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KBCH 120, 130, 140 - Schneider Electric

1. Cu B a 5 Ce oe 01 E lt a A Ce 66 72i 731 gt 168 4 KBCH 120 z 1 6 21 77 ee 22 8 23 79 at 24 01 25 81 Z3 6 1 4 26 82i 127 83 HV lo see Figure 14 ZS X Ee LV1 lo gt see Figure 14 128 4 i WD Relay health c pen S d elay healthy N A fe supply 14 3 C B e WD 31 Relay failed Phase rotation N 1 RLO 321 rip TN D RLI 6 ri ea aj b c 38 RI2 40 Tip eee 17 421 1 1 Ima 18 RL3 44 rip WM P d 29 30 5 3t Cc pP ou m si T Tu ad RL4 STI up 7 8 initia ey eel gt en e pr Pi nitiate aux timer a 31 gt ewe pU m os FEN RIS 5 Top down 5 rus i Initiate aux timer 1 L1 i M o6 ee i ug S5 mS Al Initiate aux timer 2 12 0 t R ial PR 3 4 a 7 18 oo e 1 75 ue is 461 Logic input 1 p L 77 21 2 4 E Initiate aux timer 3 13 92 14 09 80 224024 Bi 21 Initiate aux timer 4 14 d Y 2 gt c y 81 3 82 25 C26 Pa 1 i 5A Case earth 2 DS amp 49 83 184 27 28 y sel Init
2. e 6 as amp um 0 NN 4 e D E gt C m 2 E B e 4 168 4 75 KBCH 120 DEA i 6 121 77 2 x tg 23 79 wal FZE 24 o 25 am bom LE jc 1 26 82i 27 83 HV lo gt see Figure 12 4 ee d IVI lo see Figure 12 4 A 28 i 4 13 ec s WD 6 pfelyhedlly y A 14 3 C V i e WD Relay failed Phase rotation 607 N RLO E Trip 4 RU 567 Tr LY c af c 38 12 40 tip 7 pm L 7 18 i RL3 441 gt Trip 63 64 13 4 29 30 4 5 gt DE e 29 sa 5 6 i3 32 Sr SAG e v ld RIA Tr Tap up D DX Initiate aux timer O LO 9 9 7 62 ES 10 35 36 Sa E PEE ES RLS S57 V tap down 69 Xf 70 e eo Initiate aux timer 1 L1 BS dm n 39 40 27 713172 e yak c amp Al 42 T fimer2 12 429 13 Y RL 9 p Alarm TAM P nitiate aux timer e gt c 17 18 a 6 75 Mf 76 45 46 Logic input common 1 2 RL7 937 Tri gt C 9 gw HABD P 77 M 78 21 2 Ir 481 Initiate aux timer 3 13 Rm 1 J 49 50 lt 7960 meo Ts sg Mieten ta 144 y n 5 5 nitiate aux timer e t soe mx P sd PET Case earth gt c Arn uM 149 d 54 83 21
3. Figure 15 High Impedance principle Stability requirements The RMS voltage seen across an infinite impedance relay differential circuit for an external fault with one CT totally saturated and with the other CT s totally unsaturated is given by equation 1 This assumed state of CT s has been the traditional basis for high impedance protection stability calculations Vr 28 1 Where VV Relay circuit voltage If Secondary external fault current Rt CT secondary winding resistance RI Resistance of longest lead RB Resistance of other relays components in CT circuit For a relay element which is sharply tuned to operate with fundamental frequency current the stability of the differential protection scheme for an external fault has been shown by conjunctive tests to be a function of the RMS differential voltage given by equation 1 To achieve through fault stability the differential relay operating voltage must be increased by adding a stabilising resistor to the relay circuit as given by equation 2 By increasing the impedance of the relay circuit most of the spill current resulting from asymmetric CT saturation will be forced to flow through the relatively low impedance of the saturated CT circuit rather than through the relay circuit The differential operating voltage required for stability is usually known as the stability voltage setting of the protecti
4. 3 EXTERNAL CONNECTIONS Function Terminal Function Earth Terminal 1 2 Not Used Watchdog Relay b 3 4 m Break contact 5 6 Make contact A8V Field Voltage 7 8 48V Field Voltage Not Used 9 10 Not Used Not Used 11 12 Not Used Auxiliary Voltage Input 13 14 Auxiliary Voltage Input Not Used 15 16 Not Used Voltage Input Overflux In 17 18 Out Voltage Input Overflux Not Used 19 20 Not Used A Current 1 In 21 22 Out A Current 1 B Current 1 In 23 24 Out B Current 1 C Current 1 In 25 26 Out C Current 1 E F Current 1 In 27 28 Out E F Current 1 Function Terminal Function Output Relay 4 29 30 Output Relay 0 31 32 Output Relay 5 33 34 Output Relay 1 35 36 Output Relay 6 37 38 Output Relay 2 39 40 Output Relay 7 41 42 Output Relay 3 43 44 Opto Control Input L3 45 46 Opto Control Input LO Opto Control Input L4 47 48 Opto Control Input L1 Opto Control Input L5 49 50 Opto Control Input L2 Opto Control Input L 51 52 Common LO L1 L2 Opto Control Input L7 53 54 K BUS Serial Port Common L3 L4 L5 L6 L7 55 56 K BUS Serial Port Earth Terminal 57 58 Not Used Not Used 59 60 Not Used Not Used 61 62 Not Used KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 20 76 KBCH 120 130 140 Function
5. The CT s must meet the minimum requirements for relay operation The CT s must meet the requirements for through fault stability of the differential element The CT s must meet the requirements for operation and through fault stability of the restricted earth fault element s see section 2 3 4 3 Minimum requirements The knee point voltage of the CT must meet with the requirements given in sections 4 3 2 and 2 3 4 3 with a minimum value Star connected CT s 60 In Delta connected CT s 100 In Requirements for the biased differential protection Application Knee point voltage V Through fault stability limit X R If Transformers V2 241 Ra 2R Ry 40 151 Generators or or Block Differential Overall generator generator transformer and unit station transformer or Motors or Shunt reactors Generator transformers V7 241 Ra 2R Ry 40 151 V7 A8L Ra 2R 4 Rj 120 15I n KBCH EN M D11 Service Manual CHAPTER 2 Application Page 36 38 KBCH 120 130 140 Application Knee point voltage V Through fault stability limit Series reactors V7 24L R4 4 2R 4 Rj 40 151 Transformers connected to a mesh corner with 40 AOI 4 4 two sets of CT s supplying separate biased relay inputs V7 A8I R 4 2R Ry 120 151 Where Resistance of interpos
6. Figure 3 3 AC no volt trip arrangement Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 23 76 3 6 Serial communication port K BUS Connection to the K BUS Port is by standard Midos 4mm screw terminals or push on connectors A twisted pair of wires is all that is required the polarity of connection is not important It is recommended that an outer screen is used with an earth connected to the screen at the Master Station end only Termination of the screen is effected with the U shaped terminal supplied and which has to be secured with a self tapping screw in the hole in the terminal block just below terminal 56 see Figure 3 4 Operation has been tested up to 1 000 metres with cable to DEF Standard 16 2 2c 16 0 2mm dia 40 171pf m 288pf m core screen The minimum requirement to communicate with the relay is a K BUS IEC870 5 converter box Type KITZ101 102 and suitable software to run on an IBM or compatible personal computer Note K Bus must be terminated with a 1500 resistor at each end of the bus The Master Station can be located at any position but the bus should only be driven from one unit at a time This interface provides the user with a means of entering settings to the relay and of interrogating the relays to retrieve recorded data Figure 3 4 Termination arrangement for communications
7. AREVA KBCH 120 130 140 Transformer Differential Protection Relay Service Manual KBCH EN M G11 Service Manual KBCH 120 130 140 CURRENT DIFFERENTIAL RELAYS KBCH 120 130 140 CONTENT Errata Section KBCH EN M G11 Handling of Electronic Equipment Safety Instructions Technical Description Chapter 1 E11 Application Notes Chapter 2 D11 Commissioning Instructions Chapter 3 C11 Commissioning Test Results Chapter 4 C11 Repair Form KBCH EN M G11 Service Manual KBCH 120 130 140 Service Manual Issue Control KBCH 120 130 140 KBCH EN M F1 1 ISSUE F Amendments completed 07 01 2002 ISSUE E Chapter Section Page Description Measurement 1 2 10 15 Sentence added at end of paragraph Recorder Capture 1 5 3 2 40 Note amended Technical Data 1 8 54 Frequency tracking range amended to 13 65Hz Model Numbers 1 8 17 62 Amend case details P change Midos case size 8 to MiCOM Livery Size 8 40TE ISSUE D Amendments completed 07 01 2002 2 All All Layout of manual amended to corporate standard ISSUE C Amendments completed 07 01 2002 3 All All Layout of manual amended to corporate standard ISSUE C Amendments completed 07 01 2002 4 All All Layout of manual amended to corporate standard KBCH EN M F11 Service Manual Issue Control KBCH 120 130 140 Pxxxx EN SS B1 1 SAFETY SECTION Pxxxx EN SS B1 1
8. Time delayed All contacts are shown in the de energised Figure 6 1 Key to symbols used in logic diagrams Contacts have been used to represent the output of the various protection and control functions even though they are actually implemented in software The contacts are all shown in the state they would take up with no inputs applied to the protective relay The function links are also implemented in software but have been drawn as mechanical links They are shown in the factory default position for the basic factory configuration In position O the function is deselected and 1 the function is selected Opto isolated control inputs 17 10 are represented by an eight bit mask with a thicker line at the top and left hand side of the mask The control asserted by the nput is stated above the mask and the position of the 1 s within the mask will determine the input s that assert the control More than one control input may be assigned by the mask and the same control inputs may be used in several masks The output relays RLY7 RLYO are represented by an eight bit mask with a thicker line at the bottom and right hand side A mask is allocated to each protection and control function that can be assigned to an output relay The function asserted on the mask is stated by the text above it and the position of the 1 s in the mask determines which relay s operate in response More than one output relay may be assi
9. the transformer Number of transformers connected parallel KBCH EN M D11 Service Manual CHAPTER 2 Application Page 18 38 KBCH 120 130 140 2 3 2 3 1 It is difficult to accurately predict the maximum anticipated level of inrush current Typical waveform peak values are of the order of 8 10x rated current A worst case estimation of inrush could be made by dividing the transformer full load current by the per unit leakage reactance quoted by the transformer manufacturer A setting range of 5 20In RMS values is provided on the KBCH relay The high set RMS setting should be set in excess of the anticipated or estimated peak value of inrush current after ratio correction Restricted Earth Fault Protection Basic principles The KBCH uses biased differential protection to provide fast clearance for faults within the protected zone The value of earth fault current however may be limited by any impedance in the earth path or by the percentage of the winding involved in the fault The KBCH offers a restricted earth fault element for each winding of the protected transformer to provide greater sensitivity for earth faults which will not change with load current The levels of fault current available for relay measurement are illustrated in figures 13 and 14 If an earth fault is considered on an impedance earthed star winding of a Dyn transformer Fig 13 the value of current flowing in the fault It will be dependant
10. LV2 Phase Compensation PHASE CURRENT Injected current A KBCH EN 1 4 9 22 EXPECTED VALUES RELAY MEASURED VALUES Ia HV Ib HV Ic HV Ia LV Ib LV1 Ic LV LV2 Ib LV2 Ic LV2 DIFFERENTIAL CURRENT gt gt gt gt gt gt gt gt PY Theoretical value A RELAY MEASURED VALUE Ia Diff A Ib Diff A Ic Diff A gt gt gt gt gt gt gt gt KBCH EN M C11 Service Manual CHAPTER 4 Commissioning Test Results Page 10 22 KBCH 120 130 140 BIAS CURRENT Theoretical value A RELAY MEASURED VALUE Ia Bias A Ib Bias A Ic Bias A 6 1 2 Frequency Measurement F injected Hz F measured Hz 6 2 Differential Protection 6 2 1 Low set element current sensitivity Id gt Setting Group 1 Setting Group 2 if required Setting Is HV Pick up Ia HV Drop off Ib HV Pick up Ib HV Drop off Ic HV Pick up Ic HV Drop off LV1 Pick up Ia LV1 Drop off Ib LV1 Pick up Ib LV1 Drop off Ic LV1 Pick up Ic LV1 Drop off Ia LV2 Pick up Ia LV2 Drop off Ib LV2 Pick up Ib LV2 Drop off Ic LV2 Pick up Ic LV2 Drop off gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt
11. SYS Password SYS Fn Links SYS Description SYS Plant Ref SYS Model No SYS Serial No SYS Frequency SYS Comms Level SYS Rly Address SYS Setting Grp SYS S W Ref 1 SYS S W Ref 2 Service Manual KBCHNEN M C1 1 Commissioning CHAPTER 4 Test Results KBCH 120 130 140 Page 3 22 SETTINGS 1 4131211 51 Fn Links S1 Configuration S1 HV CT Ratio S1 LV1 CT Ratio S1 LV2 CT Ratio S1 HV Ratio Cor 51 HV Vector Cor S1 LV1 Ratio Cor S1 Vector Cor S1 LV2 Ratio Cor 51 LV2 Vector Cor S1 Id S1 Id gt gt S1 Io gt HV S1 Io gt LVI S1 Io gt LV2 S1 Iof S1 tof S1 V f Trip Char S1 V f Trip S1 V f Trip TMS or S1 t V f Trip S1 V f Alarm S1 t V f Alarm SETTINGS 2 S2 Fn Links S2 Configuration S2 HV CT Ratio S2 LV1 CT Ratio S2 LV2 CT Ratio S2 HV Ratio Cor S2 HV Vector Cor S2 LV1 Ratio Cor KBCH EN 1 Service Manual CHAPTER 4 Commissioning Test Results Page 4 22 KBCH 120 130 140 2 LV1 Vector Cor 2 LV2 Ratio Cor 2 LV2 Vector Cor S2 Id 2 Id gt gt 2 Io HV S2 Io LV1 S2 Io LV2
12. Service Manual Technical Description KBCH 120 130 140 CONTENT 1 HANDLING AND INSTALLATION 1 1 General considerations 1 1 1 Receipt of relays 1 1 2 Electrostatic discharge ESD 1 2 Handling of electronic equipment 1 3 Relay mounting 1 4 Unpacking 1 5 Storage 2 DESCRIPTION OF THE RELAY 2 1 Introduction 2 2 Signal Conditioning 2 2 1 Analogue to Digital conversion 2 2 2 Calibration 2 2 3 Current Transformer CT ratio and phase compensation 2 2 4 Transformer configuration 2 2 5 Differential current 2 2 6 Fourier 2 2 7 Frequency tracking 2 3 Biased differential protection function 2 3 1 Low set protection function 2 3 2 Magnetising inrush current blocking 2 3 3 Overflux blocking 2 3 4 High set protection function 2 4 Restricted earth fault REF protection function 2 5 Overflux protection function 2 6 Opto isolated control inputs 2 7 Output relays 2 8 Alternative setting group 2 9 Logic 2 10 Measurement 2 11 Fault records 2 12 Self monitoring and protection alarms 2 13 Password protection 2 14 Serial communication 2 14 1 Time tagged event records 2 14 2 Disturbance records KBCH EN M E11 CHAPTER 1 Page 1 76 0 ON NNN N 10 10 10 10 10 11 11 11 11 11 12 12 13 13 13 14 14 14 15 15 15 15 16 16 17 17 KBCH EN M E1 1 CHAPTER 1 Page 2 76 2 14 3 Remote control functions 2 14 4 Notes on serial port 2 14 5 Notes on security of remote control via the seria
13. LV1 Ratio Correction LV1 Phase Compensation LV2 CT Ratio LV2 Ratio Correction LV2 Phase Compensation Service Manual Commissioning Test Results KBCH 120 130 140 o o Service Manual Commissioning Test Results KBCH 120 130 140 PHASE CURRENT Injected current EXPECTED VALUES Ia HV Ib HV Ic HV Ia Ib LV1 Ic LV 7 1 2 LV2 LV3 measurement check Ia LV2 Ib LV2 Ic LV2 DIFFERENTIAL CURRENT Theoretical value RELAY MEASURED VALUE Ia Diff Ib Diff Ic Diff BIAS CURRENT Theoretical value RELAY MEASURED VALUE Ia Bias Ib Bias Ic Bias 7 1 3 Frequency Measurement F injected F measured KBCH EN M C1 1 CHAPTER 4 Page 13 22 RELAY MEASURED VALUES gt gt gt gt gt gt gt Hz Hz gt gt gt gt gt gt gt KBCH EN M C1 1 CHAPTER 4 Page 14 22 7 2 Differential Protection 7 2 1 Low set element current sensitivity Id Setting Group 1 Setting Is HV Pick up Ia HV Drop off Ib HV Pick up Ib HV Drop off Ic HV Pick up Ic HV Drop off Ia LV1 Pick up Ia LV1 Drop off Ib LV1 Pick up Ib LV1 Drop off Ic LV1 Pick up Ic LV1 Drop off Ia LV2 Pick up Ia LV2 Drop off Ib LV2 Pick up Ib LV2 Drop off Ic LV2 Pick
14. Remote commands are not maintained so a set reset arrangement is used to store the last received command The setting group that is currently in use can be found by looking at SYS Setting Grp in the SYSTEM DATA column of the menu or Fnow in the FAULT RECORDS of default display if selected The setting group remains as selected when the auxiliary supply is interrupted Local control of setting group Local control is asserted via the input mask INP Set Grp2 and the control input that is set in this mask The relay will respond to the group 2 settings whilst this input is energised and the setting group 1 when it is de energised Note To enable individual settings to be changed remotely System Data Link SDO must be set to 1 If instead it is set to O then it will not be possible to change individual settings over the communication link Manual tap changer control The transformer tap changer can be instructed to raise or lower a tap via commands over the serial communications link or locally via the menu system Two relay masks Tap Up and Tap Down are provided for this purpose On receiving the request to change taps the appropriate relay is operated for a time given by the appropriate setting as shown in Figure 6 9 RLY Tap Up Remote change Figure 6 9 Remote control of transformer tap changer Trip test facility As shown in Figure 6 10 a relay test facility allows each outpu
15. Safety Section Page 1 10 CONTENTS Ti INTRODUCTION 3 2 HEALTH AND SAFETY 3 3 SYMBOLS AND EXTERNAL LABELS ON THE EQUIPMENT 4 3 1 Symbols 4 3 2 Labels 4 4 INSTALLING COMMISSIONING AND SERVICING 4 5 DECOMMISSIONING AND DISPOSAL 7 6 EQUIPMENT WHICH INCLUDES ELECTROMECHANICAL ELEMENTS 7 T TECHNICAL SPECIFICATIONS FOR SAFETY 7 7 1 Protective fuse rating 7 7 2 Protective Class 7 7 3 Installation Category 7 7 4 Environment 8 8 CE MARKING 8 9 RECOGNIZED AND LISTED MARKS FOR NORTH AMERICA 9 Pxxxx EN 55 1 1 2 10 Safety Section BLANK PAGE Pxxxx EN SS B1 1 Safety Section Page 3 10 1 INTRODUCTION This guide and the relevant operating or service manual documentation for the equipment provide full information on safe handling commissioning and testing of this equipment and also includes descriptions of equipment label markings Documentation for equipment ordered from AREVA Energy Automation amp Information is despatched separately from manufactured goods and may not be received at the same time Therefore this guide is provided to ensure that printed information normally present on equipment is fully understood by the recipient Before carrying out any work on the equipment the user should be familiar with the contents of this Safety Guide Reference should be made to the external connection diagram before the equipment is installed commissioned or serviced Language specific self adhesive User Interface
16. To provide effective protection CT s should be arranged to overlap other zones of unit protection so that no blind spots exist Where suitable ratio correction or phase compensation can not be provided with the KBCH software interposing CT s an external interposing CT should be used A range of suitable interposing CT s are available from AREVA These should be used wherever possible to ensure proper protection performance To guarantee high set stability for very heavy through faults when using a KBCH 130 140 on a mesh substation connection the leads from the mesh CT s or one and a half switch bay should be approximately balanced To ensure that the quoted operating times and through fault stability limits are met the ratio of VkA RtotA Vkg Rtotg at biased inputs either side of the protected impedance should not exceed a maximum disparity ratio of 3 1 This ensures that during a through fault condition the flux density in the current transformers is not greatly different Where Knee point voltage of CT at end Service Manual Application KBCH 120 130 140 4 3 4 3 1 4 3 2 RtotA VkB RtotB C T Requirements When deciding upon the current transformer requirements for the KBCH three factors must be taken into account Total burden connected to CT at end A RCT 2RI RB KBCH EN M D11 CHAPTER 2 Page 35 38 Knee point voltage of CT at end B Total burden connected to CT at end B RCT 2RI RB
17. To replace this board Remove the processor board as described above Remove the two securing screws that hold the DSP board in place Remove the two screws at the rear of the module which secure the screening plate between the power supply and DSP board Unplug the pcb from the front bus as described for the processor board and withdraw Replace in the reverse of this sequence making sure that the screen plate is replaced with all four screws securing it Replacing the analogue input board It is not recommended to remove this board Replacing output relays and opto isolators These are located on the main microprocessor board and on the DSP board To replace remove these boards as detailed above They are replaced in the reverse order Calibration is not usually required when a pcb is replaced unless either of the two boards that plug directly on to the left hand terminal block are replaced as these directly affect the calibration Note That this pcb is a through hole plated board and care must be taken not to damage it when removing a relay for replacement otherwise solder may not flow through the hole and make a good connection to the tracks on the component side of the pcb Replacing the power supply board Remove the two screws securing the centre terminal block to the top plate of the module Remove the two screws securing the centre terminal block to the bottom plate of the module Remove the two screws securing the
18. t100ms L gt INP Aux0 RLY Aux0 e 4 INP Aux1 RLY Aux ___ 4 INP Aux2 RLY Aux2 _ Au INP Aux3 RLY Aux3 m aus INP Aud RLY Aux4 _ INP Aux5 RLY Aux5 _ _ _ 4 aus 4 INP Aux6 RLY Aux6 a tAw6 1 INP RLY Aux ____ 4 Aux 4 INP Set Grp2 SD3 m ai Sdect alternative 4 Remote change 1 setting GRP2 T ng 7 010 s QU Remote change 2 RLY TapUp 5 1 Remote change 1 tTapup 004 RLY Tap Down Remote change 2 y4 RLY Test Relay Test rest Figure 11 1 KBCH Logic Diagram KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 72 76 KBCH 120 130 140 12 CONNECTIONS DIAGRAMS Figures 12 1 12 2 12 3 and 12 4 show the external connection for KBCH120 130 and 140 respectively
19. 1 Before removing a module ensure that you are at the same electrostatic potential as the equipment by touching the case 2 Handle the module by its front plate frame or edges of the printed circuit board Avoid touching the electronic components printed circuit track or connectors 3 Do not pass the module to another person without first ensuring you are both at the same electrostatic potential Shaking hands achieves equipotential KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 8 76 KBCH 120 130 140 4 Place the module on an antistatic surface or on a conducting surface which is 1 3 1 4 1 5 at the same potential as yourself 5 Store or transport the module in a conductive bag If you are making measurements on the internal electronic circuitry of an equipment in service it is preferable that you are earthed to the case with a conductive wrist strap Wrist straps should have a resistance to ground between 500k 10M ohms If a wrist strap is not available you should maintain regular contact with the case to prevent a build up of static Instrumentation which may be used for making measurements should be earthed to the case whenever possible More information on safe working procedures for all electronic equipment can be found in BS5783 and IEC147 OF lt is strongly recommended that detailed investigations on electronic circuitry or modification work should be carried out in a Special Handling Ar
20. 1 will select the output relay and O will deselect it The selection is made using the instructions for setting links in Section 5 2 4 The output relay RLYO to RLY7 associated with each digit underlined by the cursor is shown on the top line of the display A preceding it will indicate that the trigger will occur for energisation and a will indicate the trigger will occur for de energisation Notes on recorded times The times recorded for the opto isolated inputs is the time at which the relay accepted them as valid and responded to their selected control function This will be 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz after the opto input was energised The time recorded for the output relays is the time at which the coil of the relay was energised and the contacts will close approximately 5ms later Otherwise the time tags are generally to a resolution of 1ms for events and to a resolution of lus for the samples values KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 42 76 KBCH 120 130 140 6 SELECTIVE LOGIC In this section the scheme logic is broken down into groups which are described individually The logic is represented in a ladder diagram format and the key to the symbols used is shown in Figure 6 1 INP BLOCK V f Trip Input mask RLY V F TRIP Output mask 010 Hardware representation of software S7 V F OF Trip Contact representation of output
21. If required a new password can be entered immediately after the default password is entered by following the same procedure as for entering the default password If the password has been changed and forgotten or lost a unique recovery password is available which can be supplied by the factory or service agent if given details of the Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 13 52 4 2 4 3 relay model and serial number This will be found in the SYSTEM DATA column of the menu and should correspond to the number on the label on the top right hand corner of the front plate of the relay Care should be taken to ensure that no unwanted changes are entered Refer to Table 2 for details on how to enter a new setting or how to escape from the setting mode without the setting being changed The following points should be noted For each protection and control function input required at least one opto input must be allocated in the INPUT MASK menu For each protection and control function output required at least one output relay must be allocated in the RELAY MASK menu When the relay leaves the factory it is configured with a set of default relay masks input masks and protection settings Any of these settings can be left at the default value if required Changing the system frequency All relays will leave the factory set for operation at a system frequency of 50Hz If operation at
22. KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 24 76 KBCH 120 130 140 4 2 USER INTERFACE Front plate layout The front plate of the relay carries an identification label at the top right hand corner This identifies the relay by both its model number and serial number This information is required when making any enquiry to the factory about a particular relay because it uniquely specifies the product In addition there is a rating label in the bottom left hand corner which gives details of the auxiliary voltage Vx reference voltage Vn and current ratings In see Figure 4 1 Two handles one at the top and one at the bottom of the front plate will assist in removing the module from the case Three light emitting diodes LEDs provide status indication and in addition a liquid crystal display and a four key pad for access to settings and other readable data Relay type Model number Liquid Serial number crystal display Digital identifiers Led indicators Ratings Entry keys 21725 Vn 100120 V ser Hz Figure 4 1 Front plate layout LED indications The three LEDs provide the following functions GREEN LED Indicates the relay is powered up and running It reflects the state of the watchdog relay YELLOW LED Indicates alarm conditions that have been detected by the relay These may be external alarms via the logic inputs or alarms detected during its self checking routine T
23. Serial Number Station Front plate information KBCH Date Circuit KBCHNEN M C11 CHAPTER 4 Page 1 22 Transformer Differential Relay Type KBCH Model No Serial No Rated Current In Aux Voltage Vx Voltage Vn Frequency 1 4 Inspection Check for damage CT shorting switches in case checked Serial number on module and case checked External wiring checked to diagram if available Terminals checked for continuity tick 21 amp 22 23 amp 24 25 amp 26 27 amp 28 63 amp 64 65 amp 66 67 amp 68 69 amp 70 71 amp 72 73 amp 74 1 5 Earth connection to case checked 1 7 Test block connection checked 1 8 Insulation checked tick tick tick 75 amp 76 77 amp 78 79 amp 80 81 amp 82 83 amp 84 tick KBCH EN M C1 1 Service Manual Commissioning Test Results KBCH 120 130 140 CHAPTER 4 Page 2 22 3 AUXILIARY SUPPLY TESTS 3 1 Auxiliary voltage at relay terminals Vac dc 3 2 Energisation from auxiliary voltage supply Watchdog contacts checked tick Supply off Terminals 3 amp 5 closed Terminals 4 amp 6 open Supply on Terminals 3 amp 5 open Terminal 4 amp 6 closed 3 3 Field Voltage Vdc 4 SETTINGS System Data Settings F EJ D 91 8 71 6
24. b Short terminals break before 3 Earth connections are typical only Long terminals 4 SCN Screen connection for K Bus d Pin terminal PCB type Figure 12 2 Typical external connections for KBCH130 KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 74 76 KBCH 120 130 140 E 163 69 235 3X x 164 0 165 71 z 106 721 LA 73 T d 168 41 751 KBCH 140 I LV2 lo gt see Figure 12 4 3 amp ln 77 zx Jeo 22 8 a 79 LE dO 24 0 5 CERE dX 126 82 127 83 HV lo gt see Figure 12 4 i it ZI Milo ee Figure 124 128 41 A 4 AC DC 4 3 gt WD 6 Relay healthy LF h x C B Ve WD 5T Relay failed Phase rotation kn RIO 32r STi 4 361 Rr p 8 RL2 rip 42 5 RL3 441 gt Trip 6 Su cm D 65 gt gt c zn 1 RLA ST Tap up Us Q 3 Initiate aux timer O LO i 9 10 35 36 1 gt RIS S tend ZR 7 381 Initiate aux timer 1 LI 148 t fe pm by ay be a gs 7 gt i al Initiate aux timer 2
25. for example a dedicated differential relay and the unit transformer may be placed outside the main generator transformer differential zone to give correct discrimination and relay operation for all faults as illustrated in figure 23b K Series and MiCOM schemes The Midos K range of relays offers integrated protection modules which cover numerous applications such as directional and non directional overcurrent protection auto reclose and check synchronising combination with the P340 range integrated generator protection package the KBCH transformer differential protection offers a completely digital protection approach for generating plant as well as for substations Fig 24 Figure 24 Combined digital protection scheme Simple serial communications hardware enables the numerical relays to be accessed locally or remotely from a common point Fig 25 This allows the user access to a comprehensive array of fault records event records and disturbance records KCG KCGG KBCH LGPG LEN Figure 25 Digital relays on a K bus communications network Facilities are not provided within the KBCH to record circuit breaker trip times number of circuit breaker operations or the summated contact breaking duty that can be Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 33 38 recorded by K series overcurrent relays If this information is required
26. setting 50 5th harmonic blocking timer 10 05 overfluxing pick up setting trip 2 42V Hz 110V VT on a 50Hz system 10 overflux V f Trip characteristic IDMT V f Trip TMS 1 0 KBCH EN M D11 Service Manual CHAPTER 2 Application Page 34 38 KBCH 120 130 140 overfluxing pick up setting alarm 2 31V Hz 110V VT on a 50Hz system 5 overflux V f Alarm timer setting 10s 4 2 CT connection requirements As with any protection relay the current transformer requirements have to be given careful consideration This consideration is particularly important when applying differential relays as the location of the CT s and their performance under through fault conditions can have a significant affect on operation of the protection The location of the CT s effectively defines the zone of operation of the protection for both the differential element and for the restricted earth fault element The number of CT s required is dependant upon the transformer configuration as shown in figure 26 3 Phase 3 wire Delta winding Alt phase 4 wire 3 Phase 4 wire Metrosil X i X X Figure 26 Current transformer location requirements Since the majority of faults are caused by flashovers at the transformer bushings it is advantageous to locate the CT s in adjacent switchgear This also has the advantage of incorporating the LV cables within the zone of protection
27. 0 431A Therefore there is sufficient security with 15 0 2 Example 2 Ratio correction for a three winding transformer with no tap changer 30 60MVA ONAN OFAF 132kV 33kV 10 20 YNA 1200 1 lt 1050A FLC o on 0 92Amps mid tap 0 875 Amps KBCH120 1 003 Yd1 Differential YdyO Software ICT element Software ICT 30 30 E Calculate HV and LV full load currents 50MVA The HV full load current of the transformer 22kV 3 1312 Amps 0 875A secondary 50MVA The LV1 2 full load current of the transformer di 3 2624 Amps 1 75A secondary It is necessary to calculate the low voltage winding full load currents based on the HV winding MVA rating to ensure secondary currents balance for all conditions Adjust ratio compensation for In to relay both sides The HV ratio compensation factor would be set to 1 0 875 1 14 The LV1 and LV2 ratio compensation factor would be set to 1 1 75 0 57 Determine Idiff Ibias with a 20 setting Idiff 1 14 x 875 57x1 75 0 Ibias 0 9975 0 9975 2 0 9975 0 2 0 2x 9975 0 3995 Since Idiff 0 and 0 91 0 9 x 0 399 0 36A there is sufficient security with Is 0 2 KBCH EN M D11 Service Manual APPENDIX C Page 4 4 KBCH 120 130 140 Service Manual KBCH EN M D11 KBCH 120 130 140 APPENDIX D KBCH EN M D11 Service Manual
28. 14 above Is Ratio Cor Ratio Cor Id gt gt is the high set setting which will be found in the cell Id gt gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios This is found in the cell HV Ratio Cor under the SETTINGS menu heading Inject 1 1xIs and ensure that the selected output relay operates FOR THE SECOND TEST IT IS IMPORTANT THAT THE CURRENT IS NOT APPLIED FOR LONGER THAN 1 SECOND Inject O 9xIs for 1 second and ensure that the selected output relay does not operate Repeat the above two tests for the two remaining elements of the HV side of the transformer as listed in table 13 High set element operating time This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the calculated application setting Connect the relay so that current can be injected through terminals 21 and 22 but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 3xIs into the A phase low set element terminals 21 amp 22 Check that the operating time for the relay is within the range 10ms to 20ms Repeat this test for both of the remaining phases on the HV side as listed in tabl
29. 2 There is an additional unique recovery password associated with the relay which can be supplied by the factory or service agent if given details of its serial number The serial number will be found in the system data column of the menu and should correspond to the number on the label at the top right hand corner of the front plate of the relay If they differ quote the one in the system data column 9 2 Protection settings 9 2 1 Settings for protection not displayed Check the protection is enabled in the function links found in either Settings 1 or Settings 2 which ever is applicable 9 2 2 Second setting group not displayed Set function link SD4 to 1 to turn on the group 2 settings 9 2 3 Function links cannot be changed Enter the password as these menu cells are protected Links are not selectable if associated text is not displayed 9 2 4 Setting cannot be changed Check if it is a password protected setting If so enter the password 9 3 Alarms If the watchdog relay operates first check that the relay is energised from the auxiliary supply If it is then try to determine the cause of the problem by examining the alarm flags towards the bottom of the SYSTEM DATA column of the menu This will not be possible if the display is not responding to key presses Having attempted to determine the cause of the alarm it may be possible to return the relay to an operable state by resetting it To do this remove the auxiliary power suppl
30. 3 5 3 4 In table 15 above Is corresponds to the settings for the earth fault elements These are found in the cells gt HV lo gt LV1 in the SETTINGS menu heading REF element HV side operating time Connect the relay as in section 5 3 1 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5 x Is into the relay and check that the operating time for the relay is within the range 20ms to 30 ms REF current sensitivity LV1 side gt LV1 In the SETTINGS menu go to cell S1 Fn Links and set all the bits to except bit 4 S1 Enable Io gt LV1 which should be set to 1 This will ensure that only the REF protection on the low voltage side of the transformer is enabled The relays selected for the REF protection on the LV1 side of the transformer can be found under the RELAY MASKS heading in the cell RLY gt LV1 Each bit in this cell which is set to 1 corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 83 amp 84 Slowly increase the current from amps and note the pick up value at which the relay operates Redu
31. 4 3 Connect the equipment so that current can be injected through terminals 83 amp 84 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 25 REF element LV1 side operating time Connect the relay as in section 7 3 3 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms REF current sensitivity LV2 side Io LV2 In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 5 S1 Enable Io LV2 which should be set to 1 This will ensure that only the REF protection on the LV2 side of the transformer is enabled The relays selected for the REF protection on the LV2 side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io LV2 Each bit in this cell which is set to 1corresponds to an output relay for this protection function See Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 31 52 7 3 6 section 2 4 for a fuller explanation of the configuration of the output relays Th
32. Enable REF on Tertiary winding not KBCH1 20 1 Enable Overflux Trip 1 Enable Overflux Alarm 1 Enable Overflux Block See Note below PWP HV side CT Ratio PWP LV side CT Ratio PWP LV2 side CT ratio not KBCH120 PWP HV side CT correction ratio PWP HV Phase compensation PWP LV1 side CT correction ratio PWP LV1 Phase compensation PWP LV2 side CT correction ratio not KBCH120 PWP LV2 Phase compensation not KBCH1 20 PWP Low set setting High set setting REF setting HV winding REF setting LV winding REF setting Tertiary winding not KBCH1 20 5th harmonic Overflux setting 5th harmonic Overflux detector time delay Overflux Trip Characteristic Setting for Overflux Trip Definite time setting for Overflux Trip Time multiplier for Overflux Trip Setting for Overflux Alarm Definite time setting for Overflux Alarm KBCH EN M E11 CHAPTER 1 Page 32 76 Notes on Configuration setting Service Manual Technical Description KBCH 120 130 140 Setting No of Bias Configuration Applicable to Inputs HV LV 2 bias inputs KBCH120 130 140 LV HV LV1 LV2 3 bias inputs By KBCH130 140 LV1 LV2 HV x2 LV 3 bias inputs HV KBCH130 140 LV HV LV x2 3 bias inputs M KBCH130 140 LV HV x2 LV1 LV2 4 bias inputs d Only KBCH140 LV1 LV2 HV LV1 x2 LV2 4 bias inputs j Only KBCH140 X LV2 HV x2 LV x2 4 bias inputs 9 Only KBCH140 LV Not available in
33. F short step down until the cell MS1 IcLV1 is reached checking each time that the displayed value lies in this range Only perform the checks below if the cell ST Configuration is set to HV LV otherwise go to section 7 1 2 Check that the cells MS1 Ia Diff MS1 Ib Diff and MS1 Ic Diff display the correct values of differential current In this case it should be Injected 1 x22 1096 Check that the cells MS1 Ia Bias MS1 Ib Bias and MS1 Ic Bias display the correct values of bias current In this case it should be Injected I 1096 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 26 52 KBCH 120 130 140 7 1 2 LV2 LV3 winding measurement check Connect the CT inputs to the relay as shown below OVERCURRENT TEST SET Figure 4 1 2 and LV3 winding measurement check In the MEASUREMENTS menu step down until the cell MS1 IaLV2 is displayed Inject rated current and ensure that the displayed value lies within 10 of the injected value By pressing F short step down until the cell MS1 IcLV2 is reached checking each time that the displayed value lies in this range CONFIGURATION CURRENT HV LV1 LV2 HV x2 LV HV x2 LV1 LV2 HV x2 LV x2 Vb HV 12 LV2 Phase Iinj 0 Tinj 0 Differential Iinj Iinj 2xlin 2x Iinj Bias 1 2xlinj 1 2xlinj Iinj Iinj Table 21 7 1 3 Frequency measurement check Inject
34. KBCH 120 130 140 8 16 2 Shock and bump IEC 255 21 2 1988 8 16 3 Seismic IEC 255 21 3 1993 8 16 4 Mechanical durability 8 17 9 9 1 9 2 9 2 1 9 2 2 9 2 3 9 2 4 9 3 9 3 1 9 3 2 9 3 3 9 3 4 9 3 5 9 4 9 4 1 9 4 2 9 5 9 5 1 0 922 9 5 3 9 6 9 6 1 10 10 1 10 1 1 10 1 2 10 1 3 10 2 10 2 1 10 2 2 10 2 3 10 2 4 10 3 10 3 1 10 3 2 10 3 3 Model numbers PROBLEM SOLVING Password lost or not accepted Protection settings Settings for protection not displayed Second setting group not displayed Function links cannot be changed Setting cannot be changed Alarms Watchdog alarm Unconfigured or uncalibrated alarm Setting error alarm No service alarm Fault flags will not reset Records Problems with event records Problems with disturbance records Communications Measured values do not change Relay no longer responding No response to remote control commands Output relays remain picked up Relays remain picked up when de selected by link or mask MAINTENANCE Remote testing Alarms Measurement accuracy Trip test Local testing Alarms Measurement accuracy Trip test Additional tests Method of repair Replacing the user interface board Replacing the analogue input daughter board Replacing the main processor board KBCH EN M E11 CHAPTER 1 Page 5 76 61 61 61 62 63 63 63 63 63 63 63 63 63 64 64 64 64 64 64 65 65 65 65 66 66 66 67 67 67 67 6
