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1. RED615 variants Default I O connections Binary input Default usage Connector pins X120 Bl1 Blocking input for general use X120 1 2 X120 BI2 CB Close X120 3 2 X120 BI3 CB Open X120 4 2 X120 Bl4 Locout reset X120 5 2 Binary input Default usage Connector pins X110 BI2 External start of Breaker failure protection X110 3 4 X110 BI3 Setting group change X110 5 6 X110 Bl4 Binary signal transfer input X110 7 6 X110 BI5 DC Close Truck In X110 8 9 X110 BI6 DC Open Truck Out X110 10 9 X110 BI7 ES Close X110 11 12 X110 BI8 ES Open X110 13 12 Binary output Default usage Connector pins X100 PO1 Close CB X100 6 7 X100 PO2 Breaker failure backup trip to upstream breaker X100 8 9 X100 SO1 Line differential protection trip alarm X100 10 11 12 X100 SO2 Protection communication failure or Diff prot not available X100 13 14 X100 PO3 Open CB Trip 1 X100 15 19 X100 PO4 Open CB Trip 2 X100 20 24 Binary output Default usage Connector pins X110 SO1 Start indication X110 14 15 X110 SO2 Operate indication X110 17 18 X110 SO3 Binary transfer signal X110 20 21 LED Default usage 1 Line differential protection biased stage operate 2 Line differential protection instantaneous stage operate 3 Line differential protection is not available 4 Protection communication failure 5 Current transformer failure detected 6 Phase or negative sequence component over current 7 Breaker failure operate 8 Dist
2. TCS2 Pee Figure 14 Master trip 1 and 2 functionality The operate signals from the protections described above are connected to the two trip output contacts PO3 X100 16 19 and PO4 X100 20 23 via the corresponding Master Trip Logics TRPPTRC1 and TRPPTRC2 The open control commands to the circuit breaker from local or remote CBXCRI exe op is connected directly to the output PO3 X100 16 19 The TRPPTRC1 and 2 blocks provide the lockout latching function event generation and the trip signal duration setting If the lockout operation mode is selected one binary input can be re assigned to the RST LKOUT input of the Master Trip Logics to enable external reset via a push button RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 3 RED615 variants CIRCUIT BREAKER CONTROL AND INTERLOCKING REMOTE_FEEDER_READY amp A ru X110 DCSXSWI1 CBXCBR1 fgl OPENPOS OPENPOS ena open sEECED Lt 4 RARE DCClose 8 hy BIS TI io croseros Wand eie x100 Truckin 9 K okPos BLK OPEN EXE CL PO1 16 i BLK CLOSE OPENPOS 7 Close CB DC Open i Ye BI6 EXE OP CLOSEPOS Truck out 40 ding EXE CL okPos i i l OPENPOS OPEN ENAD i i 11 BI7 CLOSEPOS CLOSE EN
3. 77 Identification 77 Functionality 2 5 2 a ten A aaa 77 ApDplICatiQns cce htt cei E ones te tp ee Le tandas UDES 77 Current circuit supervision CCRDIF sene 85 Identification rite reete ie e e ats 85 Functionality csl antennes 85 AND PIC ALON occ ooo tee oett e M cad ates dala 86 Protection communication supervision PCSRTPC 90 Identification ee eti teet negate sic ee D Ted 90 F rictionality ane cene te A eee tete E Re dd 90 Applications nta rana 91 Measurement functions 93 Basic measurements 93 Three phase current CMMXU 93 Identification 1 2 2 8 2 ceteri tei tee ce ene gites ta c Ie Ld d 93 Sequence current CSMSQI 93 Idenitificatlon eee cutie UNE 93 F nctlons 2 Let eee e ile de ist ee Ete dede cn on ee oo ned eo 93 Measurement function applications 93 Disturbance recorder 95 Functional ici studies bre ee bbb add 95 Application ih 95 Control functions iii 97 Circuit breaker control CBXCBR sss 97 Identification ist do e teh ttal tute 97 F rictioriality 5 men iiit le rit ne 97 Applications int a ds ened 97 Disconnector DCSXSWI and earthing switch ESSXSWI 98 Identification c5 oon tree Ite Ed d ee 98 Functionality 5 E eer e exter tee
4. protection available PHLPTOC PHHPTOC1 PHHPTOC1 PHHPTOC2 PHHPTOC2 PHIPTOC PHIPTOC Communication faulty MFL Line differential protection not available Line differential protection not available LNPLDF LNPLDF l PHLPTOC I PHLPTOC PHIPTOC i PHIPTOC i Figure 27 Backup overcurrent protection for line differential applications Transformer and busbar overcurrent protection with reverse blocking principle By implementing a full set of overcurrent protection stages and blocking channels between the protection stages of the incoming feeders bus tie and outgoing feeders it is possible to speed up the operation of overcurrent protection in the busbar and transformer LV side faults without impairing the selectivity Also the security degree of busbar protection is increased because there is now a dedicated selective and fast busbar protection functionality which is based on the blockable overcurrent protection principle The additional time selective stages on the transformer HV and LV sides provide increased security degree of back up protection for the transformer busbar and also for the outgoing feeders Depending on the overcurrent stage in question the selectivity of the scheme in Figure 28 is based on the operating current operating time or blockings between successive overcurrent stages With
5. RED615 Application Manual 1MRS756498 A Section 2 2 1 2 1 1 2 1 2 RED615 Application Manual Section 2 RED615 overview RED615 overview Overview RED615 is a two terminal phase segregated line differential protection IED designed for the protection measurement and supervision of feeders in utility substations and industrial power systems Re engineered from the ground up the IED has been guided by the IEC 61850 standard for communication and interoperability of substation automation devices The IED provides unit type main protection for overhead lines and cable feeders in distribution networks The IED also features current based protection functions for remote back up to the down stream protection relays and local back up for the line differential main protection The IED is adapted for the protection of overhead line and cable feeders in isolated neutral resistance earthed compensated impedance earthed and solidly earthed networks Once the standard configuration IED has been given the application specific settings it can directly be put into service The 615 series IEDs support a range of communication protocols including IEC 61850 with GOOSE messaging and Modbus Product version history IED version Release date Product history 1 1 03 10 2008 Product released PCM600 and IED connectivity package version Supported tools e Protection and Control IED Manager PCM600 Ver 2 0 SP
6. The Point List Manual describes the outlook and properties of the data points specific to the IED This manual should be used in conjunction with the corresponding Communication Protocol Manual H All manuals are not available yet Document revision history Document revision date Product version History A 03 10 2008 1 1 First release The latest revision ofthe document can be downloaded from the ABB web site http www abb com substationautomation Section 1 1MRS756498 Introduction 1 3 3 Related documentation Name of the document Document ID Modbus Communication Protocol Manual 1MRS756468 Installation Manual 1MRS756375 Operation Manual 1MRS756499 Technical Manual 1MRS756497 CT dimensioning Application Note and 1MRS756683 Setting Guide 1 4 Document symbols and conventions 1 4 1 Safety indication symbols This publication includes the following icons that point out safety related conditions or other important information The electrical warning icon indicates the presence of a hazard which could result in electrical shock The warning icon indicates the presence of a hazard which could result in personal injury The caution icon indicates important information or warning related to the concept discussed in the text It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property H The information icon alerts the rea
7. UNBLOCK L s PHHPTOC 2 PHHPTOC 1 PHLPTOC m POSRTPC BLOCK E LNPLDF UNBLOCK Ly eurroc UNBLOCK L 3 PHHPTOC PHHPTOC 1 PHLPTOC RENE EDAM sd PHLPTOC PHHPTOC 1 PHIPTOC Figure 20 Protection communication supervision detects failures on communication Small power transformers in a tap With a relatively small power transformer in a line tap the line differential protection can be applied without the need of current measurement from the tap In such cases 51 Section 5 1MRS756498 Protection functions the line differential function is time delayed for low differential currents below the high set limit and LNPLDF coordinates with the downstream IEDs in the relevant tap For differential currents above the set limit the operation is instantaneous As a consequence when the load current of the tap is negligible the low resistive line faults are cleared instantaneously at the same time as maximum sensitivity for the high resistive faults are maintained but with a time delayed operation 500kVA I 2 8 75A 43 33kV 8 75A Ij gt 1 0 024 2 400 A Figure 21 Influence of the tapped transformer load current to the stabilized low stage setting The stabilized stage provides both DT and IDMT characteristics that are used to provide time selective protection against faults external to the instantaneous stage coverage The impedance of the line is typica
8. 10 1 1 2 102 The CT accuracy primary limit current describes the highest fault current magnitude at which the CT fulfils the specified accuracy Beyond this level the secondary current of the CT is distorted and it might have severe effects on the performance of the protection relay In practise the actual accuracy limit factor F differs from the rated accuracy limit factor F and is proportional to the ratio of the rated CT burden and the actual CT burden The actual accuracy limit factor is calculated using the formula Sn S F E Xi Si ES Fn the accuracy limit factor with the nominal external burden S Sin the internal secondary burden of the CT S the actual external burden Non directional overcurrent protection The current transformer selection Non directional overcurrent protection does not set high requirements on the accuracy class or on the actual accuracy limit factor F4 of the CTS It is however recommended to select a CT with F of at least 20 The nominal primary current Ij should be chosen in such a way that the thermal and dynamic strength of the current measuring input of the relay is not exceeded This is always fulfilled when Lin gt Tkmax 100 Ikmax is the highest fault current The saturation of the CT protects the measuring circuit and the current input of the relay For that reason in practice even a few times smaller nominal primary current can be used than given by the
9. Application The disturbance recorder is used for post fault analysis and for verifying the correct operation of protection IEDs and circuit breakers It can record both analog and binary signal information The analog inputs are recorded as instantaneous values and converted to primary peak value units when the IED converts the recordings to the COMTRADE format COMTRADE is the general standard format used in storing disturbance recordings The binary channels are sampled once per task execution of the disturbance recorder The task execution interval for the disturbance recorder is the same as for the protection functions During the COMTRADE conversion the digital status values are repeated so that the sampling frequencies of the analog and binary channels correspond to each other This is required by the COMTRADE standard The disturbance recorder follows the 1999 version of the COMTRADE standard and uses the binary data file format 95 96 1MRS756498 A Section 9 9 1 9 1 1 9 1 2 9 1 3 RED615 Application Manual Section 9 Control functions Control functions Circuit breaker control CBXCBR Identification Table 42 Function identification IEC 61850 identification CBXCBR IEC 60617 identification I lt gt 0 CB ANSI IEEE C37 2 device number I lt gt 0 CB Functionality The circuit breaker control function CBXCBR is intended for circuit breaker control and status information purposes
10. EFIPTOC operate EFLPTOC2 operate PDNSPTOC operate TIPTTR operate 4 CCRBRF trret CBXCBR open A ARCPSARCIT operate ARCPSARC2 operate ARCPSARC3 operate DARREC open cb OR TRPPTRC OPERATE TRIP BLOCK CL LKOUT RST_LKOUT HELLE BI 2 LE Bi 4 Lock out reset Figure 33 Typical TRPPTRC connection 73 Section 6 1MRS756498 A Protection related functions 6 4 6 4 1 6 4 2 74 Lockout TRPPTRC is provided with possibilities to activate a lockout When activated the lockout can be manually reset after checking the primary fault by activating the RST LKOUT input or from the LHMI clear menu parameter When using the Latched mode the resetting of the TRIP output can done similarly as when using the Lockout mode It is also possible to reset the Latched mode remotely through a separate communication parameter The minimum pulse trip pulse function is not active when using the Lockout or Latched modes but only when the Non latched mode is selected Binary signal transfer BSTGGIO Identification Table 35 Function identification IEC 61850 identification BSTGGIO IEC 60617 identification BST ANSI IEEE C37 2 device number BST Functionality The binary signal transfer function BSTGGIO is used for
11. It handles run time fault situations and informs the user about the existing faults via the LHMI and the communication There are two types of fault indications e Internal faults Warnings Internal faults Internal fault indications have the highest priority on the LHMI None of the other LHMI indications can override the internal fault indication 43 Section 4 Basic functions 44 1MRS756498 A An indication about the fault is shown as a message on the LHMI The text Internal Fault with an additional text message a code date and time is shown to indicate the fault type Different actions are taken depending on the severity of the fault The IED tries to eliminate the fault by restarting After the fault is found to be permanent the IED stays in internal fault mode All other output contacts are released and locked for the internal fault The IED continues to perform internal tests during the fault situation The internal fault code indicates the type of internal IED fault When a fault appears document the code and state it when ordering the service Table 24 Internal fault indications and codes Fault indication Fault code Additional information Internal Fault 2 An internal system error has occurred System error Internal Fault 7 A file system error has occurred File system error Internal Fault 8 Internal fault test activated manually by the Test user Internal Fault
12. 11 12 10 ANSI IEEE C37 2 device number 11 12 10 Functions The three phase current measurement function CMM XU is used for monitoring and metering the phase currents of the power system The sequence current measurement CSMSQI is used for monitoring and metering the phase sequence currents The information of the measured quantity is available for the operator both locally in LHMI and remotely to a network control center via communication Measurement function applications The measurement functions are used for power system measurement supervision and reporting to LHMI a monitoring tool within PCM600 or to the station level for example via IEC 61850 The possibility to continuously monitor the measured values 93 Section 8 1MRS756498 A Measurement functions of active power reactive power currents voltages frequency power factors and so on is vital for efficient production transmission and distribution of electrical energy It provides a fast and easy overview of the present status of the power system to the system operator Additionally it can be used during testing and commissioning of protection and control relays to verify the proper operation and connection of instrument transformers that is current transformers CTs and voltage transformers VTs The proper operation of the relay analog measurement chain can be verified during normal service by a periodic comparison of the measured value from the relay to
13. 11 matrix programmable alarm LEDs on front ofthe LHMI The LEDs can be configured with PCM600 and the operation mode can be selected with the LHMI Keypad The LHMI keypad consists of push buttons which are used to navigate in different views or menus With push buttons you can give open or close commands to one primary object for example a circuit breaker disconnector or switch The push Section 2 1MRS756498 RED615 overview buttons are also used to acknowledge alarms reset indications provide help and switch between local and remote control mode Figure 3 LHMI keypad with object control navigation and command push buttons and RJ 45 communication port 2 5 WHMI The WHMI enables the user to access the IED via a web browser H WHMI is disabled by default WHMI offers the following functions Alarm indications and event lists e System supervision e Parameter settings e Measurement display Phasor diagram The menu tree structure on the WHMI is identical to the one on the LHMI 16 RED615 Application Manual 1MRS756498 A Section 2 RED615 overview ABB IED31 RED615 User Engineer Connection NoString Microsoft Internet Explorer provided by ABB E xl Ele Edit View Favorites Tools Help Ay zl SE Q O i92 GO D dre O12 GEA S Address http 192 168 2 31 htdocs application html 18 so Links 1ED31 RED615 06 06 2008 14 41 General Events Alarms P
14. 150 ms in the DT mode of operation can be used provided that the circuit breaker interrupting time is shorter than 60 ms The sensitivity and speed of the current selective stages become as good as possible due to the fact that the transient overreach is practically zero Also the effects of switching inrush currents on the setting values can be reduced by using the IED logic which recognizes the transformer energizing inrush current and blocks the operation or multiplies the current start value setting of the selected overcurrent stage with a predefined multiplier setting Finally a dependable trip of the overcurrent protection is secured by both a proper selection of the settings and an adequate ability of the measuring transformers to reproduce the fault current This is important in order to maintain selectivity and also for the protection to operate without additional time delays For additional information about available measuring modes and current transformer requirements refer to section where general function block features are described in the IED technical manual Radial outgoing feeder over current protection The basic requirements for feeder overcurrent protection are adequate sensitivity and operation speed taking into account the minimum and maximum fault current levels along the protected line selectivity requirements inrush currents and the thermal and mechanical withstand of the lines to be protected In many cases the
