS-485 ports can be selected to communicate with substation automation system by IEC protocol Time synchronization via network (SNTP), pulse and IRIG-B mode Configurable LEDs (Light Emitting Diodes) and output relays satisfied users requirement Versatile human-machine interface Multifunctional software tool for setting, monitoring, fault recording analysis, configuration, etc. 3

6 Function Protection functions Description ANSI Code IEC Logical Node Name IEC graphical symbol Distance protection Distance protection 21, 21N PDIS Z< Power-swing function 68 RPSB Zpsb Tele-protection Communication scheme for distance protection Communication scheme for earth fault protection 85 21,21N PSCH 85 67N PSCH Current protection Overcurrent protection 50,51,67 PTOC Earth fault protection 50N, 51N, 67N PEFM Emergency/backup overcurrent protection 50,51 PTOC Emergency/backup earth fault protection 50N,51N PTEF Switch-onto-fault protection 50SOTF PSOF 3I INV> 3I >> 3I >>> I 0INV> I 0>> I 0>>> 3I INV> 3I > I 0INV> I 0 > 3I >SOTF I 0>SOTF Overload protection 50OL PTOC 3I >OL Voltage protection Overvoltage protection 59 PTOV Undervoltage protection 27 PTUV 3U> 3U>> 3U< 3U<< Breaker protection and control function Circuit breaker failure protection 50BF RBRF 3I> BF I 0>BF I 2>BF Dead zone protection 50DZ 3I>DZ 4

7 Function I 0>DZ I 2>DZ STUB protection 50STUB PTOC 3I>STUB Poles discordance protection 50PD RPLD 3I< PD I 0>PD I 2>PD Synchro-check and energizing check 25 RSYN Auto-reclosing 79 RREC O I Single- and/or three-pole tripping 94-1/3 PTRC Secondary system supervision CT secondary circuit supervision VT secondary circuit supervision 97FF Monitoring functions Description Redundant A/D sampling data self-check Phase-sequence of voltage and current supervision 3I0 polarity supervision The third harmonic of voltage supervision Synchro-check reference voltage supervision Auxiliary contacts of circuit breaker supervision Broken conductor check Self-supervision Logicality of setting self-check Fault locator Fault recorder Station communication Description 5

8 Function Front communication port Isolated RS232 port for maintaining Rear communication port 0-2 isolated electrical RS485 communication ports, support IEC protocol 0-3 Ethernet electrical/optical communication ports, support IEC protocol or IEC protocol Time synchronization port, support GPS pulse or IRIG-B code Remote communication Description Communication port Contact(s) interface for power line carrier for tele-protection 0 2 fiber optical communication port(s) for tele-protection Connection mode Direction fiber cable connection Digital communication network through converter IED software tools Functions Reading measuring value, IED report Setting IED testing Disturbance recording analysis IED configuration Printing 6

9 Function Remote Communication Ports FO CONNECTION FO CONNECTION 21 Z< PDIS PSCH PLC Protection interface 1 21N PDIS Z< 85-67N PSCH PLC Protection interface 2 68 RPSB Zpsb FL RFLO 50 3I>>> PIOC 51/67 3I>>,3I> PTOC 50N I 0>>> PIEF 51N/67N I 0>>,I 0> PTEF MEASUREMENT 50BF RBRF 3I>BF 50STUB 3I>STUB PTOC MONITORING 50SOTF PSOF 50PD PD RPLD 50DZ 59 3U> PTOV 27 3U< PTUV STATION COMMUNICATION - RS232/485 - RJ45/FO - IEC IEC RSYN Fault recording 79 O I RREC 94 PTRC 7

10 Protection Startup elements The startup elements basically work as sensitive detector to all types of fault. As soon as fault or disturbance happens, the highly sensitive startup elements will operate immediately and initiate all necessary protection functions for selective clearance of the fault. The control circuit of tripping relays is controlled by the startup elements. Only when one of the startup elements is triggered, the tripping relays can be energized to trip. Thus, the maloperation, due to fatal internal hardware fault, is avoided in this way. Based on different principle, there are four kinds of startup elements listed below, which are used to enhance the sensitivity, and to guarantee the security in case of IED s internal hardware faults. Sudden-change current startup element Sudden-change phase to phase or zero sequence current elements are the main startup element that can sensitively detect most of faults. The criteria are as follows: where: or Δi= i (K) - i (K-T) - i (K-T) - i (K-2T) : AB,BC or CA, e.g. iab= ia-ib K: The present sample T: The sample quantity of one power cycle Δ3i 0: Sudden-change zero sequence current I_Abrupt: The setting value of current sudden-change elements Zero sequence current startup element Zero sequence current startup element is applied to improve the fault detection sensitivity at the high resistance earth faults. As an auxiliary startup element, it operates with a short time delay. Overcurrent startup element If overcurrent protection function is enabled, over current startup element is used to improve the fault detection sensitivity. As an auxiliary startup element, it operates with short time delay. Low-voltage startup element When one end of the protected line is a weak-source system, and the fault sudden-change phase to phase current is too low to startup the IED, low-voltage startup element can be in service to startup the tele-protection scheme with weak-echo logic. Phase selector The IED applies different phase selectors to determine the faulty phase to make tripping or Auto-reclosing initiation correctly. There are three kinds of phase selectors based on different principle for different fault stages. Sudden-change current phase selector It operates as soon as the sudden- change current startup element starts up. It makes a phase selection for fast tripping by 8

11 Protection comparison amongst changes of phase-phase currents, iab, ibc and ica. Symmetrical component phase selector During the whole period of fault, the phase selector checks the angle between negative sequence current and zero sequence current vectors to determine faulty phases. In addition, phase to phase faults will be discriminated through impedance characteristic. Low voltage phase selector Both current sudden-change phase and symmetric component phase selector are not applicable for weak-infeed end of protected line, so low-voltage phase selector is employed in this condition without VT failure. Theoretically, when one, two or three phase voltages reduce, the relevant phase(s) is selected as faulty phase. Directional elements Four kinds of directional elements are employed for reliable determination of various faults direction. The related protection modules, such as distance protection, tele-protection schemes and overcurrent and earth fault protections, utilize the output of the directional elements as one of their operating condition. All the following directional elements cooperate with the mentioned protection functions. Memory voltage directional element The IED uses the memory voltage and fault current to determine the direction of the fault. Therefore transient voltage of short circuit conditions doesn t influence the direction detection. Additionally, it improves the direction detection sensitivity for symmetrical or asymmetrical close-in faults with extremely low voltage. But it should be noted that the memory voltage cannot be effective for a long time. Therefore, the following directional elements work as supplement to detect direction correctly. Zero sequence component directional element Zero-sequence directional element has efficient features in the solidly grounded system. The directional characteristic only relates to zero sequence impedance angle of the zero sequence network of power system, regardless of the quantity of load current and/or fault resistance throughout the fault. The characteristic of the zero sequence directional element is illustrated in Figure 1. Forward 3I I0 3U0_Ref Φ0_Char 0 Bisector Figure 1 Characteristic of zero sequence directional element where: 9

12 Protection Ф 0_Char: The settable characteristic angle Negative sequence component directional element X_Set X Forward Negative sequence directional element can make an accurate directional discrimination in any asymmetric fault. The directional characteristic only relates to negative sequence impedance angle of the negative sequence network of power system, regardless the quantity of load current and/or fault resistance throughout the fault. The characteristic of the negative sequence directional element is illustrated in Figure 2. 3I n R_Set R_Set R Reverse -n X_Set Figure 3 Direction detection characteristic of impedance directional element where: R SET: The resistance setting of relevant zone of distance protection Forward -3I 2 Φ2_Char 0 3U 2_ Ref Bisector Figure 2 Characteristic of negative sequence where: directional element Ф 2_Char: The settable characteristic angle Impedance directional elements The characteristic of the impedance directional element (shown in Figure 3) is same with that of distance protection. X SET: The reactance setting of relevant zone of distance protection n: Multiplier for reverse directional element, which make the reverse directional element more sensitive than forward one Distance protection (21, 21N) The transmission line distance protection provides a five zones full scheme protection with all phase to phase faults and phase to earth fault loops independently for each zones. Zone arrangement illustrated in Figure 4. Additionally, one extension zone is employed to co-operate with Auto- -reclosing and tele-protection schemes. 10