35. KBCH 120 130 140 Service Manual KBCH EN M D11 APPENDIX D KBCH 120 130 140 Page 3 4 APPENDIX D Restricted earth fault setting example 10 MVA 10 imp 33kV 11kV 600 1 525 Amps FLC Ret RI R stab 600 1 6 3 Ohms RI Where Rct 3 70 Vk 91 volts Rstab 0 2200 Max lead length 50m RI 0 057 1 14 km Following the procedure detailed in Figure 17 a suitable Vk Vs ratio K Factor and hence operating speed can be chosen Select suitable Vk Vs ratio and K Factor For general applications a typical operating speed of two cycles is sufficient and a K Factor of 0 5 with a VK Vs ratio of 4 can be chosen Calculate stability voltage Vs The required stability voltage can be calculated using formula 3 Vs Ret 2RI If max secondary through fault current As the earth fault current in this application is limited to 1000A the maximum through fault current will be an external three phase current An estimation of the maximum three phase fault current can be estimated by ignoring source impedance If secondary full load current transformer impedance If 0 875A 0 1 8 75 Amps Vs 0 5 x 8 75 3 70 2x0 057 16 7 volts Calculate and check Vk requirements Vk 4 Vs 66 8 volts Actual Vk 91 volts which results in a Vk Vs ratio 5 5 and as can be seen from figure 16 with a factor of 0 5 the protection would be
36. LED will be lit to draw attention to this Input Overflux The trip LED can be reset by holding down the reset key 0 for at least one second The fault information is not lost by this action it is only cleared from the display The fault flags can be read by selecting FAULT RECORDS from the column headings and stepping down until the flag data Fn the flags for the last fault are displayed The red trip LED can be reset by holding the reset key depressed for 1 second whilst this cell is being displayed The next cell down contains the flags for the previous fault Fn 1 and so on to Fn 4 The currents measured during the last fault are also recorded on this page of the menu To delete all fault records the next cell after Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 27 76 5 1 5 1 1 Fn 4 must be selected This cell will read FLT Records Clear 0 and to complete the reset action the key must be held depressed for more than 1 second The only settings which can be changed with the cover in place are those that can be reset either to zero or some pre set value To change any other settings the cover has to be removed from the relay to gain access to the and keys that are used to increment or decrement a value When a column heading is displayed the key will change the display to the next column and the key will change the display to the previous column givin
37. LV1 Pick up A A Ib LV1 Drop off A A Ic LV1 Pick up A A Ic LV1 Drop off A A 5 2 2 Low set element operating time Expected 30ms to 40ms Ia HV ms ms Ib HV ms ms Ic HV ms ms KBCH EN M C1 1 CHAPTER 4 Page 8 22 5 2 3 High set element Id gt gt Setting Group 1 Setting Is tick la HV Trip la HV No Trip Ib HV Trip Ib HV No Trip Ic HV Trip Ic HV No Trip 5 2 4 High set operating time Expected 10ms to 20ms Ia HV Ib HV Ic HV 5 3 1 side current sensitivity Io HV Setting Group 1 Setting Is lo HV Pick up lo HV Drop off 5 3 2 REF HV side operating time Expected 20ms to 30ms Operating time 5 3 3 REF LV1 side current sensitivity lo gt LV1 Setting Is Io LV1 Pick up Io LV1 Drop off Service Manual Commissioning Test Results KBCH 120 130 140 Setting Group 2 if required A Setting Is tick ms ms ms Setting Group 2 if required Service Manual Commissioning Test Results KBCH 120 130 140 5 3 4 REF LVI side operating time Expected 20ms to 30ms Operating time ms 6 KBCH 130 6 1 1 HV LV1 LV2 measurement checks HV CT Ratio HV Ratio Correction HV Phase Compensation LV1 CT Ratio LV1 Ratio Correction LV1 Phase Compensation LV2 CT Ratio LV2 Ratio Correction
38. MASKS so making maximum use of the available control inputs Software filtering is applied to eliminate the adverse effects of induced ac signals in the external wiring Output relays There are eight programmable output relays and these relays can be arranged to operate in response to any or all of the available functions by suitably setting the OUTPUT MASKS In addition there is a watchdog relay for external indication of equipment failure healthy status Alternative setting group An alternative group of settings is provided The alternative settings can be selected at any time either by energising an opto isolated control input assigned to this function or by a remote command via the serial communication port of the relay A decision has to be made during commissioning as to which method is to be used to Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 15 76 2 9 2 10 select the alternative setting group It is not possible to select by both local and remote control at the same time Logic All the settings for the auxiliary timing functions are located under the LOGIC heading of the menu There are eight auxiliary timers in the relays which may be used as discrete time delays for external functions They may be initiated via the opto isolated control inputs and their outputs directed to any of the output relays by suitably setting the associated RELAY MASKS Measurement All measur
39. RI 2 maximum lead burden from CT to relay Rs value of stabilising resistor Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 25 38 2 4 2 4 1 2 4 2 The required metrosil for 1Amp relay applications can be chosen as follows For stability voltage settings 125Volts 450 For stability voltage settings gt 125Volts C 900 For 5 Amp applications AREVA T amp D should be consulted Overfluxing protection and blocking Basic principles The KBCH relay offers an overfluxing protection element which can be used to raise an alarm or initiate tripping in the event of prolonged periods of transformer overfluxing In addition a differential current 5th harmonic blocking feature is also provided within the KBCH which can be used to prevent possible maloperation of the differential element under transient overfluxing conditions To make use of the time delayed overfluxing protection the KBCH relay must be supplied with a voltage signal which is representative of the primary system voltage on the source side of the transformer The 5th harmonic blocking feature does not require a voltage signal A 5th harmonic signal is derived from the differential current wave form on each phase and blocking is on a per phase basis Transformer overfluxing Transformer overfluxing might arise for the following reasons High system voltage Generator full load rejection Ferranti effect with light loading transmissi
40. S2 Iof S2 tof S2 V f Trip Char S2 V f Trip S2 V f Trip TMS or S2 t V f Trip S2 V f Alarm S2 t V f Alarm LOGIC FUNCTIONS LOG tAUXO LOG tAUXI LOG tAUX2 LOG tAUX3 LOG tAUX4 LOG tAUX5 LOG tAUX6 LOG tAUX7 LOG tTest LOG tTapUp LOG t TapDown LOG DefaultDsply INPUT MASKS 7 6 9 4 3 2 1 0 INP Blk V F Trp INP Blk V f Alm INP Aux O INP Aux 1 Service Manual Commissioning Test Results KBCH 120 130 140 INP Aux 2 INP Aux 3 INP Aux 4 INP Aux 5 INP Aux 6 IN Aux 7 INP Set Grp 2 RELAY MASKS RLY Id gt A RLY Id gt B RLY Id gt C RLY Id gt gt A RLY Id gt gt B RLY Id gt gt C RLY Io gt HV RLY Io gt LV1 RLY Io gt LV2 RLY AUX O RLY AUX 1 RLY AUX 2 RLY AUX 3 RLY AUX 4 RLY AUX 5 RLY AUX 7 RLY Tap Up RLY Tap Down RLY Of Alarm RLY V F Trip RLY V f Alarm RECORDER KBCH EN M C11 CHAPTER 4 Page 5 22 REC Control REC Capture REC Post Trigger REC Logic trig KBCH EN M C1 1 CHAPTER 4 Page 6 22 Service Manual Commissioning
41. Terminal 7 should be positive with respect to terminal 8 and should be within the range specified in Table 9 when no load is connected Nominal dc rating V Range V 48 45 V 60 Table 9 KBCH EN M C11 Service Manual 4 1 CHAPTER 3 Commissioning Instructions Page 12 52 KBCH 120 130 140 4 SETTINGS The commissioning engineer should be supplied with all the required settings for the relay The settings should be entered into the relay via the front keypad or by using a portable PC with a K Bus connection and recorded on the commissioning test record sheet If the K Bus communications are being used then the master station can download the settings to the relay record any relay settings on disc and download recorded settings to other relays The protection settings for the relay are contained in the SETTINGS 1 and SETTINGS 2 menu columns SETTINGS 2 is only required if group 2 is used The characteristics of the relay can be further changed by setting the FUNCTION LINKS These links change the logic within the relay so that the auxiliary functions can be used for alternative tasks They can also turn OFF or block some of the unwanted functions therefore this is the first place to look if the relay is not configured as required The FUNCTION LINKS are found in the following menu headings SYSTEM DATA heading in the cell SYS Fn Links SETTINGS 1 heading in the cell S1 Fn Links SETTINGS 2
42. Terminal Function A Current 4 In 63 64 Out A Current 4 KBCH140 only B Current 4 In 65 66 Out B Current 4 KBCH140 only C Current 4 In 67 68 Out C Current 4 KBCH140 only A Current 3 In 69 70 Out A Current 3 Not on KBCH120 B Current 3 In 71 72 Out B Current 3 Not on KBCH1 20 C Current 3 In 73 74 Out C Current 3 Not on KBCH1 20 E F Current 3 In 75 76 Out E F Current 3 Not on KBCH1 20 A Current 2 In 77 78 Out A Current 2 B Current 2 In 79 80 Out B Current 2 C Current 2 In 8 82 Out C Current 2 E F Current 2 In 83 84 Out E F Current 2 3 1 Key to connection tables and indicate the polarity of the dc output from these terminals indicate the polarity for the applied dc supply In Out the signal direction for forward operation Note All relays have standard Midos terminal blocks to which connections can be made with either 4mm screws or 4 8mm pre insulated snap on connectors Two connections can be made to each terminal Auxiliary supply The auxiliary voltage may be ac or dc provided it is within the limiting voltages for the particular relay The voltage range will be found on the front plate of the relay it is marked Vx 24V 125V or Vx 48V 250V An ideal supply to use for testing the relays will be 50V dc or 110V ac because these values fall within both of the auxiliary voltage ranges The suppl
43. Test Results KBCH 120 130 140 REC Relay trig 4 3 Relay Operation tick Relay O Relay 4 Relay 1 Relay 5 Relay 2 Relay 6 Relay 3 Relay 7 5 KBCH 120 5 1 1 HV LV1 Winding Measurements Checks HV CT Ratio tick HV Ratio Correction HV Phase Compensation LV1 CT Ratio LV1 Ratio Correction LV1 Phase Compensation PHASE CURRENT Injected current EXPECTED VALUES Ia HV Ib HV Ic HV Ia Ib LV1 Ic LV DIFFERENTIAL CURRENT Theoretical value RELAY MEASURED VALUE Ia Diff Ib Diff Ic Diff BIAS CURRENT RELAY MEASURED VALUES gt gt gt gt gt gt gt gt gt gt gt gt Service Manual KBCH EN M C11 Commissioning CHAPTER 4 Test Results KBCH 120 130 140 Page 7 22 Theoretical value A RELAY MEASURED VALUE Ia Bias A Ib Bias A Ic Bias A 5 1 2 Frequency Measurement F injected Hz F measured Hz 5 2 Differential Protection 5 2 1 Low set element current sensitivity Id gt Setting Group 1 Setting Group 2 if required Setting Is A A Ia HV Pick up A A Ia HV Drop off A A Ib HV Pick up A A Ib HV Drop off A A Ic HV Pick up A A Ic HV Drop off A A Ia LV1 Pick up A A Ia LV1 Drop off A A Ib
44. This was traditionally provided by the appropriate connection of physical interposing current transformers as a replica of the main transformer winding arrangements or by a delta connection of main CT s Phase correction is provided in the KBCH via software interposing CT s for each transformer winding i e HV LV1 LV2 and as with the ratio correction the appearance KBCH EN M D11 Service Manual CHAPTER 2 Application Page 12 38 KBCH 120 130 140 of the facility in the relay menu will depend upon the selected configuration for biased inputs The phase correction settings available with KBCH are as follows YyO Odeg Yd1 30deg Yd2 60deg Yd3 90deg Yd4 120deg Yd5 150deg Yy6 180deg Yd7 150deg Yd8 120deg Yd9 90deg Yd10 60deg Yd11 30deg YdyO Odeg Ydy 180deg In addition to mimicking the phase shift of the protected transformer it is also necessary to mimic the distribution of primary zero sequence current in the protection scheme The necessary filtering of zero sequence current has also been traditionally provided by appropriate connection of interposing CT s or by delta connection of main CT secondary windings In the KBCH zero sequence current filtering is implemented in software when a delta connection is called up for a software interposing CT Where a transformer winding can pass zero sequence current to an external earth fault it is essential that some form of zero sequence c
45. Transformer Protection Package Overview of existing Practices Figure 1 shows a typical protection package for a sub transmission or large distribution transformer High speed protection is provided for faults on both the HV and LV windings by a biased differential relay 87 The relay operates on the basic differential principle that HV and LV CT secondary currents entering and leaving the zone of protection can be balanced under load and through fault conditions whereas under internal fault conditions balance will be lost and a differential current will cause the relay to trip The zone of protection is clearly defined by the CT locations and as the protection is stable for through faults it can be set to operate without any intentional time delay Figure 1 illustrates the application of an overall differential relay where an interposing CT is used to provide phase and ratio correction of CT signals in addition to trapping LV zero sequence current to prevent maloperation of the differential element for external LV earth faults More sensitive high speed earth fault protection for the LV winding is provided by a high impedance restricted earth fault relay 64 Due to the limitation of phase fault current on the HV side for LV winding earth faults and the fact that any un restricted earth fault protection in the transformer earth path requires a discriminative time delay restricted earth fault protection is widely applied The application of r
46. Vs Ip CT ratio x Is nle The required relay current setting I can be determined by equation 4 Is lt IoP CT ratio n Ie 4 Required stabilising resistor setting Once the relay current setting has been decided upon the required stabilising resistor setting can be determined from the relationship described by equation 2 The stabilising resistors supplied with KBCH are adjustable wire wound resistors For 1 Amp rated relays the range of adjustment is 0 2200 for 5 Amp rated relays the range of adjustment is 470 Metrosil assessment For applications where the maximum internal earth fault level is higher than the though fault current used to derive the required stability voltage setting a check should be made on the peak voltage that might be produced for an internal earth fault using the traditional formula below If this voltage to exceeds 3kV peak a voltage limiting non linear resistor Metrosil should be applied in parallel with the restricted earth fault relay and stabilising resistor circuit This requirement should only arise with some applications of restricted earth fault protection for the primary winding of a power transformer on a multiple earthed system The peak voltage can be estimated by using the formula below Vp 242 Vk VF V 5 Where Vf If Rct 2RI Rs Vk Actual CT kneepoint voltage If maximum internal secondary fault current Rct CT secondary winding resistance
47. a current of known frequency to terminals 21 and 22 of the relay The frequency must be in the range 15 to 65 Hz In the MEASUREMENTS menu step down until the cell MS1F is displayed Check that the displayed value lies in the range Injected frequency 296 7 2 Differential Protection The relay should be commissioned with the settings calculated for the application 7 2 1 Low set element current sensitivity Id In the SETTINGS menu go to cell S1 Fn Links and set all bits to O except bit 1 S1 Enable Id which should be set to 1 This will ensure that only the low set protection function is enabled The operation of the relay can be monitored as described in section 4 3 Relay operation The relays selected for the low set differential protection function can be found under the RELAY MASKS heading The phase A relay will be found in the cell Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 27 52 RLY Id gt A phase B relay in cell RLY Id gt B and phase C in RLY Id gt C Each bit in these cells which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation on the configuration of the output relays Connect the equipment so that current can be injected through terminals 21 and 22 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop of
48. and automatically allocate the next available address on the bus to which that relay is connected and communications will then be fully established Setting control input masks An eight bit mask is allocated to each protection and control function that can be influenced by an external input applied to one or more of the opto isolated control inputs When an input mask is selected the text on the top line of the display indicates the associated control function and the bottom line of the display shows a series of 1 s and O s for the selected mask The numbers printed on the front plate under the display indicate the number of the control input L7 to LO that is being displayed A 1 indicates that a particular input will effect the displayed control function and a O indicates that it will not The same input may be used to control more than one function Setting relay output masks An eight bit mask is allocated to each protection and control function When a mask is selected the text on the top line of the display indicates the associated function and the bottom line of the display shows a series of 1l s and O s for the selected mask The numbers printed on the front plate under the display indicate the number of the output relay RLY7 to RLYO that each bit controls A 1 indicates that the relay will respond to the displayed function and a 0 indicates that it will not The mask acts like an OR function so that more
49. bit in this cell which is set to 1 corresponds to an output relay for this function For a fuller description of the configuration of output relays see section 2 4 If there are no bits in this cell set to 1 then there is no need to perform this test There is a settable time delay associated with this function which results in a delay between the detection of the fifth harmonic current above setting and operation of the output relay This time delay is found in the cell S1 tOF under the SETTINGS menu KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 40 52 KBCH 120 130 140 heading This test should only be performed if the timer setting is not so high that testing is impractical It should be noted that the timer setting can go up to 4 hours Connect the relay as in Figure 9 but in addition connect the relay selected to operate for the fifth harmonic detector to stop the timer Configure the current source such that the timer starts upon application of the current Apply the following current to the relay ini Id Iinj 1 1 HV Ratio c Iof 5 Record the operating time and ensure that it lies within the range SItOF 10 Service Manual KBCH EN M C11 12 1 12 2 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 41 52 12 SELECTIVE LOGIC For the selective logic tests only the features that are to be used in the application should be tested Relay settings must not be
50. changed to enable other logic functions that are not being used to be tested Opto input checks To enable energisation of the opto inputs terminal 8 should be linked to terminals 52 and 55 The opto inputs can then be energised by connecting terminal 7 to the appropriate opto input listed in table 28 Note The opto isolated inputs may be energised from an external 50V battery in some installations Check that this has been disconnected before connecting the field voltage to the terminals otherwise damage to the relay may result Opto Input Number Bit Terminal LO 46 0 L1 48 1 L2 50 2 L3 45 3 L4 47 4 L5 49 2 L 51 6 L7 53 7 Table 28 The status of each opto input can be viewed by monitoring the cell SYS Logic Stat in the SYSTEM DATA menu heading When an opto input is energised the appropriate bit in this cell will be set to 1 Which bit corresponds to which opto input is listed in table 28 When the opto input is de energised the bit will be reset to O Test each opto input in turn by applying a DC voltage from terminal 7 and monitoring the cell SYS Logic Stat Ensure that the correct bit is set to 1 when the corresponding opto input is energised Controlled blocking of overflux protection This test need only be done if the relay application requires blocking of the overflux protection As there are two elements to the overflux protection there are two possibilities shown in tab
51. conventional way will give a measure of inter turn fault protection and it will also detect delta tertiary phase faults Detection of tertiary earth faults will be dependant on tertiary winding earthing For some auto transformer applications with a loaded tertiary winding the range of ratio compensation offered by KBCH may not be sufficient for the tertiary CT signals In rare cases an external interposing current transformer may be required Generator transformers Unit transformers For large generator applications it is common to provide separate differential protection schemes for the generator main transformer and for the unit transformer In addition an overall system differential relay is often employed as back up The KBCH compliments the P340 range integrated generator protection package and the P140 digital overcurrent relay range to offer protection for generating plant Overfluxing protection for the entire plant is provided by the KBCH see Fig 22 Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 31 38 LGPG KCGG 51 51N 50 3 3 il 64 REF 87 Biased Diff 2 6 51 IDMT overcurrent 51N Standby E F 50 Instantaneous o c 8 24 Overfluxing relay Figure 22 Generator and Generator Transformer protect
52. could be set to zero Since the Buchholz relay provides independent protection it should be able to initiate tripping independently of the KBCH This means that the Buchholz trip surge contact should be wired to trip the transformer circuit breaker s directly or via a separate Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 29 38 3 2 auxiliary relay Where Buchholz trip operation is to be event logged by KBCH the auxiliary relay approach can be adopted so that a volt free contact will be available for KBCH opto control Alternatively a group of opto isolators could be fed from the protection auxiliary supply rather than the 48V field voltage of the relay as long as suitable series resistors are used see below Figure 20 With this approach the Buchholz surge contact could initiate breaker tripping directly through a suitable diode as well as through the KBCH auxiliary path see Figure 20 Breaker Trip coil Buch surge a Oo Winding Temp O Dropping Resistor Dropping Resistor Figure 20 Use of opto isolators with protection Auxiliary supply Opto inputs for the KBCH are 50V Required values of dropping resistor Auxiliary supply 110 125V 10kQ 1 0W 220 250V 33kQ 2 0W A label area is provided on the front of the relay where the function of each KBCH auxiliary element
53. for instance if V f gt 1 1 The base of unit voltage should be taken as the highest voltage for which the transformer has been designed for Protection against overflux conditions does not call for high speed tripping in fact instantaneous tripping is undesirable as it would cause tripping for momentary system disturbances which can be borne safely Normal conditions must be resumed within a minute or two at the most The relay contains two overflux algorithms alarm and trip The alarm normally set to operate at a lower level than the trip will be used to initiate corrective action Both operate by comparing the ratio of Voltage to Frequency against a setting The alarm has a definite time delay the trip has a choice of definite time delay or inverse definite minimum time characteristic which is shown in Figure 2 7 Operating time as a function of the actual excitation and the set starting value for different time multiplier settings time s 1000 lt I N Y 100 X E K 63 K 40 10 20 5 1 1 1 1 1 1 2 1 3 1 4 1 5 1 6 v f V f setting Figure 2 7 Overflux tripping IDMT characteristic Opto isolated control inputs There are eight opto isolated control inputs to the relay and these can be arranged to perform alternative functions as determined by the setting of the INPUT
54. heading in the cell S2 Fn Links INPUT MASKS heading RELAY MASKS heading Table 10 The INPUT MASKS are used to assign the opto isolated inputs of the relay to control specific functions The RELAY MASKS are used to assign the output relays to operate for a specific protection or control function Changing the settings Settings and text in certain cells of the menu can be changed using either the keypad on the front of the relay or a PC and the suitable software as described in section 1 When using the keypad select the menu heading in which the cell to be changed is found by pressing F long Select the cell to be changed by pressing F short To enter the setting mode press either the or key This will cause the cursor to flash on the bottom line of the display The contents of the cell can then be changed by pressing to increment the value and to decrement the value Some of the settings on the relay are password protected and it is therefore necessary to enter the password before the relay configuration can be changed The password can be entered in the SYSTEM DATA menu heading The relay is supplied with a factory default password of AAAA When the password has been successfully entered the yellow ALARM led will flash on and off indicating that the relay configuration can now be changed This will reset after 15 minutes if no further keys are pressed and the password will have to be entered again
55. in a column contains a heading which identifies the data grouped on that column see Figure 5 1 Figure 5 1 Menu system of relay Four keys on the front plate of the relay allow the menu to be scanned and the contents displayed on the liquid crystal display LCD The act of depressing any key will result in the LCD backlight being switched on The backlight will turn off again if a key is not pressed again within one minute The display will normally be the selected default setting and a momentary press of the function key F will change the display to the heading for the first column SYSTEM DATA Further momentary presses of the F key will step down the column row by row so that data may be read If at any time the F key is pressed and held for one second the cursor will be moved to the top of the next column and the heading for that column will be displayed Further momentary presses of the F key will then move down the new column row by row In this way the full menu of the relay may be scanned with just one key and this key is accessible with the cover in place on the relay The other key that is accessible with the cover in place is the reset key 0 A momentary press of this key will switch on the back light for the LCD without changing the display in any way Following a protection trip the display will change automatically from the default display to that of the fault flags for that fault and the red trip
56. in time delayed fault clearance for some low level faults Time delayed clearance of major faults is unacceptable on larger distribution transmission and generator transformers where the effects on system operation and stability must be considered High speed protection is desirable for all faults Transformer faults are generally classified into four categories Winding and Terminal faults Core faults Abnormal operating conditions such as over voltage overfluxing and overload Sustained or uncleared external faults All of the above conditions must be considered individually and the transformer protection package designed accordingly To provide effective protection for faults within a transformer and security for normal operation and external faults the design and application of transformer protection must consider factors such as Magnetising Inrush current Winding arrangements Winding connections Connection of protection secondary circuits The way that the protection of larger transformers is typically achieved is best illustrated by examining the protective devices associated with common applications KBCH EN M D11 Service Manual CHAPTER 2 Application Page 4 38 KBCH 120 130 140 ICT A WT Winding Temp AB Buchholz OT Oil Temp 64 REF 87 Biased Diff 51N Standby E F 87 50N Inst earth fault 51 IDMT overcurrent 24 Overfluxing relay Figure 1 Typical
57. is not possible a difference of up to 15 should be allowed for When the transformer is under normal steady state load conditions and the relay is configured and wired correctly then the differential current should be less than 5 of the bias current Go to the MEASUREMENTS menu and note the current flowing in each of the following cells MS1 Ia Diff MS1 Ia Bias MS1 Ib Diff MS1 Ib Bias MS1 Ic Diff MS1 Ic Bias If the differential current is greater than 5 of the bias current then the following should be checked Ensure that the phase compensation and ratio correction settings are set to the calculated application settings These are found under the SETTINGS menu heading in the cells HV Ratio Cor HV VectorCor LV1 Ratio Cor LV1 VectorCor LV2 Ratio Cor LV2 VectorCor Note that the LV2 cells do not appear on the KBCH120 model and will not appear on the KBCH130 and KBCH140 models if they are configured as HV LV If the phase compensation and ratio correction settings are correct and the differential current is still larger than expected then check that the relay is correctly wired at the relay terminals and that the connections from the line CT s are of the correct polarity KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 48 52 KBCH 120 130 140 16 TYPICAL APPLICATION DIAGRAMS
58. jo eee 10 K 20 K 5 1 1 1 1 2 1 3 1 4 1 5 1 6 v f V f setting Figure 8 With the relay connected as in section 11 1 for a duration greater than the time t calculated from the equation above apply a voltage of V settingxfx0 95 where setting V f trip setting found in the cell 51 V f Trip in the SETTINGS menu and f system frequency and ensure that the selected output relay does not energise Next apply a voltage of V settingxfx1 05 and ensure that the selected output relay does energise and that the time is within 20 of the time t above 11 3 Overflux fifth harmonic This test checks the overflux fifth harmonic function of the relay The overflux fifth harmonic function blocks the low set differential protection from operating if fifth harmonic current above setting is detected in the input current This test can only be performed if the equipment is able to superimpose up to 5596 fifth harmonic on the fundamental Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 39 52 In the SETTINGS menu go to cell S1 Fn Links and set all bits to O except bits 1 and 9 which should be set to 1 This will ensure that only the fifth harmonic blocking function of the relay and the low set differential protection are enabled The output relay selected to operate for the low set differential protection can be found under the RELAY MASKS heading in the cell RLY Id
59. numbers Service Manual Technical Description KBCH 120 130 140 Configuration i e settings as supplied and connection diagram Sheet No varies with external connection arrangement KBCH140 CO CS RTG A Issue Rating eee i ee H 0 2 3 4 1 01 L CO f CS 4 F G 5 L M 2 5 Note Case details Mechanical assembly Relay Type First Version 2 bias inputs per phase 3 bias inputs per phase 4 bias inputs per phase Auxiliary Powered V Inrush proof current operated biased differential K Series Midos Standard configuration Back connected flush mounting standard mounting May be used as an additional digit for configuration later MiCOM Livery Size 8 40TE Standard English text French text German text Spanish text Vn 100 120V In 1A 50 60Hz Vn 100 120V In 5A 50 60Hz Vn 100 120V In HV 1A LV 5A 50 60Hz Vx 24 125V ac dc Vx 48 250V ac dc Option P 1A 5A rating is only available on KBCH120 and KBCH140 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 63 76 9 PROBLEM SOLVING 9 1 Password lost or not accepted Relays are supplied with the password set to AAAA Only uppercase letters are accepted Password can be changed by the user see Section 5 2
60. recorded and time tagged and is then available over the serial communications link Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 47 76 6 6 INP RLY AuxO INP Aux2 INP Aux3 Figure 6 7 Auxiliary time delays Change of setting group control Figure 6 8 shows that when link SD4 is set to O only the settings for one of the setting groups will be displayed the other group will be inactive and hidden To activate the second group of settings link SD4 must be set to 1 The second group of settings will then appear in the menu and can be set in the usual way Group 1 settings are normally in use and switching to the group 2 settings requires either a remote command to be received via the serial communication port or an external input via one of the opto isolated control inputs For reasons of operational safety it has not been made possible to control the setting group change both locally and remotely at the same time Link SD3 decides which method is to be used it is set to 1 for remote control of the change and to 0 for local control KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 48 76 KBCH 120 130 140 6 6 1 6 6 2 6 7 6 8 INP Set 503 Select alternative setting GRP2 Remote change 10 emote change Figure 6 8 Change setting group control logic Remote change of setting group
61. recorder stopped and record ready for retrieval When this cell is selected manual control is possible and to achieve this the relay must be put into the setting mode by pressing the key A flashing cursor will then appear on the bottom line of the display at the left hand side The key will then select RUNNING and the key will select TRIGGERED When the appropriate function has been selected the F key is pressed to accept the selection and the selected function will take effect when the key is pressed to confirm the selection To abort the selection at any stage press the reset key 0 Recorder capture The recorder can capture a SAMPLES the individual calibrated samples b MAGNITUDES the Fourier derived amplitudes c PHASES the Fourier derived phase angles The relay has no electro mechanical adjustments all calibration is effected in software and all three of the above options are used in the calibration process For normal use as a fault recorder SAMPLES will be the most useful Note If the disturbance recorder is set to SAMPLES mode the bias currents will indicate zero This is due to the bias current being calculated from the sample data Recorder post trigger The Post Trigger setting determines the length of the trace that occurs after the stop trigger is received This may be set to any increment of 5 between 5 and 505 samples When recording samples the total trace duration is 510 40 12 c
62. required Remote change of settings will be possible over the serial communication port so that settings can be downloaded via this path The password when the relay leaves the factory will be AAAA The disturbance recorder will be set to not automatically reset on restoration of the supply and will be triggered by operation of the trip relays RLY3 or RLY7 7 2 3 Initial time delay settings tAUXO 1 0s tAUX4 1 0s tAUX1 1 0s tAUX5 1 0s tAUX2 1 0s tAUX6 1 0s tAUX3 1 0s tAUX7 1 0s tTEST 2 0s tTapUp 1 0s tTapDown 1 0s 7 2 4 Initial allocation of opto isolated control inputs LO Initiate auxiliary timer L1 Initiate auxiliary timer 1 L2 Initiate auxiliary timer 2 L3 Initiate auxiliary timer LA Initiate auxiliary timer 4 L5 Initiate auxiliary timer 5 L Initiate auxiliary timer L7 Initiate auxiliary timer 7 7 2 5 Initial allocation of output relays RLYO Trip Id gt A B C Id gt gt A B C Io HV LV1 LV2 V f Trip RLY1 Trip Id gt A B C Id gt gt A B C Io HV LV1 LV2 V f Trip RLY2 Trip Id gt A B C Id gt gt A B C Io HV LV1 LV2 V f Trip RLY3 Trip Id gt A B C Id gt gt A B C Io HV LV1 LV2 V f Trip RLYA Tap Up RLY5 Tap Down RLY6 V f Alarm RLY7 Trip Id gt A B C Id gt gt A B C Io HV LV1 LV2 V f Trip 7 3 Configuring for application Before attempting to change the configuration for a particular application it is strongly recommended that experience is first gain
63. see Service Manual R8530 Figure 12 4 Typical restricted earth fault connections for KBCH140 KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 76 76 KBCH 120 130 140 Service Manual KBCH EN M D11 KBCH 120 130 140 CHAPTER 2 Application KBCH EN M D11 Service Manual KBCH 120 130 140 Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 1 38 CONTENT 1 INTRODUCTION 3 1 1 Protection of transformers 3 1 2 KBCH Protection relay 6 1 2 1 Protection Features 6 1 2 2 Non protection features 7 2 APPLICATION OF INDIVIDUAL PROTECTIVE FUNCTIONS 8 2 1 Overall Differential Protection 87 8 2 1 1 Biased elements 8 2 1 2 Ratio correction 10 2 1 3 Phase correction and zero sequence current filtering 11 2 1 4 Magnetising inrush 15 2 2 High set operation 17 2 3 Restricted Earth Fault Protection 18 2 3 1 Basic principles 18 2 3 2 Stability requirements 20 2 3 3 Operating times 22 2 3 4 Setting procedure 22 2 3 4 1 VK VS ratio 23 2 3 4 2 Stability voltage setting 23 2 3 4 3 CT kneepoint voltage requirement 23 2 3 4 4 Required current setting and CT magnetising current 24 2 3 4 5 Required stabilising resistor setting 24 2 3 4 6 Metrosil assessment 24 2 4 Overfluxing protection and blocking 25 2 4 1 Basic principles 25 2 4 2 Transformer overfluxing 25 2 4 3 Time delayed Overfluxing protection 26 2 4 4 5th Harmonic blocking 26 2 4 5 Required settings 27 3 OTHER PROTECTION CONSIDERATIO
64. technique is used to measure the level of fifth harmonic in the differential current The ratio of fifth harmonic to fundamental is compared with a setting which if exceeded inhibits the biased differential protection Detection of overflux conditions in any phase blocks that particular phase of the low set algorithm Figure 2 6 Typical overflux current waveforms High set protection function An additional unrestrained instantaneous high set differential element is provided to ensure rapid clearance of terminal faults This element is essentially peak measuring to ensure fast operation for internal faults with saturated CTs The high set is not blocked under magnetising inrush or over excitation conditions hence the setting must be set such that it will not operate for the largest inrush currents expected Restricted earth fault REF protection function Restricted earth fault protection is included to give greater sensitivity to earth faults and hence protect more of the winding A separate element is provided for each winding An external resistor is required to provide stability in the presence of saturated line current transformers The REF protection works on the high impedance circulating current principle as used in the MCAGIA relays When subjected to heavy through faults the line current transformer may enter saturation unevenly resulting in unbalance To ensure stability under these conditions the element uses a voltage o
65. the phase compensation factors provided can be used to achieve the desired phase shift In the case of a Dd10 transformer the LV current leads the HV current by 60 correcting the HV current by 30 Select Yd11 on the relay menu and the LV current by 30 Select Yd1 on the relay menu the required 60 phase shift and zero sequence filtering is achieved Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 15 38 Transformer Connection Transformer Phase Compensation Phase Shitt Factor Relay Setting HV LV DdO YyO DzO 0 Y d yO Y d yO Dy 30 YyO Yd11 Yd Yz 30 Yd1 Y d yO Dd2 Dz2 60 Yd1 Yd11 Dd4 Dz4 120 Yd11 Yd7 Dy5 150 YyO Yd7 Yd5 Yz5 150 Yd5 Y d yO Dd Yy6 Dz 180 Y d yO Y d y6 Dy7 150 YyO Yd5 Dd8 Dz8 120 Yd7 Yd11 Yd9 90 Yd9 Y d O Dd10 Dz10 60 Yd11 Yd1 Yd11 Yz11 30 Yd11 Y d yO Table 2 Selection of phase compensation factors Table 2 indicates the phase shifts associated with a variety of transformers as well as the suggested phase compensation factors to be employed on KBCH This assumes that the line current transformers are star connected The required phase shifts can be achieved using alternative correction factors if desired Where an in zone earthing connection is provided and no phase shift compensation is necessary with the chosen software ICT the required zero sequence filtering is provide
66. the phase currents are the calculated current which is flowing in the transformer winding As with the event recorder when the buffer is full the oldest record is overwritten and records are deleted if the auxiliary supply to the relay is removed This ensures that when the buffer is read the contents will all be valid KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 18 76 KBCH 120 130 140 2 14 3 2 14 4 2 14 5 The disturbance recorder is stopped and the record frozen a set time after a selected trigger has been activated For example a protection trip command could be the selected trigger and the delay would then set the duration of the trace after the fault Each sample has a time tag attached to it so that when the waveform is reconstituted it can be plotted at the correct point against the time scale thus ensuring that the time base is correct and independent of the frequency The disturbance records can only be accessed via the serial communication port Remote control functions Control functions that affect the relay and that can be performed over the serial link include the change of individual relay settings and the change between setting groups Plant control functions include remote manual tap up tap down Note If it is considered essential that it must not be possible to perform certain of these remote control functions they can be inhibited by setting software links in the relay These links are pas