15. 22 It can be used for example for external alarm purposes peee SS SS SS SS SSS SS eS et PHIPTOC operate PHHPTOC2 operate PHHPTOC1 operate i i i LNPLDF operate 34 i i i PHLPTOC operate OR CCBRBRF1 i NSPTOC1 operate NSPTOC2 operate SABE o e i A PO Z7 X100 i 51BF 51NBF p BI2 Startof CBFP a Tener 8 CBFP trip to i 0 TRBU 9 Upstream Breaker i START CB FAULT AL A BI2 CB Closed lrosciose l CB FAULT BLOCK i i i Figure 11 Breaker failure protection The breaker failure protection CCBRBRF1 is initiated through the start input by a number of different protection stages in the IED The breaker failure protection function offers different operating modes associated with circuit breaker position and the measured phase and residual currents The breaker failure protection has two operating outputs TRRET and TRBU The TRRET operate output is used for retripping its own breaker through the Master Trip Logic 2 The TRBU output is used to give a back up trip to the breaker feeding upstream For this purpose the TRBU RED615 Application Manual 1MRS756498 A 3 3 3 2 RED615 Application Manual Section 3 RED615 variants operate output signal is connected to output PO2 X100 8 9 LED 7 is used fo
16. This function executes commands and evaluates block conditions and different time supervision conditions The function performs an execution command only if all conditions indicate that a switch operation is allowed If erroneous conditions occur the function indicates an appropriate cause value The function is designed according to the IEC 61850 7 4 standard with logical nodes CILO CSWI and XCBR The circuit breaker control function has an operation counter for closing and opening cycle The operator can read and write the counter value remotely from an operator place or via LHMI Application In the field of distribution and sub transmission automation reliable control and status indication of primary switching components both locally and remotely is in a significant role They are needed especially in modern remotely controlled substations Control and status indication facilities are implemented in the same package with CBXCBR When primary components are controlled in the energizing phase for example the user must ensure that the control commands are executed in a correct sequence This can be achieved for example with interlocking based on the status indication of the related primary components An example of how the interlocking on substation level can be applied by using the IEC61850 GOOSE messages between feeders is as follows 97 Section 9 1MRS756498 Control functions Figure 49 Status indication based interlocking
17. different page views designated as follows 21 Section 3 RED615 variants 3 2 1 22 Binary input Binary output e Functions 1MRS756498 A The functions in different page views are identified by the IEC 61850 names with analogy to the functional diagrams Standard configurations The line differential protection IED RED615 supports the following functions Standard configuration functionality Std conf A DEO1 Protection Line differential protection and related measurements stabilized low set stage Line differential protection and related measurements instantaneous high set stage Three phase non directional overcurrent low set stage Three phase non directional overcurrent high set stage instance 1 Three phase non directional overcurrent high set stage instance 2 Three phase non directional overcurrent instantaneous stage Negative sequence overcurrent instance 1 Negative sequence overcurrent instance 2 Circuit breaker failure protection Three phase inrush current detection Binary signal transfer Control Circuit breaker control with interlocking Supervision and Monitoring Trip circuit supervision of two trip circuits Local and remote phase currents protection co ordinated Current circuit supervision Protection communication supervision Measurement Transient disturbance recorder Three phase cu
18. ee Peg etn 98 APPIICAION 1 reete t ta p CaS 99 3 Table of contents Interaction between control modules 99 Section 10 Requirements for measurement transformers 101 Current transformers 101 Current transformer requirements for non directional overcurrent protection 101 Current transformer accuracy class and accuracy limit L TES RE LEE 101 Non directional overcurrent protection 102 Example for non directional overcurrent protection 103 Current transformer requirements for line differential protection retire eet cet dC Medea Rd ae 104 Current transformer accuracy class and accuracy limit E H ad et 105 Section 11 Glossary 107 RED615 Application Manual 1MRS756498 A Section 1 1 1 1 2 RED615 Application Manual Section 1 Introduction Introduction This manual Application Manual contains application descriptions and setting guidelines sorted per function The manual can be used to find out when and for what purpose a typical protection function can be used The manual can also be used when calculating settings Intended audience This manual addresses the protection and control engineer responsible for planning pre engineering and engineering The protection and control engineer must be experienced in electrical power engineering and have knowledge of related tec
19. formula Recommended start current settings If Ikmin is the lowest primary current at which the highest set overcurrent stage of the relay is to operate then the start current should be set using the formula Current start value lt 0 7 x min Tin Iin is the nominal primary current of the CT RED615 Application Manual 1MRS756498 A 10 1 1 3 RED615 Application Manual Section 10 Requirements for measurement transformers The factor 0 7 takes into account the protection relay inaccuracy current transformer errors and imperfections of the short circuit calculations The adequate performance of the CT should be checked when the setting of the high set stage O C protection is defined The operate time delay caused by the CT saturation is typically small enough when the relay setting is noticeably lower than F When defining the setting values for the low set stages the saturation of the CT does not need to be taken into account and the start current setting is simply according to the formula Delay in operation caused by saturation of current transformers The saturation of CT may cause a delayed relay operation To ensure the time selectivity the delay must be taken into account when setting the operate times of successive relays With definite time mode of operation the saturation of CT may cause a delay that is as long as the time the constant of the DC component of the fault current when the current is only sl
20. of numerical multiple stage over current protection Unbalance protection Negative phase sequence current protection NSPTOC Identification Table 31 Function identification IEC 61850 identification NSPTOC IEC 60617 identification 12 gt ANSI IEEE C37 2 device number 46 Functionality The negative phase sequence current protection NSPTOC is used for increasing sensitivity to detect single phasing situations unbalanced loads due to for example broken conductors or to unsymmetrical feeder voltages The function is based on the measurement of the negative phase sequence current In a fault situation the function starts when the negative phase sequence current exceeds the set limit The operate time characteristics can be selected to be either definite time DT or inverse definite minimum time IDMT In the DT mode the function operates after a predefined operate time and resets when the fault current disappears The IDMT mode provides current dependent timer characteristics The function contains a blocking functionality It is possible to block function outputs timers or the function itself if desired 67 Section 5 1MRS756498 Protection functions 5 3 1 3 Application Since the negative sequence current quantities are not present during normal balanced load conditions the negative sequence overcurrent protection elements can be set for faster and more sensitive operation than the normal phase overcu
21. of phase currents I A I B and I C and compares the sum against the measured single reference current I REF The reference current must originate from other three phase CT cores than the phase 85 Section 7 1MRS756498 A Supervision functions currents I A I B and I C and it is to be externally summated that is outside the IED CCRDIF detects a fault in the measurement circuit and issues an alarm or blocks the protection functions to avoid unwanted tripping It must be remembered that the blocking of protection functions at an occurring open CT circuit means that the situation will remain and extremely high voltages will stress the secondary circuit 7 2 3 Application Open or short circuited current transformer cores can cause unwanted operation in many protection functions such as differential earth fault current and negative sequence current functions When currents from two independent three phase sets of CTs or CT cores measuring the same primary currents are available reliable current circuit supervision can be arranged by comparing the currents from the two sets When an error in any CT circuit is detected the protection functions concerned can be blocked and an alarm given In case of high currents the unequal transient saturation of CT cores with a different remanence or saturation factor may result in differences in the secondary currents from the two CT cores Unwanted blocking of protection functions during the tr
22. other independent meters When the zero signal is measured the noise in the input signal can still produce small measurement values The zero point clamping function can be used to ignore the noise in the input signal and hence prevent the noise to be shown in the user display Zero clamping is done for the measured analog signals and angle values The demand values can be used to neglect sudden changes in the measured analog signals when monitoring long time values for the input signal The demand values are linear average values of the measured signal over a settable demand interval The demand values are calculated for the measured analog three phase current signals The demand value calculation reports a new value when the demand interval has elapsed The limit supervision indicates if the measured signal exceeds the set limits by activating the alarm warning outputs of the function These outputs can be used to configure the reporting function events The supervision function has four different limits e low alarm limit e low warning limit high warning limit e high alarm limit There is an exception in limit supervision concerning the residual current and the residual voltage measurement only high alarm limits are available In three phase current measurement the alarm high indications are given for the phase that has the maximum measured value However a range indication is given to each phase The deadband supervision re
23. predefined setting if the ENA MULT input is activated In this configuration it is activated by the open status information of the remote end circuit breaker disconnectors and earth switch The intention of this connection is to lower the setting value of the instantaneous high stage by multiplying with setting High Op value Mult in case of internal fault The operate signal is connected to the Master Trip Logics 1 and 2 and also to the alarm LEDs LED 1 is used for start or operate of stabilized low stage and LED 2 for start or operate of instantaneous high stage indication The indication of the high or low stage operation is also connected to the output SO1 X100 10 11 12 The LED 3 is used to indicate if the line differential is not available This is due to failures in protection communication or the LNPLDF function is set to test mode 27 Section 3 1MRS756498 RED615 variants Figure 7 Protection communication supervision The protection communication supervision function PCSRTPC is used in configuration to block the operation of the line differential function By this way malfunction of the line differential is prevented Also the activation of binary signal transfer outputs during protection communication failure is blocked These are done internally without connections in configurations Anyhow the information of the protection communication supervision alarm is connected to alarm LED4 to disturbance recorder and to signal ou
24. requirements are complied with In particular any risks in applications where a system failure and or product failure would create a risk for harm to property or persons including but not limited to personal injuries or death shall be the sole responsibility of the person or entity applying the equipment and those so responsible are hereby requested to ensure that all measures are taken to exclude or mitigate such risks This document has been carefully checked by ABB but deviations cannot be completely ruled out In case any errors are detected the reader is kindly requested to notify the manufacturer Other than under explicit contractual commitments in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment Conformity This product complies with the directive ofthe Council ofthe European Communities on the approximation of the laws of the Member States relating to electromagnetic compatibility EMC Council Directive 2004 108 EC and concerning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of a test conducted by ABB in accordance with Article 10 ofthe directive in agreement with the product standards EN 50263 and EN 60255 26 for the EMC directive and with the product standards EN 60255 6 and EN 60255 27 for the low voltage directive The IED is designed in accordance with the
25. reset has occurred Watchdog reset Warning 11 The auxiliary supply voltage has dropped Power down det too low Warning 20 Error when building the IEC 61850 data IEC61850 error model Warning 21 Error in the Modbus communication Modbus error Warning 22 Error in the DNP3 communication DNP3 error Warning 24 Error in the Data set s Dataset error Warning 25 Error in the Report control block s Report cont error Table continues on next page 45 Section 4 1MRS756498 Basic functions Warning indication Warning code Additional information Warning 26 Error in the GOOSE control block s GOOSE contr error Warning 27 Error in the SCL configuration file or the file SCL config error is missing Warning 28 Too many connections in the Logic error configuration Warning 29 Error in the SMT connections SMT logic error Warning 30 Error in the GOOSE connections GOOSE input error Warning 32 Error in the GOOSE message receiving GOOSE rec error Warning 33 Analog channel configuration error AFL error Warning 40 A new composition has not been Unack card comp acknowledged accepted Warning 50 Error in protection communication Protection comm Warning 85 A continuous light has been detected on ARC1 cont light the ARC light input 1 Warning 86 A continuous light has been detected on ARC2 cont light the ARC light input 2 Warning 87 A continuous light has been d
26. setting for low set stage 3I gt is selected to be about twice the nominal current of the cable The operate time is selected so that it is selective with the next relay not visible in the figure above The settings for the high set stage and instantaneous stage are defined also so that grading is ensured with the downstream protection In addition the start current settings have to be defined so that the relay operates with the minimum fault current and it does not operate with the maximum load current The settings for all three stages are as in the figure above For the application point of view the suitable setting for instantaneous stage I gt gt gt in this example is 3 500 A 5 83 x L For the CT characteristics point of view the criteria given by the current transformer selection formula is fulfilled and also the relay setting is considerably below the F In this application the CT rated burden could have been selected much lower than 10 VA for economical reasons Current transformer requirements for line differential protection In line differential application the CT has to be chosen carefully The purpose of the CT requirements is to secure the stability of the IED at high through currents and also the quick and sensitive operation at faults occurring in the protected area where the fault currents may be high Normally when the residual flux of the current transformer is high it is not possible to dimension the CTs so that
27. the function starts the START output is set to TRUE Functions codes and symbols Parameter values are indicated with quotation marks for example IED input output messages and monitored data names are shown in Courier font Table 1 Functions included in the RED615 standard configuration Function IEC 61850 IEC 60617 ANSI Line differential protection stabilized low stage LNPLDF 3Al gt 3Al gt gt 87L and instantaneous high stage Three phase non directional overcurrent PHLPTOC1 3l 51P 1 protection low stage Three phase non directional overcurrent PHHPTOC1 31 gt gt 51P 2 protection high stage Three phase non directional overcurrent PHIPTOC1 31 gt gt gt 50P 51P protection instantaneous stage Negative sequence overcurrent protection NSPTOC1 l2 46 Circuit breaker failure protection CCBRBRF1 31 gt l9 gt BF 51BF 51NBF Three phase inrush detector INRPHAR1 312f gt 68 Binary signal transfer BSTGGIO BST BST Circuit breaker control with interlocking CBXCBR O CB Three phase current measurement CMMXU 1 3I 3l Sequence current measurement CSMSQI1 l4 l2 lo 14 l2 lo Transient disturbance recorder RDRE1 Table continues on next page Section 1 1MRS756498 A Introduction Function IEC 61850 IEC 60617 ANSI Trip circuit supervision TCSSCBR1 TCS TCM Current circuit supervision CCRDIF1 MCS 31 MCS 31 Protection communication supervision PCSRTPC1 PCS PCS
28. the time to receive a message from A to B T4 T5 are measured The station A IED delay from the sampling to the start of send T3 T4 and the local delay from receive to the station B IED sampling T5 T6 time are also measured for the station B IED and vice versa This way the time alignment factor for the local and remote samples is achieved Sampling time T2 Ts T4 T4 Ts Te Sample latency Sampling time Figure 48 Measuring sampling latency MT T P 7 2 Equation 3 S P T T 0 T Equation 4 The sampling latency Sq is calculated for each telegram on both ends The algorithm assumes that the one way propagation delay Py is equal for both directions The echo method without GPS can be used in telecommunication transmission networks as long as delay symmetry exists that is the sending and receiving delays are equal RED615 Application Manual 1MRS756498 A Section 8 8 1 8 1 1 8 1 1 1 8 1 2 8 1 2 1 8 1 3 8 1 4 RED615 Application Manual Section 8 Measurement functions Measurement functions Basic measurements Three phase current CMMXU Identification Table 40 Function identification IEC 61850 identification CMMXU IEC 60617 identification 3l ANSI IEEE C37 2 device number 3l Sequence current CSMSQI Identification Table 41 Function identification IEC 61850 identification CSMSQI IEC 60617 identification