13 Protection X R_ZSet: R_ZnPP or R_ZnPE; Zone 1 Zone 5 Zone 4 Zone 3 Zone 2 Zone Ext. X_ZSet: X_ZnPP or X_ZnPE; R_ZnPP: Resistance reach setting for phase to phase fault. Subscript n means the number of protection zone. Subscript PP R means phase to phase fault R_ZnPE: Resistance reach setting for phase Zone 4 Reverse (optional) to earth fault. Subscript X means the number of protection zone. Subscript PE Zone 5 Reverse (optional) means phase to earth fault Figure 4 Distance protection zones Individual settings of resistive and reactive reach for phase to phase and phase to earth fault of each zone give flexibility for application on overhead lines and cables of different types and lengths, considering different fault resistance for phase to phase and phase to ground short circuits. Characteristic of distance protection The IED utilizes quadrilateral characteristic as shown in Figure 5. X_ZnPP: Reactance reach setting for phase to phase fault X_ZnPE: Reactance reach setting for phase to earth fault Φ_ZTop: The upper boundary angle of the characteristic in the first quadrant is designed to avoid distance protection overreaching when a close-in fault happens on the adjacent line Φ_ZBottom: The bottom boundary angle of the characteristic in the fourth quadrant improves the reliability of the relay to operate reliably for close-in faults with arc resistance X_ZSet X Φ_ZTop Φ_ZRight: The right boundary angle of characteristic in the first quadrant is used to deal with load encroachment problems Φ_ZLeft: The left boundary angle of the characteristic in the second quadrant considers the line impedance angle which Φ_ZLeft Φ_ZRight generally is not larger than 90. Thus this angle guarantees the correct operation of R_ZSet Φ_ZBottom R the relay Extended operating characteristic Figure 5 Characteristics of distance protection where: To ensure the correct operation at close-in faults, a rectangle zone covering the 11

14 Protection original point is added to the quadrilateral characteristic. The rectangular offset characteristic (illustrated in Figure 6) is calculated automatically according to the related distance zones settings. Furthermore, the memory voltage direction element, the zero sequence directional element, and the negative sequence direction element are applied to determine the direction together. X -R_ZSet X R -X_ZSet XSet ΦTop Figure 7 Characteristic distance protection reverse zone Switch-onto- fault protection function ΦLeft XOffset ROffset ΦBottom RSet ΦRight R Under either auto reclosing or manual closing process, the protection function is able to discriminate these conditions to give an instantaneous tripping once the circuit breaker is closed on permanent faulty line. Figure 6 Extended polygonal distance protection zone characteristic Reverse zone characteristic In addition to the forward characteristic zones mentioned above, the IED provides two optional reverse zone characteristics to protect connected busbar as a backup protection. The reverse zone characteristic can be set for zones 4 and 5 individually. This reverse characteristic has been shown in Figure 7. Power swing (68) The IED provides a high reliable power swing detector which discriminates between fault and power swing with different algorithm. Power swing blocking logic According to the slow behavior of power swing phenomenon, once one of the two following conditions is met, the protection program will switch to power swing logic process: Without operation of sudden-change current startup element, all phase-to-phase impedances, Z AB, Z BC 12

15 Protection and Z CA enter into the largest zone of distance protection Without operation of sudden-change current startup element, all phase currents are bigger than the power swing current setting In addition, according to the experimental results of power swing, it is not possible for impedance vector to come into protected zones in 150 ms after triggering of the current sudden- -change startup element. After 150 ms, the protection program will be switched to power swing logic process if no tripping is issued. Therefore, according to the above condition, the IED program enters the power swing logic process and the distance protection is blocked until removing of the mentioned conditions or until a fault occurrence in the protected line. Power swing unblocking logic The unblocking logic provides possibility for selective tripping of faults on transmission lines during system oscillations, when the distance protection function is normally blocked. In order to unblock distance protection and therefore, fast clearing of the faults, the following elements are in service to discriminate between an internal fault and power swing conditions. Asymmetric faults detection element The zero and negative sequence current are always the key features of the asymmetric fault. By comparison amongst the positive, negative and zero sequence component of phase current, the element distinguishes the asymmetric fault from power swing. Three phase fault detection element Based on the experimental results and practical proof, the change rate of measuring resistance and the change vector of measuring impedance are combined to detect the three phase fault during the power swing. Tele-protection scheme for distance protection (85-21) To achieve non-delayed and selective tripping on 100 % of the line length for all faults, the communication scheme logic is provided for distance protection. The communication schemes are as follows: Permissive Overreach Transfer Trip (POTT) Permissive Underreach Transfer Trip (PUTT) Blocking scheme Following protection logic are used to ensure correct operation under some special fault conditions: Current reversal logic Weak-infeed end and echo logic Evolving fault logic Sequence tripping logic Direct Transfer Trip The function is provided to cooperate with related local protection IED, such as busbar protection, breaker failure protection, etc., to trip the opposite end circuit breaker. 13

16 Protection Tele-protection scheme for earth fault protection (85-67N) To achieve highly sensitive and selective tripping on 100 % of the line length for all faults, especially at the high resistance earth faults. It always works as complement to tele-protection for distance protection with a short time delay. Permissive transfer trip communication scheme is applied. The protection provides dedicated current and time elements independent of the earth fault protection. Following protection logic are used to ensure correct operation under some special fault conditions. Current reversal logic Weak-infeed end logic Sequence tripping logic Direct Transfer Trip The function is provided to cooperate with related local protection IED, such as busbar protection, breaker failure protection, etc., to trip the remote end circuit breaker. Overcurrent protection (50, 51, 67) The protection provides following features: Two definite time stages One inverse time stage 11 kinds of IEC and ANSI inverse time characteristic curves as well as optional user defined characteristic Settable directional element characteristic angle, to satisfy the different network conditions and applications Each stage can be set individually as directional/non-directional Each stage can be set individually for inrush restraint Cross blocking function for inrush detection Settable maximum inrush current VT secondary circuit supervision for directional protection. Once VT failure happens, the directional stage can be set to be blocked Inrush restraint function The protection relay may detect large magnetizing inrush currents during transformer energizing. In addition to considerable unbalance fundamental current, inrush current comprises large second harmonic current which does not appear in short circuit current. Therefore, the inrush current may affect the protection functions which operate based on the fundamental component of the measured current. Accordingly, inrush restraint logic is provided to prevent overcurrent protection from maloperation. Furthermore, by recognition of the inrush current in one phase, it is possible to set the protection in a way that not only the phase with the considerable inrush current, but also the other phases of the overcurrent protection are blocked for a certain time. This is achieved by cross-blocking feature integrated in the 14

17 Protection IED. The inrush restraint function has a maximum inrush current setting. Once the measuring current exceeds the setting, the overcurrent protection will not be blocked any longer. Characteristic of direction element The direction detection is performed by determining the position of current vector in directional characteristic. In other word, it is done by comparing phase angle between the fault current and the reference voltage, Figure 8 illustrates the direction detection characteristic for phase A element. Phase Current Voltage A B C I a Ib I c U bc U ca U ab For three-phase short-circuit fault, without any healthy phase, memory voltage values are used to determine direction clearly if the measured voltage values are not sufficient. The detected direction is based on the memory voltage of previous power cycles. Earth fault protection (50N, 51N, 67N) Forward 90 I A Bisector The earth fault protection can be used to clear phase to earth faults as system back-up protection. ΦPh_Char 0 U BC_Ref The protection provides following features: Two definite time stages One inverse time stage -I A 11 kinds of the IEC and ANSI inverse time characteristic curves as well as optional user defined characteristic Zero sequence directional element Figure 8 Direction detection characteristic of overcurrent protection directional element where: Ф Ph_Char: The settable characteristic angle The assignment of the applied measuring values used in direction determination has been shown in Table 1 for different types of faults. Table 1 Assignment of applied current and reference voltage for directional element Negative sequence directional element is applied as a complement to zero sequence directional element. It can be enabled/disabled by setting Each stage can be set individually as directional/non-directional Settable directional element characteristic angle, to satisfy the different network conditions and applications 15