67. the time the fault occurred AC Volts Main VT Test set DC Volts Battery Power supply AC current Main CT Test set Frequency 2 Which type of test was being used 3 Were all the external components fitted where required Yes No Delete as appropriate 4 List the relay settings being used 5 What did you expect to happen continued overleaf 6 What did happen 7 When did the fault occur Instant Yes No Intermittent Yes No Time delayed Yes No Delete as appropriate By how long 8 What indications if any did the relay show 9 Was there any visual damage 10 Any other remarks which may be useful Signature Title Name in capitals Company name Publication KBCH EN M G11 AREVA AREVA T amp D s Automation amp Information Systems Business www areva td com T amp D Worldwide Contact Centre online 24 hours a day 44 0 1785 25 OO 70 http www areva td com contactcentre
68. this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms REF current sensitivity LV2 side gt LV2 In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 5 S1 Enable Io gt LV2 which should be set to 1 This will ensure that only the REF protection on the LV2 side of the transformer is enabled The relays selected for the REF protection on the LV2 side of the transformer can be found under the RELAY MASKS heading in the cell RLY gt LV2 Each bit in this cell which is set to 1 corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 75 amp 76 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 20 REF element LV2 side operating time Connect the relay as in section 6 3 5 above but in addition connect the relay contacts for this protection function to both tr
69. to terminals 21 and 22 of the relay The frequency must be in the range 15 to 65 Hz In the MEASUREMENTS menu step down until the cell MS1F is displayed Check that the displayed value lies in the range Injected frequency 2 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 15 52 5 2 Differential Protection 5 2 1 The relay should be commissioned with the settings calculated for the application Low set element current sensitivity Id In the SETTINGS menu go to cell S1 Fn Links and set all bits to O except bit 1 S1 Enable Id which should be set to 1 This will ensure that only the low set protection function is enabled The operation of the relay can be monitored as described in section 4 3 Relay operation The relays selected for the low set differential protection function can be found under the RELAY MASKS heading The phase A relay will be found in the cell RLY Id A phase B relay in cell RLY Id B and phase C in RLY Id C Each bit in these cells which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation on the configuration of the output relays Connect the equipment so that current can be injected through terminals 21 and 22 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it res
70. unstable iterative approach is adopted to achieve the desired settings From figure 16 a Vk Vs ratio r requires a K Factor 0 6 for stability Vs can now be re calculated based on these values Vs 0 60 x 8 75 3 70 2x 0 114 20 0 volts KBCH EN M D11 Service Manual APPENDIX D Page 4 4 KBCH 120 130 140 Vk 4 Vs 80 0 volts Actual Vk 91 volts which results in a Vk Vs ratio 4 55 and as can be seen from figure 16 with a K Factor of 0 36 the protection is stable Calculate relay setting Is Required primary operating current 25 of earth fault current 6350V 6 3 x 25 252Amps Setting current Is Iop CT ratio n Ie Ie for the chosen CT 1 at voltage setting from CT magnetising characteristic Is 252x1 600 4 x 0 01 0 38 select this setting on the relay Calculate required stabilising resistance value Rs Rs Vs Is 20 0 38 53 Check Metrosil requirements If the peak voltage appearing across the relay circuit under maximum internal fault conditions exceeds 3000V peak then a suitable non linear resistor metrosil externally mounted should be connected across the relay and stabilising resistor The peak voltage can be estimated by the formula Where Vp 2 A2Nk VF Vk Vk actual CT knee point voltage Vf If Rct 2RI Rstab Where If maximum prospective secondary internal fault current As the earth fault current in this application is limited to 1000A the max
71. up Ic LV2 Drop off Ia LV3 Pick up Ia LV3 Drop off Ib LV3 Pick up Ib LV3 Drop off Ic LV3 Pick up Ic LV3 Drop off gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt ee ee ee eee ee eee eee eee Service Manual Commissioning Test Results KBCH 120 130 140 Setting Group 2 if required gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt gt ee eee ee eee ee eee eee eee Service Manual Commissioning Test Results KBCH 120 130 140 7 2 2 Low set element operating time Setting Group 1 Expected 30ms to 40ms Ia HV ms Ib HV ms Ic HV ms 7 2 3 High Set element Id gt gt Setting Is A Setting Is tick Ia HV Trip Ia HV No Trip Ib HV Trip Ib HV No Trip Ic HV Trip Ic HV No Trip 7 2 4 High set element operating time Expected 10ms to 20ms Ia HV ms Ib HV ms Ic HV ms 7 3 1 REF HV side current sensitivity Io HV Setting Group 1 Setting Is A lo HV Pick up A lo HV Crop off A 7 3 2 HV side operating time Expected 20ms to 30ms Operating time ms KBCH EN M C1 1 CHAPTER 4 Page 15 22 Setting Group 2 if required tick Setting Group 2 if required KBCH EN M C1 1 CHAPTER 4 Page 16 22 7 3
72. with components and electrical connections If removed from the case for storage the module should be placed in an electrically conducting antistatic bag There are no setting adjustments within the module and it is advised that it is not unnecessarily disassembled Although the printed circuit boards are plugged together the connectors are a manufacturing aid and not intended for frequent dismantling in fact considerable effort may be required to separate them Touching the printed circuit board should be avoided since complementary metal oxide semiconductors CMOS are used which can be damaged by static electricity discharged from the body 1 2 Handling of electronic equipment A person s normal movements can easily generate electrostatic potentials of several thousand volts Discharge of these voltages into semiconductor devices when handling electronic circuits can cause serious damage which often may not be immediately apparent but the reliability of the circuit will have been reduced The electronic circuits are completely safe from electrostatic discharge when housed in the case Do not expose them to risk of damage by withdrawing modules unnecessarily Each module incorporates the highest practicable protection for its semiconductor devices However if it becomes necessary to withdraw a module the precautions should be taken to preserve the high reliability and long life for which the equipment has been designed and manvfactured
73. 00 OB 01 OB 02 OB 03 OB 04 OB 05 OB 06 OB 07 OB 08 OB 09 OB OA OB OB OB OC OB OD OB OE OB OF OB 10 OB 11 OB 12 13 OB 15 OB 16 OB 17 Recorder OC 00 OC 01 OC 02 OC 03 OC 04 INP Aux 2 INP Aux 3 INP Aux 4 INP Aux 5 INP Aux 6 INP Aux 7 INP Set Grp 2 RELAY MASKS RLY Id gt A RLY Id gt B RLY Id gt C RLY Id gt gt A RLY Id gt gt B RLY Id gt gt C RLY Io HV RLY Io LVI RLY Io LV2 RLY AuxO RLY Aux RLY Aux2 RLY Aux3 RLY Aux4 RLY Aux5 RLY Aux6 RLY Aux7 RLY Tap Up RLY Tap Down RLY OF Alm RLY V f Trip RLY V f Alarm RECORDER REC Control REC Capture REC Post Trigger REC Logic trig KBCH EN M E11 CHAPTER 1 Page 35 76 Input to initiate tAUX2 Input to initiate tAUX3 Input to initiate tAUX4 Input to initiate tAUX5 Input to initiate tAUX6 Input to initiate tAUX7 Input to select setting group PWP Relay to be operated by A Phase low set trip Relay to be operated by B Phase low set trip Relay to be operated by C Phase low set trip Relay to be operated by A Phase high set trip Relay to be operated by B Phase high set trip Relay to be operated by C Phase high set trip Relay to close for REF trip HV winding Relay to close for REF trip LV winding Relay to close for REF trip Tertiary winding not KBCH1 20 Relay to be operated by AUX timer Relay to be operated by AUX 1 timer Relay to be operated by AUX 2 timer Relay to be operated by AUX 3 timer Relay to be operat
74. 1 CHAPTER 1 Page 71 76 000 RLY Trip Id gt Sa T 51 Id Reset d amp t100ms 5th Harmonic oD tOF E RLY Trip OF Alam 4 000 RLY Trip Id gt gt I Tip g d Reset Ld amp t100ms O00 i Sd RLY Trip lo gt HV S lo HV Reset d amp t100ms RLY Trip lo gt LV roD Set T g LV Reset ud amp t100ms a RLY Trip lo gt LV2 i lo LV2 Reset Ud amp H t100ms Inp Blk V f Trip i wir 90 Trip s7 VA OF Trip RLY Vif Trip f ES Reset Ld amp t100ms 9 gt Inp Blk V f Alarm H ev 00 5 Vif OFAlam I RLY Vif Alam 1 El Reset Lo amp
75. 1 1 1 Table 6 Note that the LCD display will only give a trip indication if the protection and control function is configured to operate either relay 3 terminals 42 and 44 or relay 7 terminals 41 and 43 If relays other than 3 or 7 are selected for a certain function then the display will not give an indication of a trip and the red trip LED will not be illuminated although the output relay contacts will still close It is advised in all cases that a continuity tester be used to monitor the output relay contacts and to ensure that the appropriate output relay has energised The display should only be used for visual indication of a trip condition Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 11 52 3 AUXILIARY SUPPLY TESTS Tests 3 1 3 2 and 3 3 have to be performed for each relay model 3 1 Auxiliary supply The relay can be operated from either an AC or a DC auxiliary supply but the incoming voltage must be within the operating range specified in Table 7 Check that the auxiliary supply voltage is within the range shown below and where applicable check that it is connected in the correct polarity Relay rating V DC operating AC operating Maximum crest range V range V voltage V DC AC 24 125 20 150 50 133 169 190 48 250 33 300 87 265 338 380 Table 7 CAUTION THE RELAY CAN WITHSTAND SOME AC RIPPLE ON A DC AUXILIARY SUPPLY HOWEVER
76. 1 software ICT s Further examples for applying zero sequence current filtering in KBCH are given in Appendix 2 KBCH EN M D11 Service Manual CHAPTER 2 Application Page 14 38 KBCH 120 130 140 Example 2 Transformer connection Dynlyn11 Dynlyn11 A LV 30 2 AMA 1 30 LV2 0 30 30 KBCH Relay Yd1 Software ICT YyO 0 Differential Yd11 Software ICT element 0 Software ICT Figure 8 Phase shift compensation and Zero sequence filtering on a three winding transformer The transformer connection shows that the first LV winding LV1 line current lags the HV line current by 30 lag 30 phase shift the phase displacement of the second LV winding with respect to the HV winding is 30 lead 30 phase shift To compensate for these phase shifts the HV phase compensation factor would be uncorrected select YyO on the relay menu the LV1 vector would then be shifted by 30 Select Yd11 on the relay menu and the LV2 vector would then be shifted by 30 Select Yd1 Phase shift on the relay menu Example 3 Transformer connection Dd10 Dd10 0 Se 60 60 KBCH Relay Yd11 Differential Yd1 Software ICT 30 element 130 Software ICT Figure 9 Phase shift compensation and Zero sequence filtering on a 410 transformer Where less common transformer connections are encountered a combination of
77. 130 140 Page 43 52 12 5 If bit 3 SYS Rem ChgGrp in the cell SYS Fn Links is set to O then the setting group can be changed by energising the opto input allocated in the INPUT MASKS menu heading in the cell INP Set Grp2 However if bit 3 is set to 1 then the setting group can only be changed using the communications channel either from the master station or a local p c equipped with suitable software To test the change of setting group initiate the change described above either by energising the relevant opto input or by a command over the communications channel The active setting group can be observed in the SYSTEM DATA column of the menu in the cell SYS Setting Grp This will display the current selected group The current setting group is stored with flags for each fault record If necessary some of the earlier setting tests can be repeated on setting group 2 to verify the settings in that group Remote control of transformer tap changer The tap changer can be instructed to raise or lower a tap via commands over the serial communications link or locally via the menu system Two cells in the RELAY MASKS menu heading TapUp and TapDown are provided for this purpose Each bit in these cells which is set to 1 corresponds to an output relay for this function On receiving the request to change the taps the appropriate relay is operated for a time given by the appropriate setting The times are found in the LOGIC FUNCTION
78. 2 1 7 2 2 7 2 3 7 2 4 7 2 5 7 3 7 4 8 1 8 1 1 8 1 2 8 2 Disturbance recorders Recorder control Recorder capture Recorder post trigger Recorder logic trigger Recorder relay trigger Notes on recorded times SELECTIVE LOGIC Biased differential trip logic Differential high set trip logic Restricted earth fault trip logic Overflux trip logic Auxiliary timers Change of setting group control Remote change of setting group Local control of setting group Manual tap changer control Trip test facility Trip and external alarm flag logic Trip and external alarm flag display format CONFIGURATION Basic configuration factory settings Initial factory applied settings Initial protection settings Initial control settings Initial time delay settings Initial allocation of opto isolated control inputs Initial allocation of output relays Configuring for application Selecting options TECHNICAL DATA Ratings Inputs Outputs Burdens KBCH EN M E11 CHAPTER 1 Page 3 76 39 39 39 40 40 40 40 41 41 41 42 43 44 44 45 46 47 48 48 48 48 49 50 51 51 51 51 52 52 52 52 52 53 54 54 54 54 54 KBCH EN M E1 1 CHAPTER 1 Page 4 76 8 2 1 Bias current circuit 8 2 2 REF current circuit 8 2 3 Voltage circuit 8 2 4 Auxiliary voltage 8 2 5 Opto isolated inputs 8 3 Setting ranges 8 3 1 Transformer configuration 8 3 2 Protection settings 8 3 3 Auxiliary timer
79. 3 REF LV1 side current sensitivity lo gt LV1 Setting Is Io LV1 Pick up Io LV1 Drop off 7 3 4 REF LV1 side operating Expected 20ms to 30ms Operating time 7 3 5 REF LV2 side current sensitivity lo gt LV2 Setting Is Io LV1 Drop off 7 3 6 REFLV2 side operating time Expected 20ms to 30ms Operating time Service Manual Commissioning Test Results KBCH 120 130 140 o Service Manual KBCH EN M C11 Commissioning CHAPTER 4 Test Results KBCH 120 130 140 Page 17 22 8 PHASE COMPENSATION Injected current A VECTOR GROUP SETTINGS DISPLAYED MEASURED VALUES HV Vector Cor LV1 Vector Cor Ia DIFF Ib DIFF Ic DIFF 9 LOW SET ELEMENT BIAS CHARACTERISTICS Setting Group 1 Tick Trip 20 12 No trip 20 12 Trip 80 12 No trip 80 12 Setting Group 2 if required Tick Trip 20 12 No trip 20 12 Trip 80 12 No trip 80 12 10 MAGNETISING INRUSH RESTRAINT Setting Group 1 Setting Group 2 if required injected A tick tick Switch S1 Closed S2 Open Low Set Differential Trip Switch S1 Open S2 Closed Low Set Differential No Trip KBCH EN M C1 1 CHAPTER 4 Page 18 22 11 OVERFLUX PROTECTION 11 1 Overflux alarm sensitivity Setting Gr
80. 4 5 2 5 Are You Sure YES NO 1 Press the 0 key if you decide not to enter password 2 Pressthe key if you want to modify the entry 3 Press the to enter the password The display will then show four stars and if the password was accepted the alarm LED will flash If the password is not accepted a further attempt can be made to enter it or the 0 key used to escape Password protection is reinstated when the alarm LED stops flashing fifteen minutes after the last key press or by selecting the PASSWORD cell and pressing the 0 key for more than one second Changing passwords After entering the current password and it is accepted as indicated by the alarm LED flashing the F key is pressed momentarily to move to the next menu cell If instead it is required to enter a new password the key must be pressed to select the setting mode A new password can be entered with the same procedure described in Section 5 2 1 Only capital upper case letters may be used for the password BE SURE TO MAKE A NOTE OF THE PASSWORD BEFORE ENTERING IT ACCESS WILL BE DENIED WITHOUT THE CORRECT PASSWORD Entering text Enter the setting mode as described in Section 5 2 and move the cursor with the F key to where the text is to be entered or changed Then using the and keys select the character to be displayed The F key may then be used to move the cursor to the position of the next character and s
81. 54 yz Case earth 2 e 49 54 83 184 27 M28 155 nitiate aux timer 5 15 e F re SCN C O See Note 4 vat p K Bus communications port u Me nitiate aux timer 6 16 See Note 4 SCN odule terminal blocks viewed from rear 53 n 7i nitiate aux timer 7 17 e e 55 V ET 48V field voltage Logic input common 2 4 e 4 ED 1 Notes VT input must be supplied with phase phase voltage Connections are typical only Figure 13 Typical external connections for KBCH140 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 51 52 KBCH 120 K LJ LJ LW UJ 82 83 zd Le 28 84i Notes E E See Service Manual R8530 for the setting of the external stabilising resistor 2 Optional voltage limiting non linear resistor see Service Manual R8530 Figure 14 Typical restricted earth fault connections for KBCH12 KBCH EN M C1 1 CHAPTER 3 Service Manual Commissioning Instructions Page 52 52 KBCH 120 130 140 Service Manual KBCH EN M C11 KBCH 120 130 140 CHAPTER 4 Commissioning Test Result KBCH EN M C11 Service Manual KBCH 120 130 140 Service Manual Commissioning Test Results KBCH 120 130 140 Transformer Differential Relay Relay Model Number
82. 5VA at rated current In 5A 0 24VA 1 excludes stabilising resistor Voltage circuit Vn 100 120V lt 0 002 VA at 110V Service Manual Technical Description KBCH 120 130 140 8 2 4 8 2 5 8 3 8 3 1 Auxiliary voltage Auxiliary Supply DC supply AC supply The burden depends upon the power supply rating the applied voltage the number KBCH EN M E11 CHAPTER 1 Page 55 76 Low Voltage Version High Voltage Version 4 8 12 0W 7 0 21 0VA 4 8 8 0W 6 7 12 0VA of inputs and outputs energised and the status of the backlight Opto isolated inputs DC supply 0 25W per input 50V 10k Setting ranges Transformer configuration External CT ratio HV CT ratio CT ratio 1 1 to 9999 LV2 CT ratio Transformer configuration The following list shows the options steps of 0 001 to 10 steps of 0 01 to 100 steps of 0 1 to 1000 steps of 1 to 9999 Setting No of Bias Configuration Applicable to Inputs HV LV 2 bias inputs KBCH120 130 140 LV HV LV1 LV2 3 bias inputs KBCH130 140 LV1 LV2 HV x2 LV 3 bias inputs Hv T KBCH130 140 LV HV LV x2 3 bias inputs ii KBCH130 140 LV HV x2 LV1 LV2 4 bias inputs d Only KBCH140 LV1 LV2 HV LV1 x2 LV2 A bias inputs jx Only KBCH140 Y LV2 HV x2 LV x2 4 bias inputs Only KBCH140 Note Not available on In 1A LV 5A versions of KBCH 140 CT ratio mismatch correction HV Rat
83. 6 08 06 09 06 0A 06 OB 06 OC 06 OD 06 OE 06 OF 06 10 S2 Configuration S2 HV CT Ratio S2 LV1 CT Ratio S2 LV2 CT Ratio S2 HV Ratio Cor S2 HV VectorCor S2 LV1 Ratio Cor 2 VectorCor S2 LV2 Ratio Cor S2 LV2 VectorCor S2 Id S2 Id gt gt S2 Io HV 2 Io LVI S2 Io LV2 1 Enable low set 1 Enable high set 1 Enable REF on HV winding 1 Enable REF on LV winding 1 Enable REF on Tertiary winding not KBCH120 1 Enable Overflux Trip 1 Enable Overflux Alarm 1 Enable Overflux Block See Note above PWP HV side CT Ratio PWP LV side CT Ratio PWP LV2 side CT ratio not KBCH120 PWP HV side CT correction ratio PWP HV Phase compensation PWP LV1 side CT correction ratio PWP LV1 Phase compensation PWP LV2 side CT correction ratio not KBCH120 PWP LV2 Phase compensation not KBCH120 PWP Low set setting High set setting REF setting HV winding REF setting LV winding REF setting Tertiary winding notKBCH120 KBCH EN M E1 1 Service Manual CHAPTER 1 Technical Description Page 34 76 KBCH 120 130 140 06 11 S2 Iof 5th harmonic Overflux setting 06 12 21 tOF 5th harmonic Overflux detector time delay 06 15 S2 V f Trip Char Overflux Trip Characteristic 06 16 S2 V f Trip Setting for Overflux Trip 06 17 S2 tV F Trip Time multiplier for Overflux Trip 06 19 S2 V f Alarm Setting for Overflux Alarm 06 1A S2 tV f Alarm Definite time settin
84. 60Hz is required then this must be set as follows Go to the SYSTEM DATA menu press F short until SYS FREQUENCY 50Hz appears on the LCD Press the key until the display shows SYS FREQUENCY 60Hz Then press F short once more followed by the key to confirm the change Relay operation This test will ensure that each output relay operates correctly and closes on command Go to the TEST CONTROL menu heading and step down until the Select Relays To Test cell is displayed Each bit in this cell corresponds to an output relay Bit is for relay O bit 1 for relay 1 and so on Select one relay at a time by setting the appropriate bit to 1 Then step down one to the Test Relays 0 cell The output relay will close for the duration that the 0 key is pressed plus the time set in the cell LOG tTest which is found under the menu heading LOGIC FUNCTIONS Operation of the relay can be monitored by indication from the relay contacts e g continuity meter Test each relay in turn as described above RELAY TERMINALS Relay O 30 32 Relay 1 34 36 Relay 2 38 40 Relay 3 42 44 Relay 4 29 31 Relay 5 33 35 Relay 6 37 39 Relay 7 41 43 Table 11 KBCH EN M C11 Service Manual 5 1 5 1 1 5 1 2 CHAPTER 3 Commissioning Instructions Page 14 52 KBCH 120 130 140 5 KBCH 120 The following tests are all applicable to the KBCH 120 model It is recommended that these tests are per
85. 7 67 67 67 67 68 68 68 68 68 KBCH EN M E1 1 CHAPTER 1 Page 6 76 10 3 4 Replacing the DSP board 10 3 5 Replacing the analogue input board 10 3 6 Replacing output relays and opto isolators 10 3 7 Replacing the power supply board 10 3 8 Replacing the back plate 10 4 Recalibration 11 LOGIC DIAGRAMS 12 CONNECTIONS DIAGRAMS Figure 2 1 Figure 2 2 Figure 2 3 Figure 2 4 Figure 2 5 Figure 2 6 Figure 2 7 Figure 3 1 Figure 3 2 Figure 3 3 Figure 3 4 Figure 4 1 Figure 5 1 Figure 6 1 Figure 6 2 Figure 6 3 Figure 6 4 Figure 6 5 Figure 6 6 Figure 6 7 Figure 6 8 Figure 6 9 Internal layout of relay Functional block diagram Measurements for mesh corner applications Differential low set characteristic Typical magnetising inrush current waveforms Typical overflux current waveforms Overflux tripping IDMT characteristic Connection to optical isolator control inputs DC shunt trip arrangement AC no volt trip arrangement Termination arrangement for communications Frontplate layout Menu system of relay Key to symbols used in logic diagrams Operation of input output masks Differential low set trip logic Differential high set trip logic REF trip logic Overflux trip amp alarm logic Auxiliary time delays Change setting group control logic Remote control of transformer tap changer Figure 6 10 Trip test facility Figure 6 11 Figure 11 1 Figure 12 1 Figure 12 2 Figure 12 3 F
86. 84 27 18 15 sel Initiate aux timer 5 L5 e j em RA SCN See Note 4 51 yak ee i 56 K Bus communications port Initiate aux timer L See Note 4 SCN Module terminal blocks viewed from rear 53 Y 7 Initiate aux timer 7 17 e f I ec 55 V EX 48 field voltage Logic input common 2 2 t N Notes 1 a e c CT shorting links make 2 VT input must be supplied with phase phase voltage before and c disconnect Connections are typical only b Short terminals break before 3 Earth connections are typical only 5 Long terminals 4 SCN Screen connection for K Bus d Pin terminal PCB type Figure 12 1 Typical external connections for KBCH120 Service Manual Technical Description KBCH 120 130 140 KBCH EN M E11 CHAPTER 1 Page 73 76 E EZ b 0 165 71 LZ 166 72 167 73 D c 2 Xx 68 4 75 KBCH 130 dE LV2 lo see Figure 12 4 6 21 77 ee eC 2 8 23 79 Gx 25 a LEE 3E A 26 82 127 83 HV lo gt see Figure 12 4 158 4 T 1 lo gt see Fig
87. Alarms The alarm status LED should first be checked to identify if any alarm conditions exist The alarm records can then be read to identify the nature of any alarm that may exist Measurement accuracy The values measured by the relay can be compared with known system values to check that they are in the approximate range that is expected If they are then the analogue digital conversion and calculations are being performed correctly Trip test A trip test can be performed remotely by using the options under the TEST CONTROL column in the menu Note These are password protected cells If a failure to trip occurs the relay status word can be viewed whilst the test is repeated to check that the output relay is being commanded to operate If it is not responding then an output relay allocated to a less essential function may be reallocated to the trip function to effect a temporary repair but a visit to site may be needed to effect a wiring change See Section 5 2 8 for how to set relay masks Local testing When testing locally similar tests may be carried out to check for correct functioning of the relay Alarms The alarm status LED should first be checked to identify if any alarm conditions exist The alarm records can then be read to identify the nature of any alarm that may exist Measurement accuracy The values measured by the relay can be checked against own values injected into the relay via the test block if fitt
88. CHAPTER 3 Commissioning Instructions Page 6 52 KBCH 120 130 140 1 2 1 3 WITH THE COVER REMOVED FROM THE CASE The key presses listed above still apply and in addition the and keys are accessible Current Display Key Press Effect of Action Column heading Moves to the previous heading Moves to the next column heading A settable cell or Puts the cell in the setting mode flashing cursor on bottom line of display if the cell is password protected the password must be entered first Setting mode Increments value Decrements value F Changes to the confirmation display If the function links relay or input masks are displayed then the F key will step through them from left to right Once the end is reached a further key press will change to the confirmation display 0 Escapes from the setting mode without the setting being changed Confirmation display Confirms setting and enters new value Returns prospective value of setting for checking and further modification Escapes from the setting mode without the setting being changed Table 2 Electrostatic discharge ESD The relays use components that are sensitive to electrostatic discharges The electronic circuits are well protected by the metal case and the internal module should not be withdrawn unnecessarily When handling the module outside its case care should
89. ER 4 2 Initi r2 Alarm gt TA 5 si nitiate aux timer 17 18 e e 75 76 45 46 Logic input common Trip e 77 SIGs 21 d oo E Initiate aux timer 3 Priel mw ma l o e 7 79 80 23 24 yl 9 Initiate aux timer 4 2 81 3 82 25 1626 19 MI Case earth C 83 sl 84 2738 5 561 Initiate aux timer 5 e SCN a See Note 4 K Bus communications port Initiate aux timer 6 Module terminal blocks viewed from rear Initiate aux timer 7 48V field voltage Logic input common Notes ms gt CT shorting links make 2 VT input must be supplied with phase phase voltage UC before and disconnect Connections are typical only b Short terminals break before c 3 Earth connections are typical only Long terminals 4 SCN Screen connection for K Bus d Pin terminal PCB type Figure 12 Typical external connections for KBCH130 KBCH EN M C1 1 CHAPTER 3 Page 50 52 Service Manual Commissioning Instructions KBCH 120 130 140 d ex 1 a b Short terminals break before 3 e Long terminals CT shorting links make 2 before b and disconn
90. F Trip which should be set to 1 This will ensure that only the overflux trip function is enabled The relay selected to operate for this protection function can be found under the RELAY MASKS heading in the cell RLY V f Trip Each bit in this cell which is set to 1 corresponds to an output relay for this function For a fuller description of the configuration of output relays see section 4 2 The timing for this function can be either definite time DT or inverse minimum definite time IDMT This will be found under the SETTINGS menu heading in the cell S1 V f Trip Char If this cell is set to DT then operation of the output relay should occur in T 10 Where T is the value in the cell S1 t V f Trip which is also found in the SETTINGS menu heading KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 38 52 KBCH 120 130 140 If the cell S1 V f Trip Char is set to IDMT then operation should occur in t 0 8 0 18 10 M 1 where K Time Multiplier found in cell S1 V f trip TMS in the SETTINGS menu and Vapplied V s setting This characteristic is plotted on the graph shown below Operating time as function of the actual excitation and the set starting value for different time multiplier settings time s 1000 i 100 A K 63 K 40
91. HV and LV software Interposing CT s could both be set to YyO since the required phase shift and zero sequence trap is provided by the line CT s Example 2 Transformer connection YNd1 with in zone earthing transformer YNd1 KBCH Relay Yd1 Differential YdyO Software ICT ne element 7579 Software ICT KBCH EN M D11 Service Manual APPENDIX B Page 2 2 KBCH 120 130 140 The phase compensation for the transformer is chosen to compensate for the 30 phase shift across the transformer Before setting the software interposing CT s the earthing arrangements and the requirements for zero sequence traps must be considered With the star point of the HV winding earthed there is a possibility that an external HV earth fault could cause relay maloperation as a corresponding zero sequence current would not flow in the LV CT s This matter can be dealt with by selecting a Yd1 HV software ICT which also provides the required phase correction With the LV earthing transformer connected within the zone of protection it is also possible for an external earth fault on the LV side of the transformer to cause the differential element to become unstable A zero sequence trap is therefore also required for the LV side of the transformer This can be arranged by selecting a YdyO LV software interposing current transformer to provide the required zero sequence trap without adding an
92. IN ALL CASES THE PEAK VALUE OF THE AUXILIARY SUPPLY MUST NOT EXCEED THE MAXIMUM CREST VOLTAGE DO NOT ENERGISE THE RELAY USING A BATTERY CHARGER WITH THE BATTERY DISCONNECTED 3 2 Energisation from auxiliary voltage supply For secondary injection testing using the test block type MMLG insert test plug MMLBO1 with CT shorting links fitted It may be necessary to link across the front of the test plug to restore the auxiliary supply to the relay Isolate the relay trip contacts and insert the module With the auxiliary disconnected from the relay use a continuity tester to monitor the state of the watchdog contacts as listed in table 8 Connect the auxiliary supply to the relay The relay should power up with the LCD showing the default display and the centre green led being illuminated this indicates that the relay is healthy The relay has a non volatile memory which remembers the state ON or OFF of the red led trip indicator when the relay was last powered and therefore the indicator may be illuminated With a continuity tester monitor the state of the watchdog contacts as listed in table 8 Terminals With relay not powered With relay powered 3 and 5 contact closed contact open 4 and contact open contact closed Table 8 3 3 Field voltage The relay generates a field voltage that should be used to energise the opto isolated inputs With the relay energised measure the field voltage across terminals 7 and 8
93. In HV 1A LV 5A versions of KBCH140 Notes on VectorCor setting Where Ia is the corrected current and IA is the uncorrected current Setting Action Phase Shift YyO Do nothing 0 Yd1 la IA IC 4 3 30 lag Ib IB 3 3 Ic IC 1B 4 3 Yd2 Ia IA IB 60 lag Ib IB IC Ic IC IA Yd3 la IB IC 43 90 lag Ib IC 43 Ic IA IB 4 3 Yd4 Ia IB 120 Ib IC Ic IA Yd5 Yd11 and Invert 150 lag Yy6 Invert currents 180 lag Yd7 Yd1 and Invert 150 lead Yd8 Yd2 and Invert 120 lead Service Manual Technical Description 5 1 5 11 1 KBCH 120 130 140 Page 33 76 Setting Action Phase Shift Yd9 Yd3 and Invert 90 lead Yd10 Yd4 and Invert 60 lead Yd11 Ia IA IB 3 30 lead Ib IB IC 4 3 Ic IC 43 YdyO Ia IA IA IB 1C 3 0 Zero sequence trap Ib IB IA IB IC 3 Ib IC IA IB 1C 3 Ydy6 YdyO and Invert 180 lag Zero sequence trap and invert Settings 2 06 00 SETTINGS 2 SET 06 01 S1 Fn Links Setting 1 function links PWP Link 1 S2 Enable Id Link 2 S2 Enable Id gt gt Link S2 Enable Io HV Link 4 S2 Enable Io LV1 Link 5 S2 Enable Io LV2 Link 7 52 Enable OF Trip Link 8 S2 Enable OF Alm Link 9 S2 Enable OF Blk 06 02 06 03 06 04 06 05 06 06 06 07 0
94. KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 46 52 KBCH 120 130 140 During this test it is necessary to measure the spill current in the relay circuit and short out the relay and stabilising resistor if fitted The current should be increased up to as near full load as possible and the current flowing through ammeter 1 noted If the connections are correct then this current should be very low only a few milliamps A high reading twice the injected current referred through the current transformer ratio indicates that one of the current transformer connections is reversed This test should be repeated for the B phase CT and neutral CT and then the C phase CT and neutral CT and every REF input that has a neutral CT connected to it Service Manual KBCH EN M C11 15 1 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 47 52 15 ON LOAD TEST There are some tests that may be carried out with the circuit on load provided that there are no operational restrictions in force that prohibit this Correct set up check The correct connection of CT s and the selection of phase and ratio correction factors are essential to the operation of the relay This test will check that the relay has been correctly configured with the settings and is correctly wired to the line CT s These tests should be performed at the transformer tap changer position that the settings calculations were made at If this
95. L2 439 t RL6 Ld Alarm 3 44 m 7 18 e 7 445 aol Logic input common 1 RIZ 957 Trip 17 48 Initiate aux timer 3 L3 3 3 21 22 e 45 1 2 c c 49 50 i 79 1680 23 104 cM Initia timer 4 14 7 Y i F 3 3 e te nitiate aux timer 813182 25 126 55 54 i v Case earth c e e 49 M 83 184 277 1 28 is 561 Initiate aux timer 5 15 5 7 TA e SCN See Note 4 boy 56 gt KBus communications port _ Initiate aux timer 6 L6 amp E See Note 4 SCN Module terminal blocks v viewed from rear 3 158 Ti Initiate aux timer 7 17 e s I c 55 V 8 48 field voltage Logic input common 2 Notes 1 CT shorting links make 2 VT input must be supplied with phase phase voltage UC before b and c disconnect Connections are typical only b Short terminals break before 3 Earth connections are typical only Long terminals 4 SCN Screen connection for K Bus d Pin terminal PCB type Figure 12 3 Typical external connections for KBCH140 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 75 76 See Note 1 KBCH 120 Notes 1 See Service Manual R8530 for the setting of the external stabilising resistor 2 Optional voltage limiting non linear resistor
96. NS 28 3 1 Use of auxiliary opto isolated inputs 28 3 2 Tap changer control 29 3 3 Generator Reactor Auto transformer protection 30 3 4 Generator transformers Unit transformers 30 KBCH EN M D11 Service Manual CHAPTER 2 Application Page 2 38 KBCH 120 130 140 3 5 K Series and MiCOM schemes 32 4 RECOMMENDED SETTINGS AND CT VT REQUIREMENTS 33 4 1 Recommended settings 33 4 2 CT connection requirements 34 4 3 C T Requirements 35 4 3 1 Minimum requirements 35 4 3 2 Requirements for the biased differential protection 35 4 4 Voltage transformer requirements 36 Figure 1 Typical Transformer Protection Package Figure 2 Typical protection package for a Generator transformer Figure 3 Fixed Bias Characteristic Showing setting range Figure 4 Application of a KBCH120 to a two winding transformer 11 Figure 5 13 Figure 6 Incorrect software ICT s 13 Figure 7 Correct software ICT s 13 Figure 8 Phase shift compensation and Zero sequence filtering on a three winding transformer 14 Figure 9 Phase shift compensation and Zero sequence filtering on a d10 transformer 14 Figure 10 Transformer magnetising characteristic 16 Figure 11 16 Figure 12 Inrush currents to a transformer star winding seen by differential elements after star delta phase correction or to a delta winding with no phase correction 17 Figure 15 High Impedance principle 20 Figure 16 Restricted earth fault operating characteristics 22 Figure 17 Restrict
97. R 4 Page 20 22 13 FUNCTION LINKS Relay final settings entered and checked Service Manual Commissioning Test Results KBCH 120 130 140 Setting Group 1 Setting Group 2 if required tick tick 14 REF PRIMARY INJECTION TEST Inject Into Inject Into Inject Int Inject Into Inject Into Inject Int Inject Into Inject Into Inject Int HV A Phase HV B Phase HV C Phase LV1 A Phase LV1 B Phase LV1 C Phase LV2 A Phase LV2 B Phase LV2 C Phase CT Ratio Primary Current Spill Current CT Ratio Primary Current Spill Current CT Ratio Primary Current Spill Current Service Manual Commissioning Test Results KBCH 120 130 140 15 ON LOAD TEST MS1 Ia Diff A MSI Ia Bias MS1 Ib Diff A MSI Ib Bias MS1 Ic Diff A MSI Ic Bias KBCH EN M C1 1 CHAPTER 4 Page 21 22 gt Commissioning Engineer Customer Witness Date Date KBCH EN M C1 1 CHAPTER 4 Service Manual Commissioning Test Results Page 22 22 KBCH 120 130 140 REPAIR FORM Please complete this form and return it to AREVA T amp D with the equipment to be repaired This form may also be used in the case of application queries AREVA T amp D St Leonards Works Stafford ST17 4LX England For After Sales Service Department Customer Ref Model No AREVA Contract Ref Serial No Date 1 What parameters were in use at
98. S menu in the cells LOG tTapUp and LOG tTapDown Go to the TEST CONTROL menu heading and step down to the cell TST Tap Control Set this to TapUp When the prompt Are You Sure t Yes No is displayed and the button is pressed the relay selected for the tap up operation will close for the duration set in the cell LOG tTapUp Verify this by configuring the relay so that it both starts and stops a timer The measured time should be in the range LOG tTapUp z 10 The TST Tap Control cell will then reset back to the default NoOperation Repeat this test for the tap down function by setting the cell TST Tap Control to Tap Down KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 44 52 KBCH 120 130 140 13 FUNCTION LINKS This check is to make sure that the function links are reset to the calculated application setting Go to cell S1 Fn Links in the SETTINGS 1 menu and ensure that it is set to the calculated application setting as recorded at the start of the commissioning test record If group 2 is required go to cell S2 Fn Links in the SETTINGS 2 menu and ensure that it is set to the calculated application setting In the SETTINGS 1 and SETTINGS 2 menus ensure that the phase compensation cells HV Vector Cor LV1 Vector Cor and LV2 Vector Cor are set back to the calculated application settings Note that LV2 Vector Cor will only appear on the KBCH130 and KBCH140 m
99. TER 3 Page 35 52 20 Characteristics 80 Characteristics In Id gt Trip No Trip Trip No Trip amps p u 12 12 12 12 amps amps amps amps amps amps amps amps 1 0 1 0 65 0 35 0 55 0 45 1 95 1 05 1 80 1 20 1 0 2 0 70 0 30 0 60 0 40 2 00 1 00 1 85 1 15 1 0 3 0 75 0 25 0 65 0 35 20 5 0 95 1 90 1 10 1 0 4 0 80 0 20 0 70 0 30 2 10 0 90 1 95 1 05 1 0 5 0 85 0 15 0 75 0 25 2 15 0 85 2 00 1 00 5 0 1 3 25 1 75 2 75 2 25 9 75 5 25 9 00 6 00 5 0 2 3 50 1 50 3 00 2 00 10 00 5 00 9 25 5 75 5 0 3 3 75 1 25 3 25 1 75 1025 475 9 75 5 25 5 0 5 4 25 0 75 3 75 1 25 10 75 4 25 10 00 5 0 Table 27 Note lt is important to ensure that the currents I1 and I2 when applied to the relay are in anti phase i e 180 out of phase KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 36 52 KBCH 120 130 140 10 MAGNETISING INRUSH RESTRAINT This test checks that the magnetising inrush restraint is functioning by simulating a typical magnetising inrush waveform by half wave rectifying an AC input signal In the SETTINGS menu go to cell 1 Fn Links and set all bits to except bit 1 S1 Enable Id which should be set to 1 This will ensure that only the low set protection function is enabled The relays selected to operate when the low set protection function operates on phase A will be found in the ce
100. Trip Io LV1 and Trip gt LV2 output masks respectively The t100ms timer ensures a minimum dwell time of 100ms Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 45 76 6 4 RLY Trip lo gt HV RLY Trip lo gt LV RLY Trip lo gt LV2 lo LV2 Figure 6 5 trip logic Overflux trip logic The overflux trip logic is shown in Figure 6 6 The overflux trip and alarm characteristics operate using the V f principle and are enabled by function links S7 and S8 respectively and the outputs directed to V f Trip and V f Alarm output masks respectively The algorithms can be individually blocked by energising the appropriate control input KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 46 76 KBCH 120 130 140 Inp Blk V f Trip V f OF Trip Inp Blk V f Alarm s8 Alarm Figure 6 6 Overflux trip amp alarm logic 6 5 Auxiliary timers Figure 6 7 shows eight auxiliary timers that may be initiated from external inputs assigned in the respective input masks and which after the set time delay operate the relays assigned in the relay masks These inputs could be used for either tripping or alarm purposes following operation of external protection for example a Buchholz relay or a Temperature relay In this way the operation of the Buchholz and or Temperature relay is