29. they repeat currents with high DC components without saturating The differential IED operates reliably even when the CTs are partially saturated RED615 Application Manual 1MRS756498 A Section 10 Requirements for measurement transformers 10 1 2 1 Current transformer accuracy class and accuracy limit factor The accuracy class recommended for the CTs to be used with the line differential function LNPLDF is 5P in which the limit of the current error at the rated primary current is one percent and the limit of the phase displacement is 60 minutes The limit of the composite error at the rated accuracy limit primary current is five percent The approximate value of the accuracy limit factor F corresponding to the actual CT burden is calculated using the formula Si ES in n F Fx in a F rated accuracy limit factor at the rated burden S rated burden Sin internal burden S actual burden of the CT More detailed considerations and dimensioning examples are presented in the CT dimensioning application note for RED615 RED615 105 Application Manual 106 Section 11 RED615 Application Manual Glossary 100BASE TX Al ANSI ASCII BI BI O BO CPU CT DC DT EEPROM EMC Ethernet FPGA GOOSE GPS HMI IEC IEC 61850 IEC 61850 8 1 IED Section 11 Glossary A physical media defined in the IEEE 802 3 Ethernet standard for local area networks LANs 100BASE TX us
30. through the monitored coil and the actual coil current is a sum of all TCS currents This must be taken into consideration when determining the resistance of Re Setting the TCS function in a protection IED not in use does not typically effect the supervising current injection Trip circuit supervision with auxiliary relays Many retrofit projects are carried out partially that is the old electromechanical relays are replaced with new ones but the circuit breaker is not replaced This creates a problem that the coil current of an old type circuit breaker may be too high for the protection IED trip contact to break The circuit breaker coil current is normally cut by an internal contact of the circuit breaker In case of a circuit breaker failure there is a risk that the protection IED trip contact is destroyed since the contact is obliged to disconnect high level of electromagnetic energy accumulated in the trip coil An auxiliary relay can be used between the protection IED trip contact and the circuit breaker coil This way the breaking capacity question is solved but the TCS circuit in the protection IED monitors the healthy auxiliary relay coil not the circuit breaker coil The separate trip circuit supervision relay is applicable for this to supervise the trip coil of the circuit breaker Dimensioning of the external resistor Under normal operating conditions the applied external voltage is divided between the relay s internal c
31. to Ethernet based communication systems via the RJ 45 connector 100BASE TX If connection to a RS 485 network is required the 9 pin screw terminal connector can be used An ST type connector for serial communication over fibre optics is available as well A RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 2 RED615 overview direct dedicated fibre optic connection is used between the IEDs as a protection communication link 1300 nm multi mode or single mode fibres with LC connectors are used for line differential communication The LC port in the IED is always the topmost 20 1MRS756498 A Section 3 3 1 3 2 RED615 Application Manual Section 3 RED615 variants RED615 variants RED615 variant list The protection and control relay RED615 is mainly intended for MV feeder applications The description of the standard configuration covers the full functionality presenting the functionality flexibility and external connections of RED615 with the specific configuration as delivered from the factory The additional BI O card is not included in the standard configuration Presentation of standard configurations Functional diagrams The functional diagrams describe the IED s functionality from the protection measuring condition monitoring disturbance recording control and interlocking perspective Diagrams show the default functionality with simple symbol logics forming principle dia
32. via GOOSE messaging 9 2 Disconnector DCSXSWI and earthing switch ESSXSWI 9 2 1 Identification Table 43 Function identification IEC 61850 identification DCSXSWI ESSXSWI IEC 60617 identification 1 lt gt 0 DC I lt gt 0 ES ANSI IEEE C37 2 device l lt gt 0 DC I lt gt 0 ES number 9 2 2 Functionality The functions DCSXSWI and ESSXSWI indicate remotely and locally the open close and undefined states of the disconnector and earthing switch The functionality of both is identical but each one is allocated for a specific purpose visible in the function names For example the status indication of disconnectors or circuit breaker truck can be monitored with the DCSXSWI function The functions are designed according to the IEC 61850 7 4 standard with the logical node XSWI 98 RED615 Application Manual 1MRS756498 Section 9 Control functions 9 2 3 Application In the field of distribution and sub transmission automation the reliable control and status indication of primary switching components both locally and remotely is in a significant role These features are needed especially in modern remote controlled substations The application area of DCSXSWI and ESSXSWI functions covers remote and local status indication of for example disconnectors air break switches and earthing switches which represent the lowest level of power switching devices without short circuit breaking capability 9 3 Interaction betw
33. 1 or later e RED615 Connectivity Package Ver 1 0 Parameter Setting Tool Disturbance Handling Tool Signal Monitoring Tool Section 2 1MRS756498 RED615 overview Signal Matrix Tool Communication Management Tool Differential Characteristics Tool Download connectivity packages from the ABB web site http www abb com substationautomation 2 2 Operation functionality 2 2 1 Standard configurations The line differential protection IED RED615 supports the following functions Standard configuration functionality Std conf A DEO1 Protection Line differential protection and related measurements stabilized low set stage Line differential protection and related measurements instantaneous high set stage Three phase non directional overcurrent low set stage Three phase non directional overcurrent high set stage instance 1 e Three phase non directional overcurrent high set stage instance 2 Three phase non directional overcurrent instantaneous stage Negative sequence overcurrent instance 1 Negative sequence overcurrent instance 2 Circuit breaker failure protection e Three phase inrush current detection Binary signal transfer e Control Circuit breaker control with interlocking Supervision and Monitoring Trip circuit supervision of two trip circuits e Local and remote phase currents protection co ordinated e Curr
34. 10 Watchdog reset has occurred too many SW watchdog error times within an hour Internal Fault 43 Faulty Signal Output relay s in card SO relay s X100 located in slot X100 Internal Fault 44 Faulty Signal Output relay s in card SO relay s X110 located in slot X110 Internal Fault 46 Faulty Signal Output relay s in card SO relay s X130 located in slot X130 Internal Fault 53 Faulty Power Output relay s in card PO relay s X100 located in slot X100 Internal Fault 54 Faulty Power Output relay s in card PO relay s X110 located in slot X110 Internal Fault 56 Faulty Power Output relay s in card PO relay s X130 located in slot X130 Internal Fault 57 Faulty ARC light sensor input s Light sensor error Internal Fault 62 Card in slot X000 is wrong type Conf error X000 Internal Fault 63 Card in slot X100 is wrong type or does not Conf error X100 belong to the original composition Internal Fault 64 Card in slot X110 is wrong type is missing Conf error X110 or does not belong to the original composition Internal Fault 65 Card in slot X120 is wrong type is missing Conf error X120 or does not belong to the original composition Internal Fault 66 Card in slot X130 is wrong type is missing Conf error X130 or does not belong to the original composition Internal Fault 72 Card in slot X000 is faulty Card error X000 Table continues on next page RED615 Application Manual 1MRS75
35. 2 Li 1 19 CARTE 18 20 f Ly S03 Sw e B2 i A 22 3 21 y 4 leaa x130 6 Bikes 10 1 ies 7 EN sot C X BIS 12 8 11 5 13 3 a gt BIG so E X 14 x X 16 455 sos CH A LAN 18 17 x2 2 LAN x5 1 3 1 GND 2 GNDC 3 L IRIG B 4 IRIG B 5 AGND 6 s TX T Ale 8 ge a ie TRX 12 Tus 1 Optional RX 2 100BaseFx LC or 100BaseTx RJ 45 TA 3 RS 485 serial bus Xi6 4 Fibre Optic ST Serial Bus Line Differential Protection Communication Figure 5 Connection diagram of the RED615 line differential relay with configuration variant A RED615 23 Application Manual Section 3 RED615 variants 3 3 3 3 1 3 3 2 24 1MRS756498 A Standard configuration A for line current differential protection Applications The standard configuration for line current differential protection is mainly intended for cable feeder applications in distribution networks The IED with this standard configuration is delivered from the factory with default settings and parameters The end user flexibility for incoming outgoing and internal signal designation within the IED enables this configuration to be further adapted to different primary circuit layouts and the related functionality needs by modifying the internal functionality with SMT and PST Functions Table 4 Fu
36. 250 ms relaying time which becomes the total fault clearing time in this case rre PRLPTOC iQ marre FJ PHHPTOC H PHHPTOC pur l ipe ccsrarr Ja PHIPTOC CCBRBRF INRPHAR l Derim rut a l irit imam ES ipee eun esee I If ccarerF MERA Re qe e CCBRBRF MEASUREMENT MEASUREMENT INCOMING INCOMING sfr i me PuuPTOC jH n a Pairroc ica p Blocking output Outgoing feeder PHHPTOC START Blocking output Outgoing feeder PHHPTOC START Figure 28 Numerical overcurrent protection functionality for a typical sub transmission distribution substation feeder protection not shown Blocking output digital output signal from the start of a protection stage Blocking in digital input signal to block the operation of a protection stage 64 RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 5 Protection functions The operating times of the time selective stages are very short because the grading margins between successive protection stages can be kept short This is mainly due to the advanced measuring principle allowing a certain degree of CT saturation good operating accuracy and short retardation times of the numerical units So for example a grading margin of
37. 5 Application Manual 1MRS756498 A Section 7 Supervision functions TCSSCBR ALARM Figure 40 Operating principle of the trip circuit supervision with an external resistor The TCSSCBR blocking switch is open enabling the trip circuit supervision to be independent of the circuit breaker position Using power output contacts without trip circuit supervision If TCS is not used but the contact information of corresponding power outputs are required the internal resistor can be by passed When bypassing the internal resistor the wiring between the terminals of the corresponding output X100 16 15 PO3 or X100 21 20 PO4 can be disconnected The internal resistor is required if the complete TCS circuit is used TCS1 Figure 41 Connection of a power output in a case when TCS is not used and the internal resistor is disconnected RED615 83 Application Manual Section 7 1MRS756498 A Supervision functions Incorrect connections and usage of trip circuit supervision Although the TCS circuit consists of two separate contacts it must be noted that those are designed to be used as series connected to guarantee the breaking capacity given in the technical manual of the IED In addition to the weak breaking capacity the internal resistor is not dimensioned to withstand current without a TCS circuit As a result this kind of incorrect connection causes immediate burning of the internal resistor when the circuit breaker is in the close
38. 5 Application Manual Section 3 RED615 variants LINE CURRENT DIFFERENTIAL PROTECTION CCRDIF1 LOCAL CT FAILURE BLOCK FAIL p ALARM PX LEDS CT FAILURE REMOTE CT FAIL OR LNPLDF1 i BLOCK OPERATE l BLOCK LS START ENA MULT HS STR LS LOC STR LS REM OPR LS LOC 4 OPR LS REM OR LED1 LDIFF BIASED STAGE OPERATE OPR HS LOC OPR Hs REM E RSTD2H LOG or LED2 LDIFF INST STAGE OPERATE RSTD2H_REM PROT_AGTIVE OR LNPLDF LS OP IND i REMOTE_CB_OPEN amp OR LNPLDF HS OP IND REMOTE FEEDER READY i i i i OR LNPLDF RSTD2H i Nor LNPLDF PROT ACTIVE T d Nor D LEDS LDIFF PROT NOT AVAILABLE i LNPLDF_NOT_AVAILABLE i LDIFFPROT OK Figure 6 Line differential protection The line current differential function LNPLDF is intended to be the main protection offering exclusive unit protection for the power distribution lines or cables The stabilized low stage can be blocked if the current transformer failure is detected The operate value of the instantaneous high stage can be multiplied by a
39. 6498 A 4 2 2 RED615 Application Manual Section 4 Basic functions Fault indication Fault code Additional information Internal Fault 73 Card in slot X100 is faulty Card error X100 Internal Fault 74 Card in slot X110 is faulty Card error X110 Internal Fault 75 Card in slot X120 is faulty Card error X120 Internal Fault 76 Card in slot X130 is faulty Card error X130 Internal Fault 79 LHMI module is faulty The fault indication LHMI module may not be seen on the LHMI during the fault Internal Fault 80 Error in the RAM memory on the CPU RAM error card Internal Fault 81 Error in the ROM memory on the CPU ROM error card Internal Fault 82 Error in the EEPROM memory on the CPU EEPROM error card Internal Fault 83 Error in the FPGA on the CPU card FPGA error Internal Fault 84 Error in the RTC on the CPU card RTC error Warnings A fault indication message which includes text Warning with additional text a code date and time is shown on the LHMI to indicate the fault type If more than one type of fault occur at the same time indication of the latest fault appears on the LCD The fault indication message can be manually cleared When a fault appears the fault indication message is to be recorded and stated when ordering service Table 25 Warning indications and codes Warning indication Warning code Additional information Warning 10 A watchdog
40. AD i ES Close i gt ITL BYPASS i 12 i i ESSXSWI1 amp LOCAL_FEEDER_READY 74 lua coros ES Open 143 K CLOSEPOS CLOSEPOS c i OKPOS i TRPPTRC1i tip 9 i TRPPTRC2 tip BI3 CB Open BI 2 CB Closed i T Figure 15 Circuit breaker control and interlocking The ENA_CLOSE input that is enable the close of circuit breaker in the breaker control function block CBXBR is a combination of the status of the Master Trip Logics disconnector and earthing switch position indications and remote feeder position indications Master trip logic disconnector and earthing switch status are local feeder ready information to be sent for remote end Open operation is always enabled If the ENA_CLOSE signal is completely removed from the breaker control function block CBXBR with SMT the function assumes that the breaker close commands are allowed continuously LINE DIFFERENTIAL TRIP AND PROTECTION COMMUNICATION FAILURE INDICATION 10 SO1 LA i Line differential i prot trip alarm i11 d 12 i i i l i i i i LNPLDF_LS_OP_IND i i i i i 1 LNPLDF HS OP IND OR TPGAPC1 le oun E E i LNPLDF NOT AVAILABLE dog iag PCSRTPC1 Alarm le m SO2 i Protection communication of line diff prot not available Lag i Li ji Figure 16 Line differential trip a
41. Amplitude corr 0 900 1 100 0 001 1 000 Amplitude correction Table 7 Alarm LED input signals Name Type Default Description Alarm LED 1 BOOLEAN O False Status of Alarm LED 1 Alarm LED 2 BOOLEAN O False Status of Alarm LED 2 Alarm LED 3 BOOLEAN O False Status of Alarm LED 3 Alarm LED 4 BOOLEAN O False Status of Alarm LED 4 Alarm LED 5 BOOLEAN O False Status of Alarm LED 5 Alarm LED 6 BOOLEAN O False Status of Alarm LED 6 Alarm LED 7 BOOLEAN O False Status of Alarm LED 7 Alarm LED 8 BOOLEAN O False Status of Alarm LED 8 Table continues on next page RED615 Application Manual 35 Section 4 1MRS756498 A Basic functions Name Type Default Description Alarm LED 9 BOOLEAN O False Status of Alarm LED 9 Alarm LED 10 BOOLEAN O False Status of Alarm LED 10 Alarm LED 11 BOOLEAN O False Status of Alarm LED 11 Table 8 Alarm LED settings Parameter Values Range Unit Step Default Description Alarm LED mode O Follow S O Follow S Alarm mode for LED 1 1 Follow F2 2 Latched S3 3 LatchedAck F S Description Alarm LEDs LED 1 Description of alarm Alarm LED mode O Follow S O Follow S Alarm mode for LED 2 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 2 Description of alarm Alarm LED mode 0 Follow S O Follow S Alarm mode for LED 3 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 3 Des
42. Application Manual Line Differential Protection and Control RED615 AA ED ED PAIDID Document ID 1MRS756498 Issued 03 10 2008 Revision A Product version 1 1 Copyright 2008 ABB All rights reserved Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB and the contents thereof must not be imparted to a third party nor used for any unauthorized purpose The software or hardware described in this document is furnished under a license and may be used copied or disclosed only in accordance with the terms of such license Trademarks ABB is a registered trademark of ABB Group All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders Guarantee Please inquire about the terms of guarantee from your nearest ABB representative ABB Oy Distribution Automation P O Box 699 FI 65101 Vaasa Finland Telephone 358 10 2211 Facsimile 358 10 22 41094 http www abb com substationautomation Disclaimer The data examples and diagrams in this manual are included solely for the concept or product description and are not to be deemed as a statement of guaranteed properties All persons responsible for applying the equipment addressed in this manual must satisfy themselves that each intended application is suitable and acceptable including that any applicable safety or other operational
43. Secondary current injection 58 Three phase current protection 61 Three phase non directional overcurrent protection PHXPTOGC eisie i e lent iii 61 Identification erre dd e tad 61 Functionality 1 2 iii anne 61 Apple 61 Unbalance protection 67 Negative phase sequence current protection NSPTOC 67 Identification suco tdt 67 Encina ERAI REM intense 67 Application iio e EE He o ee e aedes 68 Protection related functions 69 Three phase inrush detector INRPHAR 69 Identification etes catene doe demanda aaa 69 Functional Y iii arar ia 69 Application UE iM I LEE 69 Circuit breaker failure protection CCBRBRF 70 Identification denis mir E e eee nee 70 F nctlornality 4 52 alta files din Anis ccc Io 70 ApDDIICatiOri 22 Lir teedt ote test tre A tin 71 RED615 Application Manual Section 7 Section 8 Section 9 RED615 Application Manual Table of contents Protection trip conditioning TRPPTRC nn 72 Identifications dcc dee tt is 72 Furictionality 4 Mira tendre da 72 Application PE REDE 73 Binary signal transfer BSTGGIO sss 74 Identifications tite ads hs 74 Functionality ccc nn edie tende nn ae 74 AppliCatiODi hh suede dr aie de heu ee ae ur ee 75 Supervision functions 77 Trip circuit supervision TCSSCBR