18 Protection Each stage can be set individually for inrush restraint Settable maximum inrush current VT secondary circuit supervision for directional protection function. Once VT failure happens, the directional stage can be set to be blocked CT secondary circuit supervision for earth fault protection. Once CT failure happens, all stages will be blocked where: Ф 0_Char: The settable characteristic angle For earth fault protection, users can choose negative sequence directional element as the complement of zero sequence directional element. It can be used in case of too low zero sequence voltage due to some fault condition e.g. the unfavorable zero-sequence voltage. The negative sequence directional element characteristic is shown in Figure 10. Zero-sequence current is measured from earth phase CT 3I 2 90 Directional element The earth fault protection adopts zero sequence directional element which compares the zero sequence system quantities: Φ2_Char 0 3U 2_ Ref 3I 0, current is measured from earth phase CT 3U 0, the voltage is used as reference voltage. It is calculated from the sum of the three phase voltages Forward -3I 2 Bisector Figure 10 Direction detection characteristic of negative sequence directional element 3I 0 90 where: Ф 2_Char: The settable characteristic angle 3U0_Ref Φ0_Char Forward Bisector -3I0 0 Figure 9 Direction detection characteristic of zero sequence directional element Furthermore, under the VT failure situation, it can be set to block directional earth fault protection. Inrush restraint function The protection relay may detect large magnetizing inrush currents during transformer energizing. In addition to considerable unbalance fundamental current, Inrush current comprises large second harmonic current which doesn t appear in short circuit current. Therefore, 16

19 Protection the inrush current may affect the protection functions which operate based on the fundamental component of the measured current. Accordingly, inrush restraint logic is provided to prevent earth fault protection from mis-tripping. Since inrush current cannot be more than a specified value, the inrush restraint provides an upper current limit in which blocking does not occur. Emergency/backup overcurrent protection (50, 51) In the case of VT fail condition, all distance zones and protection functions related with voltage input are out of service. In this case, an emergency overcurrent protection comes into operation. Additionally, the protection can be set as backup non directional overcurrent protection according to the user s requirement. The protection provides following features: One definite time stage One inverse time stage Emergency/backup earth fault protection (50N, 51N) In the case of VT fail condition, all distance zones and protection functions related with voltage input are out of operation. An emergency earth fault protection comes into operation. Additionally, the protection can be set as backup non directional earth fault protection according to the user s requirement. The protection provides following features: One definite time stage One inverse time stage 11 kinds of IEC and ANSI inverse characteristics curve as well as optional user defined characteristic Inrush restraint can be selected individually for each stage Settable maximum inrush current CT secondary circuit supervision for earth fault protection. Once CT failure happens, all stages will be blocked 11 kinds of IEC and ANSI inverse characteristics curve as well as optional user defined characteristic Inrush restraint function can be set for each stage separately Cross blocking of inrush detection Settable maximum inrush current Zero-sequence current is measured from 3-phase currents summation Switch-onto-fault protection (50SOTF) The protection gives a trip when the circuit breaker is closed manually onto a short circuited line. The protection provide following features: 17

20 Protection One definite time overcurrent stage One definite time earth fault protection stage Inrush restraint can be selected Cross blocking for inrush detection Settable maximum inrush current Manual closing binary input detection Undervoltage protection (27) One voltage reduction can occur in the power system during faults or abnormal conditions. The protection provides following features: Two definite time stages Overload protection (50OL) The IED supervises load flow in real time. If each phase current is greater than the dedicated setting for a set delay time, the protection will issue alarm. Overvoltage protection (59) The overvoltage protection detects abnormally network high voltage conditions. Overvoltage conditions may occur possibly in the power system during abnormal conditions such as no-load, lightly load, or open line end on long line. The protection can be used as open line end detector or as system voltage supervision normally. The protection provides following features: Two definite time stages Each stage can be set to alarm or trip Measuring voltage between phase- -earth voltage and phase-phase (selectable) Settable dropout ratio Each stage can be set to alarm or trip Measuring voltage between phase- -earth voltage and phase-phase selectable Current criteria supervision Circuit breaker aux. contact supervision VT secondary circuit supervision, the Undervoltage function will be blocked when VT failure happens Settable dropout ratio Breaker failure protection (50BF) The circuit breaker failure protection is designed to detect failure of the circuit breaker during a fault clearance. It ensures fast back-up tripping of surrounding breakers by tripping relevant bus sections. The protection can be three phase started to allow use with single or three-phase tripping applications. Once a circuit breaker operating failure occurs on a feeder/transformer, the bus section which the feeder/transformer is connected with can be selectively isolated by the protection. In addition a transfer trip 18

21 Protection signal is issued to trip the opposite end circuit breaker of the feeder. In the event of a circuit breaker failure with a busbar fault, a transfer trip signal is issued to trip the remote end circuit breaker of the feeder. The current criteria are in combination with three phase current, zero and negative sequence current to achieve a higher security. The function can be set to give single- or three phase re-tripping of the local breaker to avoid unnecessary tripping of surrounding breakers in the case of the circuit breaker with two available trip coils. Additionally, during single pole tripping, stage 1 is able to re-tripping three phase with settable delay time after single phase re-tripping failure. of a fault in dead zone, the short circuit current is measured by protection relay while CB auxiliary contacts indicate the CB is open. Internal/external initiation Self-adaptive for bus side CT or line side CT When one bus side CT of feeder is applied, once a fault occurs in the dead zone, the IED trips the relevant busbar zone. Tripping logic is illustrated in Figure 11. Bus IFAULT Trip Two trip stages (local and surrounding breaker tripping) Transfer trip command to the remote line end in second stage Line1 Line2 LineN Internal/ external initiation Opened CB Closed CB Single/three phase CBF initiation Selectable CB Aux contacts checking Current criteria checking (including phase current, zero and negative sequence current) Dead zone protection (50DZ) Figure 11 Tripping logic, applying bus side CT When one line side CT is applied, when a fault occurs in the dead zone, protection relay sends a transfer trip to remote end relay to isolate the fault. Tripping logic is illustrated in Figure 12. The IED provides this protection function to protect dead zone, namely the area between circuit breaker and CT in the case that CB is open. Therefore, by occurrence 19

22 Protection Inter trip Bus Bus A Delay trip Bus B IFAULT IFAULT IFAULT Line1 Line2 LineN Trip Relay Line A Line B Closed CB Opened CB Closed CB Figure 12 Tripping logic, applying line side CT STUB protection (50STUB) The VT is mostly installed at line side of transmission lines. Therefore, for the cases that transmission line is taken out of service and the line disconnector is opened, the distance protection will not be able to operate and must be blocked. The STUB protection protects the zone between the CTs and the open dis- -connector. The STUB protection is enabled when the open position of the disconnector is connected to IED binary input. The function supports one definite stage which related concept is shown in Figure 13. Figure 13 Tripping logic of STUB protection Poles discordance protection (50PD) The phase segregated operating circuit breakers can be in different positions (close-open) due to electrical or mechanical failures during the system normal operation. The protection operates based on information from auxiliary contacts of the circuit breaker with additional criteria. The protection performs following features: 3 phase CB Aux contacts supervision Current criteria checking (including phase current, zero and negative sequence current) Synchro-check and energizing check (25) The synchro-check function checks the 20