101. V1 winding B phase Current in LV1 winding C phase Current in LV2 winding A phase Current in LV2 winding B phase Current in LV2 winding C phase Current in Differential circuit A phase Current in Differential circuit B phase Current in Differential circuit C phase Current in Bias circuit A phase Service Manual Technical Description KBCH 120 130 140 KBCH EN M E1 1 CHAPTER 1 Page 31 76 Current in Bias circuit B phase Current in Bias circuit C phase System frequency 0211 MSI Ib Bias 0212 MSI Ic Bias 0213 MSIF 5 1 4 Settings 1 0500 SETTINGS 1 05 01 S1 Fn Links Link 1 S1 Enable Id Link 2 S1 Enable Id gt Link S1 Enable Io HV Link 4 S1 Enable Io LV1 Link 5 S1 Enable Io LV2 Link 7 S1 Enable OF Trip Link 8 51 Enable OF Alm Link 9 S1 Enable OF Blk 0502 51 Configuration 0503 SI HV CT Ratio 0504 S1 LV1 CT Ratio 0505 SILV2CT Ratio 0506 51 HV Ratio Cor 0507 51 HV VectorCor 0508 S1 LV1 Ratio Cor 0509 S1 LV1 VectorCor 050A S1 LV2 Ratio Cor 05 S1 LV2 VectorCor 050C Sl Id gt 050D Sl Id gt gt 050E S1 Io gt HV 050F 511 gt LVI 0510 51 Io gt LV2 0511 5110 0512 11 0515 SI V f Trip Char 0516 SI V f Trip 0517 S1 tV Trip 0518 S1 V f Trip TMS 0519 SI V f Alarm 051A 51 tV Alarm SS 3 a ua SET Setting 1 function links PWP 1 Enable low set 1 Enable high set 1 Enable REF on HV winding 1 Enable REF on LV winding 1
102. a full column of data and text Settings are more easily entered and the final settings can be saved as a file on a disk for future reference or for printing a permanent record The instructions are provided with the Courier access software Quick guide to local menu control With the cover in place only the F and 0 push buttons are accessible so data can only be read and flags reset No protection or configuration settings can be changed The table below lists the possible key presses and the relevant functions that they perform In the table F long indicates that the key is pressed for 1s and F short for less than 0 55 This allows the same key to perform more than one function WITH THE COVER FITTED TO THE CASE Current Display Key Press Effect of Action Default display or fault F short Changes display to first menu flags after a trip or column heading SYSTEM DATA F long O short Turns on backlight O long Resets the trip led if the fault flags are displayed and returns to the selected default display Column heading F short Displays the next item of data in the column O long Returns to the selected default display without waiting for the 2 minute delay Anywhere in the menu F short Turns on backlight F long Displays the heading for the next column O short Turns on backlight O long Resets a cell if it is resettable Table 1 KBCH EN M C11 Service Manual
103. ach analogue input is conditioned by a low pass anti aliasing filter before passing to a 16 bit analogue to digital converter via a 16 channel multiplexer Each channel is sampled at forty times per cycle synchronised to the power system frequency The digital data is passed to a digital signal processor DSP which performs the protection algorithms Calibration Calibration of each channel is performed in software there are no hardware adjustments in the relay Calibration consists of gain and phase adjustment to compensate for the hardware variations and the sequential sampling effect Both calibrations are done by adjusting the magnitude of each sample as they are read in to the DSP Phase calibration is not required for the REF and voltage channels as phase plays no part in these algorithms Current Transformer CT ratio and phase compensation Each of the bias current samples are further modified depending on the appropriate relay settings for CT ratio and phase compensation as described in section 5 1 4 Transformer configuration The transformer configuration setting is used to set unused channels to zero to ensure that they play no part in the algorithms It also affects the relay measurements and disturbance recorder functions as these display the current flowing into each of the transformer windings In cases where a single CT is used this is the same as the bias current but where two CTs are used the winding current is calculated b
104. aint to block the relay during inrush conditions may result in a significant slowing of the relay during heavy internal faults due to the presence of second harmonics as a result of saturation of the line current transformers To overcome this the relay uses a waveform recognition technique to detect the inrush condition The differential current waveform associated with magnetising inrush is characterised by a period of each cycle where its magnitude is very small as shown in Figure 2 5 By measuring the time of this period of low current an inrush condition can be identified The detection of inrush current in the differential current is used to inhibit that phase of the low set algorithm AO Bo f Figure 2 5 Typical magnetising inrush current waveforms Overflux blocking When a load is suddenly disconnected from a power transformer the voltage at the input terminals of the transformer may rise by 10 20 of rated value causing an appreciable increase in transformer steady state excitation current The resulting excitation current flows in one winding only and hence appears as differential current which may rise to a value high enough to operate the differential protection A typical current waveform is shown in figure 2 6 A waveform of this type is Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 13 76 2 3 4 2 4 2 5 characterised by the presence of fifth harmonic A fourier
105. ally developed to enable generic Master Station programs to access many different types of relay without continual modification to the Master Station program The relays form a distributed data base for the Master Station and may be polled for any information required This includes 1 Measured values 2 Menu text 3 Settings and setting limits 4 Fault records 5 Event records Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 17 76 6 Disturbance records 7 Status an eight bit word that identifies the trip and alarm state busy state also the presence of event and disturbance records for collection 2 14 1 Time tagged event records An event may be a change of state of a control input or an output relay it may be a setting that has been changed locally a protection or control function that has performed its intended function A total of 50 events may be stored in a buffer each with an associated time tag This time tag is the value of a timer counter that is incremented every 1 millisecond The event records can only be accessed via the serial communication port when the relay is connected to a suitable Master Station When the relay is not connected to a Master Station the event records can still be extracted within certain limitations the event records can only be read via the serial communication port and a K BUS IEC870 5 Interface Unit will be required to enable the serial port to be
106. an withstand a 10ms interruption in the auxiliary voltage with 2 inputs and 2 outputs energised at battery auxiliary voltages of not less than 48V High frequency disturbance IEC 255 22 1 1988 The relay complies with Class III 1MHz bursts decaying to 50 of peak value after to 6 cycles repetition rate 400 second i 2 5kV between independent circuits connected together and case earth ii 2 5kV between independent circuits 1 1kV between terminals of the same circuit except output contacts Fast transient IEC 255 22 4 1992 Class IV 4kV 2 5kHz applied directly to all inputs applied via a capacitive clamp to the K Bus port Electrostatic discharge IEC 255 22 2 1989 amp IEC 801 2 1991 Class III 8kV discharge in air with cover in place Class III 8kV discharge in air with cover removed Level 2 point contact discharge with cover removed Conducted emissions EN 55011 1991 Group 1 class A limits KBCH EN M E11 CHAPTER 1 Page 59 76 Frequency range MHz Limits of conducted Interference Quasi Peak dBuV Average dBuV 0 15 to 0 50 79 66 0 50 to 30 73 60 The lower limit shall apply at the transition frequency Radiated emissions EN 5501 1991 Alternatively EN 55022 1994 Group 1 Class A limits Frequency range MHz Limits of Radiated Interference Field Strength Quasi Peak dBuV m at 30m 30 to 230 30 230 to 1000 37 The lower limi
107. aneous element operates Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 29 52 gt gt In table 24 above Is Cor 7 2 4 7 3 7 3 1 Id is the high set setting which will be found in the cell gt gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios This is found in the cell HV Ratio Cor under the SETTINGS menu heading Inject 1 1xIs and ensure that the selected output relay operates FOR THE SECOND TEST IT IS IMPORTANT THAT THE CURRENT IS NOT APPLIED FOR LONGER THAN 1 SECOND Inject O 9xIs for 1 second and ensure that the relay does not operate Repeat the above two tests for the two remaining phases of the HV side of the transformer listed in table 21 High set element operating time This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the calculated application setting Connect the relay so that current can be injected through terminals 21 and 22 but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 3xIs into the A phase low set element terminals 21 amp 22 Check that the oper
108. ap extremities with mid tap correction Ibias IRHV IRLV 2 Where IR current to the relay after ratio compensation has been applied Determine relay operating current Is 0 2 Ibias Ibias lt In Check Idiff Iop by a 10 margin for each tap extremity and adjust Is as necessary Calculate HV full load current at mid tap volts and LV full load current 30 60MVA ONAN OFAF 132kV 33kV 10 20 300 1 1200 1 4 1050A FLC o 30 0 92Amps mid tap 0 875 Amps KBCH120 1 003 Y Differential YdyO Software ICT element Software ICT 30 30 19 Tap positions 18 Tap increments 1 10 Tap 19 20 10 209 Tap increment 0 18 0 1 67 100 10 20 2 Mid Tap range 132kV 95 of 132kV 125 4kV 100 Tap No 10 KBCH EN M D11 Service Manual APPENDIX Page 2 4 KBCH 120 130 140 60 x 103 HV FLC on 10 TANE 276A Primary 276 x 1 300A Secondary 0 92A secondary 60 x 103 LV FLC 1 i V FLC 33 x 3 050A Primary 1050 x 1 1200A Secondary 0 875A secondary Adjust ratio compensation for In to relay on both sides at mid tap Required HV ratio compensation factor 1 0 0 92 1 087 select 1 09 Required LV ratio compensation factor 1 0 0 875 1 142 select 1 15 1 14 could be selected for the LV compensation factor but 1 15 gives the lowest spill current Calcul
109. as shown below O OVERCURRENT Figure 2 LV1 and LV2 windings measurement check Go to the SETTINGS menu and set all the bits in the cell S1 Fn Links to O This disables all the protection elements so that the relay will not trip Then go to the MEASUREMENTS menu and step down one until the cell MS1 IaHV is displayed Inject rated current and ensure that the displayed value lies within 10 of the values listed in table 16 By pressing F short step down until the cell MS1 Ic Bias is reached checking each time that the displayed value lies in this range KBCH EN M C1 1 Service Manual CHAPTER 3 Commissioning Instructions Page 20 52 KBCH 120 130 140 CONFIGURATION CURRENT HV LV HV LV1 LV2 HV X2 LV HV LV X2 HV Phase Iinj Iinj 2x Iinj Iinj LV1 Phase Iinj Iinj Iinj 2x Iinj LV2 Phase 0 Iinj 0 0 Differential 2x Iinj Iinj Iinj Iinj Iinj 3 2x Iinj 3 2x Iinj 3 2x Iinj Table 16 6 1 2 Frequency measurement check Inject a current of known frequency to terminals 21 and 22 of the relay The frequency must be in the range 15 to 65 Hz In the MEASUREMENTS menu step down until the cell MS1F is displayed Check that the displayed value lies in the range Injected frequency 296 6 2 Differential Protection The relay should be commissioned with the settings calculated for the application 6 2 1 Low set element current sensitivity I
110. as well as LO and L1 of relay 2 L2 is not used on either relay and has no connections made to it Common line Figure 3 1 Connection to optical isolator control inputs Analogue inputs The relays can have up to sixteen analogue inputs depending on the model Each is fed via an input transducer and low pass filter to a multiplexer and analogue to digital converter The analogue signals are sampled forty times per cycle on each channel as the sampling rate tracks the frequency of the input signal Output relays There are four programmable output relays on the microprocessor board and four on the DSP board These relays each have two make contacts connected in series to increase their rating The protection and control functions to which these relays respond are selectable via the menu system of the relay It is normal practice to allocate RLY3 and RLY7 as trip relays as these relays also control the flagging see section 6 9 In addition there is a watchdog relay which has one make and one break contact Thus it can indicate both healthy and failed conditions As these contacts are mainly used for alarm purposes single contacts are used and their rating is therefore not quite as high as that of the programmable outputs The terminal numbers for the output relay contacts are given in the table at the start of Section 3 KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 22 76 KBCH 120 130 140 3 5 Altern
111. ate HV full load current at both extremities 60 x 10 HV Full load current on tap 1 10 132x148 293A Primary 239 x 1 300 Amp secondary 0 7974 secondary 1 09 x 0 797 0 869 Amps 60 x 103 132x0 8 43 HV corrected current on tap 1 HV Full load current on tap 19 20 328A Primary 328 x 1 300 Amp secondary 1 093A secondary HV corrected current on tap 19 1 09 x 1 093 1 191 Amps Determine Idiff at both extremities with mid tap correction LV corrected current 0 875 x 1 15 1 06 Amps Idiff at tap 1 1 006 0 869 0 137A Idiff at tap 19 1 191 1 006 0 185A Determine Ibias at both extremities with mid tap correction Ibias IRHv 2 Bias current on tap 1 0 869 1 006 2 0 9375 Amps Bias current on tap 19 1 191 1 006 2 1 0985 Amps Determine relay operating current Iop Operating current at tap 1 with Ibias 0 9375A Is 0 2 Is O 2Ibias 0 2 0 2 x 0 9375 0 3875A Operating current at tap 19 with Ibias 1 0985A Is 0 2 Service Manual KBCH EN M D11 APPENDIX C KBCH 120 130 140 Page 3 4 I 0 2 Ibias 1 0 x 0 8 0 2 0 2 1 0985 1 0 x 0 8 0 4788A Check Idiff Iop by a 10 margin for each tap extremity and adjust Is as necessary Tap 1 Since Idiff 0 137A and 0 9Iop at tap 1 0 9 x 0 3875 0 349A Therefore there is sufficient security with 15 0 2 Tap 19 Since Idif 0 185A and 0 9Iop at tap 1 0 9 0 4788
112. ated to the ratio of the CT kneepoint voltage Vk to relay circuit impedance The relay element current setting Is will control its susceptibility to given levels of spill current let through the relay circuit impedance Rs Since the relay circuit impedance and relay current setting are factors which determine the stability voltage setting Vs it is the ratio Vk Vs which will govern the stability of the restricted earth fault protection for through faults This ratio has an influence on the required K factor for stability The relationship between the ratio Vk Vs and the required stability factor has been found to be of a general form for various relay designs that have undergone conjunctive testing by AREVA It is the absolute values of Vk Vs and K that vary in the relationship for different relay designs Graph 1 displays the relationship that has been found for KBCH restricted earth fault protection by conjunctive testing For a selected Vk Vs ratio Figure 16 can be used to determine the required factor K so that the stability voltage setting Vs can be calculated Some application complication arises due to the fact that Vs is derived by knowing the required factor K and that the required factor is dependent on Vs through the ratio VK Vs An iterative approach is required if the optimum factor K is to be identified for a particular application figure 17 The approach with older electromechanical restricted earth fault relays was
113. ating time for the relay is within the range 10ms to 20ms Repeat this test for both of the remaining phases on the HV side as listed in table 23 Restricted Earth Fault Protection There are three restricted earth fault elements for this relay model one on the high voltage side of the transformer and two on the low voltage side of the transformer REF current sensitivity HV side gt HV In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 3 S1 Enable Io HV which should be set to 1 This will ensure that only the REF protection on the high voltage side of the transformer is enabled The relays selected for the REF protection on the HV side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io HV Each bit in this cell which is set to 1corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 27 amp 28 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 25 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instruction
114. ative trip arrangements 3 5 1 3 5 2 Normal practice is to use a separate trip contact for each of the circuit breakers associated with the transformer DC shunt trip An auxiliary supply is required to trip the circuit breakers This will normally be a dc supply which is generally considered to be more secure than an ac supply It would be usual to use a shunt trip coil for dc energised trip circuits as shown in Figure 3 2 The trip circuit current will normally be broken by an auxiliary contact on the circuit breaker once the circuit breaker has opened If this is not the case then a trip relay with heavy duty contacts must be interposed between the relay trip contact and the trip coil Relay Figure 3 2 DC shunt trip arrangement AC no volt trip For ac tripping it may be considered safer to opt for an no volt trip release Tripping from a make contact on the relay is still possible by using the circuit shown in Figure 3 3 This arrangement will also trip the circuit breaker when the auxiliary trip supply is lost If the circuit breaker is fitted with a line VT then this may be used to provide the trip supply for the circuit breaker and the circuit breaker will then be tripped when the protected circuit is de energised The capacitor is included to reduce the release time and would tune the coil to the power frequency The series resistor would then limit the current in the coil to its rated value
115. back plane to the metalwork Unplug the back plane from the power supply pcb Withdraw the power supply board from the rear unplugging it from the front bus Reassemble in the reverse of this sequence Replacing the back plate Remove the two screws securing the centre terminal block to the top plate of the module Remove the two screws securing the centre terminal block to the bottom plate of the module Remove the two screws securing the back plane to the metalwork Unplug the back plane from the power supply pcb Twist outwards and around to the side of the module KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 70 76 KBCH 120 130 140 Replace the pcb and terminal block assembly Reassemble in the reverse of this sequence 10 4 Recalibration Whilst recalibration is not usually necessary it is possible to carry it out on site but it requires test equipment with suitable accuracy and a special calibration program to run on a PC This work is not within the capabilities of most engineers and it is recommended that the work is carried out by an authorised agency After calibration the relay will need to have all the settings required for the application re entered and so it is useful if a copy of the settings is available on a floppy disk Although this is not essential it can reduce the down time of the system Service Manual Technical Description KBCH 120 130 140 11 LOGIC DIAGRAMS KBCH EN M E1
116. be taken to avoid contact with components and electrical connections f removed from the case for storage the module should be placed in an electrically conducting anti static bag There are no user serviceable parts within the module and it is advised that it is not unnecessarily disassembled Touching the printed circuit boards should be avoided since complementary metal oxide semiconductors CMOS are used which can be damaged by static electricity discharged from the body Equipment required 1l Continuity tester multimeter 2 Overcurrent test set CFBA with time interval meter 3 Multifinger test plug type MMLBO1 for use with test block type MMLGO1 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 7 52 1 4 4 Two Variacs 2 variable resistors 0 150Q of as high a current rating as possible Timer if not available on the overcurrent test set Two pole switch Two 2 5A diodes Two multimeters 10 Frequency counter 11 Test plugs multi finger and single finger 12 Primary Injection Test Kit The following equipment would be useful but is not essential to commissioning 1 Programmable synchronised variable frequency current source capable of producing up to 5596 5th harmonic superimposed on the fundamental and also two currents in anti phase 180 out of phase 2 Portable PC with suitable software and a KITZ101 102 K bus IEC870 5 interface
117. both the cells S1 HV Vector Cor and S1 LV1 Vector Cor should be set to YyO as the rest of the commissioning checks are performed at this default setting Service Manual Commissioning Instructions KBCH 120 130 140 KBCHNEN M C1 1 CHAPTER 3 Page 33 52 HV VectorCor LV1 VectorCor Displayed Measured Values Ia DIFF Ib DIFF Ic DIFF YyO 2xlini 0 0 Yd Yd7 2xlin4J3 2xinjA3 0 Yd2 Yd8 2xlinj 0 2xlinj Yd3 Yd9 0 2xinj 3 2xlini 3 Yd4 Yd10 0 0 2xlinj Yd5 Yd11 2xinjd3 0 2xlini A 3 Yd6 YyO 2xlini 0 0 Yd7 Yd 2xlin 43 2xinj J3 0 Yd8 Yd2 2xlinj 0 2xlinj Yd9 Yd3 0 2xinj 3 2xlini J3 Yd10 Yd4 0 0 2xlinj Yd11 Yd5 2xinjd3 0 2xlini A 3 YdyO Ydy 4 3xlnj 2 3xlini 2 3xlini Ydy YdyO 4 3xlinj 2 3xlini 2 3xlini Table 26 KBCH EN 1 Service Manual CHAPTER 3 Commissioning Instructions Page 34 52 KBCH 120 130 140 9 LOW SET ELEMENT BIAS CHARACTERISTIC This test checks the low set element bias characteristic The relay has a dual slope bias characteristic therefore this test is performed at two points on the bias curve one at 20 slope and the other at 80 slope corresponding with bias currents of 0 5 p u and 1 5 p u respectively In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 1 S1 Enable Id which should be set to one This will ensure that only the low set protection function is enabled Th
118. can be described Other transformer ancillary protection or alarm devices e g winding oil temperature low oil level pressure relief valves etc may be connected in a similar fashion to provide event record data All ancillary trip paths should be independent of the KBCH as described for Buchholz protection Tap changer control The KBCH offers the possibility of remote manual tap changer control via K bus communication Remote commands act on KBCH scheme logic timers which can be set KBCH EN M D11 Service Manual CHAPTER 2 Application Page 30 38 KBCH 120 130 140 3 3 3 4 up to operate any of the output relays as illustrated in Fig 21 This remote control facility may be of interest for tapping parallel transformers apart to reduce reactive load current prior to switching out a transformer This practice is often adopted to minimise step changes in consumer supply voltage when switching out a transformer TapUp RLY Tap Down Figure 21 Tap changer controls Generator Reactor Auto transformer protection As with any biased differential relay the KBCH can be applied as differential protection for any item of plant which has some internal impedance Auto transformers can be adequately protected by a high impedance relay circulating current scheme but where a delta tertiary winding is present protection of this winding will not be provided by such a scheme Application of a biased differential relay in the
119. ce relays Where a delta tertiary winding is present the tertiary winding will not be protected by the high impedance protection for the main windings Protection of all windings can be offered by a biased differential relay such as the KBCH this is further discussed in section 3 3 KBCH EN M D11 Service Manual CHAPTER 2 Application Page 6 38 KBCH 120 130 140 1 2 KBCH Protection relay 1 2 1 The KBCH relay has been designed to bring the latest digital technology to the protection of power transformers The increased functionality of digital relays allows an enhanced protection package to be offered for a wide variety of applications which when combined with a host of non protective features can contribute to system information gathering requirements Protection Features The protection features offered by the KBCH are listed below Biased differential protection Restricted earth fault protection for individual transformer windings Overfluxing protection Instantaneous high set operation Magnetising inrush restraint 5th Harmonic Overfluxing blocking 8 opto isolated inputs for alarm trip indication of external devices The biased differential element has a dual slope bias characteristic to ensure sensitivity with load current to internal faults and stability under heavy through fault conditions The differential element is blocked for magnetising inrush conditions by utilising the waveform gap detection
120. ce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 15 In this case Is corresponds to the LV1 side earth fault element setting and is found in the cell Io LV1 under the SETTINGS menu heading REF element LV1 side operating time Connect the relay as in section 5 3 3 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5 x Is into the relay and check that the operating time for the relay is within the range 20ms to 30ms Service Manual KBCH EN M C11 6 1 6 1 1 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 19 52 6 130 The following tests are all applicable to the KBCH 130 model It is recommended that these tests are performed with the phase compensation factors HV VectorCor LV1 VectorCor and LV2 VectorCor set toYyO Measurement checks To test the relay measurement functions a current of known value should be injected into each phase input With the CT ratios in the cells HV CT Ratio LV1 CT Ratio and LV2 CT Ratio in the SETTINGS menu set to the values of the line CT s the displayed measured values will be in the equivalent primary quantities HV LV1 LV2 winding measurement checks Connect the CT inputs to the relay
121. connected to an IBM or compatible PC Suitable software will be required to run on the PC so that the records can be extracted when the event buffer becomes full the oldest record is overwritten by the next event records are deleted when the auxiliary supply to the relay is removed to ensure that the buffer does not contain invalid data the time tag will be valid for 49 days assuming that the auxiliary supply has not been lost within that time However there may be an error of 4 3s in every 24 hour period due to the accuracy limits of the crystal This is not a problem when a Master Station is on line as the relays will usually be polled once every second or so Events that are recorded include 1 change in state of logic inputs 2 change in state of relay outputs 3 change to settings made locally 4 fault records as defined in the FAULT RECORDS column of the menu 5 alarm messages Items 1 and 2 may be deleted from the events so that up to 50 fault records may be stored 2 14 2 Disturbance records The internal disturbance recorder has sixteen analogue channels plus one to record the status of the eight control inputs and one to record the status of the eight relay outputs The analogue channels record up to nine phase currents three per winding the three differential currents the three calculated through bias currents and the voltage channel In the case of mesh corner where two current transformers are used
122. could be applied with some study of the particular problem To ensure tripping for persistent overfluxing due to high system voltage or low system frequency the KBCH is provided with time delayed Volts per Hertz protection Where there is any risk of persistent geomagnetic overfluxing with normal system voltage and frequency the 5th harmonic differential current facility could be used to initiate tripping atter a long time delay Time delayed Overfluxing protection Two independently adjustable V f elements are available for overfluxing protection A definite time element with a time setting range of 0 1 60 seconds is provided for use as an alarm element The settings of this element should be such that the alarm signal can be used to prompt automatic or manual corrective action Protection against damage due to prolonged overfluxing is offered by a V f protection element with an inverse time IDMT tripping characteristic The setting flexibility of this element by adjustment of the time multiplier setting see figure 18 makes it suitable for various applications The manufacturer of the transformer or generator should be able to supply information about the short time over excitation capabilities which can be used to determine appropriate settings for the V f tripping element The IDMT overfluxing protection would be used to trip the transformer directly If preferred the V f tripping element can be set with a definite time characteri
123. current Using the MEASUREMENTS menu the resultant differential current can be noted and compared with the values listed in table 26 below Note It is important in this case that the injected currents are in anti phase i e 180 out of phase This is achieved by having two current sources that are in phase and swapping the inputs into terminals 77 and 78 as shown below Figure 5 Phase Compensation Test Connect the relay as shown in figure 5 above Go to the SETTINGS menu and set both cells ST HV VectorCor and S1 LV1 VectorCor to the same phase compensation setting Inject rated current ensuring that the currents injected are effectively 180 out of phase Go to the MEASUREMENTS menu and ensure that there are no measured values of differential current The differential current measurements are found in the cells Ia Diff Ib Diff and Ic Diff Then go to the SETTINGS menu and change the cell 51 LV1 VectorCor to the corresponding opposite setting listed in table 26 Go to the MEASUREMENTS menu and check that this time there are displayed values of differential current and that the values correspond with those listed in table 26 where Iinj is the value of injected current It is not necessary to perform checks on all the possible combinations of settings but it is recommended that the tests should be carried out with those settings that are to be used in the relay application Once the checks are complete
124. d In the SETTINGS menu go to cell S1 Fn Links and set all bits to O except bit 1 S1 Enable Id which should be set to 1 This will ensure that only the low set protection function is enabled The operation of the relay can be monitored as described in section 4 3 Relay operation The relays selected for the low set differential protection function can be found under the RELAY MASKS heading The phase A relay will be found in the cell RLY Id gt A phase B relay in cell RLY Id gt B and phase C in RLY Id C Each bit in these cells which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation on the configuration of the output relays Connect the equipment so that current can be injected through terminals 21 and 22 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off are within the range shown in Table 17 1 1 Id gt In table 17 overleaf Is Ratio Cor Ratio Cor Id is the low set setting which will be found in the cell Id gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios There is one ratio correction factor for the HV side which is found in the cell HV Ratio Cor o
125. d by selection of a software delta tertiary winding d as indicated in table 2 In some applications the line current transformers are connected in Delta to provide the required phase compensation and a zero sequence trap If this is the case and if the phase correction is correct both the HV and LV phase compensation factors on the KBCH can be set to give a O phase shift i e YyO setting on the relay Magnetising inrush The magnetising inrush phenomenon is associated with a transformer winding which is being energised where no balancing current is present in the other winding s This current appears as a large operating signal for the differential protection Special measures are taken with the relay design to ensure that no maloperation occurs during inrush The wave form gap detection method which has been successfully implemented within the MBCH transformer differential relay and which has gained many relay years of service experience is the basis for KBCH inrush restraint KBCH EN M D11 Service Manual CHAPTER 2 Application Page 16 38 KBCH 120 130 140 Flux Magnetising current le Figure 10 Transformer magnetising characteristic Figure 10 portrays a transformer magnetising characteristic To minimise material costs weight and size transformers are generally operated near to the knee point of the magnetising characteristic Consequently only a small increase in core flux above normal operating levels wil
126. d during each cycle when relatively little current flows By measuring the duration of the low current periods in any cycle quarter of a cycle minimum the relay is able to determine whether the differential current is due to magnetising inrush or due to a genvine fault Low set differential element operation is inhibited only with inrush current This wave form gap measuring technique ensures that operating times remain unaffected even during periods of significant line CT saturation High set operation The KBCH relay incorporates an independent differentia high set element to complement the protection provided by the biased differential low set element The instantaneous high set offers faster clearance for heavy internal faults and it is not blocked for magnetising inrush or transient overfluxing conditions The high set element is a peak measuring device and is not subject to the inherent time delay required for magnetising inrush detection and the delay produced by the fourier filter Stability is provided for heavy external faults but the operating threshold of the high set differential element must be set to avoid operation with inrush current As described in section 2 1 4 when a transformer is energised a high magnetising inrush current is drawn The magnitude and duration of this inrush current is dependant upon several factors which include Size and impedance of the transformer Point on wave of switching Remnant flux
127. d very simple once the basic concept is understood 7 1 Basic configuration factory settings The basic configuration contains the factory settings and calibration data It is not generally accessible because any incorrect changes would affect the accuracy and performance of the relay Any detected change to the basic configuration will cause the protection to stop and give an alarm since incorrect operation could follow 7 2 Initial factory applied settings 7 2 1 Initial protection settings As received the relay will be configured with all protection elements enabled The second setting group will be inhibited and its settings will not appear in the menu The settings for both setting groups will be set the same as follows Fn Links 0110111110 Configuration HV LV1 LV2 HV LV on KBCH1 20 HV CT ratio 1 1 LV1 CT ratio 1 1 LV2 CT ratio 1 1 HV Ratio Cor 1 0 HV VectorCor YyO deg LV1 Ratio Cor 1 0 LV VectorCor YyO 0 deg LV2 Ratio Cor 1 0 LV2 VectorCor YyO 0 deg Id 0 2PU Id gt gt Io HV 0 1PU Io LVI 0 1PU Io gt LV2 0 1PU lof 50 tOF 10s V f Trip Char IDMT V f Trip 2 42 V Hz V f Trip TMS V f Alarm 2 31 V Hz 1V f Alarm 10s KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 52 76 KBCH 120 130 140 7 2 2 Initial control settings SYS Fn Links 10001011 Automatic reset of the flags and change of setting group will be inhibited and must be selected via the SD links if
128. disable the low set element by setting bit 1 S1 Enable Id gt to Ensure that all the other bits are set to The relays selected to operate for the Id gt gt trip can be found under the RELAY MASKS heading The phase A relay will be found in the cell RLY Id gt gt A phase relay in cell RLY Id gt gt B and phase C in RLY Id gt gt C Each bit in these cells which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation of the configuration of the output relays Operation of the relays can be monitored as described in section 4 3 The relay should be connected so that current can be injected through terminals 21 amp 22 In addition the output relays should be connected to trip the test set and to stop a timer IT IS IMPORTANT TO TRIP THE TEST SET IN ORDER TO AVOID SUSTAINED APPLICATION OF EXCESSIVE CURRENTS The timer should be started when the current is applied to the relay As the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied Two tests have to be performed for his particular protection function These are listed in table 24 Id Trip Id gt gt No Trip 1 1 Is 0 9x Is Table 24 The first test to be performed is at the higher current level to check that the instant
129. during transient over fluxing conditions on a per phase basis Ratio correction To ensure correct operation of the differential element it is important that under load and through fault conditions the currents into the differential element of the relay balance In many cases the HV and LV current transformer primary ratings will not exactly match the transformer winding rated currents Ratio correction factors are therefore provided The CT ratio correction factors are applied to ensure that the signals to the differential algorithm are correct A ratio correction factor is provided which is adjustable from 0 05 to 2 0 in steps of 0 01 for each set of CT inputs This range should be adequate for virtually all applications To provide instrumentation in primary quantities the main current transformer ratios can be entered in the locations HV CT ratio LV1 CT ratio and LV2 CT ratio in the settings column The appropriate number of CT ratios will appear dependent upon the number of in service biased inputs selected Alternatively the CT ratio can be set to 1 1 so that all currents shown on the relay menu will appear as secondary values To minimise unbalance due to tap changer operation current inputs to the differential element should be matched for the mid tap position The CT ratio correction factors are found in the settings column of the KBCH menv Their use is best illustrated with an example Service Manual KBCH EN M D11 A
130. e operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 75 amp 76 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 25 REF element LV2 side operating time Connect the relay as in section 7 3 5 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 32 52 KBCH 120 130 140 8 PHASE COMPENSATION This test will verify that the relays internal phase compensation is functioning correctly In this test current is injected through the A phase HV and LV1 windings The phase compensation for both these windings should be set to the same value which will result no differential current if the magnitudes of the injected currents are equal The differential currents can be monitored using the MEASUREMENTS menu One of the phase compensation factors on one of the windings is then changed which should result in differential
131. e 13 Restricted Earth Fault Protection There are two restricted earth fault elements for this relay model one on the high voltage side of the transformer and one on the low voltage side of the transformer REF current sensitivity HV side gt HV In the SETTINGS 1 menu go to cell S1 Fn Links and set all the bits to O except bit 3 S1 Enable Io HV which should be set to 1 This will ensure that only the REF protection on the high voltage side of the transformer is enabled The relays selected for the REF protection on the HV side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io HV Each bit in this cell which is set to 1 corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 27 amp 28 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 15 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 18 52 KBCH 120 130 140 Current Level Pick up 0 9 x Is to 1 1 xIs Drop off 0 9 x Pick up to 1 0 x Pick up Table 15 5 3 2 9 3
132. e Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 13 38 Example 1 Transformer connection Ynd1 Ynd1 0 30 KBCH Relay Yd1 Differential YyO Software ICT 30 element 30 Software ICT Figure 5 The transformer connection shows that the delta connected low voltage line current lags the high voltage line current by 30 30 phase shift To ensure that this phase shift does not create a differential current the same phase shift must be introduced in the secondary circuit The HV software interposing CT is effectively a winding replica of the main power transformer It not only provides a 30 phase shift but also performs the necessary function of filtering out any HV zero sequence current component The KBCH has internal zero sequence traps which are selected by the correct selection of software interposing CT s ICT s see table 2 Dyn1 Figure 6 Incorrect software ICT s Figure 7 Correct software ICT s Figure 6 shows an application of the KBCH where the required phase shift has been provided by selecting a Yd software interposing current transformer on the HV side Although phase correction is provided instability would exist for an LV earth fault as no LV zero sequence filtering is present Figure 7 shows the correct application of the software ICT s where the required phase shift and zero sequence compensation is provided by the selection of Yd1