44. above requirements can be best fulfilled by using a multiple stage over current units Figure 29 shows an example of this A brief coordination study has been carried out between the incoming and outgoing feeders The protection scheme is implemented with three stage numerical over current protection where the low set stage PHLPTOC operates in IDMT mode and the two higher stages PHHPTOC and PHIPTOC in DT mode Also the thermal withstand of the line types along the feeder and maximum expected inrush currents of the feeders are shown Faults occurring near the station where the fault current levels are the highest are cleared rapidly by the instantaneous stage in order to minimize the effects of severe short circuit faults The influence of the inrush current is taken into consideration by connecting the inrush current detector to the start value multiplying input of the instantaneous stage By this way the start value is multiplied with a predefined setting during the inrush situation and nuisance tripping can be avoided 65 Section 5 1MRS756498 Protection functions MF Ik max Ik min OUTGOING OUTGOING INCOMING MF MF Line type 2 J Ik max Ik min I Line type 1 Ik max o HAIR min Figure 29 Functionality of numerical multiple stage overcurrent protection The coordination plan is an effective tool to study the operation of time selective operation charac
45. al 1MRS756498 A RED615 Application Manual Section 5 Protection functions Before the test the trip signal to the circuit breaker shall be blocked for example by breaking the trip circuit by opening the terminal block or by using some other suitable method When injecting current to one phase in the local end IED the current is seen as a differential current at both ends If a current linjected 18 injected L1 in phase L1 the differential and stabilizing currents for phase L1 are IDIFF _A 2xXIBIAS_A I injected Equation 1 The operation is equal for phases L2 and L3 Verifying the settings Procedure 1 Block the unwanted trip signals from the IED units involved 2 Inject a current in phase L1 and increase the current until the function operates for phase Ll The injected operate current shall correspond to the set Low operate value The monitored values for IDIFF A and IBIAS A should be equal to the injected current Repeat point 2 by current injection in phases L2 and L3 4 Measure the operating time by injecting the single phase current in phase 1 The injected current should be four times the operating current The time measurement is stopped by the trip output from the IED unit 5 Disconnect the test equipment and reconnect the current transformers and all other circuits including the trip circuit U Phasor echoing method The line differential function in one IED can be set to special test mode
46. anging settings Clearing event list Clearing disturbance records Changing system settings such as IP address serial baud rate or disturbance recorder settings Setting the IED to test mode Selecting language ADMINISTRATOR All listed above Changing password H For user authorization for PCM600 see PCM600 documentation Communication The IED supports two different communication protocols IEC 61850 and Modbus Operational information and controls are available through these protocols IEC 61850 communication can be used parallel with Modbus Modbus protocol uses either Ethernet or the RS 485 bus The IEC 61850 communication implementation supports all monitoring and control functions Additionally parameter setting and disturbance file records can be accessed using the IEC 61850 8 1 protocol Further the IED can send and receive binary signals from other IEDs so called horizontal communication using the IEC 61850 8 1 GOOSE profile where the highest performance class with a total transmission time of 3 ms is supported The IED can simultaneously report to five different IEC 61850 8 1 clients The IED can support five simultaneous clients If PCM600 reserves one client connection only four client connections are left for example for IEC 61850 and Modbus All communication connectors except for the front port connector are placed on integrated optional communication modules The IED can be connected
47. ansient stage must then be avoided The supervision function must be sensitive and have a short operate time in order to prevent unwanted tripping from fast acting sensitive numerical protections in case of faulty CT secondary circuits may damage the insulation and cause further problems This must be taken into consideration especially when the protection functions are blocked A Open CT circuits create extremely high voltages in the circuits which When the reference current is not connected to the IED the function should be turned off Otherwise the FAIL output will be activated when unbalance occur in the phase currents even though there is nothing wrong with the measurement circuit Reference current measured with core balanced current transformer The function compares the sum of phase currents with the current measured with the core balanced CT 86 RED615 Application Manual 1MRS756498 A Section 7 Supervision functions IL1 IL2 IL3 T prx 2 RE_615 oo 50 3 CCRDIF a isi LA FAIL IB ALARM I I_C 318 LREF REF BLOCK Er O ov SE 99 a 4 Figure 44 Connection diagram for reference current measurement with core balanced current transformer Current measurement with two independent three phase sets of CT cores The figures show diagrams of connections where the reference current is measured wi
48. blocking channels the operating time of the protection can be drastically shortened if compared to the simple time selective protection In addition to the busbar protection this blocking principle is applicable for the protection of transformer LV terminals and short lines The functionality and 63 Section 5 1MRS756498 Protection functions performance of the proposed overcurrent protections can be summarized as seen in the table Table 30 Proposed functionality of numerical transformer and busbar over current protection DT definite time IDMT inverse definite minimum time O C stage Operating char Selectivity mode Operation speed Sensitivity HV 31 gt DT IDMT time selective HV 31 gt gt DT blockable time selective HV 31 gt gt gt DT current selective LV 31 gt DT IDMT time selective LV 31 gt gt DT time selective LV 31 gt gt gt DT blockable In case the bus tie breaker is open the operating time of the blockable overcurrent protection is approximately 100 ms relaying time When the bus tie breaker is closed that is the fault current flows to the faulted section of the busbar from two directions the operation time becomes as follows first the bus tie relay unit trips the tie breaker in the above 100 ms which reduces the fault current in to a half After this the incoming feeder relay unit of the faulted bus section trips the breaker in approximately
49. ch protection telegram and the exchange of these protection telegrams is done eight times per power system cycle every 2 5 ms when F 50 Hz Master Master communication arrangement is used in the two terminal line differential solution Current samples are sent from both line ends and the protection algorithms are also executed on both line ends The direct intertrip however ensures that both ends are always operated simultaneously Time synchronization In numerical line differential protection the current samples from the protections which are located geographically apart from each other must be time coordinated so that the current samples from both ends of the protected line can be compared without introducing irrelevant errors The time coordination requires an extremely high accuracy Asan example an inaccuracy of 0 1 ms in a 50 Hz system gives a maximum amplitude error of approximately around 3 percent An inaccuracy of 1 ms gives a maximum amplitude error of approximately 31 percent The corresponding figures for a 60 Hz system are 4 and 38 percent respectively 91 Section 7 1MRS756498 A Supervision functions 92 In the IED the time coordination is done with an echo method The IEDs create their own time reference between each other so that the system clocks do not need to synchronize The figure shows that in the time synchronization the transmission time to send a message from station B to station A T1 T2 and
50. cription of alarm Alarm LED mode O Follow S O Follow S Alarm mode for LED 4 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 4 Description of alarm Alarm LED mode O Follow S O Follow S Alarm mode for LED 5 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 5 Description of alarm Alarm LED mode 0 Follow S O Follow S Alarm mode for LED 6 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 6 Description of alarm Alarm LED mode O Follow S O Follow S Alarm mode for LED 7 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 7 Description of alarm Alarm LED mode O Follow S O Follow S Alarm mode for LED 8 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 8 Description of alarm Table continues on next page 36 RED615 Application Manual 1MRS756498 Section 4 Basic functions Parameter Values Range Unit Step Default Description Alarm LED mode O Follow S 0 Follow S Alarm mode for LED 9 1 Follow F 2 Latched S 3 LatchedAck F S Description Alarm LEDs LED 9 Description of alarm Alarm LED mode O Follow S 1 Follow F 2 Latched S 3 LatchedAck F S 0 Follow S Alarm mode for LED 10 Description Alarm LEDs LED 10 Description of alarm Alarm LED mode 0 Follow S 1 Follow F 2 Latched S 3 LatchedAck F S O Follow S Alarm mode for LED 11 Description 1 Non latched mode 2 Non latched blinki
51. ction functions are routed through the trip logic The most simplified alternative of a logic function is linking the trip signal and ensuring that the signal is long enough The tripping logic in the protection relay is intended to be used in the three phase tripping for all fault types 3ph operating To prevent the closing of a circuit breaker after a trip the function can block the CBXCBR closing The TRPPTRC function is intended to be connected to one trip coil of the corresponding circuit breaker If tripping is needed for another trip coil or another circuit breaker which needs for example different trip pulse time another trip logic function can be used The two instances of the PTRC function are identical only the names of the functions TRPPTRC1 and TRPPTRC2 are different Therefore even if all references are made only to TRPPTRCI they also apply to TRPPTRC2 The inputs from the protection functions are connected to the OPERATE input Usually a logic block OR is required to combine the different function outputs to this input The TRIP output is connected to the digital outputs on the IO board This signal can also be used for other purposes within the IED for example when starting the breaker failure protection TRPPTRC is used for simple three phase tripping applications PHLPTOC operate PHHPTOC1 operate PHHPTOC2 operate PHIPTOC operate NSPTOC1 operate NSPTOC2 operate EFLPTOC1 operate EFHPTOC operate
52. current I 2H and the fundamental frequency current I 1H exceeds the set value The operate time characteristic for the function is of definite time DT type The function contains a blocking functionality Blocking deactivates all outputs and resets timers Application Transformer protections require high stability to avoid tripping during magnetizing inrush conditions A typical example of an inrush detector application is doubling the Start value of an overcurrent protection during inrush detection The inrush detection function can be used to selectively block overcurrent and earth fault function stages when the ratio of second harmonic component over the fundamental component exceeds the set value Other applications of this function include the detection of inrush in lines connected to a transformer 69 Section 6 1MRS756498 A Protection related functions all VIT ju ii TA 2 ln Ratio SR 12H 1_1H 2H 1 1H BLK2H Figure 31 Inrush current in transformer 6 2 Circuit breaker failure protection CCBRBRF 6 2 1 Identification Table 33 Function identification IEC 61850 identification CCBRBRF IEC 60617 identification 31 gt l0 gt BF ANSI IEEE C37 2 device number 51BF 51NBF 6 2 2 Functionality The breaker failure function CCBRBRF is activated by trip commands from the protection functions The commands are either internal commands to the terminal or 70 RED615 Applica
53. d e g for blocking SEND SIG 1 RECV SIG 3 RECV SIG 4 SEND SIG 6 SEND SIG 7 SEND SIG 8 LL LLLI ual e e o a O RECV_SIG_A Local CB open position indication r l l l l L COMMUNICATION MEDIA Figure 34 Example of usage of binary signal transfer for position indication change 75 76 1MRS756498 A Section 7 7 1 7 1 1 7 1 2 7 1 3 RED615 Application Manual Section 7 Supervision functions Supervision functions Trip circuit supervision TCSSCBR Identification Table 36 Function identification IEC 61850 identification TCSSCBR IEC 60617 identification TCS ANSI IEEE C37 2 device number TCM Functionality The trip circuit supervision function TCSSCBR is designed for supervision purposes of control circuits The invalidity of a control circuit is detected by using a dedicated output contact that contains the supervision functionality The failure of a circuit is reported to the corresponding function block in the IED configuration The function starts and operates when TCS detects a trip circuit failure The operate time characteristic for the function is of DT type The function operates after a predefined operating time and resets when the fault disappears The function contains a blocking functionality Blocking deactivates the ALARM output and resets
54. dbus Registered Client 4 Table continues on next page RED615 Application Manual 39 Section 4 Basic functions 1MRS756498 A Parameter Values Range Unit Step Default Description ClientIP5 000 000 000 000 Modbus Registered Client 5 CtlStructPWd1 arse Password for Modbus control struct 1 CtlStructPWd2 TER Password for Modbus control struct 2 CtlStructPWd3 use Password for Modbus control struct 3 CtlStructPWd4 ANEN Password for Modbus control struct 4 CtlStructPWd5 TUNE Password for Modbus control struct 5 CtlStructPWd6 ipid Password for Modbus control struct 6 CtlStructPWd7 NNUS Password for Modbus control struct 7 CtlStructPWd8 rer Password for Modbus control struct 8 Table 16 Serial communication settings Parameter Values Range Unit Step Default Description Fiber mode OzNo fiber OzNo fiber Fiber mode for COM1 1 Fiber light ON loop 2 Fiber light OFF loop 3 Fiber light ON star 4 Fiber light OFF star Serial mode 1 RS485 2Wire 1 RS485 2Wire Serial mode for COM1 2 RS485 4Wire CTS delay 0 60000 0 CTS delay for COM1 RTS delay 0 60000 0 RTS delay for COM1 Baudrate 1 300 6 9600 Baudrate for COM1 2 600 3 1200 4 2400 5 4800 6 9600 7 19200 8 38400 9 57600 10 115200 Parity O none 2 even Parity for COM1 1 odd 2 even Table 17 Time settings Parameter Values Range Unit Step Default Descriptio
55. delayed protection telegrams can jeopardize the demand operate speed of the differential protection When a short term interference is detected in the protection communication channel the function issues a warning and the line differential functions are automatically and internally blocked PCSRTPC reacts fast for the protection communication interferences and the blocking takes place within one fundamental network period in case interruption is detected When a severe and long lasting interference or total interruption in the protection communication channel is detected an alarm is issued after a five second delay The protection communication supervision quality status is exchanged continuously online by the local and remote PCSRTPC instances This ensures that both local and remote ends protection blocking is issued coordinately This further enhances the security of the line differential protection by forcing both line end IEDs to the same blocking state during a protection communication interference even in cases where the interference is detected with only one line end IED There is also the Reset delay time settings parameter available which is used for changing the required interference free time before releasing the line differential protection back in operation after a blocking due to an interference in communication Application Communication principle Analog samples trip start and user programmable signals are transferred in ea
56. der to relevant facts and conditions The tip icon indicates advice on for example how to design your Q project or how to use a certain function Although warning hazards are related to personal injury it should be understood that operation of damaged equipment could under certain operational conditions result in degraded process performance leading to personal injury or death Therefore comply fully with all warning and caution notices 8 RED615 Application Manual 1MRS756498 A 1 4 2 1 4 3 RED615 Application Manual Section 1 Introduction Document conventions The following conventions are used for the presentation of material e Abbreviations in this manual are spelled out in the section Glossary In addition the section contains descriptions on several terms e Push button navigation in the HMI menu structure is presented by using the push button icons for example To navigate between the options use MM and m HMI menu paths are presented as follows Select Main menu Configuration HMI Menu names are shown in bold in WHMI for example Click Information in the WHMI menu structure HMI messages are shown in Courier font for example To save the changes in non volatile memory select Yes and press Parameter names are shown in italics for example The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off for example When
57. e binary input thresholds 18 176 V DC are selected by adjusting the IED s parameter settings The connection diagrams of different hardware modules are presented in this manual 13 Section 2 1MRS756498 RED615 overview See the Installation Manual for more information about the case and the plug in unit 2 4 LHMI EH Figure 1 LHMI The LHMI of the IED contains the following elements Display Buttons LED indicators Communication port The LHMI is used for setting monitoring and controlling 14 RED615 Application Manual 1MRS756498 A 2 4 1 2 4 2 2 4 3 RED615 Application Manual Section 2 RED615 overview LCD The LHMI includes a graphical LCD that supports two character sizes The character size depends on the selected language The amount of characters and rows fitting the view depends on the character size Character size Rows in view Characters on row Small mono spaced 6x12 5 rows 20 pixels 10 rows with large screen Large variable width 13x14 4 rows min 8 pixels 8 rows with large screen The display view is divided into four basic areas 1 2 E Monitoring Ay IED status Control 1 0 status FB status 376 4 Figure 2 Display layout 1 Header 2 Icon 3 Content 4 Scroll bar appears when needed LEDs The LHMI includes three protection indicators above the display Ready Start and Trip There are also