23 Protection both side voltages of the circuit breaker for synchronism conditions. The synchronization function ensures the stability of the network in three phase reclosing condition. To do this, the two side voltages of the circuit breaker are compared in terms of magnitude, phase angle and frequency differences. Additionally, closing can be done safely in conditions that at least one side of the CB has dead voltage. Available for automatic reclosing (internally or externally) Based on voltage/ angle/ frequency difference Synchro-check modes: Synch-check Energizing check, and synch-check if energizing check failure Override Modes of energizing check: Dead V 4 and dead V 3Ph Dead V 4 and live V 3Ph Live V 4 and dead V 3Ph Synchro-check reference voltage supervision If the automatic reclosing is set for synchronization check or energizing check, during the automatic reclosing period, the synchronization condition of the voltages between both sides of CB cannot be met, an alarm will be issued after default time delay. Auto-reclosing (79) For restoration of the normal service after a fault an auto reclosing attempt is mostly made for overhead lines. Experiences show that about 85% of faults have transient nature and will disappear after an auto reclosing attempt is performed. This means that the line can be re-energized in a short period. The reconnection is accomplished after a dead time via the automatic reclosing function. If the fault is permanent or short circuit arc has not been extinguished, the protection will re-trip the breaker. Main features of the Auto-reclosing are as follows: Up to 4 shots (selectable) Individually settable dead time for three phase and single phase fault and for each shot Internal/external AR initiation Three phase AR operation CB status supervision CB Aux. contact supervision Cooperation with internal synch-check function for reclosing command Secondary system supervision Current transformer secondary circuit supervision Open or short circuited CT cores can cause unwanted operation of some protection functions such as earth fault current and negative sequence current functions. 21

24 Protection Interruption of the CT secondary circuit is detected based on zero-sequence current. Once CT failure happens, each stage of earth fault protection is blocked. Voltage transformer secondary circuit supervision A measured voltage failure, due to a broken conductor or a short circuit fault in the secondary circuit of voltage transformer, may result in unwanted operation of the protection functions which work based on voltage criteria. VT failure supervision function is provided to block these protection functions and enable the backup protection functions. The features of the function are as follows: Symmetrical/asymmetrical VT failure detection 3-phase AC voltage MCB monitoring 1-phase AC voltage MCB monitoring Zero and negative sequence current monitoring Applicable in solid grounded, compensated or isolated networks 22

25 Monitoring Phase-sequence of voltage and current supervision The phase-sequence of three phase voltage and current are monitored in the normal condition to determine that the secondary circuit of CT or VT is connected with IED correctly. 3I0 polarity supervision The IED compare the magnitude and phase angle of the calculated zero sequence current with the measured one to determine that the polarity is connected in a right way. The third harmonic of voltage supervision If the third harmonic voltage is excessive, the alarm without blocking protection will be given with delay time for checking of the secondary circuit of voltage transformer. Auxiliary contacts of circuit breaker supervision Current flowing through the transmission line and connected CB aux. contacts are monitored in phase segregated. Therefore, the conflict condition is reported as alarm. For example, If CB aux. contacts indicate that CB is open in phase A and at the same time flowing current is measured in this phase, related alarm is reported. Broken conductor detection The main purpose of the broken conductor detection function is to detect the broken conductors on protected transmission lines and cables. Detection can initiate an alarm or tripping. Self-supervision All modules can perform selfsupervision to its key hardware components and program, as soon as energizing. Parts of the modules are self-supervised in real time. All internal faults or abnormal conditions will initiate an alarm. The fatal faults among them will result in the whole IED blocked The sampled data from the redundant A/D sampling channels compare with each other in real time. If the difference exceeds the specified threshold, it will be considered as analog input channel fault and the protection will be blocked immediately CPU module and communication module perform real time inter- -supervision. Therefore communication interruption between them is detected and related alarm will be given CRC checks for the setting, program and configuration, etc. Fault locator The built-in fault locator is an impedance measuring function giving the distance from the IED measuring location to the fault position in km. The IED reports fault location after the IED tripping. 23

26 Communication Station communication Overview The IED is able to connect to one or more substation level systems or equipments simultaneously, through the communication ports with communica- -tion protocols supported. (Shown in Figure 14) Front communication port There is a serial RS232 port on the front plate of all the IEDs. Through this port, the IED can be connected to the personal computer for setting, testing, and configuration using the dedicated Sifang software tool. RS485 communication ports Up to 2 isolated electrical RS485 communication ports are provided to connect with substation automation system. These two ports can work in parallel for IEC Ethernet communication ports Up to 3 electrical or optical Ethernet communication ports are provided to connect with substation automation system. These two out of three ports can work in parallel for protocol, IEC61850 or IEC Server or Work Station 1 Server or Work Station 2 Work Station 3 Switch Work Station 4 Net 1: IEC61850/IEC103,Ethernet Port A Switch Net 2: IEC61850/IEC103,Ethernet Port B Switch Switch Switch Gateway or converter Switch Gateway or converter Net 3: IEC103, RS485 Port A Net 4: IEC103, RS485 Port B Figure 14 Connection example for multi-networks of station automation system Note: All four ports can work in parallel Communication protocol The IED supports station communication with IEC and IED protocols. By means of IEC61850, GOOSE peer- -to-peer communication make it possible that bay IEDs can exchange information to each other directly, and a simple master-less system can be set up for bay and system interlocking and other interactive function. Time synchronization port 24

27 Communication All IEDs feature a permanently integrated electrical time synchronization port. It can be used to feed timing telegrams in IRIG-B or pulse format into the IEDs via time synchronization receivers. The IED can adapt the second or minute pulse in the pulse mode automatically. Meanwhile, SNTP network time synchro- -nization can be applied. The Figure 15 illustrates the optional time synchronization modes. between the two IEDs on the two end of the transmission line or cable respectively. This functionality is mainly used for the line Tele-protection schemes, e.g., POTT or PUTT schemes, blocking scheme and inter trip and so on. Remote communication channel The IEDs are able to communicate with each other in two types: Directly fiber-optical cable connection mode at distances up to 100 km (see Figure 16 and Figure 17) SNTP IRIG-B Pulse Through the communication converter with G.703 or G.703E1 interface through the public digital communica- -tion network (see Figure 18 and Figure 19) Ethernet port IRIG-B port Binary input Figure 15 Time synchronizing modes Remote communication Binary signal transfer The binary signals can be exchanged through remote communication channels Because there are up to two selectable fiber-optical remote communication ports, the IED can work in the redundant communication channel mode, with advantage of no time-delay channel switch in case of the primary channel broken (Figure 17, Figure 19 and Figure 20). Overhead Line or Cable Single-mode FO Length: <60kM or 60~100kM Channel A IED IED 25

28 Communication Figure 16 Single channel, communication through dedicated fiber optical cable Overhead Line or Cable Single-mode FO Length: <60kM or 60~100kM Channel A IED Channel B IED Figure 17 Double channels, communication through dedicated fiber optical cable Communication converter The link between the IED and a multiplexed communication network is made by dedicated communication converters (CSC186). They have a fiber-optic interface with 1310 nm and 2 FC connectors to the protection IED. The converter can be set to support an electrical G kbit/s or G703-E1 2Mbit/s interface, according the require- -ment of the multiplexed communication network. Overhead Line or Cable G703.5(E1: 2048kbit/s) G703.1(64kbit/s) o e Digital communication network e o IED Communication converter Communication converter IED Figure 18 Single Channel, communication through digital communication network 26

29 Communication Overhead Line or Cable G703.5(E1: 2048kbit/s) G703.1(64kbit/s) Channel A IED o e o e Communication converter Digital communication network Digital communication network Channel B e o e o Communication converter IED Figure 19 Double channels, communication through digital communication network Overhead Line or Cable Single-mode FO Length: <60kM or 60~100kM Channel A IED o e Digital communication network Channel B G703.5(E1: 2048kbit/s), G703.1(64kbit/s) e o IED Figure 20 Double channels, one channel through digital communication network, one channel through dedicated fiber optical cables 27