133. e automatic address allocation feature and 255 is reserved for global messages The factory set address is 255 000 SYS Plant Status READ The plant status is not used in these relays 0000 SYS Control Status READ The control status is not used in these relays OOOE SY Setting Group READ Where a relay has alternative groups of settings which can be selected then this cell indicates the current group being used by the relay For these relays it is either Group 1 or Group 2 0011 SYS S W Ref 1 READ The version of software for the microprocessor is coded into this number It cannot be changed 0012 SYS S W Ref 2 READ The version of software for the DSP is coded into this number It cannot be changed 0020 SYS Logic Stat Current state of opto isolated logic control inputs Note this function is repeated in cell 0001 0021 SYS Relay Stat Current state of relay outputs Note this function is repeated in cell ODO2 0022 SYS Alarms Current state of alarm flags see Section 5 2 11 KBCH EN M E1 1 CHAPTER 1 Page 30 76 5 1 2 Fault records 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 00 01 02 03 05 06 07 09 OA OB OD OE OF 10 11 12 13 14 15 16 17 18 19 FAULT RECORDS FLT Ia HV FLT Ib HV FLT Ic HV FLT Ia LV FLT Ib LV1 FLT Ic LV1 FLT Ia LV2 FLT Ib LV2 FLT Ic LV2 FLT Ia Diff FLT Ib Diff FLT Ic Diff FLT Ia Bias FLT Ib Bias FLT Ic B
134. e fault records Event records are however generated KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 50 76 KBCH 120 130 140 6 10 Trip and external alarm flag display format Trip display External alarm displays Fn OxA B C F External alarms AUXO 123456710123 AUXO1234567 FEDCBA9876543210 FEDCBA9876543210 Fnow Current state of flags not latched Fn Flags for last fault Fn 1 Flags for previous fault Fn 2 Flags for previous fault Fn 3 Flags for previous fault Fn 4 Flags for previous fault Gx x Setting group number Differential Trip on A Phase A High Set Trip on A Phase AT Differential High Set Trip on A Phase F Overflux Trip AUX 0 Auxiliary O AUX 1 Auxiliary 1 AUX 2 Auxiliary 2 AUX 3 Auxiliary 3 AUX 4 Auxiliary 4 AUX 5 Auxiliary 5 AUX 6 Auxiliary 6 AUX 7 Auxiliary 7 Io 1 REF Trip HV Winding Jo 2 REF Trip LV Winding Io 3 REF Trip Tertiary Winding LV2 KBCH EN M E11 CHAPTER 1 Page 51 76 Service Manual Technical Description KBCH 120 130 140 7 CONFIGURATION Configuration is the act of selecting from the available options those that are required for the application It is also the software equivalent of rewiring a relay to connect the functions together in a different way so that they operate in a new sequence to provide the required composite function At first this may seem to be a complicated process but it will in fact be foun
135. e given in Section 10 Screen plate Main processor board Screen plate DSP board Screen plate Power supply board User interface board Backplane Analogue input board board Bias current input transformers Analogue input daugther board REF current transformers Voltage transformer Figure 2 1 Internal layout of relay The relay is fully digital containing two microprocessors a digital signal processor DSP and a 80C196 which communicate with each other internally The 80C196 is responsible for the user interface serial communications and scheme logic The DSP is responsible for the protection algorithms The main functions performed in each are shown in Figure 2 2 KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 10 76 KBCH 120 130 140 2 2 2 2 1 2 2 2 2 2 3 2 2 4 Optos Protection Status amp Magnitudes Relive Serial Data from A D LCD Diplay Settings Serial Comms Keypad Low Set High Set User Interface Mag Inrush Scheme Logic Overflux Blocking Overflux Tripping amp Alarm REF Aux Time Delays Figure 2 2 Functional block diagram Signal Conditioning Analogue to Digital conversion The relay has up to sixteen analogue inputs twelve are bias currents used in the differential protection three are currents used in the restricted earth fault REF protection and one is a voltage used in the overflux protection E
136. e operation of the relay can be monitored as described in section 4 3 Relay operation The relays selected for the low set differential protection function can be found under the RELAY MASKS heading The relay to be monitored in this case is the A phase relay which is found in the cell RLY Id gt A Each bit in this cell which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation on the configuration of the output relays Note It is important in this case that the injected currents are in anti phase i e 180 out of phase This is achieved by having two current sources that are in phase and swapping the inputs into terminals 77 and 78 as shown below Figure 6 Low set bias characteristic In total 4 tests should be performed one to cause the relay to trip and one to not cause the relay to trip for both sections of the bias curve From table 27 select the appropriate values of currents for each test depending upon the setting and rating of the relay Using the equations below calculate the values of currents to apply to the relay I1 and I2 In all cases the current should not be applied for longer than 1 second In all cases the applied current should be within 5 of the calculated values Ul 12 IT Hy CT Ratio Cor MS FV Ratio Cor Service Manual Commissioning Instructions KBCH 120 130 140 KBCH EN M C1 1 CHAP
137. e relay will be locked in a non operate state Default display LCD The LCD changes to a default display if no key presses are made for 15 minutes The default display can be selected to any of the options listed in Section 5 1 6 KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 40 76 KBCH 120 130 140 5 3 5 3 1 5 3 2 5 3 3 LOGIC FUNCTIONS location LOG Default Display by following the setting procedure given in Section 5 2 5 The display can be returned to the default value without waiting for the 15 minute delay by selecting any column heading and then holding the reset key depressed for 1 second When the protection trips the display changes automatically to display the fault flags The trip LED indication must be reset as described in Section 5 2 10 before the relay returns to the selected default display Disturbance recorders The disturbance recorder may be triggered by several different methods dependent on the settings in this column of the menu However the records have to be read via the serial communication port and suitable additional software is required to reconstruct and display the waveforms Only one complete record is stored and the recorder must be retriggered before another record can be captured Recorder control This cell displays the state of the recorder a RUNNING recorder storing data overwriting oldest data b TRIGGERED recorder stop delay triggered c STOPPED
138. e touched until the electrical power is removed UL and CSA Listed or Recognized Equipment To maintain UL and CSA approvals the equipment should be installed using UL and or CSA Listed or Recognized parts of the following type connection cables protective fuses fuseholders or circuit breakers insulation crimp terminals and replacement internal battery as specified in the equipment documentation Equipment operating conditions The equipment should be operated within the specified electrical and environmental limits Current transformer circuits Do not open the secondary circuit of a live CT since the high voltage produced may be lethal to personnel and could damage insulation Generally for safety the secondary of the line CT must be shorted before opening any connections to it For most equipment with ring terminal connections the threaded terminal block for current transformer termination has automatic CT shorting on removal of the module Therefore external shorting of the CTs may not be required the equipment documentation should be checked to see if this applies For equipment with pin terminal connections the threaded terminal block for current transformer termination does NOT have automatic CT shorting on removal of the module Pxxxx EN SS B11 Page 6 10 p i ii pe e p gt gt Safety Section External resistors including voltage dependent resistors VDRs Where external resistors including voltage dep
139. ea such as described in the above mentioned BS and IEC documents Relay mounting Relays are dispatched either individually or as part of a panel rack assembly If loose relays are to be assembled into a scheme then construction details can be found in Publication R7012 If a MMLG test block is to be included it should be positioned at the right hand side of the assembly viewed from the front Modules should remain protected by their metal case during assembly into a panel or rack The design of the relay is such that the fixing holes are accessible without removal of the cover For individually mounted relays an outline diagram is normally supplied showing the panel cut outs and hole centres These dimensions will also be found in Publication R6530 Unpacking Care must be taken when unpacking and installing the relays so that none of the parts are damaged or the settings altered and they must only be handled by skilled persons The installation should be clean dry and reasonably free from dust and excessive vibration The site should be well lit to facilitate inspection Relays that have been removed from their cases should not be left in situations where they are exposed to dust or damp This particularly applies to installations which are being carried out at the same time as construction work Storage If relays are not to be installed immediately upon receipt they should be stored in a place free from dust and moisture in their ori
140. ealthy phase to neutral voltages are allowed to rise to 80 of the phase to phase voltage This means that the phase to neutral voltage could rise to 139 on healthy phases during an earth fault The V T input is rated 100 120V A C KBCH EN M D11 Service Manual CHAPTER 2 Application Page 38 38 KBCH 120 130 140 Service Manual KBCH EN M D11 KBCH 120 130 140 APPENDIX A KBCH EN M D11 Service Manual KBCH 120 130 140 Service Manual KBCH EN M D11 APPENDIX A KBCH 120 130 140 Page 1 2 APPENDIX A Transformer connection referencing system The transformer HV windings are indicated by capital letters and the LV winding by small letters The numbers refer to positions on a clock face and indicate the phase displacement of balanced 3 phase LV line currents with respect to balanced 3 phase HV line currents An additional N Ynd1 lower case for LV n indicates a neutral to earth connection on the respective winding of the power transformer This bears no relationship to the required phase connection and has been omitted from the relay menu The presence of an in zone earth connection does however demand a zero sequence current filter as discussed in section 2 1 3 Example 1 A Ynd1 connection indicates a two winding transformer with an earthed Star connected high voltage winding and a Delta connected low voltage winding The low voltage balanced line currents lag the high voltage balanced line currents by 30 30 phase s
141. ect Pin terminal PCB type Earth connections are typical only 4 SCN Screen connection for K Bus 63 T za St Eum 65 XX EZ 66 67 73 gt 6 4 75 KBCH 140 3 X lV2 lo see Figure 14 6 121 77 5 12 8 123 79 Xx _ XX 124 00 25 zx gt 4 5 2 27 83 HV lo see Figure 14 x t E x LV1 lo see Figure 14 A 28 4 A EZ 44 13 AC DC fy ue D WD 5 Rely healty supply 4 on 3 C B Vx 4 09 WD 5 Relay failed Phase rotation ST N RLO 2 ri UE o cs P 34 RU S61 Trip 38 RL2 Trip i tc 17 42 2 amp 18 X gt Trip 63 64 3 4 29 30 e 2S gt Tm xi 65 66 gt 9 RL4 1 lap up A al 5 e 3 Ml nitiate aux timer O LO 9H E d 53 9 10 35 36 e J sw DP S w E X RLS 5 gt Tap down 5 e nitiate aux timer 1 L1 E mul 15 6 40 2 amp 74 i 21 Initiate aux timer 2 12 RLO 7 08 P 52 YI i 75 M 76 adi Logic input common 1 4 RL7 43 gt Tri 3 o ED 7778 21 22 Lar 481 nitiate aux timer 3 13 S 2 C D gt c 49 50 cs 79 XC 80 2330 C24 v x a 147 X X 57 L 71 2l nitiate aux timer 4 14 eG 813682 25 126 53
142. ed or injected directly into the relay terminals Suitable test methods will be found in the section of this manual dealing with commissioning These tests will prove the calibration accuracy is being maintained Trip test A trip test can be performed remotely by using the options under the TEST CONTROL column in the menu Note These are password protected cells If an output relay is found to have failed an alternative relay can be reallocated until such time as a replacement can be fitted See Section 5 2 8 for how to set relay masks KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 68 76 KBCH 120 130 140 10 2 4 Additional tests 10 3 10 3 1 10 3 2 10 3 3 Additional tests can be selected from the Commissioning Instructions as required Method of repair Please read the handling instructions in Section 1 before proceeding with this work This will ensure that no further damage is caused by incorrect handling of the electronic components Refer to Figure 2 1 in Section 2 for the module layout Replacing the user interface board Withdraw the module from its case Remove the six screws on the front plate Remove the front plate Lever the top edge of the user interface board forwards to unclip it from its mounting Then pull the pcb upwards to unplug it from the connector at its lower edge Replace with a new interface board and assemble in the reverse order Replacing the analogue input daughter b
143. ed at this time to explain why some of the items listed below may not appear in the menu for the relay that is being compared with the full list The menu cells that are read only are marked READ Cells that can be set are marked SET Cells that can be reset are marked RESET Cells that are password protected are marked PWP System data 0000 SYSTEM DATA 0001 SYS Language The language used in the text READ 0002 SYS Password Password PWP 0003 SYS Fn Links Function Links PWP LINK SYS Rem ChgStg 1 Enable remote setting changes LINK 1 SYS Rem Tap Ctrl 1 Enable remote control of tap changer LINK 3 SYS Rem ChgGrp 1 Enable remote change of setting group LINK 4 SYS Enable Grp2 1 Enable setting group 2 LINK 5 SYS Auto Reset 1 Enable auto flag reset function LINK 6 SYS Auto Rec 1 Enable auto reset of recorder KBCH EN M E1 1 CHAPTER 1 Page 28 76 LINK 7 SYS En Log Evts Service Manual Technical Description KBCH 120 130 140 1 Enable event records to be stored 0004 SYS Description Description or user scheme identifier PWP 0005 SYS Plant Ref User plant location identifier PWP 0006 SYS Model No Model number READ 0008 SYS Serial No Serial number READ 0009 SYS Frequency Frequency SET 000A SYS Comms Level Communication level READ OOOB SYS Rly Address Communication address SET OOOC SYS Plant Status Not used READ 0000 SYS Ctrl Status Not used READ OOOE SYS Settin
144. ed by AUX 4 timer Relay to be operated by AUX 5 timer Relay to be operated by AUX 6 timer Relay to be operated by AUX 7 timer Relay to cause Tap Changer to Tap Up Relay to cause Tap Changer to Tap Down Relay to operate when any overflux condition is detected based on 5th harmonic Relay to operate for Overflux Trip V f Relay to operate for Overflux Alarm V f RUNNING TRIGGERED STOPPED SET SAMPLES MAGNITUDE PHASE SET Trace length after trigger SET Select logic input to trigger SET KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 36 76 KBCH 120 130 140 OC 05 REC Relay trig Select relay output to trigger SET 5 1 10 Test Control OD 00 TEST CONTROL OD 01 TST Logic Stat State of control inputs READ OD 02 TST Relay Stat State of relay outputs READ OD 03 Select Relays Relay to operate for trip test SET To Test OD 04 Test Relays 0 Facility to test relays using Relay Test mask SET OD 05 TST Tap Control Tap Changer Control No Operation Tap Up Tap Down SET 5 2 Changing text and settings To enter the setting mode Settings and text in certain cells of the menu can be changed via the user interface To do this the cover must be removed from the front of the relay to gain access to the and keys Give the F key a momentary press to change from the selected default display and switch on the backlight the heading SYSTEM DATA will be displayed Use the and keys or a long F key press t
145. ed by a restricted earth fault relay 64 which is arranged to measure Ir directly Although more sensitive protection is provided by REF the operating current for the overall differential protection is still significant for faults over most of the winding For this reason independent REF protection may not have previously been considered necessary for a solidly earthed winding especially where an additional relay would have been required With the KBCH the REF protection is available at no extra cost if a neutral CT is available Restricted earth fault protection is also commonly applied to Delta windings of large power transformers to improve the operating speed and sensitivity of the protection package to winding earth faults When applied to a Delta winding this protection is commonly referred to as balanced earth fault protection It is inherently restricted in its zone of operation when it is stabilised for CT spill current during inrush or during phase faults The value of fault current flowing will again be dependant upon system earthing arrangements and the fault point voltage The application of the KBCH Restricted Earth Fault REF elements is based on the high impedance differential principle offering stability for any type of fault occurring outside the protected zone but operation for earth faults within the zone KBCH EN M D11 Service Manual CHAPTER 2 Application Page 20 38 KBCH 120 130 140 2 3 2 If prim
146. ed earth fault setting procedure 23 Figure 18 Inverse time IDMT Overfluxing protection characteristic 26 Figure 19 28 Figure 20 Use of opto isolators with protection Auxiliary supply 29 Figure 21 Tap changer controls 30 Figure 22 Generator and Generator Transformer protection 31 Figure 23 Unit transformer configurations 31 Figure 24 Combined digital protection scheme 32 Figure 25 Digital relays on a K bus communications network 32 Figure 26 Current transformer location requirements 34 Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 3 38 1 INTRODUCTION 1 1 Protection of transformers The development of modern power systems has been reflected in the advances in transformer design This has resulted in a wide range of transformers with sizes from a few kVA to several hundred MVA being available for use in a wide variety of applications The considerations for a transformer protection package vary with the application and importance of the transformer To reduce the effects of thermal stress and electrodynamic forces it is advisable for the overall protection package to minimise the time that a fault is present within a transformer On smaller distribution transformers effective and economically justifiable protection can be achieved by using either fuse protection or IDMT instantaneous overcurrent relays Due to the requirements of co ordination with the down stream power system protection this results
147. ed output relay operates FOR THE SECOND TEST IT IS IMPORTANT THAT THE CURRENT IS NOT APPLIED FOR LONGER THAN 1 SECOND Inject O 9xIs for 1 second and ensure that the relay does not operate Repeat the above two tests for the two remaining elements of the HV side of the transformer as listed in table 18 High set element operating time This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the calculated application setting Connect the relay so that current can be injected through terminals 21 and 22 but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 23 52 Inject 3xIs into the A phase low set element terminals 21 amp 22 Check that the operating time for the relay is within the range 10ms to 20ms Repeat this test for both of the remaining phases on the HV side as listed in table 18 6 3 Restricted Earth Fault Protection There are three restricted earth fault elements for this relay model one on the high voltage side of the transformer and two on the low voltage side of the transformer 6 3 1 REF current sensitivity HV side Io HV In the SETTINGS menu go to cell S1 Fn Links and set all the bits t
148. ed to the relay the timer starts Inject 5xIs into the A phase low set element terminals 21 amp 22 Check that the operating time for the relay is within the range 30ms to 40ms Repeat this test for both of the remaining phases on the HV side listed in table 18 above High set element current sensitivity Id gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test checks the instantaneous current sensitivity of the differential high set element relay This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the calculated application setting KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 22 52 KBCH 120 130 140 6 2 4 Go to the cell S1 Fn Links in the SETTINGS menu and set bit 2 S1 Enable Id gt gt to 1 thus enabling the high set function Then disable the low set element by setting bit 1 S1 Enable Id gt to Ensure that all the other bits are set to The relays selected to operate for the Id gt gt trip can be found under the RELAY MASKS heading The phase A relay will be found in the cell RLY Id gt gt A phase relay in cell RLY Id gt gt B and phase C in RLY Id gt gt C Each bit in these cells which is set to 1 corresponds to an output relay which is selected for thi
149. ed with the initial factory selected Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 53 76 7 4 options as supplied For example practice moving through the menu and then changing some of the visible individual protection settings When familiar with the relay it will be easier to configure it for a specific application This involves selecting as described in Section 6 those available options that are required for the application These will then respond in the display those that are not selected will be inoperative and some of them will be hidden their current set values being of no concern The next stage is to allocate output relays to the chosen functions This must be done with care because it will determine which functions latch the flags and those which latch the TRIP LED Selecting options 1 Select SYSTEM DATA heading from the menu step down to SYS Password and enter the password The alarm LED will flash to indicate that the relay is no longer password protected If required a new password can be entered at this stage Select the function link settings in the next menu cell down and enter any changes The Description will state the main functions for example Bias I P REF This may be changed to the user configuration reference The Plant Reference can be used to identify the plant circuit or circuit breaker that the relay is associated with The communication addre
150. ement values can be displayed on the front of the relay The display consists of up to nine phase current values depending on model and configuration The currents displayed are those measured before the effects of phase compensation If the primary current transformer ratios are entered in the SETTINGS column the phase current values will be in primary amperes The default setting for these ratios is 1 1 in which case the displayed measured values are then the secondary quantities as seen by the relay In the case of mesh corner where two current transformers are used the displayed currents are the calculated current which is flowing in the transformer winding The differential and through bias currents are displayed in secondary terms The minimum current that is measured by KBCH is 30mA or 150mA for 1A or 5A respectively Fault records Fault values are recorded for the last fault but the fault flags are recorded for the last five faults They are stored in non volatile memory and can be accessed via the user interface There is provision for clearing these records A copy of the fault record is also stored in the event records and up to 50 of these records can be held at any one time provided all other events are de selected These records will carry a time tag which is valid for 49 days However the event records will be lost if the relay is de energised and they can only be accessed via the serial communication port Self monitoring a
151. endent resistors VDRs are fitted to the equipment these may present a risk of electric shock or burns if touched Battery replacement Where internal batteries are fitted they should be replaced with the recommended type and be installed with the correct polarity to avoid possible damage to the equipment buildings and persons Insulation and dielectric strength testing Insulation testing may leave capacitors charged up to a hazardous voltage At the end of each part of the test the voltage should be gradually reduced to zero to discharge capacitors before the test leads are disconnected Insertion of modules and pcb cards Modules and pcb cards must not be inserted into or withdrawn from the equipment whilst it is energised since this may result in damage Insertion and withdrawal of extender cards Extender cards are available for some equipment If an extender card is used this should not be inserted or withdrawn from the equipment whilst it is energised This is to avoid possible shock or damage hazards Hazardous live voltages may be accessible on the extender card Insertion and withdrawal of integral heavy current test plugs It is possible to use an integral heavy current test plug with some equipment CT shorting links must be in place before insertion or removal of heavy current test plugs to avoid potentially lethal voltages External test blocks and test plugs Great care should be taken when using external tes
152. estricted earth fault protection is further discussed in section 2 3 Earth fault protection is provided on the HV winding by the inherently restricted earth fault element associated with the HV overcurrent CT s 50N The Delta winding of the transformer draws no HV zero sequence current for LV earth faults and passes no zero sequence current to upstream HV earth faults hence there is no requirement to grade this element with other earth fault protection and it can be set to operate without any intentional time delay The high impedance differential principle is used to ensure stability in the event of asymmetric CT saturation for external phase faults and during inrush conditions Sustained external LV faults are cleared by the IDMT overcurrent protection on the HV winding 51 or by the standby earth fault relay 51N in the transformer earth Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 5 38 connection The extent of backup protection employed will vary according to the transformer installation and application The protection scheme may be further enhanced by the use of other protective devices associated with the transformer such as the Buchholz pressure relief and winding temperature devices These devices can act as another main protective system for large transformers and they may also provide clearance for some faults which might be difficult to detect by protection devices operating from line current t
153. et to 1 alternatively the address must be entered manually via the user interface on the relay Address cannot be allocated automatically unless the address is first manually set to O This can also be achieved by a global command including the serial number of the relay Relay address set to 255 the global address for which no replies are permitted Measured values do not change Values in the MEASUREMENTS 1 column are snap shots of the values at the time they were requested To obtain a value that varies with the measured quantity it should be added to the poll list as described in the communication manual Relay no longer responding Check if other relays that are further along the bus are responding and if so power down the relay for 10 seconds and then re energise to reset the communication KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 66 76 KBCH 120 130 140 9 5 3 9 6 9 6 1 processor This should not be necessary as the reset operation occurs automatically when the relay detects a loss of communication If relays further along the bus are not communicating check to find out which are responding towards the Master Station If some are responding then the position of the break in the bus can be determined by deduction If none are responding then check for data on the bus or reset the communication port driving the bus with requests Check there are not two relays with the same address on the bus N
154. ets Check that the pick up and drop off are within the range shown in Table 12 1 1 Id gt In table 12 below Is Ratio Cor Id is the low set setting which will be found in the cell Id gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios There is one ratio correction factor for the HV side which is found in the cell HV Ratio Cor and one for the LV1 side found in the cell LV1 Ratio Cor Both of these are found under the SETTINGS menu headings The appropriate CT ratio factor should be used to calculate the current to inject depending upon whether it is being injected into the HV or the LV inputs Current Level Pick up 0 9 x Is to 1 1 xIs Drop off 0 9 x Pick up to 1 0 x Pick up Table 12 Repeat the above test for each of the remaining phases on the HV side and for all three phases on the LV1 side These are listed in table 13 Input Terminals IA HV 21 22 IB HV 23 24 HV 25 26 IA LV1 77 78 IB LV1 79 80 IC LV1 81 82 Table 13 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 16 52 KBCH 120 130 140 Note As the CT inputs to each phase have been verified by both the 5 2 2 5 2 3 measurement checks and the low set differential trip checks it is only necessary to check the operating time and t
155. f value at which it resets Check that the pick up and drop off are within the range shown in Table 22 1 1 Id gt In table 22 below Is TCT Ratio Cor Id gt is the low set setting which will be found in the cell Id gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios There is one ratio correction factor for the HV side which is found in the cell HV Ratio Cor one for the LV1 side found in the cell LV1 Ratio Cor and one for the LV2 side found in the cell LV2 Ratio Cor All of these are found under the SETTINGS menu heading The appropriate CT ratio factor should be used to calculate the current to inject depending upon whether it is being injected into the HV LV1 or the LV2 inputs Current Level Pick up 0 9 x Is to 1 1 x Is Drop off 0 9 x Pick up to 1 0 x Pick up Table 22 Repeat the above test for each of the remaining phases on the HV side and for all three phases on the LV1 side all three on the LV2 side and the LV3 side These are listed in table 23 Input Terminals IA HV 21 22 IB HV 23 24 IC HV 25 26 IA LV 77 78 IB LV1 79 80 IC LV1 81 82 IA LV2 69 70 IB LV2 71 72 IV LV2 73 74 IA LV3 63 64 IB LV3 65 66 IC LV3 67 68 Table 23 Note As the CT inputs to each phase have been verified by both the measuremen
156. figuration of the relay if the relay is changed from the factory configuration 0005 SYS Plant Reference SET The plant reference can be entered by the user but it is limited to 16 characters This reference is used to identify the primary plant with which the relay is associated Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 29 76 0006 SYS Model Number READ The model number that is entered during manufacture has encoded into it the mechanical assembly ratings and configuration of the relay It is printed on the front plate and should be quoted in any correspondence concerning the product 0008 SYS Serial Number READ The serial number is the relay identity and encodes also the year of manufacture It cannot be changed from the menu 0009 SYS Frequency SET The set frequency from which the relay starts tracking on power up 000A SYS Communication Level READ This cell will contain the communication level that the relay will support It is used by Master Station programs to decide what type of commands to send to the relay OOOB SYS Relay Address SET An address between 1 and 254 that identifies the relay when interconnected by a communication bus These addresses may be shared between several communication buses and therefore not all these addresses will necessarily be available on the bus to which the relay is connected The address can be manually set Address O is reserved for th
157. formed with both the phase compensation factors HV VectorCor and LV1 VectorCor set to YyO Measurement checks To test the relay measurement functions a current of known value should be injected into each phase input With the CT ratios in the cells HV CT Ratio and LV1 CT Ratio in the SETTINGS menu set to the values of the line CT s the displayed measured values will be in the equivalent primary quantities HV and LV1 winding measurement checks Connect the CT inputs to the relay as shown below OVERCURRENT TEST SET Figure 1 and LVI windings measurement check Go to the SETTINGS menu and set all the bits in the cell S1 Fn Links to O This disables all the protection elements so that the relay will not trip Then go to the MEASUREMENTS menu and step down one until the cell MS1 IaHV is displayed Inject rated current and ensure that the displayed value lies within 10 of the injected value By pressing F short step down until the cell MS1 IcLV1 is reached checking each time that the displayed value lies in this range Check that the cells MS1 Ia Diff MS1 Ib Diff and MS1 Ic Diff display the correct values of differential current In this case it should be Injected I x2 10 Check that the cells MS1 Ia Bias MS1 Ib Bias and MS1 Ic Bias display the correct values of bias current In this case it should be Injected I 10 Frequency measurement check Inject a current of known frequency
158. g Grp Setting group in use 1 2 READ 0011 SYS S W Ref 1 0012 SYS S W Ref 2 0020 SYS Logic Stat 0021 SYS Relay Stat 0022 SYS Alarms Software reference number 1 READ Software reference number 2 READ Current state of logic control inputs READ Current state of output relays READ State of alarms READ The following notes describe each setting 0001 SYS Language READ The language in which the text is displayed is shown at this location On these particular relays it is not selectable 0002 SYS Password PWP The selected configuration of the relay is locked under this password and cannot be changed until it has been entered Provision has been made for the user to change the password which may consist of four upper case letters in any combination In the event of the password becoming lost a recovery password can be obtained on request but the request must be accompanied by a note of the model and serial numbers of the relay The recovery password will be unique to one relay and will not work on any other unless the user set password is the same 0003 SYS Function Links PWP These function links enable selection to be made from the system options for example which commands over the serial link will be acted upon 0004 SYS Description PWP This is text that describes the relay type for example 2 Bias I P REF It is password protected and can be changed by the user to a name which may describe the scheme con
159. g a faster selection When a cell containing a relay setting is displayed the action of pressing either the or keys will indicate to the relay that a value is to be changed and a flashing cursor will appear on the display To escape from the setting mode without making any change the 0 key should be depressed for one second For instruction on how to change the various types of settings refer to Section 5 2 Menu contents Related data and settings are grouped together in separate columns of the menv Each column has a text heading that identifies the data contained in that column Each cell may contain text values limits and or a function The cells are referenced by the column number row number For example 0201 is column 02 row 01 The full menu is given in the following notes but not all the items will be available in a particular relay For example a KBCH120 relay would not display any settings related to the tertiary winding LV2 Those cells that do not provide any useful purpose are not made available in the factory configuration to avoid the confusion that would occur in deciding what values to set them to n a similar way certain settings will disappear from the menu when the user de selects them the alternative setting group is a typical example If System Data Link SD4 is set to O alternative settings SETTINGS 2 will be hidden and to select them and make them visible link SD4 must be set to 1 This note is includ
160. g for Overflux Alarm Note Settings 02 OB are common to both Settings groups 1 and 2 as they relate to the transformer and line current transformers 5 1 6 Logic functions 5 1 7 09 00 09 02 09 03 09 04 09 05 09 06 09 07 09 08 09 09 09 OA 09 OB 09 OC 09 OD LOGIC FUNCTIONS SET LOG tAUXO Time delay associated with AUXO output LOG tAUXI Time delay associated with AUX1 output LOG tAUX2 Time delay associated with AUX2 output LOG tAUX3 Time delay associated with AUX3 output LOG tAUX4 Time delay associated with AUXA output LOG tAUX5 Time delay associated with AUX5 output LOG tAUX6 Time delay associated with AUX6 output LOG tAUX7 Time delay associated with AUX7 output LOG tTEST Test Relay close pulse setting LOG tTapUp Tap Changer Tap Up closure time LOG tTapDown Tap Changer Tap Down closing time LOG Default Dsply Selected default display Default Display SET N II 6 Input masks OA 00 OA 07 OA 08 OA 09 OA OA AREVA K SERIES MIDOS Description or User Defined Scheme Reference Plant Reference User Defined HV la Ib Ic LVI Ia Ib Ic LV2 Ia Ib Ic F now INPUT MASKS PWP INP Blk V f Trp Input to Block Overflux Trip INP Blk V f Alm Input to Block Overflux Alarm INP Aux 0 Input to initiate tAUXO INP Aux 1 Input to initiate tAUX1 Service Manual Technical Description KBCH 120 130 140 5 1 9 00 OA OF OA 10 11 Relay masks OB
161. ginal cartons Where de humidifier bags have been included in the packing they should be retained The action of the de humidifier crystals will be impaired if the bag has been exposed to ambient conditions and may be restored by gently heating the bag for about an hour prior to replacing it in the carton Dust which collects on a carton may on subsequent unpacking find its way into the relay in damp conditions the carton and packing may become impregnated with moisture and the de humidifier will lose its efficiency Storage temperature 25 C to 70 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 9 76 2 DESCRIPTION OF THE RELAY 2 1 Introduction The relay types covered by this manual are KBCH1 20 2 biased inputs per phase Transformer Differential Relay KBCH130 3 biased inputs per phase Transformer Differential Relay KBCH140 4 biased inputs per phase Transformer Differential Relay The relay is housed in size 8 Midos modular cases and is physically fully compatible with the existing relays in the range The Midos system provides compact construction with a metallic case and integral mounted screw push on terminal connections on the rear of the housing The case is suitable for rack or panel mounting and makes the relay ideally suited to retrofit applications The relay contains a number of printed circuit boards as shown in Figure 2 1 Instructions for removing each pcb ar
162. gned by a mask and the same relay may be assigned by several masks Figure 6 2 shows by example how the input and output masks may be used 1 Function 1 is initiated by LO as indicated by the position of the in the input mask The input masks act as an OR gate so that for function 2 it is initiated by either or both LO and L1 but L1 will not initiate function 1 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 43 76 6 1 Both functions 3 and 4 can be initiated by L3 but only function 4 is initiated by L5 Similarly the output masks can be used to direct the output of a function to any relay The relay masks also act as OR gates so that several functions can be directed to a particular output relay In the example function 1 operates relays 3 and 6 however relay 3 is also operated by functions 2 3 and 4 Function 1 Function 2 Function 3 Function 4 Relay status Logic status Figure 6 2 Operation of input output masks Biased differential trip logic The biased differential trip logic is shown in Figure 6 3 If selected by link S1 the output from the differential algorithm Id gt sets a latch The output of the latch is directed to the Trip Id gt mask This will result in the output relay s designated by the mask being energised The t100ms timer ensures a minimum dwell time of 100ms Operation of the
163. gt gt gt gt gt gt gt gt Service Manual Commissioning Test Results KBCH 120 130 140 6 2 2 Low set element operating time Setting Group 1 Expected 30ms to 40ms Ia HV ms Ib HV ms Ic HV ms 6 2 3 High Set element Id gt Setting Is A Setting Is tick Ia HV Trip HV No Trip Ib HV Trip Ib HV No Trip Ic HV Trip Ic HV No Trip 6 2 4 High set element operating time Expected 10ms to 20ms Ia HV ms Ib HV ms Ic HV ms 6 3 1 REF HV side current sensitivity lo gt HV Setting Group 1 Setting Is A Io HV Pick up A Io HV Crop off A KBCH EN M C1 1 CHAPTER 4 Page 11 22 Setting Group 2 if required tick Setting Group 2 if required KBCH EN M C1 1 CHAPTER 4 Page 12 22 6 3 2 6 3 3 6 3 4 6 3 5 6 3 6 7 1 1 REF HV side operating time Expected 20ms to 30ms Operating time REF LV1 side current sensitivity lo gt LV1 Setting Is Io LV1 Pick up Io LV1 Drop off REF LV1 side operating Expected 20ms to 30ms Operating time REF LV2 side current sensitivity lo gt LV2 Setting Is Io LV1 Drop off REF LV2 side operating time Expected 20ms to 30ms Operating time KBCH 140 HV LV1 Measurement checks HV CT Ratio HV Ratio Correction HV Phase Compensation LV1 CT Ratio
164. gt A Each bit in this cell which is set to 1 corresponds to an output relay for this function For a fuller description of the configuration of output relays see section 2 4 Connect the relay as shown below in Figure 9 Tinj Figure 9 Fifth harmonic blocking circuit Inject the following current into the relay and ensure that the output relay for the low set differential protection operates T Id gt zl f 0 Iinj 1 1 HV Ratio Cor lof 5 where Id gt low set setting found in the cell Id gt A HV Ratio Cor CT ratio correction found in the cell HV RatioCor Iof Fifth harmonic current setting found in the cell S1 Iof All of the above settings are found under the SETTINGS menu heading In this case the fifth harmonic content of the input current is below setting and the low set differential protection should operate Next inject the following current and ensure that the output relay for the low set differential protection does not operate nx Id Iinj 1 1 Ratio Gor t lof 5 In this case the fifth harmonic content of the input current is above setting and the low set differential protection should be blocked from operating Overflux fifth harmonic relay operating time The overflux fifth harmonic detector can be selected to operate an output relay if required The output relay selected to operate for this function is found under RELAY MASKS heading in the cell RLY OF Alarm Each