58. e disconnected from the terminal of the IED during testing Check all the connected signals so that both input voltage level and polarity are in accordance with the IED specifications However attention must be paid to the electrical safety instructions RED615 Application Manual 1MRS756498 A 5 1 4 3 5 1 4 4 RED615 Application Manual Section 5 Protection functions Binary output circuits Always check the entire circuit from the IED to the equipment interface to make sure that all signals are connected correctly If a particular output needs to be tested the corresponding wiring can be disconnected from the terminal of the IED during testing Check all the connected signals so that both load and polarity are in accordance with the IED specifications However attention must be paid to the electrical safety instructions Checking optical connections Check that the Tx and Rx optical connections are correct Applying required settings for the IED Download all calculated settings and measurement transformer parameters in the IED Connecting test equipment to the IED Before testing connect the test equipment according to the IED specific connection diagram Pay attention to the correct connection of the input and output current terminals Check that the input and output logical signals in the logic diagram for the function under test are connected to the corresponding binary inputs and outputs of the IED Also pay attent
59. e due to a mistake in connecting the CT s measurement core to the IED e CT excitation test to ensure that the CT is of the correct accuracy rating and that there are no short circuited turns in the CT windings Manufacturer s design curves should be available for the CT to compare the actual results e Check the earthing of the individual CT secondary circuits to verify that each three phase set of main CTs is properly connected to the station earth and only at one electrical point nsulation resistance check e Phase identification of CT shall be made Both primary and secondary sides must be disconnected from the line and IED when plotting the excitation characteristics or removed without the CT primary being de energized first dangerous voltages may be produced This can be lethal and damage for example insulation The re energizing of the CT primary should be inhibited as long as the CT secondary is open or unearthed A Ifthe CT secondary circuit is opened or its earth connection is missing Checking the power supply Check that the auxiliary supply voltage remains within the permissible input voltage range under all operating conditions Check that the polarity is correct Checking binary I O circuits Binary input circuits Always check the entire circuit from the equipment to the IED interface to make sure that all signals are connected correctly If there is no need to test a particular input the corresponding wiring can b
60. eb HMI timeout 120 3600 S 180 Web HMI login timeout Table 15 MODBUS settings Parameter Values Range Unit Default Description InOv O False 0 False Modbus Internal Overflow TRUE System level 1 True overflow occured indication only Serial port 1 OzNot in use 1 COM 1 COM port for Serial interface 1 1 COM 1 2 COM 2 Address 1 1 255 1 Modbus unit address on Serial interface 1 Link mode 1 1 RTU 1 RTU Modbus link mode on Serial interface 1 2 ASCII Start delay 1 0 20 char 4 Start frame delay in chars on Serial interface 1 End delay 1 0 20 char 4 End frame delay in chars on Serial interface 1 Serial port 2 OzNot in use OzNot in use COM port for Serial interface 2 1 COM 1 2 COM 2 Address 2 1 255 2 Modbus unit address on Serial interface 2 Link mode 2 1 RTU 1 RTU Modbus link mode on Serial interface 2 2 ASCII Start delay 2 0 20 char 4 Start frame delay in chars on Serial interface 2 End delay 2 0 20 char 4 End frame delay in chars on Serial interface 2 MaxTCPClients 0 5 5 Maximum number of Modbus TCP IP clients TCPWriteAuthority OzNo clients 2 All clients Write authority setting for Modbus TCP IP clients 1 Reg clients 2 All clients EventID 0 Address 0 Address Event ID selection 1 UID TimeFormat O UTC 1 Local Time format for Modbus time stamps 1 Local ClientIP1 000 000 000 000 Modbus Registered Client 1 ClientIP2 000 000 000 000 Modbus Registered Client 2 ClientIP3 000 000 000 000 Modbus Registered Client 3 ClientIP4 000 000 000 000 Mo
61. eders in a distribution network LNPLDF provides absolute selectivity and fast operating times as unit protection also in short lines where distance protection cannot be applied LNPLDF provides selective protection for radial looped and meshed network topologies and can be used in isolated neutral networks resistance earthed networks compensated impedance earthed networks and solidly earthed networks In atypical network configuration where the line differential protection scheme is applied the protected zone that is the line or cable is fed from two directions 49 Section 5 Protection functions 50 1MRS756498 A INCOMING PROTECTED ZONE INCOMING Figure 18 Line protection with phase segregated line differential IEDs LNPLDF can be utilized for various types of network configurations or topologies Case A shows the protection of a ring type distribution network The network is also used in the closed ring mode LNPLDF is used as the main protection for different sections of the feeder In case B the interconnection of two substations is done with parallel lines and each line is protected with the line differential protection In case C the connection line to mid scale power generation typical size around 10 50MV A is protected with the line differential function In case D the connection between two substations and a small distribution transformer is located at the tapped load The usage of LNPLDF is no
62. een control modules A typical substation feeder with IED control function consists of a combination of logical nodes or functions CONTROL Select request handling Reservation fesponse BLOCK Local Remote handling TRPPTRC Trip logic PHxPTOC Over current Reservation request SELECTED CBXCBR Circuit breaker control DARREC Start AR Close enable m Auto reclosure Position DCSXSWI Pos from Interlocking Disconnector status indication other bays logic Position Position ESSXSWI Earthing switch status indication Figure 50 Example overview of interactions between functions in a typical distribution feeder RED615 99 Application Manual 100 1MRS756498 A Section 10 10 1 10 1 1 10 1 1 1 RED615 Application Manual Section 10 Requirements for measurement transformers Requirements for measurement transformers Current transformers Current transformer requirements for non directional overcurrent protection For reliable and correct operation of the overcurrent protection the CT has to be chosen carefully The distortion of the secondary current of a saturated CT may endanger the operation selectivity and co ordination of protection However when the CT is correctly selected a fast and reliable short circuit protection can be enabled The selection of a CT depends not only on the CT specifications b
63. ent circuit supervision Protection communication supervision e Measurement Transient disturbance recorder Three phase current measurement Table continues on next page 12 RED615 Application Manual 1MRS756498 A 2 2 2 2 3 RED615 Application Manual Section 2 RED615 overview Current sequence components o Differential current measurement Bias current measurement Optional functions The optional functions available in the IED are e Modbus TCP IP or RTU ASCII Physical hardware The IED consists of two main parts plug in unit and case The plug in unit content depends on the ordered functionality Table 2 Plug in unit and case Main Content options unit Plug HMI in unit CPU module Auxiliary power 48 250V DC 100 240 V AC binary output module 2 normally open PO contacts slot X100 1 change over SO contacts 1 normally open SO contact 2 double pole PO contacts with TCS 1 dedicated internal fault output contact AI module slot 3 phase current inputs 1 5A X120 1 residual current input 1 5A 4 Bls BI O module slot 7 Bis X110 3 SO contacts Case Optional BI O 6 Bls module slot X130 3 SO contacts Al module interface connectors Auxiliary power binary output module interface connectors BI O module interface connectors Communication module The rated input levels are selected in the IED software for phase current and residual current Th
64. es twisted pair cabling category 5 or higher with RJ 45 connectors Analog input American National Standards Institute American Standard Code for Information Interchange Binary input Binary input output Binary output Central processing unit Current transformer Direct current Definite time Electrically Erasable Programmable Read Only Memory Electromagnetic compatibility A large diverse family of frame based computer networking technologies that operate at many speeds for LANs interconnecting computing devices Ethernet is a trademark of Xerox Corporation Inc and defined in the IEEE 802 3 standard in which computers access the network through a CSMA CD protocol Field Programmable Gate Array Generic Object Oriented Substation Event Global Positioning System Human machine interface International Electrotechnical Commission International standard for substation communication and modelling A communication protocol based on the IEC 61850 standard series and a standard for substation modelling Intelligent Electronic Device 107 Section 11 Glossary 108 IP address LAN LCD LED LHMI LON Modbus Modbus TCP IP MV NPS PCM600 PO PST RAM RJ 45 ROM RS 485 RTC RTU SCL SMT SNTP SO SW TCS VT WAN WHMI Internet protocol address is a set of four numbers between 0 and 255 separated by periods Each server connected to the Internet is assigned a unique IP address that specifies a location for
65. etected on ARC3 cont light the ARC light input 3 4 3 Time synchronization The IED uses SNTP server or GPS controlled IRIG B time code generator to update its real time clock The time stamp is used for synchronizing the events The IED can use one of two SNTP servers the primary server or the secondary server The primary server is mainly in use whereas the secondary server is used if the primary server cannot be reached While using the secondary SNTP server the IED tries to switch to the primary server at every third SNTP request attempt If both SNTP servers are offline the event time stamps have the time invalid status The time is requested from the SNTP server every 60 seconds If the Modbus RTU ASCIH protocol is used the time synchronization can be received from Modbus master instead of SNTP When Modbus TCP is used SNTP time synchronization should be used for better synchronization accuracy IRIG B time synchronization requires the IRIG B format B000 B001 with IEEE 1344 extensions The synchronization time can be either UTC time or local 46 RED615 Application Manual 1MRS756498 A 4 4 RED615 Application Manual Section 4 Basic functions time As no reboot is necessary the time synchronization starts immediately after the IRIG B sync source is selected and the IRIG B signal source is connected ABB has tested the IRIG B with the following clock masters Tekron TTMO1 GPS clock with IRIG B out
66. grams The external connections to primary devices are also shown stating the default connections to measuring transformers The positive measuring direction of directional protection functions is towards the outgoing feeder The functional diagrams are divided into sections which each constitute one functional entity The external connections are also divided into sections Only the relevant connections for a particular functional entity are presented in each section Protection function blocks are part of the functional diagram They are identified based on their IEC 61850 name but the IEC based symbol and the ANSI function number are also included Some function blocks such as PHHPTOC are used several times in the configuration To separate the blocks from each other the IEC 61850 name IEC symbol and ANSI function number are appended with a running number that is an instance number from one upwards If the block has no suffix after the IEC or ANSI symbol the function block has been used that is instantiated only once The IED s internal functionality and the external connections are separated with a dashed line presenting the IED s physical casing Signal Matrix Tool With SMT the user can modify the standard configuration according to the actual needs The IED is delivered from the factory with default connections described in the functional diagrams for BI s BO s function to function connections and alarm LEDs SMT has a number of
67. hasor Diagrams Parameter list WHMI settings Logout a IED LA RED615 gt Monitoring gt IED status gt Self supervision RED615 amp Enable Write Refresh Values Setting Group 1 Language Wess Parameter Setting PAED status Olself supervision Group Parameter Name IED Value All ok 7 9 Composition changes Warning All ok Q Time synchronization Control command Internal Fault All ok All ok e amp 3I O status O FB status O Alarm LED status 5Recorded data settings Configuration Tests information Q Clear Disturbance records Events Measurements Figure 4 Example view of the WHMI The WHMI can be accessed Locally by connecting your laptop to the IED via the front communication port e Remotely through the Internet or over LAN WAN 2 6 Authorization The user categories have been predefined for the LHMI and the WHMI each with different rights and default passwords The default passwords can be changed with Administrator user rights User authorization is disabled by default but WHMI always uses authorization RED615 17 Application Manual Section 2 RED615 overview 2 7 18 1MRS756498 A Table 3 Predefined user categories Username User rights VIEWER Read only access OPERATOR Selecting remote or local state with ER only locally Changing setting groups Controlling Clearing alarm and indication LEDs and textual indications ENGINEER Ch
68. he reference current A connection diagram shows an example of a case where the phase currents and the reference currents are measured from the same core RED615 89 Application Manual Section 7 Supervision functions 7 3 7 3 1 7 3 2 90 1MRS756498 A IL1 IL2 IL3 CCRDIF Core 1 protection LA FAIL B pou m j Figure 47 Example of incorrect reference current connection Protection communication supervision PCSRTPC Identification Table 39 Function identification IEC 61850 identification PCSRTPC IEC 60617 identification PCS ANSI IEEE C37 2 device number PCS Functionality The protection communication supervision function PCSRTPC monitors the protection communication channel PCSRTPC blocks the line differential protection functions when interference in the protection communication channel is detected The blocking takes place automatically for the LNPLDF and BSTGGIO functions which are dependent on the continuous availability of the protection communication channel RED615 Application Manual 1MRS756498 A 7 3 3 RED615 Application Manual Section 7 Supervision functions The protection communication channel is continuously monitored by PCSRTPC The function detects missing or delayed protection telegrams Protection telegrams are used for transferring the sampled analog and other protection related data Missing or
69. hnology such as communication and protocols Section 1 1MRS756498 A Introduction 1 3 Product documentation 1 3 1 Product documentation set g 3 28 g D esd a 8 QoS ob 2 5 6o D 7A S D o ES 7 E Bo E S f ES T 5 om a ui 3 O AS Engineering manual e X i Installation manual i gt o Commissioning manual i i Operation manual i aaa Service manual i i i Application manual e E Technical manual e EN Communication protocol manual i i i i en07000220 vsd Engineering Manual contains instructions on how to engineer the IEDs The manual provides instructions on how to use the different tools for IED engineering It also includes instructions on how to handle the tool component available to read disturbance files from the IEDs on the basis of the IEC 61850 definitions It further introduces the diagnostic tool components available for IEDs and the PCM600 tool Installation Manual contains instructions on how to install the IED The manual provides procedures for mechanical and electrical installation The chapters are organized in the chronological order in which the protection IED should be installed Commissioning Manual contains instructions on how to commission the IED The manual can also be used as a reference during periodic testing The manual provides procedures for energizing and checking of external circuitry setting and configuration as well as ve
70. ightly higher than the starting current This depends on the accuracy limit factor of the CT on the remanence flux of the core of the CT and on the operate time setting With inverse time mode of operation the delay should always be considered as being as long as the time constant of the DC component With inverse time mode of operation and when the high set stages are not used the AC component of the fault current should not saturate the CT less than 20 times the starting current Otherwise the inverse operation time can be further prolonged Therefore the accuracy limit factor F should be chosen using the formula F gt 20 Current start value Iin The Current start value is the primary pickup current setting of the relay Example for non directional overcurrent protection The following figure describes a typical medium voltage feeder The protection is implemented as three stage definite time non directional overcurrent protection 103 Section 10 1MRS756498 A Requirements for measurement transformers 10 1 2 104 3 gt 1200A 2 00xL 0 75 s 0 75 s AR 3D gt gt 1800A 3 00xL 0 50s 0 505 3D 3500A 583xL 600 1 A 3 0 20s 0 20s 10 VA 5P20 In 500 A Figure 51 Example of three stage overcurrent protection The maximum three phase fault current is 41 7 kA and the minimum three phase short circuit current is 22 8 kA The actual accuracy limit factor of the CT is calculated to be 59 The start current
71. international standards of the IEC 60255 series Table of contents Table of contents Section 1 INTO D 5 FAS manual rs O Ear 5 Intended audience 5 Product documentation 6 Product documentation set 6 Document revision history 7 Related documentation 8 Document symbols and conventions 8 Safety indication symbols 8 Document conventions 9 Functions codes and symbols 9 Section 2 RED615 overview ns 11 OLE A A f he tr 11 Product version history 11 PCM600 and IED connectivity package version 11 Operation functionality 12 Standard configurations 12 Optional fuhctlons iiec tete t geb Ete eg Idus 13 Physical hardWare sod dedita dace ne cre tada edid ce dde 13 BHFIMIE s n idit taedet LE o 14 EG Deco cd Me eT Ce eden 15 LEDS xt net ton nio A Meith iie dcc elec ER rot ma sr vis ss 15 Keypad roe tede eee RR o Ee uo rid 15 WEIME chac e o Eae sse ede oth 16 Authorization ee lex RR ONERE 17 Communication otitis 18 Section 3 RED615 variants 21 RED615 variant list e e de eei ente 21 Presentation of standard configurations 21 Standard configurations 22 Connection diagrams a 23 Standard configuration A f