30 Software tool A user-friendly software tool is offered for engineering, setting, disturbance analysis and monitoring. It provides versatile functionalities required throughout the life cycle of protection IEDs. Its features are as follows: diagrams, vector diagrams, bar charts and data sheet. Device administration in projects with freely configurable hierarchies for any substation and electrical power station topology Intelligent plausibility checks rule out incorrect input Modification, import and export of parameter sets sorted by protection functions, with setting logicality check Precise fault analysis with visualization of fault records in curves, circle Graphical visualization of charac- -teristics and zone diagrams with direct manipulation of the curves Password-protected access for different jobs such as parameter setting, commissioning and controlling (authorized staff only) Testing and diagnostic functions decisive support in the commissioning phase 28

31 Hardware Front plate The whole front plate is divided into zones, each of them with a well-defined 1 functionality: 5 4 CSC Figure 21 Front plate 1 Liquid crystal display (LCD) 2 LEDs 3 Shortcut function keys 4 Arrow keys 5 Reset key 6 Quit key 7 Set key 8 RS232 communication port Rear plate Test port For BIM and BOM Ethernet ports Fiber Optical ports X10 PSM X 9 X8 X7 X6 X5 X4 X 3 COM X2 CPU1 X1 AIM Figure 22 Rear plate of the protection IED 29

32 Hardware Modules Analogue Input Module (AIM) The analogue input module is used to galvanically separate and transform the secondary currents and voltages generated by the measuring transformers. CPU Module (CPU) The CPU module handles all protection functions and logic. The redundant A/D sampling channels are equipped. By comparing the data from redundant sampling channels, any sampling data errors and the channel hardware faults can be detected immediately and the proper alarm and blocking is initiated in time. Communication Module (COM) The communication module performs communication between the internal protection system and external equipments such as HMI, engineering workstation, substation automation system, RTU, etc., to transmit remote metering, remote signaling, SOE, event reports and record data. Up to 3 channels isolated electrical or optical Ethernet ports and up to 2 channels RS485 serial communication ports can be provided in communication module to meet the communication demands of different substation automation system and RTU at the same time. The time synchronization port is equipped, which can work in pulse mode or IRIG-B mode. SNTP mode can be applied through communication port. In addition, a series printer port is also reserved. Binary Input Module (BIM) The binary input module is used to connect the input signals and alarm signals such as the auxiliary contacts of the circuit breaker (CB), etc. Binary Output Module (BOM) The binary output modules mainly provide tripping output contacts, initiating output contacts and signaling output contacts. All the tripping output relays have contacts with a high switching capacity and are blocked by protection startup elements. Each output relay can be configured to satisfy the demands of users. Power Supply Module (PSM) The power supply module is used to provide the correct internal voltages and full isolation between the terminal and the battery system. 30

33 Hardware Dimension C E A D B Figure 23 4U, 19 case with rear cover Table 2 Dimension of the IED case Legend A B C D E Dimension (mm) E C D A B Figure 24 Cut-out on the panel Table 3 Dimension of the cutout for IED mounting Legend A B C D E Dimension (mm)

34 Connection A. Typical rear terminal diagram X1 a01 b01 a02 b02 a03 b03 a04 b04 a05 b05 a06 b06 a07 b07 a08 b08 a09 b09 a10 b10 a11 b11 a12 b12 X2 IA IB IC I0 I4 Null Null Null Null Null Null Null Null U4 UB UC UA UN RX connector of optical fiber port 1 CSC-161 1) BI01 BI02 BI03 BI04 BI05 BI06 BI07 BI08 BI09 BI10 BI11 BI12 BI13 BI14 BI15 BI16 BI17 BI18 BI19 BI20 BI21 BI22 BI23 BI24 BI25 BI26 BI27 BI28 BI29 BI30 BI-COM1(-) BI-COM2(-) X4 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 TX connector of optical fiber port 1 X RX connector of optical fiber port 2 TX connector of optical fiber port 2 Null Null Null Null RS485-2B RS485-2A RS485-1B RS485-1A GPS GPS - GND Null Null Null Null Null Null Ethernet Port 1 - RJ45 Ethernet Port 2 - RJ45 2) Output relay 01 Output relay 02 Output relay 03 Output relay 04 Output relay 05 Output relay 06 Output relay 07 Output relay 08 Output relay 09 Output relay 10 Output relay 11 Output relay 12 Output relay 13 Output relay 14 Output relay 15 Output relay 16 X5 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 Note: 1) The two optical fiber ports are optional for protection remote communication 2) Alternative Ethernet ports for station communication are 2 ST optical fiber ports, shown as following, Ethernet Port 1 - ST Ethernet Port 2 - ST 32

35 Connection CSC-161 X6 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 Output relay 01 Output relay 02 Output relay 03 Output relay 04 Output relay 05 Output relay 06 Output relay 07 Output relay 08 Output relay 09 Output relay 10 Output relay 11 Output relay 12 Output relay 13 Output relay 14 Output relay 15 Output relay 16 Output relay 01 Output relay 02 Output relay 03 Output relay 04 Output relay 05 Output relay 06 Output relay 07 Output relay 08 Output relay 09 Output relay 10 Output relay 11 Output relay 12 Output relay 13 Output relay 14 Output relay 15 Output relay 16 X8 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 X7 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 Output relay 01 Output relay 02 Output relay 03 Output relay 04 Output relay 05 Output relay 06 Output relay 07 Output relay 08 Output relay 09 Output relay 10 Output relay 11 Output relay 12 Output relay 13 Output relay 14 Output relay 15 Output relay 16 1) X9 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 Note : 1) X9 is optional terminal set, for additional binary output module ordered by user. 33

36 Connection CSC-161 Power failure alarm relay 1 Power failure alarm relay 2 DC 24V + output Null Null DC 24V - output Null Null AUX DC + input Null Null AUX DC - input Null Null Terminal for earthing Terminal for earthing X10 a02 c02 a04 c04 a06 c06 a08 c08 a10 c10 a12 c12 a14 c14 a16 c16 a18 c18 a20 c20 a22 c22 a24 c24 a26 c26 a28 c28 a30 c30 a32 c32 34

37 Connection B. Typical analogue inputs connection for one breaker of single or double busbar arrangement A B C * * * a01 b01 a02 b02 a03 b03 a04 b04 Protection IED IA IB IC IN a12 a11 b11 b12 UA UB UC UN a10 b10 U4 35

38 Connection C. Typical analogue inputs connection for one and half breaker arrangement A B C * * * * * * Protection IED a01 b01 IA a02 b02 a03 b03 a04 b04 IB IC IN a12 a11 b11 b12 UA UB UC UN a10 b10 U4 A B C 36

39 Connection D. Typical analogue inputs connection for parallel lines A B C Protection IED a01 b01 IA a02 b02 IB * * * a03 b03 IC * * * a04 b04 IN a12 a11 b11 b12 UA UB UC UN a10 b10 U4 a05 b05 INM 37

40 Technical data Frequency Item Standard Data Rated system frequency IEC Hz or 60Hz Internal current transformer Item Standard Data Rated current I r IEC or 5 A Nominal current range Nominal current range of sensitive CT 0.05 I r to 30 I r to 1 A Power consumption (per phase) 0.1 VA at I r = 1 A; 0.5 VA at I r = 5 A 0.5 VA for sensitive CT Thermal overload capability IEC IEC I r for 1 s 4 I r continuous Internal voltage transformer Item Standard Data Rated voltage V r (ph-ph) IEC V /110 V Nominal range (ph-e) Power consumption at V r = 110 V IEC DL/T V to 120 V 0.1 VA per phase Thermal overload capability (phase-neutral voltage) IEC DL/T V r, for 10s 1.5 V r, continuous Auxiliary voltage Item Standard Data Rated auxiliary voltage U aux IEC to 250V DC Permissible tolerance IEC ±%20 U aux Power consumption at quiescent state Power consumption at maximum load IEC IEC W per power supply module 60 W per power supply module 38