165. h safety engineering practices e are trained in emergency procedures first aid The operating manual for the equipment gives instructions for its installation commissioning and operation However the manual cannot cover all conceivable circumstances or include detailed information on all topics In the event of questions or specific problems do not take any action without proper authorization Contact the appropriate AREVA technical sales office and request the necessary information Pxxxx EN SS B11 Page 4 10 Safety Section 3 3 1 3 2 SYMBOLS AND EXTERNAL LABELS ON THE EQUIPMENT For safety reasons the following symbols and external labels which may be used on the equipment or referred to in the equipment documentation should be understood before the equipment is installed or commissioned Symbols A Caution refer to equipment documentation Caution risk of electric shock WD EE Protective Conductor Earth terminal IE Functional Protective Conductor Earth terminal Note This symbol may also be used for a Protective Conductor Earth terminal if that terminal is part of a terminal block or sub assembly e g power supply NOTE THE TERM EARTH USED THROUGHOUT THIS GUIDE IS THE DIRECT EQUIVALENT OF THE NORTH AMERICAN TERM GROUND Labels See Safety Guide SFTY 4L M for equipment labelling information INSTALLING COMMISSIONING AND SERVICING 4 Equipment connections Personnel undertak
166. he alarm lamp flashes when the password is entered password inhibition temporarily overridden RED LED Indicates a trip that has been issued by the relay The trip flags give further information Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 25 76 4 3 Keypad 4 4 Four keys on the front plate of the relay enable the user to select the data to be displayed and settings to be changed The keys perform the following functions F FUNCTION SELECT KEY INCREMENT VALUE KEY DECREMENT VALUE KEY 0 RESET ESCAPE KEY Liquid crystal display The liquid crystal display LCD has two lines each of sixteen characters that are used to display settings measured values and records which are extracted from the relay data bank A backlight is activated when any of the keys on the front plate of the relay is momentarily pressed This enables the display to be read in all conditions of ambient lighting The numbers printed on the front plate just below the display identify the individual digits that are displayed for some of the settings i e function links relay masks etc KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 26 76 KBCH 120 130 140 5 MENU SYSTEM Data within the relays is accessed via a MENU table The table is divided into columns and rows to form cells rather like a spreadsheet Each cell may contain text values limits and functions The first cell
167. he high set current sensitivity for each phase element on one side of the transformer only Low set element operating time Connect the relay so that current can be injected through terminals 21 and 22 but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the A phase low set element terminals 21 amp 22 Check that the operating time for the relay is within the range 30ms to 40ms Repeat this test for both of the remaining phases on the HV side as listed in table 13 above High set element current sensitivity Id gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test checks the instantaneous current sensitivity of the differential high set element relay This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the calculated application setting Go to the cell S1 Fn Links in the SETTINGS menu and set bit 2 S1 Enable Id gt gt to 1 thus enabling the high set function Then disable the low set element by setting bit 1 S1 Enable Id to Ensure that all the other bits are set to O The relays selected to operate for the Id gt gt trip can be f
168. hift Example 2 A Dynlyn11 connection indicates a three winding transformer with a Delta connected high voltage winding and two earthed Star connected low voltage windings The phase displacement of the first LV winding with respect to the HV winding is 30 lag 30 phase shift the phase displacement of the second LV winding with respect to the HV winding is 30 lead 30 phase shift KBCH EN M D11 Service Manual APPENDIX A Page 2 2 LFCB 120 130 140 Service Manual KBCH EN M D11 KBCH 120 130 140 APPENDIX B KBCH EN M D11 Service Manual KBCH 120 130 140 Service Manual KBCH EN M D11 APPENDIX B KBCH 120 130 140 Page 1 2 APPENDIX B Zero sequence current filtering worked examples Example Transformer connection Dyn11 Dyn11 0 Gp 30 KBCH Relay YyO Differential Yd1 Software ICT ro element ro Software ICT The phase correction for the transformer is provided by the selection of the phase correction factors HV phase correction factor 0 LV phase correction factor Yd As can be seen the delta winding introduced with the LV software interposing CT will provide the required zero sequence trap as would have been the case if the vector correction factor has been provided using an external interposing current transformer If in the above example the line CTs on the LV side of the transformer are connected in delta then the
169. ias FnowGx Fn Gx Fn 1 Gx Fn 2Gx Fn 3Gx Fn 4Gx FLT Records Clear 0 5 1 3 Measurements 1 02 00 02 01 02 02 02 03 02 05 02 06 02 07 02 09 02 02 OB 02 OD 02 OE 02 OF 02 10 MEASUREMENTS 1 MS1 Ia HV MS1 Ib HV MS1 Ic HV MS1 Ia LV1 MS1 Ib LV1 MS1 Ic LV1 MS1 Ia LV2 MS1 Ib LV2 MS1 Ic LV2 MS1 Ia Diff MS1 Ib Diff MS1 Ic Diff 1 Ia Bias Service Manual Technical Description KBCH 120 130 140 READ Fault Current in HV winding A phase Fault Current in HV winding B phase Fault Current in HV winding C phase Fault Current in LV1 winding A phase Fault Current in LV1 winding B phase Fault Current LV1 winding C phase Fault Current in LV2 winding A phase Fault Current in LV2 winding B phase Fault Current in LV2 winding C phase Fault Current in Differential circuit A phase Fault Current in Differential circuit B phase Fault Current in Differential circuit C phase Fault Current in Bias circuit A phase Fault Current in Bias circuit B phase Fault Current in Bias circuit C phase Current state of flags not latched flags for last fault n RESET trip led only flags for previous fault n 1 previous fault flags for previous fault n 2 flags for previous fault n 3 flags for previous fault n 4 Clear fault records RESET READ Current in HV winding A phase Current in HV winding B phase Current in HV winding C phase Current in LV winding A phase Current in L
170. iate aux timer 5 L5 9 r3 EC RE 5 SCN CD See Note 4 D 561 gt communications port Initiate aux timer 6 L e T See Note 4 SCN Module terminal blocks v 9 viewed from rear 153 7 Initiate aux timer 7 17 r e 155 Y 8 48 field voltage Logic input common 2 9 4 N Notes 1 CT shorting links make 2 VT input must be supplied with phase phase voltage before b and disconnect Connections are typical only b 5 Short terminals break before 3 Earth connections are typical only Long terminals 4 SCN Screen connection for K Bus d Pin terminal PCB type Figure 11 Typical external connections for KBCH 120 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 49 52 KBCH 130 LJ UJ LJ LJ W LJ W LJ t LV1 lo see Figure 14 Relay healthy Relay failed Phase rotation N rip n mm rip a b c rip 5 1 rip SF j 6 3 2 65 UE 66 D e jap up gt l n 5 e u EI Initiate aux timer O 9 xo e down 69 mE 7 381 Initiate aux timer 1 P REGE 3 39 40 7172 a
171. igure 12 4 Trip and flag logic KBCH Logic Diagram Typical external connections for KBCH120 Typical external connections for KBCH130 Typical external connections for KBCH140 Typical restricted earth fault connections for KBCH140 Service Manual Technical Description KBCH 120 130 140 69 69 69 69 69 70 71 72 10 11 12 12 13 14 21 22 22 23 24 26 42 43 44 44 45 46 47 48 48 48 49 71 72 73 74 75 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 7 76 1 HANDLING AND INSTALLATION 1 1 General considerations 1 1 1 Receipt of relays Protective relays although generally of robust construction require careful treatment prior to installation on site Upon receipt relays should be examined immediately to ensure no damage has been sustained in transit If damage has been sustained during transit a claim should be made to the transport contractor and an AREVA T amp D representative should be promptly notified Relays that are supplied unmounted and not intended for immediate installation should be returned to their protective polythene bags 1 1 2 Electrostatic discharge ESD The relays use components that are sensitive to electrostatic discharges The electronic circuits are well protected by the metal case and the internal module should not be withdrawn unnecessarily When handling the module outside its case care should be taken to avoid contact
172. imum internal fault current is limited to 1000A If B 1000 600 1 67 VE 1 67 3 70 0 114 53 94 88V Vp 24f2x91x 94 88 91 53 15V This value is below maximum of 3000V peak and therefore no Metrosils are required with the relay Service Manual KBCH EN M C11 KBCH 120 130 140 CHAPTER 3 Commissioning Instructions KBCH EN M C11 Service Manual KBCH 120 130 140 Service Manual Commissioning Instructions KBCH 120 130 140 CONTENT 1 COMMISSIONING PRELIMINARIES 1 1 Quick guide to local menu control 1 2 Electrostatic discharge ESD 1 3 Equipment required 1 4 Inspection 1 5 Earthing 1 6 Main current transformers 1 7 Test block 1 8 Insulation 2 COMMISSIONING TEST NOTES 2 1 Commissioning the relay with its calculated application settings 2 2 Commissioning the relay with the selective logic functions 2 3 Resetting fault flags 2 4 Configuration of output relays 3 AUXILIARY SUPPLY TESTS 3 1 Auxiliary supply 3 2 Energisation from auxiliary voltage supply 3 3 Field voltage 4 SETTINGS 4 1 Changing the settings 4 2 Changing the system frequency 4 3 Relay operation 5 KBCH 120 5 1 Measurement checks 5 1 1 HV and LV1 winding measurement checks 5 1 2 Frequency measurement check 5 2 Differential Protection 5 2 1 Low set element current sensitivity Id gt 5 2 2 Low set element operating time 5 2 3 High set element current sensitivity Id gt gt 5 2 4 High set element operati
173. ing and other relays components CT circuit In the majority of cases interposing current transformers are not required and the CT requirements should be modified to remove the burden of the ICT Where line CT s are connected in Delta an additional factor must be taken account of in the CT requirements i e Vk 24 f3 In Ra 281 The above current transformer requirements are based upon results of conjunctive relay C T tests performed by AREVA with a heavy current test plant It may be necessary on occasions to use CT s where the requirements detailed above for biased differential operation are not met If this is the case the following should be taken into account when modifying the CT equation The degree of CT saturation that could occur for a through fault will be dependant upon the through fault current magnitude and the X R ratio for the impedance limiting the current X R ratio governing the rate of decay of any transient DC component of current waveform For a transformer differential application the X R ratio will be moderate less than 30 and the through fault current will be fairly high above 10In For a generator differential application the X R ratio could be fairly high above 100 but the maximum through fault current could be fairly low less than 5In It is more difficult to assure stability for a generator circuit application due to the fact that the bias current can be fairly small in magnitude compa
174. ing installation commissioning or servicing work for this equipment should be aware of the correct working procedures to ensure safety The equipment documentation should be consulted before installing commissioning or servicing the equipment Terminals exposed during installation commissioning and maintenance may present a hazardous voltage unless the equipment is electrically isolated Any disassembly of the equipment may expose parts at hazardous voltage also electronic parts may be damaged if suitable electrostatic voltage discharge ESD precautions are not taken If there is unlocked access to the rear of the equipment care should be taken by all personnel to avoid electric shock or energy hazards Voltage and current connections should be made using insulated crimp terminations to ensure that terminal block insulation requirements are maintained for safety To ensure that wires are correctly terminated the correct crimp terminal and tool for the wire size should be used The equipment must be connected in accordance with the appropriate connection diagram Safety Section gt gt gt Pxxxx EN 55 1 1 Page 5 10 Protection Class Equipment Before energising the equipment it must be earthed using the protective conductor terminal if provided or the appropriate termination of the supply plug in the case of plug connected equipment The protective conductor earth connection must not be removed since
175. ings and or more than one set of CT s associated with each winding e g in mesh or one and a half circuit breaker substation arrangements The variety of protective functions offered by the KBCH makes it ideal not only for the protection of power transformers but also for a variety of applications where biased differential or high impedance protection is commonly applied these include Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 7 38 Overall Generator Transformer protection Generators Reactors 1 2 2 protection features In addition to providing all of the common relaying requirements for a transformer protection package the KBCH relay shares many common features with the other relays in the K range The KBCH offers this variety of additional features by virtue of its digital design and standardisation of hardware These features are listed below Electrical Instrumentation with local remote display Fault records summary of reasons for tripping etc Event records summary of alarms and relay events Disturbance records record of analogue wave forms and operation of opto isolated inputs output relays Date and time tagging of all records Commissioning aids Remote communications with a K bus network interface High level of continuous self monitoring and diagnostic information Remote manual Tap changer control Relay menu available in English Fre
176. ining batteries should have them removed before disposal taking precautions to avoid short circuits Particular regulations within the country of operation may apply to the disposal of batteries EQUIPMENT WHICH INCLUDES ELECTROMECHANICAL ELEMENTS AN A A Electrical adjustments It is possible to change current or voltage settings on some equipment by direct physical adjustment e g adjustment of a plug bridge setting The electrical power should be removed before making any change to avoid the risk of electric shock Exposure of live parts Removal of the cover may expose hazardous live parts such as relay contacts these should not be touched before removing the electrical power TECHNICAL SPECIFICATIONS FOR SAFETY Protective fuse rating The recommended maximum rating of the external protective fuse for equipments is 16A high rupture capacity HRC Red Spot type NIT or TIA or equivalent unless otherwise stated in the technical data section of the equipment documentation The protective fuse should be located as close to the unit as possible DANGER CTs must NOT be fused since open circuiting them may produce lethal hazardous voltages Protective Class IEC 61010 1 2001 Class unless otherwise specified in the equipment EN 61010 1 2001 documentation This equipment requires a protective conductor earth connection to ensure user safety Installation Category IEC 61010 1 2001 Installation Category III Ove
177. io Cor LV1 Ratio Cor 0 05 to 2 in steps of 0 01 LV2 Ratio Cor KBCH EN M E1 1 CHAPTER 1 Page 56 76 8 3 2 8 3 3 Phase compensation correction YyO Odeg Yd1 30deg Yd2 60deg Yd3 HV VectorCor LV1 VectorCor LV2 VectorCor Protection settings 0deg Service Manual Technical Description KBCH 120 130 140 Yd4 120deg Yd5 150deg Yy6 180deg Yd7 150deg Yd8 120deg Yd9 90deg Yd10 60deg Yd11 30deg YdyO Odeg 180deg Differential Protection settings Protection settings Id Id gt gt lof tOF REF Protection settings Io gt HV Io LVI Io LV2 Overflux Protection settings V f Trip Char V f Trip 1V f Trip V f Trip TMS V f Alarm tV f Alarm Auxiliary timers Auxiliary timers tAUXO tAUX1 tAUX2 tAUX3 tAUX4 tAUX5 tAUX6 tAUX7 RPP c2 c2 c2 we Setting range 0 1 to 0 5PU 5 to 20PU 10 to 50 0 1s to 14 4ks 4 Hours 0 05 to 1 0PU DT IDMT 1 5 to 3 V Hz 0 1 to 60s 1 to 63 1 5 to 3 V Hz 0 1 to 60s Setting range 0 to 14 4ks 4 Hours Step size 0 1 0 5 5 0 01 0 005 0 01 0 1 DT selected 1 IDMT selected 0 01 0 1 Step size 1 0 01 to 0 1 to 100s 1000s 10 000s 10 to 14 400s Service Manual Technical Description KBCH 120 130 140 8 4 8 5 8 6 8 7 tTEST tTapUp tTapDown Operating times Element Id gt Id gt gt I
178. ion KBCH EN M D11 Service Manual CHAPTER 2 Application Page 10 38 KBCH 120 130 140 2 1 2 140 Id 12 13 14 i e vectorial sum Ib In 12 13 14 2 ie scalar sum The basic pick up level of the low set differential element is variable between 0 11 and 0 5In in 0 1In steps where In is the rated current of the relay The setting chosen is dependant upon the item of plant being protected and by the amount of differential current that might be seen during normal operating conditions A setting of 0 2In is generally recommended when the KBCH is used to protect a transformer The initial bias slope from zero up to rated current is fixed at 2096 to ensure sensitivity to internal faults up to load current This allows for the 1596 mismatch which can occur at the limit of the transformer s tap changer range and an additional 596 for any CT ratio errors The slope is then increased to 8096 for bias currents above rated current This ensures stability under heavy through fault conditions which could lead to increased differential current due to asymmetric saturation of CT s No adjustment of the bias slopes is provided When protecting generators and other items of plant where shunt magnetising current is not present a lower differential setting can be used and 0 1 In would be more typical The biased low set differential protection is blocked under magnetising inrush conditions and optionally
179. ion If a unit transformer is directly connected at the generator terminals a number of considerations apply The unit transformer current for an LV system fault must be eliminated for large unit transformers in the Generator transformer differential protection by connecting the protection as a three ended scheme Practice has varied in the past and Figure 23 shows that the unit transformer CTs can be placed on the primary or secondary side of the unit transformer EAH S en Eme E 87 l 37 A 87 UT UT A GT D j 87 GT 23a 23b 87 GT Main Transformer protection 87 UT Unit Transformer protection Figure 23 Unit transformer configurations Placing the unit transformer in zone as figure 23a may not afford adequate protection for the unit transformer The unit transformer s relatively low rating and corresponding high impedance may mean that the main generator transformer differential protection will not be sensitive to faults within the unit transformer The degree of ratio compensation required for the unit transformer LV CT s may also be in excess of the KBCH ratio compensation setting range KBCH EN M D11 Service Manual CHAPTER 2 Application Page 32 38 KBCH 120 130 140 3 5 The unit transformer should generally have separate protection
180. ip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms Service Manual KBCH EN M C11 7 1 7 1 1 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 25 52 7 140 The following tests are all applicable to the KBCH 140 model It is recommended that these tests are performed with the phase compensation factors HV VectorCor LV1 VectorCor and LV2 VectorCor set toYyO Measurement checks To test the relay measurement functions a current of known value should be injected into each phase input With the CT ratios in the cells HV CT Ratio LV1 CT Ratio and LV2 CT Ratio in the SETTINGS menu set to the values of the line CT s the displayed measured values will be in the equivalent primary quantities HV LV1 winding measurement checks Connect the CT inputs to the relay as shown below OVERCURRENT TEST SET JO Figure 3 LV1 windings measurement check Go to the SETTINGS menu and set all the bits in the cell S1 Fn Links to O This disables all the protection elements so that the relay will not trip Then go to the MEASUREMENTS menu and step down one until the cell MS1 IaHV is displayed Inject rated current and ensure that the displayed value lies within 10 of the injected value By pressing
181. is approved for operation T 2 G outside an ATEX hazardous area It is however approved for connection to Increased Safety Ex e motors with rated ATEX protection Equipment Category 2 to ensure their safe operation in gas Zones 1 and 2 hazardous areas ATEX Potentially Explosive CAUTION Equipment with this marking is not itself Atmospheres directive suitable for operation within a potentially explosive 94 9 EC for equipment atmosphere Compliance demonstrated by Notified Body certificates of compliance Radio and Compliance demonstrated by compliance to the Low Telecommunications Terminal Voltage Directive 73 23 EEC amended by 93 68 EEC Equipment R amp TTE down to zero volts by reference to safety standards directive 95 5 EC Pxxxx EN SS B1 1 Safety Section Page 9 10 9 RECOGNIZED AND LISTED MARKS FOR NORTH AMERICA CSA Canadian Standards Association UL Underwriters Laboratory of America UL Recognized to UL USA requirements 2 UL Recognized to UL USA and CSA Canada requirements c e UL Listed to UL USA requirements UL Listed to UL USA and CSA Canada requirements e oe SE US LISTED PRODUCT IDENTITY XXXX Certified to CSA Canada requirements Pxxxx EN 55 1 1 10 10 Safety Section BLANK PAGE Service Manual KBCH EN M E11 KBCH 120 130 140 CHAPTER 1 Technical Description KBCH EN M E11 Service Manual KBCH 120 130 140
182. l Class 3 50mV 0 1 unbalance applied to all communication circuits IEEE ANSI specifications IEEE Surge Withstand Capacity SWC ANSI C37 90 1 1990 Reaff 1994 4 5kV fast transient and 2 5kV oscillatory Applied directly to each input and earth Applied directly across the auxiliary power supply opto isolated input and each output contact IEEE Radiated immunity ANSI C37 90 2 1995 25 1000MHz zero and 10096 square wave modulated Field strength 35V m Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 61 76 8 15 8 15 1 8 15 2 8 15 3 8 16 8 16 1 8 16 2 8 16 3 8 16 4 Atmospheric environmental Temperature IEC 68 2 1 IEC 68 2 2 1974 Storage and transit 25 C to 70 C Operating 25 C to 55 C Humidity IEC 68 2 3 1969 56 days at 93 relative humidity and 40 C Enclosure protection IEC 529 1989 IP50 Dust protected Mechanical environmental Vibration IEC 255 21 1 1988 Vibration Response Class 2 1g between 10Hz and 150Hz Vibration Endurance Class 2 2g between 10Hz and 150Hz Shock and bump IEC 255 21 2 1988 Shock response Class 2 10g 3 pulses Shock withstand Class 1 15g 3 pulses Bump Class 1 10g 1000 pulses Seismic IEC 255 21 3 1993 Class 2 Frequency range 1 35Hz Mechanical durability Loaded contact 10 000 operations minimum Unloaded contact 100 000 operations minimum KBCH EN M E11 CHAPTER 1 Page 62 76 8 17 Model
183. l port 3 3 1 3 2 3 3 3 4 3 5 3 5 1 3 5 2 3 6 4 1 4 2 4 3 4 4 5 1 5 1 34 5 1 5 1 5 1 5 1 5 1 Sls 5 1 Dus 5 2 5 2 1 5 2 2 5 2 3 5 2 4 3D 5 2 6 5 2 7 5 2 8 5 2 9 100 EXTERNAL CONNECTIONS Auxiliary supply Opto isolated control inputs Analogue inputs Output relays Alternative trip arrangements DC shunt trip AC no volt trip Serial communication port K BUS USER INTERFACE Front plate layout LED indications Keypad Liquid crystal display MENU SYSTEM Menu contents System data Fault records Measurements 1 Settings 1 Settings 2 Logic functions Input masks Relay masks Recorder Test Control Changing text and settings Entering passwords Changing passwords Entering text Changing function links Changing setting values Setting communication address Setting control input masks Setting relay output masks Resetting values and records Service Manual Technical Description KBCH 120 130 140 18 18 18 19 20 21 21 21 22 22 22 23 24 24 24 25 25 26 27 27 30 30 31 33 34 34 35 35 36 36 36 37 37 37 37 38 38 38 38 Service Manual Technical Description KBCH 120 130 140 5 2 10 Resetting TRIP LED indication 5 2 11 Alarm records 5 2 12 Default display LCD 5 3 5 3 1 5 3 2 5 3 3 5 3 4 5 3 5 5 3 6 6 6 1 6 2 6 3 6 4 6 5 6 6 6 6 1 6 6 2 6 7 6 8 6 9 6 10 7 1 7 2 7
184. l result in a high magnetising current Steady state m Im 2F m F Switch on at voltage zero No residual flux Figure 11 Under normal steady state conditions the magnetising current associated with the operating flux level is relatively small usually less than 196 of rated current However if a transformer winding is energised at a voltage zero with no remnant flux the flux level during the first voltage cycle 2 x normal max flux will result in core saturation and in a high non sinusoidal magnetising current waveform This current is commonly referred to as magnetising inrush current and may persist for several cycles The magnitude and duration of magnetising inrush current waveforms are dependant upon a number of factors such as transformer design size system fault level point on wave of switching number of banked transformers etc Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 17 38 2 2 1 cycle Figure 12 Inrush currents to a transformer star winding seen by differential elements after star delta phase correction or to a delta winding with no phase correction Figure 12 shows typical magnetising inrush wave forms seen by differential protection elements for a three phase transformer As can be seen from these typical examples the magnetising inrush wave forms are characterised by the presence of a perio
185. labels are provided in a bag for some equipment 2 HEALTH AND SAFETY The information in the Safety Section of the equipment documentation is intended to ensure that equipment is properly installed and handled in order to maintain it in a safe condition It is assumed that everyone who will be associated with the equipment will be familiar with the contents of that Safety Section or this Safety Guide When electrical equipment is in operation dangerous voltages will be present in certain parts of the equipment Failure to observe warning notices incorrect use or improper use may endanger personnel and equipment and cause personal injury or physical damage Before working in the terminal strip area the equipment must be isolated Proper and safe operation of the equipment depends on appropriate shipping and handling proper storage installation and commissioning and on careful operation maintenance and servicing For this reason only qualified personnel may work on or operate the equipment Qualified personnel are individuals who e are familiar with the installation commissioning and operation of the equipment and of the system to which it is being connected e are able to safely perform switching operations in accordance with accepted safety engineering practices and are authorised to energize and de energize equipment and to isolate ground and label it e are trained in the care and use of safety apparatus in accordance wit
186. le 29 below Input to Block Input Mask Overflux trip INP Blk V f Trp Overflux alarm INP Blk V f Alm Table 29 To perform the overflux blocking tests one or more opto isolated input has to be allocated for each blocking function When the allocated opto input is energised as in section 11 1 the appropriate protection function will be blocked KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 42 52 KBCH 120 130 140 12 3 12 4 For the overflux trip function energise the appropriate opto input and repeat test 11 2 at the higher voltage setting V fxsettingx1 05 and check that the element is correctly blocked and does not operate For the overflux alarm function energise the appropriate opto input and repeat test 11 1 at the higher voltage setting and check that the element is correctly blocked and does not operate Auxiliary timers The auxiliary timers present in the relay should only be tested if they are to be used in the intended application and if the timer settings are not so high that testing is impractical It should be noted that the timer settings can go up to 4 hours Which opto isolated inputs are configured to initiate which timers can be found under the INPUT MASKS menu heading These are listed in table 30 Input Mask Description INP Aux 0 Input to initiate tauxO INP Aux 1 Input to initiate taux INP Aux 2 Input to initiate
187. ll RLY Id gt A See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relays can be monitored as described in section 4 3 Connect the relay as shown below ensuring that the diode is able to withstand the applied current OVERCURRENT TEST SET Figure 7 Magnetising inrush restraint circuit With switch S1 closed and switch S2 open inject 4xIs where 1 1 gt Ratio Cor Id gt is the low set setting found under the SETTINGS menu heading HV Ratio Cor is the CT ratio correction factor which is used to compensate for a mismatch in currents due to the line side current transformer ratios This is found in the cell HV RatioCor in the SETTINGS menu heading Ensure that the relay selected for the low set differential protection trips Then open switch S1 and close switch S2 and inject 4xIs Ensure that the relay selected for the low set differential protection does not trip thus indicating that the magnetising inrush detector has successfully blocked the low set differential protection Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 37 52 11 OVERFLUX PROTECTION The overflux protection has two independent elements one which is used to give an alarm indication and one which is used to cause a trip Note that the yellow alarm LED on the relay is used to indicate an internal fault in the relay and not a pr
188. ll require attention It may be left running provided the error does not cause any grading problems To return the relay to a serviceable state the initial factory configuration will have to be reloaded and the relay recalibrated It is recommended that the work be carried out at the factory or entrusted to a recognised service centre Setting error alarm A SETTING alarm indicates that the area of non volatile memory where the selected protection settings are stored has been corrupted The current settings should be checked against those applied at the commissioning stage or any later changes that have been made If a personal computer PC is used during commissioning then it is recommended that the final settings applied to the relay are copied to a floppy disc with the serial number of the relay used as the file name The setting can then be readily loaded back into the relay if necessary or to a replacement relay No service alarm This alarm flag can only be observed when the relay is in the calibration or configuration mode when the protection program will be stopped Fault flags will not reset These flags can only be reset when the flags Fn are being displayed or by resetting the fault records see Section 5 2 10 Records Problems with event records Fault records will only be generated if RLY3 is operated as this relay is the trigger to store the records Fault records can be generated in response to another protection
189. magnetising inrush detector blocks the differential algorithm integral part of algorithm Operation of any 5th harmonic overflux detector 5th Harmonic enabled by function link S9 block its own phase differential algorithm integral part of algorithm In addition the 5th harmonic overflux signal starts a timer tOF the output of which is directed to a OF Alarm mask to indicate an overflux condition exists KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 44 76 KBCH 120 130 140 6 2 6 3 RLY Trip Id gt Reset Ja P 5th Harmonic tOF RLY Trip OF Alarm Figure 6 3 Differential low set trip logic Differential high set trip logic The differential high set trip logic is shown in Figure 6 4 If selected by link S2 the output from the differential algorithm Id gt gt sets a latch The output of the latch is directed to the Trip Id gt gt mask This will result in the output relay s designated by the mask being energised The t100ms timer ensures a minimum dwell time of 100ms The high set is not restrained by the magnetising inrush or over excitation detectors Figure 6 4 Differential high set trip logic Restricted earth fault trip logic The restricted earth fault REF trip logic is shown in Figure 6 5 The REF for the HV LV1 and LV2 windings are enabled by function links S3 4 and S5 respectively and the outputs are directed to Trip Io HV
190. measurement check LV2 and LV3 winding measurement check Phase Compensation Test Low set bias characteristic Magnetising inrush restraint circuit Figure 8 Figure 9 Fifth harmonic blocking circuit Figure 10 REF Primary injection test set up Figure 1 1 Typical external connections for KBCH 120 Figure 12 Typical external connections for KBCH130 Figure 13 Typical external connections for KBCH140 Figure 14 Typical restricted earth fault connections for KBCH12 KBCH EN M C1 1 CHAPTER 3 Page 3 52 32 34 36 37 37 37 38 39 41 41 41 42 42 43 44 45 45 47 47 48 14 19 25 26 32 34 36 38 39 45 48 49 50 51 KBCH EN M C1 1 CHAPTER 3 Service Manual Commissioning Instructions Page 4 52 KBCH 120 130 140 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 5 52 T 1 1 COMMISSIONING PRELIMINARIES When commissioning a K series relay for the first time the engineer should allow an hour to get familiar with the menu Please read section 1 1 which provides simple instructions for negotiating the relay menu using the push buttons and 0 on the front of the relay Individual cells can be viewed and the settable values can be changed by this method If a portable PC is available together with a K Bus interface unit Kitz 101 102 and the Courier access software then the menu can be viewed one page at a time to display
191. n indicator 3 Light Emitting Diodes internally powered 16 character by 2 line Liquid Crystal Display with backlight Communication port Language Courier Transmission Synchronous RS485 voltage levels Format HDLC Baud Rate 64k bit per second K Bus Cable Screened twisted pair K Bus cable length 1000m of cable K Bus Loading 32 units multidrop system Current transformer requirements See Application section for details REF requirements See Application section for details High voltage withstand Dielectric withstand IEC 255 5 1977 2 0kVrms for one minute between all terminals and case earth 2 0kVrms for one minute between all terminals of independent circuits including contact circuits 1 5kVrms for one minute across open contacts of output relays 1 7 1 0kVrms for one minute across open contacts of the watch dog relay Impulse IEC 255 5 1977 5kV peak 1 2 50ys 0 5 between i all terminals connected together and case earth ii independent circuits iii terminals of the same circuit except output contacts Insulation resistance IEC 255 5 1977 The insulation resistance is greater than 100 Service Manual Technical Description KBCH 120 130 140 8 13 8 13 1 8 13 2 8 13 3 8 13 4 8 13 5 8 13 6 Electrical environmental DC supply interruptions IEC 255 11 1979 The relay can withstand a 10ms interruption in the auxiliary voltage with up to 4 inputs energised The relay c
192. nch German or Spanish KBCH EN M D11 Service Manual CHAPTER 2 Application Page 8 38 KBCH 120 130 140 2 1 1 APPLICATION OF INDIVIDUAL PROTECTIVE FUNCTIONS Overall Differential Protection 87 In applying the well established principles of differential protection to transformers a variety of considerations have to be taken into account These include compensation for any phase shift across the transformer possible unbalance of signals from current transformers either side of windings and the effects of the variety of earthing and winding arrangements In addition to these factors which can be compensated for by correct application of the relay the effects of normal system conditions on relay operation must also be considered The differential element must be blocked for system conditions which could result in maloperation of the relay such as high levels of magnetising current during inrush conditions or during transient overfluxing In traditional transformer differential schemes the requirements for phase and ratio correction were met by the application of external interposing current transformers as a secondary replica of the main transformer winding arrangements or by a delta connection of main CT s phase correction only Within the KBCH software interposing CT s ICT s are provided where the same setting criteria apply The advantage of having replica interposing CT s in software is that it gives the KBCH the flexibility to ca
193. nd protection alarms The monitoring circuits within the relay continuously perform a self test routine Any detected loss of operation in the first instance initiates a reset sequence to return the equipment to a serviceable state The voltage rails are also supervised and the processors are reset if the voltage falls outside their working range Should the main processor fail and not restart the watchdog relay will provide an alarm This relay will also signal an alarm on loss of the auxiliary energising supply to the relay In addition the memory of the relay is checked for possible corruption of data and any detected errors will result in an alarm being generated An ALARM LED indicates several states which can be identified by viewing the alarm flags that are to be found towards the end of the SYSTEM DATA column of the menu and consist of seven characters that may be either 1 or O to indicate the set and reset states of the alarm The flags offer the following indications KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 16 76 KBCH 120 130 140 2 13 Alarm Flags Indication 6 5 4 3 2 0 Unconfig Protection not operational needs to be configured Uncalib Protection is running uncalibrated calibration error 1 Setting Protection is running possible setting error No service Protection is out of service 1 No opto Protection not sampling opto inputs 1 No S Logic Protection no
194. ne for the LV1 side found in the cell LV Ratio Cor and one for the LV2 side found in the cell LV2 Ratio Cor All of these are found under the SETTINGS menu heading The appropriate CT ratio factor should be used to calculate the current to inject depending upon whether it is being injected into the HV LV1 or the LV2 inputs Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 21 52 Current Level Pick up 0 9 x Is to 1 1 xIs Drop off 0 9 x Pick up to 1 0 x Pick up Table 17 6 2 2 6 2 3 Repeat the above test for each of the remaining phases on the HV side and for all three phases on the LV1 side and all three on the LV2 side These are listed in table 18 below Input Terminals IA HV 21 22 IB HV 23 24 IC HV 25 26 IA 77 78 IB LV1 79 80 LV 81 82 IA LV2 69 70 IB LV2 71 72 IV LV2 73 74 Table 18 Note As the CT inputs to each phase have been verified by both the measurement checks and the low set differential trip checks it is only necessary to check the operating time and the high set current sensitivity for each phase element on one side of the transformer only Low set element operating time Connect the relay as in section 6 2 1 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is appli
195. netic disturbance the 5th harmonic blocking element can be routed to an output contact via an associated timer Operation of this element could be used to give an alarm to the network control centre If such alarms are received from a number of transformers they could serve as a warning of geomagnetic disturbance so that operators could take some action to safeguard the power system Alternatively this element can be used to initiate tripping in event of prolonged pick up of a 5th harmonic measuring element It is not expected that this type of overfluxing condition would be detected by the AC overfluxing protection This form of time delayed tripping should only be applied in regions where geomagnetic disturbances are a known problem and only after proper evaluation through simulation testing Required settings IDMT DT V f element The pick up for the overfluxing elements will be dependant upon the nominal core flux density levels Generator transformers are generally run at higher flux densities than transmission and distribution transformers and hence require a pick up setting and shorter tripping times which reflect this Transmission transformers can also be at risk from overfluxing conditions and withstand levels should be consulted when deciding upon the required settings A setting range of 1 5 to 3 Volts Hz is provided Example A required setting of 1 05 pu overfluxing factor with a 110V VT secondary on a 50Hz system would require a