72. ion functions Auxiliary voltage TRIP output Relay program EA Cire REx615 Circuit Breaker Figure 36 Circuit breaker trip circuit supervision application without an external resistor Trip circuit supervision and other trip contacts It is typical that the trip circuit contains more than one trip contact in parallel for example in transformer feeders where the trip of a buchholz relay is connected in parallel with the feeder terminal and other relays involved The constant test current flow is shown in the following figure The supervising current cannot detect if one or all the other contacts connected in parallel are not connected properly 79 Section 7 1MRS756498 A Supervision functions 80 Figure 37 Current flow in parallel trip contacts and trip circuit supervision In case of parallel trip contacts the recommended way to do the wiring is that the TCS test current flows through all wires and joints as shown in the following figure Figure 38 Improved connection for parallel trip contacts Several trip circuit supervision functions parallel in circuit Not only the trip circuit often have parallel trip contacts it is also possible that the circuit has multiple TCS circuits in parallel Each TCS circuit causes its own RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 7 Supervision functions supervising current to flow
73. ion to selecting the correct auxiliary voltage source according to the power supply module of the IED Also pay attention to selecting the correct auxiliary voltage source according to the power supply module of the IED 57 Section 5 Protection functions 5 1 4 5 58 1MRS756498 A I I I I ll Breakable i X x terminal i I I Figure 24 Example of connections to test the line differential IED Secondary current injection There are two alternative modes to check the operation of a line differential IED These are not exclusive methods for each other and can be used for various test on the IED Normal mode In normal mode that is the mode when the function is on normal operation the local end IED sends phasors to the remote end IED and receives phasors measured by the remote end IED This mode can be used in testing the operating level and time of the low and high stages of the local end IED This is due to a test situation when the remote end does not measure any current and therefore all the current fed to the local end current circuit is seen as differential current at both ends Testing of the line differential protection is done with both IEDs separated geographically from each other It is important to note that local actions in one IED cause operation also in the remotely located IED When testing the line differential function actions have to be done in both IEDs RED615 Application Manu
74. ircuit and the external trip circuit so that at the minimum 20 V 15 20 V remains over the relay s internal circuit Should the external circuit s resistance be too high or the internal circuit s too low for example due to welded relay contacts the fault is detected Mathematically the operation condition can be expressed as Uc Rext R in Rs XIc 2 20V AC DC Equation 2 Uc Operating voltage over the supervised trip circuit lc Measuring current through the trip circuit appr 1 5 mA 0 99 1 72 mA Rex external shunt resistance Rint internal shunt resistance 1kW Rs trip coil resistance If the external shunt resistance is used it has to be calculated not to interfere with the functionality of the supervision or the trip coil Too high a resistance will cause too high a voltage drop jeopardizing the requirement of at least 20 V over the internal circuit while a resistance too low may enable false operations of the trip coil 81 82 Section 7 1MRS756498 A Supervision functions Table 37 Values recommended for the external resistor Re Operating voltage U Shunt resistor Re 48 V DC 1 2k0 5W 60 V DC 5 6 KQ 5 W 110 V DC 22k0 5W 220 V DC 33 KQ 5 W X100 HH NM CBPOS open TCS blocking Figure 39 Operating principle of the trip circuit supervision without an external resistor The TCS blocking switch is set to block the TCSSCBR when the circuit breaker is open RED61
75. lly an order of magnitude lower than the transformer impedance providing significantly higher fault currents when the fault is located on the line 52 RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 5 Protection functions 400A 1 1 1 500kVA p 96 23A 43 33kV 0 10 L eee 1A 0 244 24 400 Figure 22 Influence of the short circuit current at LV side of the tapped transformer to the differential current Detection of the inrush current during transformer start up When the line is energized the transformer magnetization inrush current is seen as differential current by the line differential protection and may cause malfunction of the protection if not taken into account The inrush situation may only be detected on one end but the differential current is always seen on both ends The inrush current includes high order harmonic components which can be detected and used as the blocking criteria for the stabilized stage The inrush detection information is changed between two ends so that fast and safe blocking of the stabilized stage can be issued on both ends 53 Section 5 1MRS756498 Protection functions l BLOCKED l BLOCKED INCOMING Epy AN Tee I liu FULMEN A AE Figure 23 Blocking of line differential functions during detected transformer startup current If the protection stage is allowed to start during the inrush situatio
76. ls to trip for the protected component The detection of a failure to break the current through the breaker is made by measuring the current or by detecting the remaining trip signal unconditional CCBRBREF can also retrip This means that a second trip signal is sent to the protected circuit breaker The retrip function is used to increase the operational reliability of the breaker The function can also be used to avoid back up tripping of several breakers in case mistakes occur during relay maintenance and tests CCBRBRF is initiated by operating different protection functions or digital logics inside the IED It is also possible to initiate the function externally through a binary input CCBRBREF can be blocked by using an internally assigned signal or an external signal from a binary input This signal blocks the function of the breaker failure protection even when the timers have started or the timers are reset The retrip timer is initiated after the start input is set to true When the pre defined time setting is exceeded CCBRBRF issues the retrip and sends a trip command for example to the circuit breaker s second trip coil Both a retrip with current check and an unconditional retrip are available When a retrip with current check is chosen the retrip is performed only if there is a current flow through the circuit breaker The back up trip timer is also initiated at the same time as the retrip timer If CCBRBRE detects a failure i
77. mented with four overcurrent stages so that under normal conditions that is when the line differential communication is healthy only two lowest stages are available for the remote backup protection In case a line differential communication failure exists two more stages are released for rapid local backup overcurrent and short circuit protection These stages are blocked in normal situation and automatically unblocked when the communication failure is detected The setting of the overcurrent stages for local backup protection has to be considered carefully in order to achieve the best possible protection performance under abnormal conditions Two situations case A and B are shown in Figure 27 In case A the communication media is valid and therefore the line differential protection is in operation In this case the two lowest stages of overcurrent protection are in operation simultaneously In case B a communication failure causes a situation where the line differential function is not able to work properly Unblocking of the two highest overcurrent protection 62 RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 5 Protection functions stages releases these functions to protect the line against over currents and short circuits Communication healthy MF LNPLDF Line differential MFF LNPLDF Line differential protection available l l PHLPTOC l i l
78. n Date 0 Date Time 0 Time Time format 1 24H MM SS MS 1 24H MM SS M Time format 2 12H MM SS MS S Table continues on next page 40 RED615 Application Manual 1MRS756498 A Section 4 Basic functions Parameter Values Range Unit Step Default Description Date format 1 DD MM YYYY 2 DD MM YYYY 3 DD MM YYYY 4 MM DD YYYY 5 MM DD YYYY 6 YYYY MM DD 7 YYYY DD MM 8 YYYY DD MM 1 DD MM YYYY Date format Local time offset 720 720 min Local time offset in minutes Synch source 0 None 1 SNTP 2 Modbus 5 IRIG B 8 Line differential 1 SNTP Time synchronization source IP SNTP primary 010 058 125 165 IP address for SNTP primary server IP SNTP secondary 192 168 002 165 IP address for SNTP secondary server DST on time 02 00 Daylight savings time on time hh mm DST on date 01 05 Daylight savings time on date dd mm DST on day OzNot in use OzNot in use Daylight savings time on day of week 1 Mon 2 Tue 3 Wed 4 Thu 5 Fri 6 Sat 7 Sun DST offset 720 720 60 Daylight savings time offset in minutes DST off time 02 00 Daylight savings time off time hh mm DST off date 25 09 Daylight savings time off date dd mm DST off day OzNot in use OzNot in use Daylight savings time off day of week 1 Mon 2 Tue 3 Wed 4 Thu 5 Fri 6 Sat 7 Sun Table 18 X100 PSM binary output signals Name Type Default Descrip
79. n the time delay can be selected in such a way that the stabilized stage does not operate in the inrush situation 5 1 4 Commissioning The commissioning of the line differential protection scheme would be difficult without any support features in the functionality because of the relatively long distance between the IEDs This has been taken into consideration in the design of the line differential protection The communication channel can be used for echoing the locally fed current phasors from the remote end By using this mode it is possible to verify that differential calculation is done correctly in each phase Also the protection communication operation is taken into account with the differential current calculation when this test mode is used 5 1 4 1 Required material for testing the IED Calculated settings Terminal diagram e Circuit diagrams e Technical and application manuals of the IED Single of three phase secondary current source Single phase primary current source 54 RED615 Application Manual 1MRS756498 A 5 1 4 2 RED615 Application Manual Section 5 Protection functions Timer with start and stop interfaces Auxiliary voltage source for the IEDs PC with related software a web browser for web HMI The setting and configuration of the IED must be completed before testing The terminal diagram available in the technical manual is a general diagram of the IED Note that the same diagram 1s n
80. n the number of start phase settings is set to 1 out of 3 the operation of PHxPTOC is enabled with the presence of high current in one phase When the setting is 2 out of 3 or 3 out of 3 single phase faults are not detected The setting 3 out of 3 requires the fault to be present in all three phases Many applications require several steps using different current start levels and time delays PHxPTOC consists of three protection stages e Low PHLPTOC High PHHPTOC Instantaneous PHIPTOC PHLPTOC is used for overcurrent protection The function contains several types of time delay characteristics PHHPTOC and PHIPTOC are used for fast clearance of very high overcurrent situations Overcurrent protection with line differential protection The line differential IED has also four separate overcurrent functions which can be used as the backup protection of line differential function for lines and cables There are three stages available with definite or inverse time characteristics and an instantaneous stage The differential protection is available only if the communication between the units is working properly and no CT failure situation is detected If a communication failure exists the protect area or unit is left out from the primary protection scheme Therefore it is practical to use overcurrent protection as a local backup functionahty In the standard configuration of the IED the backup overcurrent protection is imple
81. n tripping the fault within the set back up delay time which is longer than the retrip time it sends a back up trip signal to the chosen back 71 Section 6 1MRS756498 A Protection related functions up breakers The circuit breakers are normally upstream breakers which feed fault current to a faulty feeder The back up trip always includes a current check criterion This means that the criterion for a breaker failure is that there is a current flow through the circuit breaker after the set back up delay time m Normal protective trip B Re Trip REF615 g BackUp Trip Figure 32 Typical breaker failure protection scheme in distribution substations 6 3 Protection trip conditioning TRPPTRC 6 3 1 Identification Table 34 Function identification IEC 61850 identification TRPPTRC IEC 60617 identification IO ANSI IEEE C37 2 device number 94 6 3 2 Functionality The protection trip conditioning function TRPPTRC is used as a trip command collector and handler after the protection functions The features of this function influence the trip signal behavior ofthe circuit breaker The user can set the minimum trip pulse length when the non latched mode is selected It is also possible to select the latched or lockout mode for the trip signal 72 RED615 Application Manual 1MRS756498 A 6 3 3 RED615 Application Manual Section 6 Protection related functions Application All trip signals from different prote
82. nctions included in the RED615 configuration Function IEC 61850 IEC symbol _ ANSI symbol Line differential protection and related 3ld gt measurements stabilized and inst stages LNPLDF1 3ld gt gt 87L Three phase non directional overcurrent low stage PHLPTOC1 3l 51P 1 Three phase non directional overcurrent high stage instance 1 PHHPTOC1 31 gt gt 1 51P 2 1 Three phase non directional overcurrent high stage instance 2 PHHPTOC2 31 gt gt 2 51P 2 2 Three phase non directional overcurrent inst stage PHIPTOC1 31 gt gt gt 50P 51P Negative sequence overcurrent protection instance 1 NSPTOC1 12 gt 1 46 1 Negative sequence overcurrent protection instance 2 NSPTOC2 12 gt 2 46 2 Circuit breaker failure protection CCBRBRF1 3l lo BF 51BF 51NBF Three phase inrush detector INRPHAR1 312f gt 68 Binary signal transfer BSTGGIO1 BST BST Circuit breaker control with interlocking CBXCBR1 O lt gt O lt gt TCSSCBR1 TCS 1 TCM 1 Trip circuit supervision for two trip coils TCSSCBR2 TCS 2 TCM 2 Current circuit supervision CCRDIF1 CCRDIF CCRDIF Protection communication supervision PCSRTPC1 PCS PCS Transient disturbance recorder RDRE1 Three phase current measurement CMMXU1 3I 3l Sequence current measurement CSMSQM 11 12 10 14 12 10 RED615 Application Manual 1MRS756498 A 3 3 2 1 RED615 Application Manual Section 3
83. nd protection communication failure indication The signal outputs from the IED are connected to give dedicated information on 33 Section 3 1MRS756498 RED615 variants start of any protection function SO1 X100 10 12 operation trip of any protection function SO2 X100 13 15 The TRGAPCI is a timer and used for setting the minimum pulse length for the outputs BINARY SIGNAL TRANSFER FUNCTIONALITY PETS el S03 Binary 5 I ae o i i X110 BSTGGIO1 Mod 22 Transfer Signal Binary Signal 6 a BI 4 BST input Transfer Input 7 U4 SEND_SIG_1 RECV_SIG_1 SEND_SIG 2 RECV_SIG 2 SEND SIG 3 RECV SIG 3 l REMOTE FEEDER READY LOCAL FEEDER READY REMOTE CB OPEN LOCAL CB OPEN 57 i li li li LOCAL_CT_FAILURE REMOTE_CT_FAIL SEND SIG A RECV SIG A F LED11 BST SENT 1 LED10 BST RECEIVED Figure 17 Binary signal transfer functionality The binary signal transfer function BSTGGIO is used for changing any binary information which can be used e g in protection schemes interlocking alarms etc There are eight separate inputs and corresponding outputs available In this configuration one physical input BI3 X110 6 7 is connected to the binary signal transfer channel one Local feeder ready and local CB open information are connected to input 6 and 7 These a
84. ng mode 3 Latched mode 4 Latched blinking mode Alarm LEDs LED 11 Description of alarm Table 9 Authorization settings Parameter Values Range Unit Step Default Description Local override 0 False 1 True Disable authority 1 True Remote override O False3 1 True Disable authority 1 True Local viewer 0 Set password Local operator 0 Set password Local engineer 0 Set password Local admin 0 Set password Remote viewer 0 Set password Remote operator 0 Set password Remote engineer 0 Set password Remote admin 0 Set password 1 Authorization override is disabled LHMI password must be entered 2 Authorization override is enabled LHMI password is not asked 3 Authorization override is disabled communication tools ask password to enter the IED 4 Authorization override is enabled communication tools do not need password to enter the IED except for WHMI which always requires it RED615 Application Manual 37 Section 4 Basic functions 1MRS756498 A Table 10 Binary input settings Parameter Values Range Default Description Threshold voltage 18 176 Digital input threshold voltage Input osc level 2 50 Digital input oscillation suppression threshold Input osc hyst 2 50 Digital input oscillation suppression hysteresis Table 11 Ethernet front port settings Parameter Values Range Unit Step Default De
85. on setting group parameters Those parameters are presented in connection to application functions RED615 Application Manual 1MRS756498 A Section 5 5 1 5 1 1 9 1 2 5 1 3 RED615 Application Manual Section 5 Protection functions Protection functions Line differential protection LNPLDF Identification Table 28 Function identification IEC 61850 identification LNPLDF IEC 60617 identification 3dl gt 3dl gt gt ANSI IEEE C37 2 device number 87L Functionality The phase segregated line differential protection LNPLDF is used as feeder differential protection for the distribution network lines and cables LNPLDF includes low stabilized and high non stabilized stages The stabilized low stage provides a fast clearance of faults while remaining stable with high currents passing through the protected zone increasing errors on current measuring Second harmonic restraint insures that the low stage does not operate due to the startup of the tapped transformer The high stage provides a very fast clearance of severe faults with a high differential current regardless of their harmonics The operating time characteristic for the low stage can be selected to be either definite time DT or inverse definite time IDMT The direct inter trip ensures both ends are always operated even without local criteria Application LNPLDF is designed for the differential protection of overhead line and cable fe