41 Technical data Inrush Current IEC T 10 ms/i 25 A per power supply module, Binary inputs Item Standard Data Input voltage range IEC /125 V DC 220/250 V DC Threshold1: guarantee operation IEC V, for 220/250V DC 77V, for 110V/125V DC Threshold2: uncertain operation IEC V, for 220/250V DC; 66V, for 110V/125V DC Response time/reset time IEC Software provides de-bounce time Power consumption, energized IEC Max. 0.5 W/input, 110V DC Max. 1 W/input, 220V DC Binary outputs Item Standard Data Max. system voltage IEC V DC/AC Current carrying capacity IEC A continuous, 30A,200ms ON, 15s OFF Making capacity IEC W(DC) at inductive load with L/R>40 ms 1000 VA(AC) Breaking capacity IEC VDC, 0.15A, at L/R 40 ms 110VDC, 0.30A, at L/R 40 ms Mechanical endurance, Unloaded IEC ,000,000 cycles (3 Hz switching frequency) Mechanical endurance, making IEC cycles Mechanical endurance, breaking IEC cycles Specification state verification IEC IEC IEC UL/CSA TŰV 39

42 Technical data Contact circuit resistance measurement Open Contact insulation test (AC Dielectric strength) IEC IEC IEC IEC IEC mΩ AC1000V 1min Maximum temperature of parts and materials IEC Front communication port Item Number 1 Data Connection Communication speed Max. length of communication cable Isolated, RS232; front panel, 9-pin subminiature connector, for software tools 9600 baud 15 m RS485 communication port Item Data Number 0 to 2 Connection Max. length of communication cable Test voltage 2-wire connector Rear port in communication module 1.0 km 500 V AC against earth For IEC protocol Communication speed Factory setting 9600 baud, Min baud, Max baud Ethernet communication port Item Electrical communication port Data Number 0 to 3 Connection Max. length of communication cable RJ45 connector Rear port in communication module 100m For IEC protocol 40

43 Technical data Communication speed 100 Mbit/s For IEC protocol Communication speed 100 Mbit/s Optical communication port ( optional ) Number 0 to 2 Connection Optical cable type Max. length of communication cable SC connector Rear port in communication module Multi-mode 2.0km IEC protocol Communication speed 100 Mbit/s IEC protocol Communication speed 100 Mbit/s Time synchronization Mode IRIG-B signal format Item Pulse mode IRIG-B000 Data Connection Voltage levels 2-wire connector Rear port in communication module differential input Fiber optic communication ports for remote communication Item Data Number 1 to 2 Fiber optic cable type Single-mode Optic wavelength 1310nm, when the transmission distance <60km; 1550nm, when the transmission distance >60km Optic received sensitivity -38dBm Emitter electric level >-8dBm; (the transmission distance <40km) >-4dBm; (the transmission distance 40~60km) >-3dBm; (the transmission distance >60km) Fiber optic connector type FC, when the transmission distance <60km) SC, when the transmission distance >60km Data transmission rate 64 kbit/s, G703; 2,048 kbit/s, G703-E1 Max. transmission distance 100kM 41

44 Technical data Environmental influence Item Recommended permanent operating temperature Storage and transport temperature limit Permissible humidity Data -10 C to +55 C (Legibility of display may be impaired above +55 C /+131 F) -25 C to +70 C 95 % of relative humidity IED design Case size Weight Item 4U 19inch 10kg Data 42

45 Technical Data Product safety-related Tests Item Standard Data Over voltage category IEC Category III Pollution degree IEC Degree 2 Insulation IEC Basic insulation Degree of protection (IP) Power frequency high voltage withstand test Impulse voltage test Insulation resistance IEC IEC IEC EN ANSI C37.90 GB/T DL/T IEC IEC EN ANSI C37.90 GB/T DL/T IEC IEC EN ANSI C37.90 GB/T Front plate: IP40 Rear, side, top and bottom: IP 30 2KV, 50Hz 2.8kV DC between the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs case earth 500V, 50Hz between the following circuits: Communication ports to case earth time synchronization terminals to case earth 5kV (1.2/50μs, 0.5J) If U i 63V 1kV if U i<63v Tested between the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs case earth Note: U i: Rated voltage 100 MΩ at 500 VDC 43

46 Technical Data DL/T Protective bonding resistance IEC Ω Fire withstand/flammability IEC Class V2 Electromagnetic immunity tests Item Standard Data 1 MHz burst immunity test IEC IEC IEC EN ANSI/IEEE C Electrostatic discharge IEC IEC EN Class III 2.5 kv CM ; 1 kv DM Tested on the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs 1 kv CM ; 0 kv DM Tested on the following circuits: communication ports Level 4 8 kv contact discharge; 15 kv air gap discharge; both polarities; 150 pf; R i = 330 Ω Radiated electromagnetic field disturbance test Radiated electromagnetic field disturbance test Electric fast transient/burst immunity test IEC EN IEC EN IEC , IEC EN ANSI/IEEE C Frequency sweep: 80 MHz 1 GHz; 1.4 GHz 2.7 GHz spot frequencies: 80 MHz; 160 MHz; 380 MHz; 450 MHz; 900 MHz; 1850 MHz; 2150 MHz 10 V/m AM, 80%, 1 khz Pulse-modulated 10 V/m, 900 MHz; repetition rate 200 Hz, on duration 50 % Class A, 4KV Tested on the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs 44

47 Technical Data Class A, 1KV Tested on the following circuits: communication ports Surge immunity test IEC IEC Conduct immunity test IEC IEC kV L-E 2.0kV L-L Tested on the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs 500V L-E Tested on the following circuits: communication ports Frequency sweep: 150 khz 80 MHz spot frequencies: 27 MHz and 68 MHz 10 V AM, 80%, 1 khz Power frequency immunity test IEC Class A 300 V CM 150 V DM Power frequency magnetic field test IEC Level 4 30 A/m cont. / 300 A/m 1 s to 3 s 100 khz burst immunity test IEC kv CM ; 1 kv DM Tested on the following circuits: auxiliary power supply CT / VT inputs binary inputs binary outputs 1 kv CM ; 0 kv DM Tested on the following circuits: communication ports DC voltage interruption test Item Standard Data DC voltage dips IEC % reduction 20 ms 45

48 Technical Data 60% reduction 200 ms 30% reduction 500 ms DC voltage interruptions IEC % reduction 5 s DC voltage ripple IEC %, twice rated frequency DC voltage gradual shut down /start-up IEC s shut down ramp 5 min power off 60 s start-up ramp DC voltage reverse polarity IEC min Electromagnetic emission test Item Standard Data Radiated emission Conducted emission IEC EN CISPR22 IEC EN CISPR22 30MHz to 1GHz ( IT device may up to 5 GHz) 0.15MHz to 30MHz Mechanical tests Item Standard Data Sinusoidal Vibration response test Sinusoidal Vibration endurance test Shock response test Shock withstand test IEC EN IEC EN IEC EN IEC EN Class 1 10 Hz to 60 Hz: mm 60 Hz to 150 Hz: 1 g 1 sweep cycle in each axis Relay energized Class 1 10 Hz to 150 Hz: 1 g 20 sweep cycle in each axis Relay non-energized Class 1 5 g, 11 ms duration 3 shocks in both directions of 3 axes Relay energized Class 1 15 g, 11 ms duration 3 shocks in both directions of 3 axes 46

49 Technical Data Relay non-energized Bump test IEC Class 1 10 g, 16 ms duration 1000 shocks in both directions of 3 axes Relay non-energized Seismic test IEC Class 1 X-axis 1 Hz to 8/9 Hz: 7.5 mm X-axis 8/9 Hz to 35 Hz :2 g Y-axis 1 Hz to 8/9 Hz: 3.75 mm Y-axis 8/9 Hz to 35 Hz :1 g 1 sweep cycle in each axis, Relay energized Climatic tests Item Standard Data Cold test - Operation IEC C, 16 hours, rated load IEC Cold test Storage IEC IEC C, 16 hours Dry heat test Operation [IEC C, 16 hours, rated load IEC Dry heat test Storage IEC C, 16 hours IEC Change of temperature IEC IEC Test Nb, figure 2, 5 cycles -10 C / +55 C Damp heat static test IEC C, 93% r.h. 10 days, rated load IEC Damp heat cyclic test IEC IEC C, 93% r.h. 6 cycles, rated load CE Certificate EMC Directive Low voltage directive Item Data EN and EN (EMC Council Directive 2004/108/EC) EN (Low-voltage directive 2006/95 EC). 47