196. ng time 5 3 Restricted Earth Fault Protection KBCHNEN M C1 1 CHAPTER 3 Page 1 52 U 10 10 11 11 11 11 12 12 13 13 14 14 14 14 15 15 16 16 17 17 KBCH EN M C1 1 CHAPTER 3 Page 2 52 5 3 1 current sensitivity HV side gt HV 5 3 2 element HV side operating time 5 3 3 current sensitivity LV1 side gt LV1 5 3 4 element LV1 side operating time 6 KBCH 130 6 1 Measurement checks 6 1 1 HV LV1 LV2 winding measurement checks 6 1 2 Frequency measurement check 6 2 Differential Protection 6 2 1 Low set element current sensitivity Id gt 6 2 2 Low set element operating time 6 2 3 High set element current sensitivity Id gt gt 6 2 4 High set element operating time 6 3 Restricted Earth Fault Protection 6 3 1 REF current sensitivity HV side Io HV 6 3 2 element HV side operating time 6 3 3 current sensitivity LV1 side gt LV1 6 3 4 REF element LV1 side operating time 6 3 5 REF current sensitivity LV2 side gt LV2 6 3 6 REF element LV2 side operating time 7 KBCH 140 7 1 Measurement checks 7 1 1 HV winding measurement checks 7 1 2 1 2 LV3 winding measurement check 7 1 3 Frequency measurement check 7 2 Differential Protection 7 2 1 Low set element current sensitivity Id gt 7 2 2 set element operating time 7 2 3 High set element current sensitivity 1 gt gt 7 2 4 High set elemen
197. o V f Note Accuracy KBCH EN M E1 1 CHAPTER 1 Page 57 76 0 5 to 10s 0 1 0 5 to 10s 0 1 0 5 to 10s 0 1 Operating time Disengagement time typically 30 to 35ms typically 50ms typically 15ms typically 30ms typically 20 to 40ms typically 25ms typically 30ms A minimum contact dwell time of 100ms is incorporated on the protection trip functions such that if a fault condition is removed within the 100ms then the disengagement times will be extended by the dwell The accuracy under reference conditions is 7 596 Opto isolated inputs Capture time Release time 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz 12 5 2 5ms at 50Hz 10 4 2 1ms at 60Hz Maximum series lead resistance 5kQ 2 optos in parallel Maximum ac induced loop voltage 50Vrms thermal limit Maximum capacitance coupled ac voltage 250Vrms via 0 1UF Contacts Output relays Make Carry Break Watchdog relays Make Carry Break Eight single make 30A and carry for 0 2s 5A continuous DC 50W resistive 25W inductive L R 0 04s AC 1250VA 5A maximum Subject to maxima of 5A and 300V One make and one break 10A and carry for 0 2s 5A continuous DC resistive KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 58 76 KBCH 120 130 140 8 8 8 9 8 12 8 12 1 8 12 2 8 12 3 15W inductive L R 0 04s AC 1250 5A maximum Subject to maxima of 5A and 300V Operatio
198. o O except bit 3 S1 Enable Io HV which should be set to 1 This will ensure that only the REF protection on the high voltage side of the transformer is enabled The relays selected for the REF protection on the HV side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io gt HV Each bit in this cell which is set to 1 corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 27 amp 28 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 20 Current Level Pick up 0 9 x Is to 1 1 xIs Drop off 0 9 x Pick up to 1 0 x Pick up Table 20 In table 20 above Is corresponds to the settings for the earth fault element These are found in the cells Io2 HV Io21V1 and Io gt LV2 in the SETTINGS menu depending upon which winding is being tested 6 3 2 element HV side operating time Connect the relay as in section 6 3 1 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test se
199. o on Follow the instructions in Section 5 2 to exit from the setting change Changing function links Select the page heading required and step down one line to FUNCTION LINKS and press either the or 7 to put the relay in the setting change mode A cursor will flash on the bottom line at the extreme left position This is link F as indicated by the character printed on the front plate under the display Press the F key to step along the row of links one link at a time until some text appears on the top line that describes the function of a link The key will change the link to a 1 to select the function and the key will change it to a O to deselect it Not all links can be set some being factory selected and locked The links that are locked in this way are usually those for functions that are not supported by a particular relay when they will be set to 0 Merely moving the cursor past a link position does not change it in any way Changing setting values Move through the menu until the cell that is to be edited is displayed Press the or key to put the relay into the setting change mode A cursor will flash in the extreme left hand position on the bottom line of the display to indicate that the relay is ready to have the setting changed The value will be incremented in single steps by each momentary press of the key or if the key is held down the value will be incremented with increasing rapidity un
200. o response to remote control commands Check that the relay is not inhibited from responding to remote commands by observing the system data function link settings If so reset as necessary a password will be required System data function links cannot be set over the communication link if the remote change of settings has been inhibited by setting system data function link SDO to 0 Reset SDO to 1 manually via the user interface on the relay first Output relays remain picked up Relays remain picked up when de selected by link or mask If an output relay is operated at the time it is de selected either by a software link change or by de selecting it in an output mask it may remain operated until the relay is powered down and up again It is therefore advisable to momentarily remove the energising supply after such changes Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 67 76 10 MAINTENANCE 10 1 Remote testing 10 1 1 10 1 2 10 1 3 10 2 10 2 1 10 2 2 10 2 3 K Series Midos relays are self supervising and so require less maintenance than earlier designs of relay Most problems will result in an alarm so that remedial action can be taken However some periodic tests could be done to ensure that the relay is functioning correctly If the relay can be communicated with from a remote point via its serial port then some testing can be carried out without actually visiting the site
201. o select the column containing the setting or text cell that is to be changed Then with the F key step down the column until the contents of the cell are displayed Press the or key to put the relay into the setting mode which will be indicated by a flashing cursor on the bottom line of the display If the cell is a read only cell then the cursor will not appear and the relay will not be in the setting mode To escape from the setting mode TO ESCAPE FROM THE SETTING PROCEDURE WITHOUT EFFECTING ANY CHANGE HOLD THE 0 KEY DEPRESSED FOR ONE SECOND THE ORIGINAL SETTING WILL BE RETAINED To accept the new setting Press the F key until the display reads Are You Sure YES NO 1 Press the 0 key if you decide not to make any change 2 Press key if you want to further modify the data before entry 3 Press the to accept the change This will terminate the setting mode 5 2 1 Entering passwords The and keys can be used to select a character at the position of the cursor When the desired character has been set the F key can be given a momentary press to move the cursor to the position for the next character The process can then be repeated to enter all four characters that make up the password When the fourth character is acknowledged by a momentary press of the F key the display will read Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 37 76 5 2 2 5 2 3 5 2
202. oard Remove the six screws on the front plate Remove the front plate Lever the top edge of the analogue input daughter board forwards to unclip it from its mounting Then pull the pcb upwards to unplug it from the connector at its lower edge Replace with a new analogue input daughter board and assemble in the reverse order Replacing the main processor board This is the pcb at the extreme left of the module when viewed from the front To replace this board First remove the screws holding the side screen in place There are two screws through the top plate of the module and two more through the base plate Remove screen to expose the pcb Remove the two retaining screws one at the top edge and the other directly below it on the lower edge of the pcb Separate the pcb from the sockets at the front edge of the board Note that they are a tight fit and will require levering apart taking care to ease the connectors apart gradually so as not to crack the front pcb card The connectors are designed for ease of assembly in manufacture and not for continual disassembly of the unit Reassemble in the reverse of this sequence making sure that the screen plate is replaced with all four screws securing it Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 69 76 10 3 4 Replacing the DSP board 10 3 5 10 3 6 10 3 7 10 3 8 This is the second board in from the left hand side of the module
203. odels Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions 14 1 KBCH 120 130 140 Page 45 52 14 REF PRIMARY INJECTION TESTS Primary injection tests will be used to check that the current transformers for the restricted earth fault scheme are correctly connected Correct set up check Before commencing any primary injection tests it is essential to ensure that the circuit is dead isolated from the remainder of the system and that only those earth connections associated with the primary injection test equipment are in position This test should only be performed for each REF input that has a neutral CT connected to it If there is no neutral CT then there is no need to perform the test on that particular input Figure 10 shows the connections for the LVlinput This and the other restricted earth fault inputs are listed below REF Input Relay Terminals HV 27 28 LV 83 84 LV2 75 76 Table 31 Note that the LV2 winding does not appear on the KBCH120 and will only appear on the 130 and 140 models if they are configured to have the LV2 winding connected Connect the relay shown below Primary Injection Test Set Stabilising Resistor S e 04 S 65 P T 67 S Tem Temporary Connection oo re KBCH 120 LS 6 21 Df LI cr LJ LJ LJ WJ Figure 10 REF Primary injection test set up
204. oduced Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 23 38 2 3 4 1 2 3 4 2 2 3 4 3 Select suitable Revise Vk Vs ratio 2 3 4 1 Vk Vs ratio amp K factor 5 from figure 16 Calculate Vs 2 3 4 2 Calculate Vk required Check Metrosil Requirements from formula 4 from formula 2 from formula 5 Calculate Is Calculate Rs 2 3 4 7 Figure 17 Restricted earth fault setting procedure VK VS ratio From the operating time curve Figure 16 a minimum Vk Vs ratio should be selected to give satisfactory average internal fault operating times It is recommended that this ratio should be at least 4 0 to give average operating times of two cycles for a 50Hz system Stability voltage setting From figure 16 the required K factor can be read off once the minimum Vk Vs ratio has been decided The required K factor will be 0 5 when the target Vk Vs ratio is 4 0 Once the required K factor has been established equation 3 can be applied to determine the required stability voltage setting CT kneepoint voltage requirement Once the stability voltage setting has been determined the REF CT kneepoint voltage requirement can be calculated using the Vk Vs ratio that was decided upon in section 2 3 4 1 If the REF CT kneepoint voltage requirement is less than the required voltage for the biased differential protection see section 4 the CT s must be designed to meet the higher requi
205. of seven characters that may be either 1 or O to indicate the set and reset states of the alarm The control keys perform for this menu cell in the same way as they do for Function Links The cell is selected with the function key F and the relay then put in the setting mode by pressing the key to display the cursor The cursor will then be stepped through the alarm word from left to right with each press of the F key and text identifying the alarm bit selected will be displayed Alarm Flags Indication 6 5 4 3 2 0 1 Unconfig protection not operational needs to be configured Uncalib protection is running uncalibrated calibration 1 error Setting protection is running possible setting error 1 No Service protection is out of service No Opto protection not sampling opto inputs No S Logic Protection not operational scheme logic not running 1 DSP Faulty Protection not operational Fault detected in DSP For the above listed alarms the ALARM LED will be continuously lit However there is another form of alarm that causes the ALARM LED to flash and this indicates that the password has been entered to allow access to change protected settings within the relay This is not generally available as a remote alarm and the alarm flags do not change No control will be possible via the keypad if the Unconfigured alarm is raised because th
206. on Vs Is Rs 2 Where Vs Stability voltage setting Is Relay current setting Stabilising resistance Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 21 38 In equation 2 the resistance of the relay element itself has been ignored since the resistance of a modern electronic relay is much lower than the external resistance required for through fault stability The general stability voltage requirement is described by equation 3 which expresses the required stability voltage setting Vs in relation to the relay differential voltage that is given by equation 1 for an external fault The relationship is expressed in terms of a required stability factor K Vs gt K If Rct 2RI RB 3 The assumption that one CT is completely saturated for an external fault does not describe what actually happens when asymmetric CT saturation occurs The CT that saturates will only saturate during parts of each current wave form cycle This means that the spill current wave form seen by the restricted earth fault element will be highly non sinusoidal The sensitivity of the relay element to non sinusoidal spill wave forms for through faults will be a function of the relay element frequency response its operating speed the differential voltage setting Vs and the wave shapes Relay frequency response and operating speed are factors which are inherent to the relay design Spill current wave shapes will be rel
207. on lines Low system frequency Generator excitation at low speed with AVR in service Geomagnetic disturbance Low frequency earth current circulation through a transmission system The initial effects of overfluxing will be to increase the magnetising current for a transformer This current will be seen as a differential current lf it reaches a high level without a waveshape which would cause operation of the inrush blocking system there would be a risk of differential protection tripping Persistent overfluxing may result in thermal damage or degradation of a transformer as a result of heating caused by eddy currents that may be induced in non laminated metalwork of a transformer The flux levels in such regions would normally be low but excessive flux may be passed during overfluxed operation of a transformer The following protection strategy is proposed to address potential overfluxing conditions Maintain protection stability during transient overfluxing Ensure tripping for persistent overfluxing In most applications the recommended minimum differential trip threshold for KBCH its filtering action and possible operation of the inrush detector will ensure stability of the differential element If more difficult situations exist the KBCH relay is offered with a 5th KBCH EN M D11 Service Manual CHAPTER 2 Application Page 26 38 KBCH 120 130 140 2 4 3 2 4 4 harmonic differential current blocking facility This facility
208. operating if RLY3 or RLY7 are operated by one of its trip contacts via an auxiliary input This will result in the fault values as measured by the relay being stored at the instant RLY3 and RLY7 resets The flag display will include a flag to identify the auxiliary input that initiated the record Fault currents recorded are lower than actual values as the fault is interrupted before measurement is completed Few fault records can be stored when changes in state of logic inputs and relay outputs are stored in the event records These inputs and outputs can generate a lot of events for each fault occurrence and limit the total number of faults that can be stored Setting System Dota Link 7 to O will turn off this feature and allow the maximum number of fault records to be stored Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 65 76 9 4 2 9 5 9 5 1 95 2 The event records are erased if the auxiliary supply to the relay is lost for a period exceeding the hold up time of the internal power supply Events can only be read via the serial communication port and not on the LCD Any spare opto inputs may be used to log changes of state of external contacts in the event record buffer of the relay The opto input does not have to be assigned to a particular function in order to achieve this The oldest event is overwritten by the next event to be stored when the buffer becomes full When a Mas
209. otection function alarm Overflux alarm sensitivity In the SETTINGS menu heading go to cell S1 Fn links and set all bits to except bit 8 S1 Enable OF Alm which should be set to 1 This will ensure that only the overflux alarm is enabled The relay selected to operate for this protection function can be found under the RELAY MASKS heading in the cell RLY V f Alarm Each bit in this cell which is set to lcorresponds to an output relay which is selected for this function For a fuller description of the configuration of output relays see section 2 4 Configure the equipment so that an AC voltage can be applied to terminals 17 and 18 starting a timer when the voltage is applied and stopping the timer when the output relay energises For a duration greater than the time set in the cell t V f Alarm found in the SETTINGS menu heading apply a voltage of settingxfx0 95 volts to terminals 17 and 18 where setting V f alarm setting found in the cell S1 V f Alarm and f system frequency Ensure that the selected output relay does not energise Next apply a voltage of V settingxfx1 05 volts to terminals 17 and 18 and ensure that the selected output relay does energise and that the time is within 20 of the time set in the cell t V f Alarm found in the SETTINGS menu heading Overflux trip sensitivity In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 7 S1 Enable O
210. ound under the RELAY MASKS heading The phase A relay will be found in the cell RLY Id A phase B relay in cell RLY Id gt gt B and phase C in RLY Id gt Each bit in these cells which is set to 1 corresponds to an output relay which is selected for this function See section 2 4 for a fuller explanation of the configuration of the output relays Operation of the relays can be monitored as described in section 4 3 The relay should be connected so that current can be injected through terminals 21 amp 22 In addition the output relays should be connected to trip the test set and to stop a timer IT IS IMPORTANT TO TRIP THE TEST SET IN ORDER TO AVOID SUSTAINED APPLICATION OF EXCESSIVE CURRENTS The timer should be started when the current is applied to the relay As the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied Two tests have to be performed for his particular protection function These are listed in table 14 Id Trip Id gt No Trip 1 1x Is 0 9x Is Table 14 Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 17 52 5 2 4 5 3 5 3 1 The first test to be performed is at the higher current level to check that the instantaneous element operates Id gt gt In table
211. oup 1 Overflux alarm relay no trip Overflux alarm relay trip Operating time 11 2 Overflux trip sensitivity Overflux alarm relay no trip Overflux alarm relay trip Operating time 11 3 Overflux fifth harmonic blocking I injected tick Low set differential no trip Low set differential trip 11 4 Overflux fifth harmonic relay operating time S1 tOF Operating time S Service Manual Commissioning Test Results KBCH 120 130 140 Setting Group 2 if required V V m 5 V V m 5 tick 52 tOF 5 Service Manual Commissioning Test Results KBCH 120 130 140 12 12 1 12 2 12 3 12 4 12 5 SELECTIVE LOGIC Opto input checks tick LO L4 L1 L5 L2 L L3 L7 Controlled blocking of overflux protection Overflux trip successfully blocked Oveflux alarm successfully blocked Auxiliary timers KBCH EN 11 CHAPTER 4 Page 19 22 tick tick Setting Measured value Auxiliary timer O Auxiliary timer 1 Auxiliary timer 2 Auxiliary timer 3 Auxiliary timer 4 Auxiliary timer 5 Auxiliary timer 6 Auxiliary timer 7 Change of setting group Change to setting group 2 Remote control of transfomer tap changer Tap up Tap down tick KBCH EN M C1 1 CHAPTE
212. p 68 77 amp 78 25 amp 26 69 amp 70 79 amp 80 27 amp 28 71 amp 72 81 amp 82 63 amp 64 73 amp 74 83 amp 84 Table 3 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 8 52 KBCH 120 130 140 1 5 Earthing 1 6 1 7 1 8 Check that the case earthing connection above the rear terminal block is used to connect the relay to a local earth bar and where there is more than one relay the copper earth bar is in place connecting the earth terminals of each case in the same tier together Check that the local earth bar is solidly connected to the cubicle earth terminal Main current transformers DO NOT OPEN THE SECONDARY CIRCUIT OF A LIVE CT SINCE THE HIGH VOLTAGE PRODUCED MAY BE LETHAL TO PERSONNEL AND COULD DAMAGE THE INSULATION Test block If the MMLG test block is provided the connections should be checked to the scheme diagram particularly that the supply connections are to the live side of the test block coloured orange with the terminals allocated odd numbers 1 3 5 7 etc The auxiliary supply is normally routed via terminals 13 and 15 but check this against the schematic diagram for the installation Insulation Insulation tests only need to be done when required Isolate all wiring from the earth and test the insulation with an electronic or brushless insulation tester at a dc voltage not exceeding 1000V Terminals of the same circuits should be tempo
213. perated high impedance circuit set to operate at a voltage slightly higher than that developed by the current transformers under maximum external fault conditions i e one CT fully saturated Harmonics particular third are rejected by basing the measurement on the fundamental frequency fourier magnitude Overflux protection function Power frequency overvoltage causes both an increase in stress on the insulation and a proportionate increase in the working flux The latter effect causes an increase in the iron loss and a disproportionate increase in magnetising current In addition flux is diverted from the core into the steel structural parts and in particular under extreme over excitation into the core bolts These normally carry very little flux but under these conditions they may be rapidly heated to a temperature which causes their insulation to fail and eventually causes the main insulation to fail Over excitation is caused by an increase in voltage or a reduction in frequency It follows therefore that transformers can withstand an increase in voltage with a corresponding increase in frequency but not an increase in voltage with a decrease in frequency KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 14 76 KBCH 120 130 140 2 6 2 7 2 8 Operation cannot be sustained when the ratio of voltage to frequency with these quantities expressed as per unit of rated values exceeds unity by more than a small amount
214. pplication CHAPTER 2 KBCH 120 130 140 Page 11 38 Example 1 Two winding transformer KBCH1 20 20MVA Transformer Dyn1 33 11kV HV CT ratio 400 1 LV CT ratio 1500 1 Dyn 400 1 20MVA 33 11kV 1500 1 350A 1050A 0 30 KBCH Relay YyO 0 Differential 0 11 Software ICT HA element na Software ICT Figure 4 Application of a KBCH120 to a two winding transformer Phase correction is applied as detailed in section 2 1 3 with the YyO option chosen for the HV CT s and with the Yd11 option chosen for the LV CT s 20 MVA 33kV full load current 33kV 43 350 Amps Secondary current 350 x 1 400 0 875 Amps 20 MVA 11kV full load current kV A8 1050 Amps Secondary current 1050x 1 1500 0 7 Amps Each of these secondary currents are corrected to relay rated current in this case 1A HV ratio correction factor 1 0 875 1 14 Setting applied to relay LV ratio correction factor 1 0 7 1 43 Setting applied to relay When a Star Delta software interposing CT is chosen no additional account has to be taken for the 4 3 factor which would be introduced by the delta winding This is accounted for by the relay Further examples for applying ratio compensation in KBCH are given in Appendix C Phase correction and zero sequence current filtering To compensate for any phase shift between two windings of a transformer it is necessary to provide phase correction
215. ransformers e g winding inter turn faults or core lamination faults These devices are connected to directly trip the breaker in addition to operating auxiliary relays for flagging purposes WT Winding Temp B Buchholz OT Oil Temp 64 87 Biased Diff 51N Standby E F 51 IDMT overcurrent 24 Overfluxing relay Figure 2 Typical protection package for a Generator transformer The protection package for a generator transformer is similar to that for any other large transformer High speed protection is provided for phase to phase faults by the provision of a biased differential relay In addition for large generators the transformer is commonly included within an overall second main differential arrangement which incorporates the generator and transformer within the overall zone of protection Earth fault protection is provided by a restricted earth fault relay on the star winding Overfluxing protection is commonly applied to generator circuits to prevent generator or transformer damage from prolonged overfluxing conditions Other protection devices will again complement the relay protection package Auto transformers are commonly used to couple EHV and HV power networks if the ratio of their voltages is moderate The protection arrangements for an auto transformer are similar in most respects to the protection of a two winding transformer Differential protection can be provided by high impedan
216. rarily strapped together Service Manual KBCH EN M C11 2 1 2 2 Commissioning CHAPTER 3 Instructions KBCH 120 130 140 Page 9 52 2 COMMISSIONING TEST NOTES All the tests in these instructions should be carried out unless stated otherwise Section 5 is applicable to the KBCH 120 model section 6 to the KBCH 130 and section 7 to the KBCH 140 model Sections 3 4 8 9 10 11 12 13 and 14 are applicable to all relay models The values quoted in these instructions make no allowance for errors due to tolerances of measuring equipment or site conditions Note 1 The relay has internal transformer phase compensation which can be set in the SETTINGS menu depending on the transformer winding configuration As this compensation is based on manipulating three phase currents it is advised that for all secondary injection commissioning tests and checks the cells HV VectorCor LV1 VectorCor and LV2 VectorCor in the SETTINGS 1 or SETTINGS 2 menu are set to YyO unless stated otherwise This is because all the tests are performed with single phase rather than three phase currents Note that the LV2 VectorCor will only appear on the KBCH 130 and 140 models 2 All the current settings in the relay are in per unit values and therefore should be multiplied by 5 if the relay is rated at 5 amps In 5A to convert to the equivalent actual value 3 all the commissioning tests are complete the function link cells 51 Fn Link
217. red to the degree of CT saturation that could occur in the presence of a transient DC component with a slow rate of decay This is why better CT s are required for high X R applications As can be seen the KBCH CT requirements are specific to two categories one for X R ratios up to 40 representative of transformer differential applications and the second for X R ratios up to 120 representative of generator circuit applications A reduction in the required CT Vk requirements can not be recommended on the basis of reduced through fault current for the reasons given above On the assumption that the level of CT saturation will be proportional to If x X R the CT Vk factor for a generator circuit can be reduced from 48 depending on the actual X R in proportion to 120 The following formula would then apply Vk gt 24 24 X R 40 120 40 Rct 2R1 Voltage transformer requirements When using the V f overfluxing protection element a voltage transformer signal is required from the source side of the protected transformer i e the side from which the overfluxing condition may be imposed To cover all applications a phase to phase Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 37 38 connection is used If phase to neutral volts were used there is a possibility that fast IDMT V f tripping times could occur due to voltage rises on healthy phases during earth faults With multiple earthed systems the h
218. rement This means that the REF application procedure so far must be repeated using higher Vk Vs ratios until the REF CT kneepoint voltage requirement matches the requirement of the biased differential protection If the required REF CT kneepoint voltage cannot be met for some reason the application procedure so far must be repeated using lower Vk Vs ratios until the REF CT kneepoint voltage requirement can be met This situation might arise when using CT s that are already in situ The penalty for using a lower Vk Vs ratio is that the protection average operating times could be longer KBCH EN M D11 Service Manual CHAPTER 2 Application Page 24 38 KBCH 120 130 140 2 3 4 4 Required current setting and CT magnetising current 2 3 4 5 2 3 4 6 To achieve the required primary operating current a suitable setting 15 must be chosen for the relay The recommended primary operating current for REF protection is usually determined by the minimum fault current available for operation Typical settings for REF protection are Solidly earthed system 60 of winding rated current Resistance earthed system 10 2596 minimum earth fault current for fault at the transformer terminals The primary operating current Ip in secondary terms is a function of the CT ratio the relay operating current Is the number of CT s in parallel with the relay element n and the magnetising current of each CT Ie at the stability voltage
219. rvoltage Category III EN 61010 1 2001 Distribution level fixed installation Equipment in this category is qualification tested at 5kV peak 1 2 50us 5000 0 5J between all supply circuits and earth and also between independent circuits Pxxxx EN 55 1 1 8 10 7 4 8 Safety Section Environment The equipment is intended for indoor installation and use only If it is required for use in an outdoor environment then it must be mounted in a specific cabinet or housing which will enable it to meet the requirements of IEC 60529 with the classification of degree of protection IP54 dust and splashing water protected Pollution Degree Pollution Compliance is demonstrated by reference to safety Degree 2 standards Altitude operation up to 2000 m IEC 61010 1 2001 EN 61010 1 2001 CE MARKING C Compliance with all relevant European Marking Community directives Product safety Compliance demonstrated by reference to Low Voltage Directive 73 23 EEC safety standards amended by 93 68 EEC EN 61010 1 2001 EN 60950 1 2001 EN 60255 5 2001 IEC 60664 1 2001 Electromagnetic Compatibility Directive Compliance demonstrated via the Technical EMC 89 336 EEC amended by Construction File route 93 68 EEC The following Product Specific Standard was used to establish conformity EN 50263 2000 Where applicable The equipment is compliant with Article 1 2 of European directive 94 9 EC It
220. s 8 4 Operating times 8 5 Accuracy 8 6 Opto isolated inputs 8 7 Contacts 8 8 Operation indicator 8 9 Communication port 8 10 Current transformer requirements 8 11 REF requirements 8 12 High voltage withstand 8 12 1 Dielectric withstand IEC 255 5 1977 8 12 2 Impulse IEC 255 5 1977 8 12 3 Insulation resistance IEC 255 5 1977 8 13 Electrical environmental 8 13 1 DC supply interruptions IEC 255 11 1979 8 13 2 High frequency disturbance IEC 255 22 1 1988 8 13 3 Fast transient IEC 255 22 4 1992 8 13 4 Electrostatic discharge IEC 255 22 2 1989 amp IEC 801 2 1991 8 13 5 Conducted emissions EN 55011 1991 8 13 6 Radiated emissions EN 5501 1991 8 13 7 Radiated immunity IEC 255 22 3 1989 amp IEC 801 3 1984 8 13 8 Conducted immunity ENV 50141 1993 amp IEC801 6 8 13 9 EMC Compliance 8 13 10 Power frequency interference 8 14 8 14 1 8 14 2 8 15 8 15 1 8 15 2 8 15 3 8 16 8 16 1 IEEE ANSI specifications IEEE Surge Withstand Capacity SWC IEEE Radiated immunity Atmospheric environmental Temperature IEC 68 2 1 IEC 68 2 2 1974 Humidity IEC 68 2 3 1969 Enclosure protection IEC 529 1989 Mechanical environmental Vibration IEC 255 21 1 1988 Service Manual Technical Description KBCH 120 130 140 54 54 54 55 55 55 55 56 56 57 57 57 57 58 58 58 58 58 58 58 58 59 59 59 59 59 59 59 60 60 60 60 60 60 60 61 61 61 61 61 61 Service Manual Technical Description
221. s Page 30 52 KBCH 120 130 140 Current Level Pick up 0 9 x Is to 1 1 xIs Drop off 0 9 x Pick up to 1 0 x Pick up Table 25 7 3 2 7 3 3 7 3 4 7 3 5 In table 25 above Is corresponds to the settings for the earth fault element These are found in the cells lo gt HV Io21V1 and Io gt LV2 in the SETTINGS menu heading depending upon which winding is being tested REF element HV side operating time Connect the relay as in section 7 3 1 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms REF current sensitivity LV1 side gt LV1 In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 4 S1 Enable Io LV1 which should be set to 1 This will ensure that only the REF protection on the low voltage side of the transformer is enabled The relays selected for the REF protection on the LV1 side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io LV1 Each bit in this cell which is set to 1corresponds to an output relay for this protection function See section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section
222. s and S2 Fn Links and the vector correction factors should be set back to their calculated application settings Finally all the calculated application settings should be checked Commissioning the relay with its calculated application settings After the auxiliary supply tests in section 3 the settings required for the particular application should be entered as described in section 4 lt is important that once entered these settings are not changed as the relay should be commissioned at its calculated application settings If these are not available then the relay should be commissioned at the factory default settings Commissioning the relay with the selective logic functions The relay should be commissioned with the selective logic settings required for a particular application Table 4 lists the selective logic schemes and the tests that must be performed on the relay to ensure that these work correctly SELECTIVE LOGIC FUNCTION TEST Opto Blocking Logic 12 1 Overflux Blocking Function 12 2 Timer Blocking Functions 12 3 Change of Setting Group 12 4 Tap Changer Control 12 5 Table 4 KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 10 52 KBCH 120 130 140 2 3 Resetting fault flags 2 4 When the relay trips and the red trip LED is illuminated this can be reset by pressing 0 long This should be done each time the relay trips in order to both reset the LED and to clear
223. s function See section 2 4 for a fuller explanation of the configuration of the output relays Operation of the relays can be monitored as described in section 4 3 The relay should be connected so that current can be injected through terminals 21 amp 22 In addition the output relays should be connected to trip the test set and to stop a timer IT IS IMPORTANT TO TRIP THE TEST SET IN ORDER TO AVOID SUSTAINED APPLICATION OF EXCESSIVE CURRENTS The timer should be started when current is applied to the relay As the setting is above the continuous current rating of the relay DO NOT INCREASE THE CURRENT SLOWLY since this may damage the relay before it can operate Instead the current level should be set and then suddenly applied Two tests have to be performed for his particular protection function These are listed in table 19 Id Trip Id gt gt No Trip 1 1x Is 0 9x Is Table 19 The first test to be performed is at the higher current level to check that the instantaneous element operates Id gt gt In table 19 above Is CT Ratio Cor Id gt gt is the high set setting which will be found in the cell 9 gt gt under the SETTINGS menu heading CT Ratio Cor is the CT ratio correction which is used to compensate for a mismatch in currents due to the line side current transformer ratios This is found in the cell HV Ratio Cor under the SETTINGS menu heading Inject 1 1xIs and ensure that the select
224. setting on the relay of 110 50Hz x 1 05 2 31 V Hz KBCH EN M D11 Service Manual CHAPTER 2 Application Page 28 38 KBCH 120 130 140 3 OTHER PROTECTION CONSIDERATIONS 3 1 Use of auxiliary opto isolated inputs KBCH provides 8 auxiliary timer circuits AuxO Aux7 as shown in Figure 19 These can be used as timers or if the time setting is set to zero as simple auxiliary follower relays with the advantage that operation of these followers will be event logged and monitored via the K bus communication link Operation of any auxiliary timer will illuminate the yellow warning LED on the relay front plate INP Aux0 RLY AuxO LTT TT TT TI t AuxO INP Aux RLY Aux INP 2 RLY Aux2 Aux2 INP Aux3 RLY Aux3 TRETTEN N INP Aux4 RLY Aux4 E t Aux INP Aux5 RLY Aux5 1 LTT TTT TT I t Aux5 INP Aux6 RLY Aux TT ITI T TL LJ t Aux INP Aux7 RLY Aux7 fT TTT Ty Ty t Aux7 Figure 19 Buchholz protection could be connected in a protection scheme with a KBCH relay The Buchholz alarm gas contact could energise an opto input which is programmed to operate one of the auxiliary timer paths Operation of the opto input will be logged as an event in the relay s event record A replacement alarm output contact can be provided if required by using the follower elements output relay mask The timer
225. ss is to be entered manually or by the auto addressing function of the Master Station as described in Section 5 2 6 Moving to the SETTINGS column of the menu the function links are first selected Any protection not required is disabled by setting the appropriate bit 10 This will remove the unrequired settings from the menv The CT ratios for each winding may be entered if it is required to display the line currents in primary values of current Otherwise these ratios should be set at 1 1 when the measured values will be displayed in the secondary quantities applied to the relay terminals Next select the configuration appropriate to the transformer being protected Again unrequired settings will be removed from the menu Next the setting related to the vector group compensation and CT ratio mismatch for each winding can be entered The protection settings can now be entered Note these do not require the password to be entered first The timers in the LOGIC column of the menu should now be set to the required times The input and output masks are then set Section 6 9 gives some important notes on the allocation of output relays Finally the password protection should be established This will occur automatically fifteen minutes after the last key press alternatively select the password cell and hold the reset key pressed until the alarm LED stops flashing The backlight on the display is turned off one minute after the last ke
226. stic t 0 8 0 18xK M 1 1 Operating K 63 time s CO S Setting Figure 18 Inverse time IDMT Overfluxing protection characteristic 5th Harmonic blocking The 5th Harmonic blocking feature is available for possible use to prevent unwanted operation of the low set differential element under transient overfluxing conditions When overfluxing occurs the transformer core becomes partially saturated and the resultant magnetising current waveforms increase in magnitude and become harmonically distorted Such waveforms have a significant 5th harmonic content which can be extracted and used as a means of identifying the abnormal operating condition The 5th harmonic blocking threshold is adjustable between 10 5096 differential current Id The threshold should be adjusted so that blocking will be effective when the Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 27 38 2 4 5 magnetising current rises above the chosen threshold setting of the low set differential protection Where the magnetising current is just in excess of the differential element setting the magnetising inrush detection will not be effective in all applications with all types of transformers AREVA T amp D intend to offer some guidance in this respect To offer some protection against damage due to persistent overfluxing that might be caused by a geomag
227. sword protected see Section 5 Notes on serial port Each relay in the K Series has a serial communication port configured to K BUS Standards K BUS is a communication interface and protocol designed to meet the requirements of communication with protective relays and transducers within the power system substation environment It has to be as reliable as the protective relays themselves and must not result in their performance being degraded in any way Hence error checking and noise rejection have been major concerns in its design The communication port is based on RS485 voltage transmission and reception levels with galvanic isolation provided by a transformer A polled protocol is used and no relay unit is allowed to transmit unless it receives a valid message without any detected error addressed to it Transmission is synchronous over a pair of screened wires and the data is FMO coded with the clock signal to remove any dc component so that the signal will pass through transformers This method of encoding the data allows the connection to the bus wiring to be made in either polarity With the exception of the Master Units each node in the network is passive and any failed unit on the system will not interfere with communication to the other units The frame format is high level data link control HDLC and the data rate is 64kbits s Up to 32 units may be connected to any bus at any point with a maximum length of 1000m Notes on securit