86. or line current differential protection 24 Applications 2 e A peti epe tatu Ie Ente Eee d 24 FUACLIONS DI E 24 Default I O connections 25 Functional diagrams 26 Functional diagrams for protection 26 RED615 i Application Manual Table of contents Section 4 Section 5 Section 6 Functional diagrams for disturbance recorder and trip CIRCUIT SUPEIVISION zx iactat eh to reete Net uade hte ta tatto thats 31 Functional diagrams for control interlocking and Mmeasurements nn 32 Basic MACHONS Ein uen 35 General parameters 35 Self supervision nnnnncnnnn 43 Int rmalfaults z22 sus auf RR eb bU 43 IAE Mc 45 Time synchronization eene 46 Parameter setting groups 47 Protection functions 49 Line differential protection LNPLDF 49 Identification eese aiii ad 49 Functi onality wiii ica 49 Application Do ES Re een ae 49 Commissioning ss 54 Required material for testing the IED 54 Checking the external optical and electrical connections 55 Applying required settings for the IED 57 Connecting test equipment to the IED 57
87. ot always applicable to each specific delivery especially for the configuration of all the binary inputs and outputs Therefore before testing check that the available terminal diagram corresponds to the IED Also the circuit diagrams of the application are recommended to be available Especially these are required for checking the terminal block numbers of the current trip alarm and possibly other auxiliary circuits The technical and application manuals contain application and functionality summaries function blocks logic diagrams input and output signals setting parameters and technical data sorted per function The minimum requirement for a secondary current injection test device is the ability to work as a one phase current source Prepare the IED for the test before testing a particular function Consider the logic diagram of the tested protection function when performing the test All included functions in the IED are tested according to the corresponding test instructions in this chapter The functions can be tested in any order according to user preferences Therefore the test instructions are presented in alphabetical order Only the functions that are in use Operation 1s set to On should be tested The response from the test can be viewed in different ways Binary output signals Monitored data values in the local HMI logical signals A PC with a web browser for web HMI use logical signals and phasors All
88. ply the active settings for instantaneous stage over current protection All operate signals are connected to the Master Trip Logics 1 and 2 and also to the alarm LEDs LED 6 is used for collective overcurrent and negative sequence overcurrent protection operate indication 29 Section 3 RED615 variants 30 1MRS756498 A i UPSTREAM OVER CURRENT BLOCKING 1 x110 qi SO1 1 Upstream Over Current Blocking PHHPTOCA start l 316 PHHPTOC2 start OR PHIPTOC stat i Figure 9 Blocking of the upstream overcurrent relay The upstream blocking from the start of the over current protection functions is connected to the output SOI X110 14 15 16 The purpose of this output is to send a blocking signal to the relevant overcurrent protection stage of the IED at the upstream bay BACK UP O C or NPS PROTECTION TRIP i jo i 2110 i 17 PHIPTOC operat 117 i PHHPTOGZ operate TPGAPC2 s02 j Backup Protection PHHPTOC1 operate OR i Operate Indication PHLPTOC operate e Eo BE NSPTOC2 operate DON NSPTOC1 operate i CE ES eS A eS SSS Se J Figure 10 Indication of overcurrent or NPS overcurrent operation The indication of backup overcurrent protection operation is connected to the output SO2 X110 20 21
89. ports a new measurement value if the input signal has gone out of the deadband state The deadband supervision can be used in value reporting between the measurement point and operation control When the deadband supervision is properly configured it will help in keeping the communication load in minimum and yet measurement values will be reported frequently enough 94 RED615 Application Manual 1MRS756498 A 8 2 8 2 1 8 2 2 RED615 Application Manual Section 8 Measurement functions Disturbance recorder Functionality The IED is provided with a disturbance recorder featuring up to 12 analog and 64 binary signal channels The analog channels can be set to record either the waveform or the trend of the currents and voltage measured The analog channels can be set to trigger the recording function when the measured value falls below or exceeds the set values The binary signal channels can be set to start a recording on the rising or the falling edge of the binary signal or both By default the binary channels are set to record external or internal relay signals for example the start or trip signals of the relay stages or external blocking or control signals Binary relay signals such as a protection start or trip signal or an external relay control signal over a binary input can be set to trigger the recording The recorded information is stored in a non volatile memory and can be uploaded for subsequent fault analysis
90. position and the voltage is applied to the trip circuit The following picture shows incorrect usage of a TCS circuit when only one of the contacts is used Figure 42 Incorrect connection of trip circuit supervision A connection of three protection IEDs with a double pole trip circuit is shown in the following figure Only the IED R3 has an internal TCS circuit In order to test the operation of the IED R2 but not to trip the circuit breaker the upper trip contact of the IED R2 is disconnected as shown in the figure while the lower contact is still connected When the IED R2 operates the coil current starts to flow through the internal resistor of the IED R3 and the resistor burns immediately As proven with the previous examples both trip contacts must operate together Attention should also be paid for correct usage of the trip circuit supervision while for example testing the IED 84 RED615 Application Manual 1MRS756498 A 7 2 7 2 1 7 2 2 RED615 Application Manual Section 7 Supervision functions Figure 43 Incorrect testing of IEDs Current circuit supervision CCRDIF Identification Table 38 Function identification IEC 61850 identification CCRDIF IEC 60617 identification MCS 31 ANSI IEEE C37 2 device number MCS 31 Functionality The current circuit supervision function CCRDIF is used for monitoring current transformer secondary circuits CCRDIF calculates internally the sum
91. put e Meinberg TCGS11 controlled by GPS167 Datum ET6000L i IRIG B time synchronization requires a COM card with an IRIG B input The time synchronization messages can be received from the other line end IED within the protection telegrams The IED begins to synchronize its real time clock with the remote end IEDs time if the Line differential time synchronization source is selected This does not affect the protection synchronization used in the line differential protection or the selection of the remote end IEDs time synchronization method Parameter setting groups There are four IED variant specific setting groups For each setting group the parameter setting can be made independently The active setting group 1 4 can be changed by parameter or via binary input if a binary input is enabled for it To enable active setting group changing via binary input connect any of the free binary inputs to SGCB block input named Protection 0 ActSG using PCM600 Signal Matrix Tool Table 26 Active setting group binary input state BI state Active setting group OFF 1 ON 2 The active setting group defined by parameter is overridden when a binary input is enabled for changing the active setting group Table 27 Settings Parameter Setting Value Default Description Access rights 47 Section 4 Basic functions 48 1MRS756498 A All the parameters are not included in these setting groups for example n
92. r backup TRBU operate indication Functional diagrams for disturbance recorder and trip circuit supervis ion DISTURBANCE RECORDER LNPLDF start RDRE1 LNPLDF operate PHIPTOC start PHHPTOC2 start PHHPTOCH1 start NSPTOC2 start NSPTOC start CCBRBRF trret CCBRBRF trbu PHXPTOC operate NSPTOCX operate INPHAR1 blk2h PCSRTPC1 alarm LNPLDF_R _RSTD2H LNPLDF PROT ACTIVE Bi TRIGGERED pr LED8 DR TRIGGERED frs l l i l i PHLPTOC start i l i l l l l Bl 2 Start of CBFP m een General 1 i BI 1 Blocking blocking 5 17K Ly BI 2 CB Closed CB Close 3 Xs BI 3 CB Open BI 4 BST input Figure 12 Disturbance recorder Bi 21 BI 22 BI 23 BI 24 BI 25 BI 26 BI 27 BI 28 BI 29 BI 30 BI 31 BI 32 The disturbance recorder has 64 digital inputs of which 32 are connected as a default All start and operate signals from the protection stages are routed to trigger the disturbance recorder or alternatively only to be recorded by the disturbance recorder depending on the parameter settings Additionally the five binary inputs from X120 are also connected BI 3 CB Open TRPPTRCA trip TRIP CIRCUIT SUPERVISION TCSSCBR1 TRPPTRC2 trip Fig
93. re interlocking information from control logic The information of detected current transformer fault is connected to input 8 As a consequence of sending interlocking information to remote end also receiving of same information locally is needed Therefore remote feeder ready remote CB open and remote CT failure are connected to binary signal transfer function outputs All binary signal transfer outputs are connected to output SO3 X110 20 21 22 The receive and send information are connected to alarm LEDs 10 and 11 34 RED615 Application Manual 1MRS756498 A Section 4 4 1 Basic functions General parameters Section 4 Basic functions Table 5 Analog channel settings phase currents Parameter Values Range Unit Step Default Description Secondary current 1 0 2A 2 1A Rated recondary 2 1A current 3 5A Primary current 1 0 6000 0 A 0 1 100 0 Rated primary current Amplitude corr A 0 900 1 100 0 001 1 000 Phase A amplitude correction factor Amplitude corr B 0 900 1 100 0 001 1 000 Phase B amplitude correction factor Amplitude corr C 0 900 1 100 0 001 1 000 Phase C amplitude correction factor Table 6 Analog channel settings residual current Parameter Values Range Unit Step Default Description Secondary current 1 0 2A 2 1A Secondary current 2 1A 3 5A Primary current 1 0 6000 0 A 0 1 100 0 Primary current
94. rifying settings and performing directional tests The chapters are organized in the chronological order in which the IED should be commissioned 6 RED615 Application Manual 1MRS756498 A 1 3 2 RED615 Application Manual Section 1 Introduction Operation Manual contains instructions on how to operate the IED during normal service once it has been commissioned The manual can be used to find out how to handle disturbances or how to view calculated and measured network data in order to determine the cause of a fault Service Manual contains instructions on how to service and maintain the IED The manual also provides procedures for de energizing de commissioning and disposal of the IED Application Manual contains application descriptions and setting guidelines sorted per function The manual can be used to find out when and for what purpose a typical protection function can be used The manual can also be used when calculating settings Technical Manual contains application and functionality descriptions and lists function blocks logic diagrams input and output signals setting parameters and technical data sorted per function The manual can be used as a technical reference during the engineering phase installation and commissioning phase and during normal service The Communication Protocol manuals describe the different communication protocols supported by the IED The manuals concentrate on vendor specific implementations
95. rrent measurement Current sequence components Differential current measurement Bias current measurement RED615 Application Manual 1MRS756498 Section 3 RED615 variants 3 2 2 Connection diagrams L1 L2 L3 X120 2 100 1 1 Positive 2 mai p gt Bl1 i Uaux Current 2 Direction 3 Vs 1 3 4 Kaa IRF 4 4 Vc B3 5 f PER pot TE 5 5S7 a Protection C 6 k 6 Core Q n s2 7 T 36 IL1 N 1 rg PO2 F 2 al e IL2 31 8 10 9 11 l i 10 ES soi H 4 12 4 18 C 11 C o 12 CT Supervision HA Isi 14 1 is Reference Current rama Soz 5 LCL se x110 14 Pz 3 Ys 16 H BI2 m7 E 4 PO3 Ab 17 MEL gia is Ei TCS1 H B RL B4 20 7 t 22 PO4 4H 9 NL pis 2 s 5 TCS2 H 24 6 5 BIG 11 S m7 110 12 14 L ELL gia SO1 A 13 16 15 a 17 130 s0
96. rrent protection for fault conditions occurring between two phases The negative sequence overcurrent protection also provides a back up protection functionality for the feeder earth fault protection in solid and low resistance earthed networks The negative sequence overcurrent protection provides the back up earth fault protection on the high voltage side of a delta wye connected power transformer for earth faults taking place on the wye connected low voltage side If an earth fault occurs on the wye connected side of the power transformer negative sequence current quantities appear on the delta connected side of the power transformer Multiple time curves and time multiplier settings are also available for coordinating with other devices in the system 68 RED615 Application Manual 1MRS756498 A Section 6 6 1 6 1 1 6 1 2 6 1 3 RED615 Application Manual Section 6 Protection related functions Protection related functions Three phase inrush detector INRPHAR Identification Table 32 Function identification IEC 61850 identification INRPHAR IEC 60617 identification 312f gt ANSI IEEE C37 2 device number 68 Functionality The transformer inrush detection INRPHAR is used to coordinate transformer inrush situations in distribution networks Transformer inrush detection is based on the following principle the output signal BLK2H is activated once the numerically derived ratio of second harmonic
97. rt value 2 H 20 kbo o 10 50 9 Restraint mode None ine amp H 9 Reset delay time 0 CS ms 0 60000 e Minimum operate time 40 Eo ms 40 50000 9 CT ratio correction 0 500 bso 0 200 5 000 o CT connection type Type 2 wez2 m e Figure 25 An example of a test mode situation where three phase currents are injected to the local end IED Phasor diagrams Local phase currents Remote phase currents 90 0 IL1 321 934 15 77 IL2 321 884 135 18 IL3 321 124 104 889 Figure 26 400A 270 IL1 160 814 163 79 IL2 161 124 44 29 IL3 160 454 75 04 Local and remote end currents presented in a web HMI of the ED RED615 Application Manual 1MRS756498 A 5 2 5 2 1 5 2 1 1 5 2 1 2 5 2 1 3 RED615 Application Manual Section 5 Protection functions Three phase current protection Three phase non directional overcurrent protection PHxPTOC Identification Table 29 Function identification Different stages Low stage High stage Instantaneous stage IEC 61850 identification PHLPTOC PHHPTOC PHIPTOC IEC 60617 identification 3I 31 gt gt 31 gt gt gt ANSI IEEE C37 2 device number 51P 1 51P 2 50P 51P Functionality The three phase overcurrent protection PHxPTOC is used as one phase two phase or three phase non directional overcurrent and short circuit protection for feeders The function starts when the current exceeds the se
98. ry data is used as blocking signals for the line differential protection the transfer response is extremely high Binary signal interchange can be used in applications such as e Remote position indications nter tripping of the circuit breakers on both line ends Blocking of the line differential protection during transformer inrush or current circuit supervision failure Protection schemes blocking or permissive Remote alarming The figure shows the overall chain to transfer binary data in an example application The position indication of the local circuit breaker is connected to the IED s input interface and is then available for the IED configuration The circuit breaker position indication is connected to the first input of BSTGGIO which is used to send information to the remote end via communication In the remote end this information is handled as a remote circuit breaker open position and it is available from the first output of BSTGGIO This way the information can be exchanged IED configuration IED configuration Remote CB open 5255 Remote CB open Position indication to be used e g for blocking BSTGGIO SEND SIG 1 RECV SIG 1 SEND SIG 2 SEND SIG 3 SEND SIG 4 SEND SIG 5 SEND SIG 6 SEND SIG 7 SEND SIG 8 BSTGGIO RECV SIG 1 RECV SIG 2 SEND siG 3 RECV SIG 3 RECV SIG 4 RECV SIG 5 RECV SIG 6 RECV SIG 7 RECV SIG 8 SEND SIG A RECV SIG A Position indication to be use
99. scription IP address 192 168 000 254 IP address for front port fixed Mac address XX XX XX XX Mac address for front port XX XX Table 12 Ethernet rear port settings Parameter Values Range Unit Step Default Description IP address 192 168 2 10 IP address for rear port s Subnet mask 255 255 255 0 Subnet mask for rear port s Default gateway 192 168 2 1 Default gateway for rear port s Mac address XX XX XX XX Mac address for rear port s XX XX Table 13 General system settings Parameter Values Range Unit Ste Default Description Rated frequency 1 50Hz 1 50Hz Rated frequency of the network 2 60Hz Phase rotation 1 ABC 1 ABC Phase rotation order 2 ACB Blocking mode 1 Freeze timer 1 Freeze timer Behaviour for function BLOCK inputs 2 Block all 3 Block OPERATE output Bay name 38 RED615 Bay name in system RED615 Application Manual 1MRS756498 A Section 4 Basic functions Table 14 HMI settings Parameter Values Range Unit Default Description FB naming convention 1 IEC61850 1 IEC61850 FB naming convention used in IED 2 IEC61617 3 IEC ANSI Default view 1 Measurements 1 Measurements LHMI default view 2 Main menu Backlight timeout 10 3600 S 180 LHMI backlight timeout Web HMI mode 1 Active read only 3 Disabled Web HMI functionality 2 Active 3 Disabled W
100. t 2 inversion 0 False O False Connectors 3 4 1 True Input 3 inversion O False O False Connectors 5 6c 1 True Input 4 inversion 0 False O False Connectors 7 6c 1 True Input 5 inversion 0 False O False Connectors 8 9c 1 True Input 6 inversion 0 False O False Connectors 10 9c 1 True Input 7 inversion 0 False O False Connectors 11 12c 1 True Input 8 inversion O False O False Connectors 13 12c 1 True 42 RED615 Application Manual Section 4 1MRS756498 A Basic functions Table 22 X120 AIM binary input signals Name Type Description X120 Input 1 BOOLEAN Connectors 1 2c X120 Input 2 BOOLEAN Connectors 3 2c X120 Input 3 BOOLEAN Connectors 4 2c X120 Input 4 BOOLEAN Connectors 5 6 Table 23 X120 AIM binary input settings Parameter Values Range Unit Ste Default Description Input 1 filter time 1 1000 ms 5 Connectors 1 2c Input 2 filter time 1 1000 ms 5 Connectors 3 2c Input 3 filter time 1 1000 ms 5 Connectors 4 2c Input 4 filter time 1 1000 ms 5 Connectors 5 6 Input 1 inversion O False O False Connectors 1 2c 1 True Input 2 inversion O False O False Connectors 3 2c 1 True Input 3 inversion O False O False Connectors 4 2c 1 True Input 4 inversion O False O False Connectors 5 6 1 True 4 2 Self supervision 4 2 1 RED615 Application Manual The IED s extensive self supervision system continuously supervises the software and the electronics