50 Technical Data Functions NOTE: Ir: CT rated secondary current, 1A or 5A; Distance protection (ANSI 21, 21N) Item Rang or Value Tolerance Number of settable zone 5 zones, with additional extended zone Distance characteristic Resistance setting range Reactance setting range Polygonal 0.01Ω~120Ω, step 0.01Ω, when Ir=5A; 0.05Ω~600Ω, step 0.01Ω, when Ir=1A; 0.01Ω~120Ω, step 0.01Ω, when Ir=5A; 0.05Ω~600Ω, step 0.01Ω, when Ir=1A; ± 5.0% static accuracy Conditions: Voltage range: 0.01 Ur to 1.2 Ur Current range: 0.12 Ir to 20 Ir Time delay of distance zones 0.00 to 60.00s, step 0.01s ±1% or +20 ms, at 70% operating setting and setting time > 60ms Operation time Dynamic overreaching for zone 1 22ms typically at 70% setting of zone 1 ±5%, at 0.5<SIR<30 Tele-protection (ANSI 85 21, 21N, 67N) Item Rang or Value Tolerance Operating time 25ms typically in permission mode for 21/21N, at 70% setting Overcurrent protection (ANSI 50, 51, 67) Item Rang or Value Tolerance Definite time characteristics Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00 to 60.00s, step 0.01s ±1% setting or +40ms, at 200% operating setting 48

51 Technical Data Inverse time characteristics Current 0.08 Ir to Ir ±3% setting or ±0.02Ir IEC standard ANSI user-defined characteristic Normal inverse; Very inverse; Extremely inverse; Long inverse Inverse; Short inverse; Long inverse; Moderately inverse; Very inverse; Extremely inverse; Definite inverse T= ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with IEC ±5% setting + 40ms, at 2 <I/ISETTING < 20, in accordance with ANSI/IEEE C37.112, ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with IEC Time factor of inverse time, A to 200.0s, step 0.001s Delay of inverse time, B to 60.00s, step 0.01s Index of inverse time, P to 10.00, step set time Multiplier for step n: k 0.05 to 999.0, step 0.01 Minimum operating time Maximum operating time Reset mode 20ms 100s instantaneous Directional element Operating area range Characteristic angle 0 to 90, step 1 ±3, at phase to phase voltage >1V Earth fault protection (ANSI 50N, 51N, 67N) Item Rang or value Tolerance Definite time characteristic Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00 to 60.00s, step 0.01s Inverse time characteristics ±1% setting or +40ms, at 200% operating setting Current 0.08 Ir to Ir ±3% setting or ±0.02Ir IEC standard Normal inverse; Very inverse; Extremely inverse; IEC ±5% setting + 40ms, at 2 <I/I SETTING < 20 49

52 Technical Data Long inverse ANSI user-defined characteristic Time factor of inverse time, A Inverse; Short inverse; Long inverse; Moderately inverse; Very inverse; Extremely inverse; Definite inverse T= to 200.0s, step 0.001s ANSI/IEEE C37.112, ±5% setting + 40ms, at 2 <I/I SETTING < 20 IEC ±5% setting + 40ms, at 2 <I/I SETTING < 20 Delay of inverse time, B to 60.00s, step 0.01s Index of inverse time, P to 10.00, step set time Multiplier for step n: k 0.05 to 999.0, step 0.01 Minimum operating time Maximum operating time 20ms 100s Reset mode instantaneous Directional element Operating area range of zero sequence directional element Characteristic angle 0 to 90, step 1 Operating area range of negative sequence directional element Characteristic angle 50 to 90, step 1 ±3, at 3U0 1V ±3, at 3U2 2V Emergency/backup overcurrent protection (ANSI 50, 51) Item Rang or Value Tolerance Definite time characteristics Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00 to 60.00s, step 0.01s Inverse time characteristics ±1% setting or +40ms, at 200% operating setting Current 0.08 Ir to Ir ±3% setting or ±0.02Ir IEC standard Normal inverse; Very inverse; Extremely inverse; Long inverse ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with IEC

53 Technical Data ANSI Inverse; Short inverse; Long inverse; Moderately inverse; Very inverse; Extremely inverse; Definite inverse user-defined characteristic T= Time factor of inverse time, A to 200.0s, step 0.001s ±5% setting + 40ms, at 2 <I/ISETTING < 20, in accordance with ANSI/IEEE C37.112, ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with IEC Delay of inverse time, B to 60.00s, step 0.01s Index of inverse time, P to 10.00, step set time Multiplier for step n: k 0.05 to 999.0, step 0.01 Minimum operating time 20ms Maximum operating time 100s Reset mode instantaneous Emergency/backup earth fault protection (ANSI 50N, 51N) Item Rang or value Tolerance Definite time characteristic Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00 to 60.00s, step 0.01s Inverse time characteristics ±1% setting or +40ms, at 200% operating setting Current 0.08 Ir to Ir ±3% setting or ±0.02Ir IEC standard ANSI user-defined characteristic Normal inverse; Very inverse; Extremely inverse; Long inverse Inverse; Short inverse; Long inverse; Moderately inverse; Very inverse; Extremely inverse; Definite inverse T= ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with IEC ±5% setting + 40ms, at 2 <I/ISETTING < 20, in accordance with ANSI/IEEE C37.112, ±5% setting + 40ms, at 2 <I/I SETTING < 20, in accordance with 51

54 Technical Data IEC Time factor of inverse time, A to 200.0s, step 0.001s Delay of inverse time, B to 60.00s, step 0.01s Index of inverse time, P to 10.00, step set time Multiplier for step n: k 0.05 to 999.0, step 0.01 Minimum operating time Maximum operating time Reset mode 20ms 100s instantaneous Inrush restraint function Item Range or value Tolerance Upper function limit Max current for inrush restraint Ratio of 2 nd harmonic current to fundamental component current Cross-block (IL1, IL2, IL3) (settable time) 0.25 Ir to Ir ±3% setting value or ±0.02Ir 0.10 to 0.45, step s to s, step 0.01s ±1% setting or +40ms Switch-onto-fault protection (ANSI 50SOTF) Item Rang or Value Tolerance Phase current 0.08 Ir to Ir ±3% setting or ±0.02Ir Zero-sequence current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay of phase overcurrent 0.00s to 60.00s, step 0.01s ±1% setting or +40ms, at 200% operating setting Time delay of zero sequence current 0.00s to 60.00s, step 0.01s ±1% setting or +40ms, at 200% operating setting Breaker failure protection (ANSI 50 BF) Item Rang or Value Tolerance phase current Negative sequence current zero sequence current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay of stage s to s, step 0.01s ±1% setting or +25 ms, at Time delay of stage s to s, step 0.01s 200% operating setting 52

55 Technical Data Reset time of stage 1 < 20ms Dead zone protection (ANSI 50DZ) Item Rang or Value Tolerance Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00s to 32.00s, step 0.01s ±1% setting or +40 ms, at 200% operating setting Pole discordance protection (ANSI 50PD) Item Rang or Value Tolerance Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00s to 60.00s, step 0.01s ±1% setting or +40 ms, at 200% operating setting STUB protection (ANSI 50STUB) Item Rang or Value Tolerance Current 0.08 Ir to Ir ±3% setting or ±0.02Ir Time delay 0.00s to 60.00s, step 0.01s ±1% setting or +40 ms, at 200% operating setting Undervoltage protection (ANSI 27) Item Rang or Value Tolerance Voltage connection Phase-to-phase voltages or phase-to-earth voltages ±3 % setting or ±1 V Phase to earth voltage 5 to 75 V, step 1 V ±3 % setting or ±1 V Phase to phase voltage 10 to 150 V, step 1 V ±3 % setting or ±1 V Reset ratio 1.01 to 2.00, step 0.01 ±3 % setting Time delay 0.00 to s, step 0.01 s ±1 % setting or +50 ms, at 80% operating setting Current criteria 0.08 to 2.00 Ir ±3% setting or ±0.02Ir Reset time 50 ms 53