228. t blocks and test plugs such as the MMLG MMLB and MiCOM P990 types hazardous voltages may be accessible when using these CT shorting links must be in place before the insertion or removal of MMLB test plugs to avoid potentially lethal voltages Note when a MiCOM P992 Test Plug is inserted into the MiCOM P991 Test Block the secondaries of the line CTs are automatically shorted making them safe Fibre optic communication Where fibre optic communication devices are fitted these should not be viewed directly Optical power meters should be used to determine the operation or signal level of the device Cleaning The equipment may be cleaned using a lint free cloth dampened with clean water when no connections are energised Contact fingers of test plugs are normally protected by petroleum jelly which should not be removed Safety Section 7 1 7 2 7 3 Pxxxx EN 55 1 1 7 10 DECOMMISSIONING AND DISPOSAL Decommissioning The supply input auxiliary for the equipment may include capacitors across the supply or to earth To avoid electric shock or energy hazards after completely isolating the supplies to the equipment both poles of any dc supply the capacitors should be safely discharged via the external terminals prior to decommissioning Disposal It is recommended that incineration and disposal to water courses is avoided The equipment should be disposed of in a safe manner Any equipment conta
229. t checks and the low set differential trip checks it is KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 28 52 KBCH 120 130 140 7 2 2 7 2 3 only necessary to check the operating time and the high set current sensitivity for each phase element on one side of the transformer only Low set element operating time Connect the relay as in section 7 2 1 above but in addition connect the relay contacts for this protection function to both trip the test set and to stop a timer Configure the test set so that when the current is applied to the relay the timer starts Inject 5xIs into the A phase low set element terminals 21 amp 22 Check that the operating time for the relay is within the range 30ms to 40ms Repeat this test for both of the remaining phases on the HV side as listed in table 23 above High set element current sensitivity Id gt gt WARNING THE RELAY MAY BE DAMAGED BY APPLYING EXCESSIVE CURRENT FOR LONG DURATIONS DURING TESTING OR IN RECURRENT BURSTS WITHOUT ALLOWING TIME FOR THE RELAY TO COOL DOWN This test checks the instantaneous current sensitivity of the differential high set element relay This test can only be performed if the test set is able to inject sufficient current into the relay to cause the element to trip at the customers setting Go to the cell S1 Fn Links in the SETTINGS menu and set bit 2 S1 Enable Id gt gt to 1 thus enabling the high set function Then
230. t operating time 7 3 Restricted Earth Fault Protection 7 3 1 REF current sensitivity HV side Io gt HV 7 3 2 element HV side operating time 7 3 3 current sensitivity LV1 side Io LV1 7 3 4 REF element LV1 side operating time 7 3 5 current sensitivity LV2 side Io LV2 7 3 6 REF element LV2 side operating time Service Manual Commissioning Instructions KBCH 120 130 140 17 18 18 18 19 19 19 20 20 20 21 21 22 23 23 23 23 24 24 24 25 25 25 26 26 26 26 28 28 29 29 29 30 30 30 30 31 Service Manual Commissioning Instructions KBCH 120 130 140 8 9 10 11 11 1 11 2 11 3 11 4 12 12 1 12 2 12 3 12 4 12 5 13 14 14 1 15 15 1 16 Figure 1 Figure 2 Figure 3 Figure 4 Figure 5 Figure 6 Figure 7 PHASE COMPENSATION Low set element bias characteristic Magnetising inrush restraint OVERFLUX PROTECTION Overflux alarm sensitivity Overflux trip sensitivity Overflux fifth harmonic Overflux fifth harmonic relay operating time Selective logic Opto input checks Controlled blocking of overflux protection Auxiliary timers Change of setting group Remote control of transformer tap changer FUNCTION LINKS REF PRIMARY INJECTION TESTS Correct set up check ON LOAD TEST Correct set up check TYPICAL APPLICATION DIAGRAMS HV and LV1 windings measurement check HV LV1 and LV2 windings measurement check HV LV1 windings
231. t operational scheme logic not running DSP Faulty Protection not operational Fault detected in DSP For the above listed alarms the ALARM LED will be continuously lit the alarm bit will be set in the STATUS word as a remote alarm and the watchdog relay will operate However there is another form of alarm that causes the ALARM LED to flash this indicates that the password has been entered to allow access to change protected settings within the relay and this is not generally available as a remote alarm Note No control will be possible via the key pad if the Unconfigured alarm is raised because the relay will be locked in a non operate state Password protection Password protection is only provided for the configuration settings of the relay This includes transformer configuration phase compensation selection CT ratio correction CT ratios function link settings opto input and relay output allocation Any accidental change to configuration could seriously affect the ability of the relay to perform its intended functions whereas a setting error may only cause a grading problem Individual protection settings are protected from change when the relay cover is in place Serial communication Serial communications are supported over K BUS a multidrop network that readily interfaces to IEC870 5 FT1 2 Standards The language and protocol used for communication is Courier It has been especi
232. t relay to be operated via the menu either individually or in groups as determined by the RELAY TEST mask The timer ensures there is a minimum closure time RLY Test Relay Test Figure 6 10 Trip test facility Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 49 76 6 9 Trip and external alarm flag logic Not all protection functions will be used for tripping purposes some may be used for control or alarm The trip flag latching has been made programmable so that it can be set to suit the application Figure 6 11 shows that the trip LED and the trip flags are latched for operation of relays RLY3 and or RLY7 To ensure correct flagging RLY3 and RLY7 should not be used for alarm or control functions Relay 3 Latch trip led Relay 7 Log fault current D Log CB data Latch fault flags generate fault flags Figure 6 11 Trip and flag logic The status of external protection routed to the relay via the logic inputs and auxiliary timers may not be required to trip the circuit breakers In this case RLY3 or RLY7 would not be selected in the auxiliary timer output masks and the trip flag logic just described would not operate In this case the output from the auxiliary timers is displayed on an additional External Alarms display which replaces the default display The Alarm LED and the flags are latched but are not stored in non volatile memory nor do they effect th
233. t shall apply at the transition frequency For measurements made at 10m the limits are increased by 10dB KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 60 76 KBCH 120 130 140 8 13 7 Radiated immunity IEC 255 22 3 1989 amp IEC 801 3 1984 8 13 8 8 13 9 Reference document is EN 50082 2 1995 Immunity Standard for Industrial Environments Frequency Level Class Modulation 20 to 1000MHz 10V m Class Ill 1kHz 80 AM 1 7 to 1 9GHz 10V m Keyed Carrier 50 duty cycle 200Hz prf Note extended frequency range Additional range for digital mobile phones Additional spot frequency checks at 27MHz 86MHz 100MHz 170MHz 460MHz and 934MHz Conducted immunity ENV 50141 1993 amp IEC801 6 Frequency Level Class Modulation 0 15 to 80MHz 10Vrms Level 3 1kHz 80 AM Additional spot frequency checks at 200kHz 1MHz 8MHz and 20MHz EMC Compliance Compliance to the European Commission Directive 89 336 EEC on EMC is claimed via the Technical Construction File route Generic Standards EN 50081 2 1994 and EN 50082 2 1995 were used to establish conformity 8 13 10 Power frequency interference 8 14 8 14 1 8 14 2 EA PAP Document Environmental Test Requirements for Protection relays and Systems Issue Draft 4 2 1 1995 500 V a c common mode 250 V a c differential mode via 0 1uF for 2s applied to all inputs except those for which 50Hz input is norma
234. t so that when the current is applied to the relay the timer starts Inject 5xIs into the relay and check that the operating time for the relay is within the range 20ms to 30ms 6 3 3 current sensitivity LV1 side Io LV1 In the SETTINGS menu go to cell S1 Fn Links and set all the bits to O except bit 4 S1 Enable Io LV1 which should be set to 1 This will ensure that only the REF protection on the LV1 side of the transformer is enabled The relays selected for the REF protection on the LV1 side of the transformer can be found under the RELAY MASKS heading in the cell RLY Io LV1 Each bit in this cell which is set to 1corresponds to an output relay for this protection function See KBCH EN M C11 Service Manual CHAPTER 3 Commissioning Instructions Page 24 52 KBCH 120 130 140 6 3 4 6 3 5 6 3 6 section 2 4 for a fuller explanation of the configuration of the output relays The operation of the relay can be monitored as described in section 4 3 Connect the equipment so that current can be injected through terminals 83 amp 84 Slowly increase the current from amps and note the pick up value at which the relay operates Reduce the current slowly and note the drop off value at which it resets Check that the pick up and drop off values are within the range shown in Table 20 REF element LV1 side operating time Connect the relay as in section 6 3 3 above but in addition connect the relay contacts for
235. taux2 INP Aux 3 Input to initiate taux3 INP Aux 4 Input to initiate taux4 INP Aux 5 Input to initiate taux5 INP Aux 6 Input to initiate taux INP Aux 7 Input to initiate taux7 Table 30 Each bit in the cells INP Aux to INP Aux 7 which is set tol corresponds to the opto input which when energised will initiate the appropriate timer The time delay associated with each timer can be found in the LOGIC FUNCTIONS menu heading in the cells LOG tAUX 0 to LOG tAUX 7 The relays operated by the auxiliary timers can be found under the RELAY MASKS menu heading in the cells RLY Aux 0 to RLY Aux 7 To test any of the auxiliary time delays an external switch must be connected to start an external timer and to energise the opto input which activates the relevant auxiliary timer The external timer must be stopped by the selected relay when it operates The measured time delay should be within the range set time x 1096 Change of setting group This test will check that the setting group i e SETTINGS 1 and SETTINGS 2 can be changed remotely either from the master station or via a local p c equipped with the suitable software This test need only be performed if bit 4 SYS Enable Grp2 in the cell SYS Fn Links under the SYSTEM DATA menu heading is set to 1 If bit 4 is set to O then there is no need for the tests in this section to be carried out Service Manual KBCH EN M C11 Commissioning CHAPTER 3 Instructions KBCH 120
236. technique successfully employed in the MBCH relay In addition the differential element can be optionally blocked under transient overfluxing conditions by a 5th Harmonic blocking feature Reduced operating times for heavy internal faults are achieved by the use of a differential instantaneous high set element Restricted earth fault protection based upon the high impedance stability principle is available for each transformer winding to offer increased sensitivity to low level winding earth faults The V f overfluxing element provides protection against damage that may result from prolonged overfluxing Independent alarm and trip characteristics are provided to enable corrective action to be undertaken prior to tripping being initiated Use of the eight available opto isolators as trip repeat and alarm paths for other transformer protection devices Buchholz Oil pressure winding temperature etc allows operation of these devices to be event logged Interrogation of the relay fault event and disturbance records offers an overall picture of an event or fault of the transformer protection performance and sequences of operation All models of the KBCH are three phase units with internal phase compensation CT ratio correction and zero sequence filtering thus eliminating the need for external interposing transformers in virtually all applications Up to four biased inputs can be provided to cater for power transformers with more than two wind
237. ter for line CT s connected in either star or delta as well as being able to compensate for a variety of system earthing arrangements Biased elements The number of biased differential inputs required for an application depends upon the transformer and its primary connections It is recommended that where ever possible a set of biased CT inputs is used per set of current transformers There are three basic models of the KBCH relay KBCH120 Two biased differential inputs KBCH130 Two or Three biased differential inputs KBCH140 Two Three or Four biased differential inputs Where a KBCH 140 130 is chosen they can be programmed to provide 2 3 4 and 2 or 3 biased windings respectively Versions of the KBCH120 and KBCH140 are available with 1A HV CT inputs and 5A LV CT inputs for applications where the CT s either side of a transformer are of different secondary ratings Table 1 shows the variety of connections which can be catered for by the range of KBCH relays Menu setting No of biased Configuration Required relay type inputs HV LV 2 KBCH120 130 140 HV LV1 LV2 3 E KBCH130 140 LV1 LV2 Service Manual KBCH EN M D11 Application CHAPTER 2 KBCH 120 130 140 Page 9 38 Menu setting No of biased Configuration Required relay type inputs HV x2 LV 3 w L KBCH130 140 LV HV LV x2 3 KBCH130 140 LV HV x2 LV1 LV2 4 Only KBCH140 LV1 LV2 HV LV1
238. ter Station has successfully read a record it usually clears it automatically and when all records have been read the event bit in the status byte is set to O to indicate that there are no longer any records to be retrieved Problems with disturbance records Only one record can be held in the buffer and the recorder must be reset before another record can be stored Automatic reset can be achieved by setting function link SD6 to 1 It will then reset the recorder 3 seconds after current has been restored to the protected circuit The disturbance records are erased if the auxiliary supply to the relay is lost for a period exceeding the hold up time of the internal power supply Disturbance records can only be read via the serial communication port It is not possible to display them on the LCD No trigger selected to initiate the storing of a disturbance record Disturbance recorder automatically reset on restoration of current for greater than 3 seconds Change function link SD6 to O to select manual reset Post trigger set to maximum value and so missing the fault When a Master Station has successfully read a record it will clear it automatically and the disturbance record bit in the status byte will then be set to O to indicate that there is no longer a record to be retrieved Communications Address cannot be automatically allocated if the remote change of setting has been inhibited by function link SDO This must be first s
239. than one relay may be allocated to the same function An output mask may be set to operate the same relay as another mask so that for example one output relay may be arranged to operate for all the functions required to trip the circuit breaker and another for the functions that are to initiate autoreclose Resetting values and records Some values and records can be reset to zero or some predefined value To achieve this the menu cell must be displayed then the 0 key must be held depressed for ot least one second to effect the reset The fault records are slightly different because they are a group of settings and to reset these the last cell under FAULT RECORDS must be selected This will display Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 39 76 5 2 10 5 2 11 5 2 12 FLT clear records 0 To reset the fault records hold the 0 key depressed for more than 1 second Resetting TRIP LED indication The TRIP LED can be reset when the flags for the last fault are displayed They are displayed automatically after a trip occurs or can be selected in the fault record column The reset is effected by depressing the 0 key for 1 second Resetting the fault records as described in 5 2 9 will also reset the TRIP LED indication Set function link SD5 to 1 for automatic reset of trip led Alarm records The alarm flags are towards the end of the SYSTEM DATA column of the menu and consist
240. the fault indication on the display The output relays will not latch when they have tripped and will reset when the fault condition has been removed Note that the LED and the fault display can only be reset when the fault condition has been removed Configuration of output relays The relay has 8 output relays each of which can be configured to operate for more than one protection function Which relay is configured to which protection function can be found in the cells under the RELAY MASKS menu heading Each protection function has its own cell followed by an 8 bit binary number Each bit in this binary number corresponds to an output relay as shown in table 5 below Bit7 Bit Bit5 Bit4 Bit3 Bit2 Bit RLY7 RLY6 RLY5 RLY4 RLY3 RLY2 RLY1 RLYO Terminals 41843 37839 33835 29 amp 31 42844 38840 34 amp 36 32830 Table 5 If a bit is set to 1 then the relay which corresponds to that bit will be selected to operate for that particular protection function For example the cell RLY Id gt A defines which relays are to be operated by the A phase low set trip If the bits in this cell are set as in table 6 below this means that relays 7 3 2 1 and will trip when this particular protection function operates Any one relay can have more than one protection and control function assigned to it Bit7 Bit Bit5 Bit4 Bit3 Bit2 Bit BitO 1 0 0 0 1
241. the overcurrent relay fitted as back up protection can be utilised When the KBCH initiates tripping an output contact from the KBCH can be programmed to activate an auxiliary element via an opto isolated input on the K series overcurrent relay The activated auxiliary on the overcurrent relay must have relay 3 or 7 programmed as its output contact to enable it to log the circuit breaker data RECOMMENDED SETTINGS AND CT VT REQUIREMENTS Recommended settings The following settings are recommended and are applied to the relay as default settings The relevant sections of the application notes should be cross referenced prior to applying the settings ensuring they are correct for the application Setting Function links Fn Links 0 1 101 1 11 1 0 Link O Not used Link 1 Enable Id Link 2 Enable Id gt Link 3 Enable Io HV Link 4 Enable Ilo gt LV1 Link 5 Enable lo gt LV2 Link 6 Not used Link 7 Enable V f Trip Link 8 Enable V f Alarm Link 9 Enable OF Block Differential element Sections 2 1 and 2 2 Differential setting of biased differential element Id O 2In Differential high set setting Id gt gt 10 In Restricted earth fault element Section 2 3 Restricted earth fault setting HV gt 0 1 Restricted earth fault setting LV lo gt 0 1 Stabilising resistor value see section 2 3 2 Overfluxing protection and blocking Section 2 4 5th harmonic blocking
242. the protection against electric shock provided by the equipment would be lost The recommended minimum protective conductor earth wire size is 2 5 mm 3 3 mm for North America unless otherwise stated in the technical data section of the equipment documentation or otherwise required by local or country wiring regulations The protective conductor earth connection must be low inductance and as short as possible All connections to the equipment must have a defined potential Connections that are pre wired but not used should preferably be grounded when binary inputs and output relays are isolated When binary inputs and output relays are connected to common potential the pre wired but unused connections should be connected to the common potential of the grouped connections Before energising the equipment the following should be checked Voltage rating polarity rating label equipment documentation CT circuit rating rating label and integrity of connections Protective fuse rating Integrity of the protective conductor earth connection where applicable Voltage and current rating of external wiring applicable to the application Equipment Use If the equipment is used in a manner not specified by the manufacturer the protection provided by the equipment may be impaired Removal of the equipment front panel cover Removal of the equipment front panel cover may expose hazardous live parts which must not b
243. til the key is released Similarly the key can be used to decrement the value Follow the instructions in Section 5 2 to exit from the setting change KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 38 76 KBCH 120 130 140 Note When entering CT RATIO the overall ratio should be entered i e 5 2 6 Su 5 2 8 5 2 9 2000 5 CT has an overall ratio of 400 1 With rated current applied the relay will display 5A when CT RATIO has the default value of 1 1 and when the RATIO is set to 400 1 the displayed value will be 400 x 5 2000A Setting communication address The communication address will normally be set to 255 the global address to all relays on the network when the relay is first supplied Reply messages are not issued from any relay for a global command because they would all respond at the same time and result in contention on the bus Setting the address to 255 will ensure that when first connected to the network they will not interfere with communications on existing installations The communication address can be manually set by selecting the appropriate cell for the SYSTEM DATA column entering the setting mode as described in Section 5 2 and then decrementing or incrementing the address It is recommended that the user enters the plant reference in the appropriate cell and then sets the address manually to O The Master Station will then detect that a new relay has been added to the network
244. to use a universally safe K factor of 1 0 but the older relays operated quickly with a lower Vk Vs ratio Vk Vs 2 0 With more modern relays it is desirable to identify the optimum K factor for stability so that the required Vk Vs ratio for stability and operating speed will not make CT kneepoint voltage requirements worse than traditional requirements KBCH EN M D11 Service Manual CHAPTER 2 Application Page 22 38 KBCH 120 130 140 2 3 3 2 3 4 70 o a AB FACTOR UNSTABLE N Factor STABLE OVERALL OPERATION TIME milliseconds e Figure 16 Restricted earth fault operating characteristics Operating times Having considered attaining stability of restricted earth fault protection for through faults the next performance factor to consider is the operating time for internal faults The CT kneepoint voltage as a multiple of the protection stability voltage setting Vk Vs will govern the operating time of a differential relay element for heavy internal faults with transiently offset fault current waveforms With the aid of the operating time curve derived for KBCH Figure 16 it is possible to identify the ratio Vk Vs that is required to achieve a desired average operating speed for internal faults Setting procedure To simplify the procedure for setting a KBCH restricted earth fault element the following flow chart has been pr
245. ugh bias current The calculated fourier magnitude of the differential current is also used in the algorithm The minimum differential current required for operation is adjustable between 0 1PU and 0 5PU based on rated current Under normal operation steady state magnetising current and the use of tap changers result in unbalanced conditions and hence differential current To accommodate these conditions the initial slope is 20 for bias currents of zero up to rated current This ensures sensitivity to faults whilst allowing for up to 15 mismatch when the power transformer is at the limit of its tap range At currents above rated extra errors may be gradually introduced as a result of CT saturation The bias slope is therefore increased to 80 to compensate for this KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 12 76 KBCH 120 130 140 2 3 2 2 3 3 Operate Differential current xIn 11 12 13 14 Restrain Setting range 0 1 0 5In Effective Bias xIn I1 I2 13 14 2 Figure 2 4 Differential low set characteristic Magnetising inrush current blocking Particularly high inrush currents may occur on transformer energisation depending on the point on wave of switching as well as the magnetic state of the transformer core Since the inrush current flows only in the energised winding differential current results The use of traditional second harmonic restr
246. unit Inspection Remove the polycarbonate front cover by unscrewing the four knurled plastic nuts with a small screwdriver The module can now be withdrawn by pulling the black handles at the top and the bottom Care should be taken as some force is required to do so and the relay module is heavy Once removed carefully examine the module and case to see that no damage has occurred since installation and visually check that the current transformer shorting switches in the case are wired into the correct circuit and are closed when the module is withdrawn Check that the serial number on the module and case are identical and that the model number and rating information are correct The serial number of the relay appears on the label on the inside of the cover and on the front plate of the relay module The serial numbers marked on these two locations should match The only time that they may not match is when a faulty relay module has been replaced for continuity of protection Check that the external wiring is correct to the relevant relay diagram or scheme diagram The relay diagram number appears inside the case on a label at the left hand side With the relay removed from its case check that it is isolated from the voltage and current transformer inputs and ensure that the terminals listed below in table 3 are closed by checking with a continuity tester TERMINALS 21 amp 22 65 amp 66 75 amp 76 23 amp 24 67 am
247. upon two factors These are the value of earthing impedance and the fault point voltage which is governed by the fault location The value of fault current If is directly proportional to the location of the fault restricted earth fault element 64 is connected to measure lf directly to provide more sensitive earth fault protection The overall differential protection is less sensitive since it only measures the HV current Is The value of I is limited by the number of faulted secondary turns in relation to the HV turns KBCH EN M D11 CHAPTER 2 Page 19 38 Service Manual Application KBCH 120 130 140 Source 1 0 10 Current Current x full load x full load 5 4 0 2 5 0 2 0 4 0 6 0 8 1 0 0 2 1 0 Fault position from neutral Impedance earthing Fault position from neutral Solid earthing Figure 13 Fault limitation on an impedance earthed system Figure 14 Fault limitation on a solidly earthed system If a fault on a solidly earthed star winding Fig 14 is considered the fault current is limited by the leakage reactance of the winding any impedance in the fault and by the fault point voltage The value of fault current varies in a complex manner with fault location As in the case of the impedance earthed transformer the value of current available as an overall differential protection operating quantity is limited More sensitive earth fault protection is provid
248. ure 12 4 ai 12 1 AT ud PL gt Z Wo 5 teer heat 2 A pd 14 31 C B EE WD 51 Relay failed Phase rotation 0 Set RIO 2 rn ri IM EE T 34 E RLI Sel Trip LY cC 38 c R201 Mp 17 42 IRE lu n X 44 Tip 6 3 oa 29 30 yes gt e 29 65 LC 66 5 e 5 E RL4 ST Tap up 7 8 3 34 i LM 2 Initiate aux timer O lO TG T T is xl Nl J nu 1 zd RLS 5 69 y 381 Initiate aux timer 1 L1 4 3 O Es TEE IG 39 40 Y B Wo 68 ee cs FS 4 42 Initia fi 212 150 1d rt RL 9 gt Alarm Is s if nitiate aux timer e c 17 08 52 75 MC gt 145 461 Logic input 1 RL7 431 Trip TUT ns 55 E Initiate aux timer 3 13 3 3 J A di un i Boc Ts E Initiate aux timer 4 14 Z a 2 c c t z c 81 3482 25 1626 y Case earth 2S RE Ts d 49 54 83 184 27 8 P ra Initiate aux timer 5 L5 e F RAI SCN C See Note 4 si y p 56 gt KBus communications port Initiate aux timer 6 L e j Hn Nod SCN Module terminal blocks Y viewed from rear 53 7 Initiate aux timer 7 17 e e 55 Vo 8 48 field voltage Logic input common 2 e ZN 1 p m Notes 1 a gt CT shorting links make 2 VT input must be supplied with phase phase voltage UC before and c disconnect Connections are typical only
249. urrent filtering is employed This ensures out of zone earth faults will not cause the relay to maloperate An external earth fault on the star side of a Dyn11 transformer will result in zero sequence current flowing in the current transformers associated with the star winding but due to the effect of the delta winding there will be no corresponding zero sequence current in the current transformers associated with the delta winding In order to ensure stability of the protection the LV zero sequence current must be eliminated from the differential current Traditionally this has been achieved by either delta connected line CT s or by the inclusion of a delta winding in the connection of an interposing current transformer Selection of the phase correction settings will be dependant on the phase shift required across the transformer and on zero sequence filtering requirements As with ratio correction factors the phase correction is applied either side of the relay element Providing replica interposing CT s in software has the advantage of being able to cater for line CT s connected in either star or delta as well as being able to cater for in zone earthing transformers To aid selection of the correct setting on the relay menu the description of the available phase correction factors has been simplified by the use of the reference system described in Appendix 1 Phase correction and zero sequence current filtering worked examples Servic
250. x2 LV2 4 i Only KBCH140 LV1 LV2 HV x2 LV x2 4 Bp Only KBCH140 LV Note Not available on In HV 1A LV 5A versions of KBCH140 Table 1 Biased input configurations available on the KBCH To ensure that the KBCH looks at the currents into the transformer windings for instrumentation and differential purposes it is important that the correct configuration is chosen on the KBCH relay menu When applied to a three winding transformer HV LVI LV2 should be chosen whereas for a two winding transformer with a requirement for three biased inputs either HV x2 LV or HV LVx2 should be chosen The KBCH relay achieves stability for through faults in two ways both of which are essential for correct relay operation The first consideration is the correct sizing of the current transformers as described in Chapter 4 the second is by providing a relay bias characteristic as shown in Fig 3 Differential current 2 Operate 80 Restrain Setting range 0 1 0 51n 0 1 2 3 4 Effective Bias Figure 3 Fixed Bias Characteristic Showing setting range The differential current on a per phase basis is defined as the vectorial sum of all the input currents after phase ratio and zero sequence correction has been performed The bias current on a per phase basis is defined as half the scalar sum of all the input currents after phase ratio and zero sequence correct
251. y summing the two bias currents as shown in Figure 2 3 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 11 76 2 2 5 2 2 6 2 2 7 2 3 2 3 1 12 Ihv 12 Figure 2 3 Measurements for mesh corner applications Differential current The differential current for each phase is calculated by summing the four individual bias currents related to that phase Fourier The fundamental frequency magnitude and phase are calculated by a technique which uses fourier transforms A single cycle fourier is applied to each of the sixteen channels the three differential channels and the nine winding current channels Phase angle is not calculated for the three REF channels and the voltage channel as these are not required for the algorithms The fouriers are calculated eight times per cycle Frequency tracking The bias currents and voltage channels are used to determine the system frequency This is used to adjust the sample rate to maintain 40 samples per cycle and also in the overflux protection algorithms Biased differential protection function The relay contains two differential protection algorithms described below Each algorithm is applied to each of the three phases independently Low set protection function The biased low set differential element characteristic is shown in Figure 2 4 The calculated bias current fourier magnitudes are summed to determine the thro
252. y additional phase shift Example 3 Transformer connection YNynO YNynO KBCH Relay YdyO Differential YdyO Software ICT 0 element 0 Software ICT Whenever an in zone earthing connection is provided a zero sequence trap should always be provided In this example there will be some difference between HV and LV zero sequence currents as a result of the zero sequence magnetising current of the transformer This is normally small but not if a three limb core is used To avoid any problems with any application the above rule for zero sequence traps should be applied with earthed windings Service Manual KBCH EN M D11 KBCH 120 130 140 APPENDIX C KBCH EN M D11 Service Manual KBCH 120 130 140 Service Manual KBCH EN M D11 APPENDIX C KBCH 120 130 140 Page 1 4 APPENDIX C Setting examples Example 1 Ratio compensation with tap changer When deciding upon the required ratio connection factors for the differential element checks should be made to ensure that the optimum differential setting has been chosen For simplicity the following procedure can be followed Calculate full load current at mid tap volts and LV full load current Adjust ratio compensation for In to relay on both sides at mid tap Calculate HV full load current at both tap extremities Determine Idiff at both tap extremities with mid tap correction Determine Ibias at both t
253. y for 10 seconds or so possibly by withdrawing the module from its case Then re establish the supplies and the relay should in most cases return to an operating state Recheck the alarm status if the alarm LED is still indicating an alarm state The following notes will give further guidance 9 3 1 Watchdog alarm The watchdog relay will pick up when the relay is operational to indicate a healthy state with its make contact closed When an alarm condition that requires some action to be taken is detected the watchdog relay resets and its break contact will close to give an alarm Note The green LED will usually follow the operation of the watchdog relay KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 64 76 KBCH 120 130 140 9 3 2 9 3 3 9 3 4 9 3 5 9 4 9 4 1 There is no shorting contact across the case terminals connected to the break contact of the watchdog relay Therefore the indication for a failed healthy relay will be cancelled when the relay is removed from its case If the relay is still functioning the actual problem causing the alarm can be found from the alarm records in the SYSTEM DATA column of the menu see Section 2 12 Unconfigured or uncalibrated alarm For a CONFIGURATION alarm the protection is stopped and no longer performing its intended function For an UNCALIBRATED alarm the protection will still be operational but there will be an error in its calibration that wi
254. y of remote control via the serial port Access to the memory of the relay is restricted to that addressed via the menu system of the relay In addition all setting changes are reflexed back to the Master Station for verification before the EXECUTE command is issued On reception of the EXECUTE command the new setting is checked against the limits stored in the relay before they are entered Only then does the relay respond to the new setting All remote commands are reflexed back to the Master Station for verification before they are executed and any command left set is automatically rejected if not executed within the time out period No replies are permitted for global commands as this would cause contention on the bus instead a double send is used for verification purposes with this type of command Remote control is restricted to those functions that have been selected in the relay s menu table and the selection cannot be changed without entering the password Cyclical redundancy checksum CRC and message length checks are used on each Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 19 76 message received No response is given for received messages with a detected error The Master Station can be set to re send a command a set number of times if it does not receive a reply or receives a reply with a detected error
255. y press KBCH EN M E11 Service Manual CHAPTER 1 Technical Description Page 54 76 KBCH 120 130 140 8 1 8 1 1 8 1 2 8 2 8 2 1 8 2 2 8 2 3 The relay is now configured for the application and the configuration may be stored on a disc and referenced with a suitable name The file can then be retrieved and down loaded to other relays that require the same configuration This provides a quick method of setting the relay but requires the use of additional equipment such as a KITZ101 interface unit and a portable PC with suitable software such as Protection Access Software and Toolkit from AREVA T amp D TECHNICAL DATA Ratings Inputs Reference Current In Nominal Rating Continuous 3s ls In 1A 3In 30In 100A In 5A 3In 30In 400A Reference Voltage Vn Nominal Rating Nominal Range Continuous Rating Vn 100 120V 140V phase phase 180V phase phase Auxiliary Voltage Vx Nominal Rating Operative Range Absolute DC Supply 50 60Hz Maximum 24 125V ac dc 20 150V 50 133V 190V crest 48 250V ac dc 33 300V 87 265V 380V crest Frequency Fn Nominal Rating Tracking Range 50 Hz or 60 Hz 13 65Hz Opto lsolated Inputs Supply Nominal Rating Reference Range 50V dc only 25 60V dc only Outputs Field Voltage 48V dc Current limited to 60mA Burdens Bias current circuit In lt 0 045VA at rated current In 5A lt 0 22VA REF current circuit lt 0 08
256. y should be connected to terminals 13 and 14 only To avoid any confusion it is recommended that the polarity of any applied voltage is kept to the Midos standard for supplies positive lead connected to terminal 13 and the negative to terminal 14 for ac supplies the live lead is connected to terminal 13 and the neutral lead to terminal 14 Note To avoid damage to the relay do not connect any auxiliary supplies to terminals 7 and 8 Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 21 76 3 2 Opto isolated control inputs 3 3 3 4 The opto isolated control inputs are rated for 48V dc and energised from the isolated 48V field voltage provided on terminals 7 and 8 of the relay Terminal 8 must be connected to terminals 52 and 55 The opto isolated control inputs can then be energised by connecting a volt free contact between terminal 7 and the terminal associated with the required input LO to L7 given in the above table The circuit for each opto isolated input contains a blocking diode to protect it from any damage that may result from the application of voltage with incorrect polarity Where the opto isolated input of more than one relay is to be controlled by the same contact it will be necessary to connect terminal 7 of each relay together to form a common line In the example shown in Figure 3 1 contact X operates L1 of relay 1 and contact Y operates LO of relay 1
257. ycles because the interval between the samples is equivalent to one fortieth of a cycle However the Fourier derived values are calculated eight times per cycle and so the total trace length when recording these calculated phase or amplitude values is 510 8 63 cycles Service Manual KBCH EN M E11 Technical Description CHAPTER 1 KBCH 120 130 140 Page 41 76 5 3 4 Recorder logic trigger 5 3 5 5 3 6 Any or all of the opto isolated inputs may be used as the stop trigger and the trigger may be taken from either the energisation or the de energisation of these inputs The bottom line of the display for this cell will show a series of 16 characters each of which may be set to 1 or 0 A 1 will select the input as a trigger and a 0 will deselect it The selection is made using the instructions for the setting links in Section 5 2 4 The opto isolated input LO to L7 associated with each digit is shown on the top line of the display for the digit underlined by the cursor A preceding it will indicate that the trigger will occur for energisation and a will indicate the trigger will occur for de energisation Recorder relay trigger Any or all of the output relays may be used as a stop trigger and the trigger may be taken from either the energisation or the de energisation of these outputs The bottom line of the display for this cell will show a series of 16 characters each of which may be set to 1 or 0

KBCH 120, 130, 140 - Schneider Electric

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