101. t limit The operate time characteristics for low stage PHLPTOC and high stage PHHPTOC can be selected to be either definite time DT or inverse definite minimum time IDMT The instantaneous stage PHIPTOC always operates with the DT characteristic In the DT mode the function operates after a predefined operate time and resets when the fault current disappears The IDMT mode provides current dependent timer characteristics The function contains a blocking functionality Itis possible to block function outputs timers or the function itself if desired Application PHxPTOC is used in several applications in the power system The applications include but are not limited to e Selective overcurrent and short circuit protection of feeders in distribution and subtransmission systems e Back up overcurrent and short circuit protection of power transformers and generators e Overcurrent and short circuit protection of various devices connected to the power system for example shunt capacitor banks shunt reactors and motors e General back up protection 61 Section 5 1MRS756498 A Protection functions PHxPTOC is used for single phase two phase and three phase non directional overcurrent and short circuit protection Typically overcurrent protection is used for clearing two and three phase short circuits Therefore the user can choose how many phases at minimum must have currents above the start level for the function to operate Whe
102. t limited to these applications p 3ld gt 31d gt 3ld v LI V 0 0 1 0 L 0 0 LI 1 4 0 0 4 LI 3ld 3ld 3ld Figure 19 Line differential applications RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 5 Protection functions Communication supervision A typical line differential protection application includes LNPLDF as main protection Backup over current functions are needed in case of a protection communication failure When the communication supervision function detects a failure in the communication between the protective units the safe operation of the line is still guaranteed by blocking the line differential protection and unblocking the over current functions When a communication failure is detected the protection communication supervision function issues block for the LNPLDF line differential protection and unblock for the instantaneous and high stages instance 2 of the over current protection These are used to give backup protection for the remote end feeder protection IED Although there can be a situation where the selectivity is weaker than usually the protection should still be available for the system PCSRTPC BLOCK pj LNPLDF UNBLOCK LL phproc
103. teristics All the points mentioned earlier required to define the overcurrent protection parameters can be expressed simultaneusly in a coordination plan In Figure 30 the coordination plan shows an example of operation characteristics in the LV side incoming feeder and radial outgoing feeder 66 RED615 Application Manual 1MRS756498 A 5 3 5 3 1 5 3 1 1 5 3 1 2 RED615 Application Manual Section 5 Protection functions 10 0 t F i F e i a a Bend HM 6 1 Operation characteristics of O C protection of radial outgoing feeder TTN PM 2 Operation characteristics of O C protection of incoming feeder I 3 Maximum expected switching inrush current of outgoing feeder 4 Maximum expected switching inrush current of incoming feeder 11 0 LN i Bi 5 Thermal whitstand of line type 1 g 3 LE 6 Thermal whitstand of line type 2 O Maximum and minimum fault current in busbar AN E Maximum and minimum fault current at the end ofline type 2 Maximum and minimum fault current at the end of line type 1 0 1 Operation characteristics during normal operation Rated current of incoming feeder Operation characteristics during 69 Rated current of line type 2 inrush situation i E LAN 2 Rated current of line type 1 OE VOX id f 7 ii PTT i t ED 1 Yi il f a Maximum load current of outgoing feeder 4 3 10 10 Figure 30 Example coordination
104. th two independent three phase sets of CT cores RED615 87 Application Manual Section 7 1MRS756498 Supervision functions IL1 IL2 IL3 Core 1 protection CCRDIF 3IE LA LA FAIL alg LB 18 ALARM l f JE REF jl L REF BLOCK Other protection devices Core 2 protection SE PEN HE Figure 45 Connection diagram for current circuit supervision with two sets of three phase current transformer protection cores When using the measurement core for reference current measurement it should be noted that the saturation level of the measurement core is much lower than with the protection core This should be taken into account when setting the current circuit supervision function RED615 Application Manual 1MRS756498 A Section 7 Supervision functions IL1 IL2 IL3 A c 9 5 CCRDIF og Q 31 LA bLA FAIL LB ALARM LREF BLOCK Measurement device Core 2 measurement TN 3C HE Figure 46 Connection diagram for current circuit supervision with two sets of three phase current transformer cores protection and measurement Example of incorrect connection The currents must be measured with two independent cores that is the phase currents must be measured with a different core than t
105. that is the Operation setting is set to Test blocked When this mode is in use the remote end IED echoes locally injected current phasors back with the shifted phase and settable amplitude The local end line differential function is also automatically blocked during this and the remote end line differential function discards the phasors it receives from the IED that is in the test mode When the test mode is active the CT connection type and CT ratio correction setting parameter values are still used by the line differential protection function as in the normal operation mode These can be used for shifting the phase 0 or 180 degrees and setting the amplitude of the echoed back phasors For example if three phase currents are injected to the local end IED which is also set to the test mode the selected CT connection type is Type 2 and the CT ratio correction setting parameter value is 0 500 59 Section 5 Protection functions 60 1MRS756498 A Parameter Setting Operation test blocked test blocked o High operate value 2000 2000 200 4000 o High Op value Mult 1 0 1 0 0 5 1 0 9 Low operate value 10 ro 10 200 9 End section 1 100 Ro o 200 o Slope section 2 50 50 10 50 o End section 2 500 oo 200 2000 o Slope section 3 150 iso 100 200 9 Operate delay time i00 Boo ms 40 200000 e Operating curve type IEC Def Time IEC Def Time E 9 Time multiplier 1 00 Rho o 0 05 15 00 o Sta
106. the TCP IP protocol Local area network Liquid crystal display Light emitting diode Local Human Machine Interface Local operating network A serial communication protocol developed by the Modicon company in 1979 Originally used for communication in PLCs and RTU devices Modbus RTU protocol which uses TCP IP and Ethernet to carry data between devices Medium voltage Negative phase sequence Protection and Control IED Manager Power output Parameter Setting Tool Random access memory Galvanic connector type Read only memory Serial link according to EIA standard RS485 Real Time Clock Remote Terminal Unit Substation Configuration Language Signal Matrix Tool Simple Network Time Protocol Signal output Software Trip circuit supervision Voltage transformer Wide area network Web Human Machine Interface RED615 Application Manual 109 AA ED ED PADDED ABB Oy Distribution Automation P O Box 699 FI 65101 VAASA Finland Phone 358 10 22 11 Fax 358 10 22 41094 www abb com substationautomation Copyright 2008 ABB All rights reserved 1MRS756498 A
107. the timer Application TCSSCBR detects faults in the electrical control circuit of the circuit breaker The function can supervise both open and closed coil circuits This kind of supervision is necessary to find out the vitality of the control circuits continuously The following figure shows an application of the trip circuit supervision function usage The best solution is to connect an external R shunt resistor in parallel with the circuit breaker internal contact Although the circuit breaker internal contact is open TCS can see the trip circuit through R The Rext resistor should have such a resistance that the current through the resistance remains small that is it does not harm or overload the circuit breaker s trip coil 77 Section 7 1MRS756498 A Supervision functions 78 Auxiliary voltage REx615 TRIP output Relay program TCS input Circuit Breaker Rex Figure 35 Circuit breaker trip circuit supervision application with an external resistor If the TCS is required only in a closed position the external shunt resistance may be omitted When the circuit breaker is in the open position the TCS sees the situation as a faulty circuit One way to avoid TCS operation in this situation would be to block the supervision function whenever the circuit breaker is open RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 7 Supervis
108. tion X100 PO1 BOOLEAN 0 False Connectors 6 7 X100 PO2 BOOLEAN 0 False Connectors 8 9 X100 SO1 BOOLEAN 0 False Connectors 10c 11nc 12no X100 SO2 BOOLEAN 0 False Connectors 13c 14no X100 PO3 BOOLEAN 0 False Connectors 15 17 18 19 X100 PO4 BOOLEAN 0 False Connectors 20 22 23 24 RED615 41 Application Manual Section 4 1MRS756498 A Basic functions Table 19 X110 BIO binary output signals Name Type Default Description X110 SO1 BOOLEAN 0 False Connectors 14c 15no 16nc X110 SO2 BOOLEAN 0 False Connectors 17c 18no 19nc X110 SO3 BOOLEAN 0 False Connectors 20c 21no 22nc Table 20 X110 BIO binary input signals Name Type Description X110 Input 2 BOOLEAN Connectors 3 4 X110 Input 3 BOOLEAN Connectors 5 6c X110 Input 4 BOOLEAN Connectors 7 6c X110 Input 5 BOOLEAN Connectors 8 9c X110 Input 6 BOOLEAN Connectors 10 9c X110 Input 7 BOOLEAN Connectors 11 12c X110 Input 8 BOOLEAN Connectors 13 12c Table 21 X110 BIO binary input settings Parameter Values Range Unit Step Default Description Input 2 filter time 1 1000 ms 5 Connectors 3 4 Input 3 filter time 1 1000 ms 5 Connectors 5 6c Input 4 filter time 1 1000 ms 5 Connectors 7 6c Input 5 filter time 1 1000 ms 5 Connectors 8 9c Input 6 filter time 1 1000 ms 5 Connectors 10 9c Input 7 filter time 1 1000 ms 5 Connectors 11 12c Input 8 filter time 1 1000 ms 5 Connectors 13 12c Inpu
109. tion Manual 1MRS756498 A 6 2 3 RED615 Application Manual Section 6 Protection related functions external commands through binary inputs The start command is always a default for three phase operation CCBRBRF includes a three phase conditional or unconditional re trip function and also a three phase conditional back up trip function CCBRBREF uses the same levels of current detection for both re trip and back up trip The operating values of the current measuring elements can be set within a predefined setting range The function has two independent timers for trip purposes a re trip timer for the repeated tripping of its own breaker and a back up timer for the trip logic operation for upstream breakers A minimum trip pulse length can be set independently for the trip output The function contains a blocking functionality It is possible to block the function outputs if desired Application The n 1 criterion is often used in the design of a fault clearance system This means that the fault is cleared even if some component in the fault clearance system is faulty A circuit breaker is a necessary component in the fault clearance system For practical and economical reasons it is not feasible to duplicate the circuit breaker for the protected component but breaker failure protection is used instead The breaker failure function issues a back up trip command to adjacent circuit breakers in case the original circuit breaker fai
110. tput SO2 X100 13 14 15 28 RED615 Application Manual 1MRS756498 A RED615 Application Manual Section 3 RED615 variants OVER CURRENT PROTECTION AND INRUSH DETECTION PHLPTOC1 3l 51P 1 a START BLOCK OPERATE ENA MULT PHHPTOC1 31 gt gt 1 He 51P 2 1 gt a Starr BLOCK OPERATE ENA MULT PHHPTOC2 31 gt gt 2 eA 51P 2 2 31 START LDIFFPROT_OK ae TU OR S LED6 OC or NPS OPERATE ENA_MULT PHIPTOC1 31 gt gt gt BI 1 Blocking OR 50P 51P 31 START INRPHA 3lx gt BLOCK OPERATE ENA MULT BLK2H OR PHXPTOC operate o PROTECTION sf pin Hx SE NEGATIVE SEQUENCE CURRENT PROTECTION Setting group change r TXI NSPTOC1 gt 1 46 3l START BLOCK OPERATE ENA_MULT OR NSPTOCX operate NGF TOY l gt 46 31 START BLOCK OPERATE ENA_MULT Figure 8 Overcurrent protection Four overcurrent stages are offered for overcurrent and short circuit protection The instantaneous stage PHIPTOC1 can be blocked by energizing the binary input 1 X120 1 2 Two negative sequence overcurrent stages NSPTOCI and NSPTOC2 are offered for phase unbalance protection The inrush detection block s INRPHAR1 output BLK2H caters the possibility to multi
111. transferring binary signals between the local and remote end line differential protection IEDs The function includes eight binary signals that are transferred in the protection communication telegram and can be freely configured and used for any purpose in the line differential application BSTGGIO transfers binary data continuously over the protection communication channel between the terminals Each of the eight signals are bidirectional and the binary data sent locally is available remotely as a received signal BSTGGIO includes a minimum pulse time functionality for the received binary signals Each received signal has its own minimum pulse time setting parameter BSTGGIO includes two alarm output signals The SEND SIG A output signal is updated according to the status of the sent binary signals The RECV SIG A output signal is updated according to the status of the received binary signals Each signal can be separately included or excluded from the alarm logic with a setting parameter RED615 Application Manual 1MRS756498 A 6 4 3 RED615 Application Manual Section 6 Protection related functions Application Among with the analog data the binary data can also be exchanged with the line differential protection IEDs The usage of the binary data is application specific and can vary in each separate case The demands for the speed of the binary signals vary depending on the usage of the data When the bina
112. urbance recorder triggered Table continues on next page 25 Section 3 1MRS756498 RED615 variants LED Default usage 9 Trip circuit supervision alarm 10 Binary signal transfer receive 11 Binary signal transfer send 3 3 3 Functional diagrams The functional diagrams describe the default input output alarm LED and function to function connections The default connections can be viewed with SMT and changed according to the application requirements ifnecessary The analog channels measurements from CTs and VTs have fixed connections towards the different function blocks inside the IED s standard configuration Exceptions from this rule are the eight analog channels available for the disturbance recorder function These channels are freely selectable and a part of the disturbance recorder s parameter settings thus not included in the SMT functionality The analog channels are assigned to different functions as shown in the functional diagrams The common signal marked with 31 represents the three phase currents The signal marked with I0 represents the measured residual current via a sum connection of second CT cores of the phase current transformers 3 3 3 1 Functional diagrams for protection The following functional diagrams describe the IED s protection functionality in detail and according to the factory set default connections in SMT 26 RED615 Application Manual 1MRS756498 A RED61
113. ure 13 OR BLOCK ALARM TCSSCBR2 BLOCK ALARM Trip circuit supervision l i l i i i OR y LED9 TCS ALARM i i i i l i i Two separate TCS functions have been included TCSSCBRI for PO3 X100 16 19 and TCSSCBR2 for PO4 X100 20 23 Both functions are blocked by the Master Trip 31 Section 3 RED615 variants 3 3 3 3 32 1MRS756498 A Logic and the circuit breaker open signal The TCS alarm indication is connected to LED 9 Functional diagrams for control interlocking and measurements vs PHLPTOC operate PHHPTOC1 operate PHHPTOC2 operate PHIPTOC1 operate NSPTOC1 operate NSPTOC2 operate LNPLDF operate OR MASTER TRIP 1 TRPPTRC1 BLOCK TRIP OPERATE CL_LKOUT A PO3 RST_LKOUT With lock out mode selection OR TCS1 4 6 Open CB 7 trip coil 1 Lock Out 5 BI 4 Rest E AA CBXCBR1 exe op cocos po ee MASTER TRIP 2 2 Open CB trip coil 2 PO4 i i i PHLPTOC operate PHHPTOC1 operate TRPPTRO2 i BLOCK TRIP OPERATE CL LKOUT i NSPTOC1 operate RST_LKOUT i NSPTOC2 operate With lock out mode LNPLDF operate 34 selection CCBRBF1 trret i PHHPTOC2 operate PHIPTOC1 operate OR
114. used setting groups should be tested Checking the external optical and electrical connections The user must check the installation to verify that the IED is connected to the other required parts of the protection system The IED and all the connected circuits are to be de energized during the check up Checking CT circuits The CTs must be connected in accordance with the terminal diagram provided with the IED both with regards to phases and polarity The following tests are recommended for every primary CT or CT core connected to the IED 55 Section 5 Protection functions 56 1MRS756498 A e Primary injection test to verify the current ratio of the CT the correct wiring up to the protection IED and correct phase sequence connection that is L1 L2 L3 Polarity check to prove that the predicted direction of secondary current flow is correct for a given direction of primary current flow This is an essential test for the proper operation of the directional function protection or measurement in the IED e CT secondary loop resistance measurement to confirm that the current transformer secondary loop dc resistance is within specification and that there are no high resistance joints in the CT winding or wiring e CT excitation test to ensure that the correct core in the CT is connected to the IED Normally only a few points along the excitation curve are checked to ensure that there are no wiring errors in the system for exampl
115. ut also on the network fault current magnitude desired protection objectives and the actual CT burden The protection relay settings should be defined in accordance with the CT performance as well as other factors Current transformer accuracy class and accuracy limit factor The rated accuracy limit factor F is the ratio of the rated accuracy limit primary current to the rated primary current For example a protective current transformer of type 5P10 has the accuracy class 5P and the accuracy limit factor 10 For protective current transformers the accuracy class is designed by the highest permissible percentage composite error at the rated accuracy limit primary current prescribed for the accuracy class concerned followed by the letter P meaning protection Table 44 Limits of errors according to IEC 60044 1 for protective current transformers Accuracy class Current error at Phase displacement at rated primary Composite error rated primary current at rated accuracy current limit prima minutes centiradians ee Ay 5P 1 60 1 8 5 10P 3 10 The accuracy classes 5P and 10P are both suitable for non directional overcurrent protection The 5P class provides a better accuracy This should be noted also if there are accuracy requirements for the metering functions current metering power metering and so on of the relay 101 Section 10 1MRS756498 A Requirements for measurement transformers

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