56 Technical Data Overvoltage protection (ANSI 59) Item Rang or Value Tolerance Voltage connection Phase-to-phase voltages or phase-to-earth voltages ±3 % setting or ±1 V Phase to earth voltage 40 to 100 V, step 1 V ±3 % setting or ±1 V Phase to phase voltage 80 to 200 V, step 1 V ±3 % setting or ±1 V Reset ratio 0.90 to 0.99, step 0.01 ±3 % setting Time delay 0.00 to s, step 0.01s ±1 % setting or +50 ms, at 120% operating setting Reset time <40ms Synchro-check and voltage check (ANSI 25) Operating mode Item Rang or Value Tolerance Synchronization check: Synch-check Energizing check, and synch-check if energizing check failure Override Energizing check: Dead V4 and dead V 3Ph Dead V4 and live V 3Ph Live V4 and dead V 3Ph Voltage threshold of dead line or bus Voltage threshold of live line or bus V-measurement Voltage difference 10 to 50 V (phase to earth), step 1 V 30 to 65 V (phase to earth), step 1 V 1 to 40 V (phase-to-earth), steps 1 V ± 3 % setting or 1 V ± 3 % setting or 1 V ± 1V Δf-measurement (f2>f1; f2<f1) 0.02 to 2.00 Hz, step, 0.01 Hz, ± 20 mhz Δα-measurement (α2>α1; α2<α1) 1 to 80, step, 1 ± 3 Minimum measuring time 0.05 to s, step,0.01 s, ± 1.5 % setting value or +60 ms Maximum synch-check extension time 0.05 to s, step,0.01 s, ± 1 % setting value or +50 ms 54

57 Technical Data Auto-Reclosing (ANSI 79) Item Rang or Value Tolerance Number of reclosing shots Up to 4 Shot 1 to 4 is individually selectable AR initiating functions Dead time, separated setting for shots 1 to 4 Reclaim time Blocking duration time (AR reset time) Circuit breaker ready supervision time Dead time extension for synch-check (Max. SYNT EXT) Internal protection functions External binary input 0.05 s to s, step 0.01 s ± 1 % setting value or +50 ms 0.50 s to 60.00s, step 0.01 s 0.05 s to 60.00s, step 0.01 s 0.50 s to s, step 0.01 s 0.05 s to s, step 0.01 s VT secondary circuit supervision (97FF) Item Range or value Tolerances Minimum current 0.08Ir to 0.20Ir, step 0.01A ±3% setting or ±0.02Ir Minimum zero or negative sequence current 0.08Ir to 0.20Ir, step 0.01A ±5% setting or ±0.02Ir Maximum phase to earth voltage 7.0V to 20.0V, step 0.01V ±3% setting or ±1 V Maximum phase to phase voltage 10.0V to 30.0V, step 0.01V ±3% setting or ±1 V Normal phase to earth voltage 40.0V to 65.0V, step 0.01V ±3% setting or ±1 V 55

58 Ordering Pre-configure scheme Pre-configure Scheme M01 M02 M03 Application Full function Double or single busbar arrangement breaker arrangement Distance protection (21, 21N) Power-swing logic (68) Communication scheme for distance protection (85 21,21N) Communication scheme for earth fault protection (85 67N) Overcurrent protection (50, 51, 67) 1 Earth fault protection (50N, 51N, 67N) Emergency/backup overcurrent protection (50, 51) Emergency/backup earth fault protection (50N, 51N) Switch-onto-fault protection (50HS) Overload protection (50OL) Overvoltage protection (59) Under voltage protection (27) Breaker failure protection (50BF) 1 Dead zone protection (50SH-Z) 1 STUB protection (50STUB) 1 1 Synchro-check and energizing check (25) 1 1 Auto-reclosing (79) 1 1 Three pole tripping (94) CT secondary circuit supervision VT secondary circuit supervision (97FF) Analogue input module (5I + 4U) CPU modules

59 Ordering Communication module(with Ethernet interfaces, RS485 interfaces and time synchronizing interface) Binary input module (30 BI) Binary output modules (16 relays for tripping and initiation) Binary output modules (16 relays for signal) Power supply module Programmable LEDs Case, 4U, NOTE: n : Quantity of standard function or standard hardware, n= 1, 2,.; (n) : Quantity of optional function or optional hardware, n= 1, 2,.; 57

60 Ordering Ordering code No.1~16 No.17~36 C S C L F T Pre-configure scheme Pre-configure scheme code Pre-configure scheme number 1 Pre-configure scheme number 2 M 0~9 0~9 HMI Language (L) note English Russian French Portuguese Spanish Rated Frequency (F) 50 Hz 5 60 Hz 6 Station Communication Protocols (T) Ethernet interface:iec ; RS485 interface: IEC Ethernet interface:iec ; RS485 interface: IEC Note: Chinese is always offered as default HMI language. 58

61 Ordering No.1~16 No.17~22 No.23~36 C S C A M C Slot 1 Analogue Input Module (A) 5I (1A)+4U 5I (5A)+4U 5 6 Slot 2 CPU Module 1 (M) without FDDI 4 1 FDDI, 2Mbps, single mode, SC type, transmission distance <40 km 5 1 FDDI, 2Mbps, single mode, SC type, transmission distance 40~60kM 1 FDDI, 2Mbps, single mode, SC type, transmission distance 60~100kM 2 FDDIs, 2Mbps, SC type, Channel A: transmission distance 40~60 km; Channel B: transmission distance <40 km 2 FDDIs, 2Mbps, SC type, Channel A: transmission distance 60~100 km; Channel B: transmission distance <40 km 2 FDDIs, 2Mbps, SC type, Channel A: transmission distance <40 km; Channel B: transmission distance <40 km 2 FDDIs, 2Mbps, SC type, Channel A: transmission distance 60~100 km; Channel B: transmission distance 60~100 km e f Slot 3 Communication module (C) 3 electrical Ethernet ports, 1 RS485 ports, IRIG-B 1 3 electrical Ethernet ports, 1 RS485 ports, Pulse 2 2 electrical Ethernet ports, 2 RS485 ports, IRIG-B 3 2 electrical Ethernet ports, 2 RS485 ports, Pulse 4 2 optical Ethernet ports, 2 RS485 ports, IRIG-B 5 2 optical Ethernet ports, 2 RS485 ports, Pulse 6 59

62 Ordering No.1~22 No.23~30 No.31~36 C S C I O Slot 4 Binary Input Module (I) 30BI (220V DC), with startup blocking relay 1 30BI (110V DC), with startup blocking relay 2 Slot 5 Binary Output Module (O) 16 relays for tripping 1 Slot 6 Binary Output Module (O) 16 relays for tripping 1 16 relays (with 19 contacts) for signalling Null 3 x Slot 7 Binary Output Module (O) 16 relays for tripping 16 relays (with 19 contacts) for signalling Null 1 3 x Slot 8 Binary Output Module (O) 16 relays for tripping 16 relays (with 19 contacts) for signalling Null 1 3 x Slot 9 Binary Output Module (O) 16 relays for tripping 16 relays (with 19 contacts) for signalling Null 1 3 x 60

63 Ordering No.1~30 No.31~36 C S C P K Z Slot 10 Power Supply Module (P) 110V - 250V DC 1 Case and Front Plate (K) Case: 4U, 19' Front plate: Medium size LCD; 20 LEDs 3 Accessories (Z) Null x 61

64 Address: No.9 Shangdi 4th Street, Haidian District, Beijing, P.R.C Tel: , ext.8998 Fax: Website: