ABB REC650 ANSI Applications Manual Download Page 296

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100

IMagComp5

IMagComp30

IMagComp100

-10

+10

Magnitude
compensation

% of In

Measured

current

% of In

0-5%:

Constant

5-30-100%: Linear
>100%:

Constant

100

IAngComp5

IAngComp30

IAngComp100

-10

+10

Angle
compensation

Degrees

Measured

current

% of In

ANSI05000652_3_en.vsd

ANSI05000652 V3 EN

Figure 132:

Calibration curves

12.4.4

Setting examples

Three setting examples, in connection to Measurement function (CVMMXN), are
provided:

•

Measurement function (CVMMXN) application for a 380kV OHL

•

Measurement function (CVMMXN) application on the secondary side of a
transformer

•

Measurement function (CVMMXN) application for a generator

For each of them detail explanation and final list of selected setting parameters values will
be provided.

The available measured values of an IED are depending on the actual
hardware (TRM) and the logic configuration made in PCM600.

Section 12

1MRK 511 286-UUS A

Monitoring

290

Application manual

Summary of Contents for REC650 ANSI

Page 1: ...Relion 650 series Bay control REC650 ANSI Application manual...

Page 2: ......

Page 4: ...L Project for use in the OpenSSL Toolkit http www openssl org This product includes cryptographic software written developed by Eric Young eay cryptsoft com and Tim Hudson tjh cryptsoft com Trademarks...

Page 5: ...roduct failure would create a risk for harm to property or persons including but not limited to personal injuries or death shall be the sole responsibility of the person or entity applying the equipme...

Page 6: ...ning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60...

Page 7: ...ble busbar in solidly grounded network 32 Single breaker line bay single or double busbar in high impedance grounded network 33 Bus coupler in a solidly grounded network 35 Bus coupler in a high imped...

Page 8: ...settings for LV side breaker failure protection CCRBRF 50BF 58 Section 4 Analog inputs 61 Introduction 61 Setting guidelines 61 Setting of the phase reference channel 61 Relationships between setting...

Page 9: ...ut OC4PTOC 51 67 92 Identification 92 Application 92 Setting guidelines 93 Settings for steps 1 to 4 94 2nd harmonic restrain 96 Instantaneous residual overcurrent protection EFPIOC 50N 102 Identifica...

Page 10: ...on 136 Application 136 Setting guidelines 137 Broken conductor check BRCPTOC 46 137 Identification 137 Application 137 Setting guidelines 138 Directional over under power protection GOPPDOP GUPPDUP 32...

Page 11: ...delines 158 Power supply quality 159 High impedance grounded systems 159 Direct grounded system 160 Settings for Two step residual overvoltage protection 161 Loss of voltage check LOVPTUV 27 163 Ident...

Page 12: ...izing check and synchronizing SESRSYN 25 183 Identification 183 Application 183 Synchronizing 183 Synchronism check 184 Energizing check 186 Voltage selection 187 External fuse failure 188 Application...

Page 13: ...ion 205 Auto recloser parameter settings 209 Apparatus control 212 Identification 212 Application 212 Interaction between modules 220 Setting guidelines 223 Switch controller SCSWI 223 Switch SXCBR SX...

Page 14: ...C_LINE 3 255 Application 255 Signals from bypass busbar 256 Signals from bus coupler 257 Configuration setting 260 Interlocking for transformer bay AB_TRAFO 3 261 Application 261 Signals from bus coup...

Page 15: ...71 Configurable logic blocks 272 Identification 272 Application 274 Configuration 275 Fixed signals FXDSIGN 276 Identification 276 Application 277 Boolean 16 to integer conversion B16I 278 Identificat...

Page 16: ...cation 283 Application 284 Setting guidelines 284 IEC61850 generic communication I O functions MVGGIO 284 Identification 284 Application 284 Setting guidelines 284 Measurements 285 Identification 285...

Page 17: ...SSIMG 63 306 Identification 306 Application 306 Insulation liquid monitoring function SSIML 71 307 Identification 307 Application 307 Circuit breaker condition monitoring SSCBR 307 Identification 307...

Page 18: ...ing 329 Identification 329 Application 329 Setting guidelines 330 Test mode functionality TESTMODE 330 Identification 330 Application 330 Setting guidelines 331 Change lock CHNGLCK 331 Identification...

Page 19: ...urrent transformer requirements 345 Current transformer classification 345 Conditions 346 Fault current 347 Secondary wire resistance and additional load 347 General current transformer requirements 3...

Page 20: ...IEC 60044 6 class TPS and old British Standard class X 352 Current transformers according to ANSI IEEE 352 Voltage transformer requirements 353 SNTP server requirements 354 SNTP server requirements 3...

Page 21: ...manual can also provides assistance for calculating settings 1 2 Intended audience This manual addresses the protection and control engineer responsible for planning pre engineering and engineering Th...

Page 22: ...he manual provides instructions on how to set up a PCM600 project and insert IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions...

Page 23: ...ion can be used The manual can also provides assistance for calculating settings The technical manual contains application and functionality descriptions and lists function blocks logic diagrams input...

Page 24: ...S MICS 1MRG 010 656 PICS 1MRG 010 660 PIXIT 1MRG 010 658 1 4 Symbols and conventions 1 4 1 Symbols The electrical warning icon indicates the presence of a hazard which could result in electrical shock...

Page 25: ...e between the options use and HMI menu paths are presented in bold For example select Main menu Settings LHMI messages are shown in Courier font For example to save the changes in non volatile memory...

Page 26: ...20...

Page 27: ...ynchronous networks is also provided A number of protection functions are available for flexibility in use for different station types and busbar arrangements The auto reclose includes priority circui...

Page 28: ...ontrol OV2 PTOV 59 U PH PIOC 50 3I CC RBRF 50BF 3I BF V MMXU Meter C MMXU Meter ETP MMTR Wh 189 989 989G 289G 189G EF4 PTOC 51N 67N IN Q CBAY Control WA1 S CILO Control S CILO Control S CILO Control S...

Page 29: ...89G G 189G EF4 PTOC 51N 67N IN Q CBAY Control WA1 WA2 S CILO Control S CILO Control S CILO Control S CILO Control S CILO Control S CILO Control S CILO Control SEL GGIO Control C MSQI Meter V MSQI Mete...

Page 30: ...O Control S CILO Control S CILO Control S CILO Control S CILO Control S CILO Control SEL GGIO Control DRP RDRE Mont 52 189 289 289G 189G WA1 WA2 1189G 2189G CC RBRF 50BF 3I BF PH PIOC 50 3I CC RPLD 52...

Page 31: ...5 103 1 1 1 1 I103USRCMD Function commands user defined for IEC60870 5 103 4 4 4 4 I103GENCMD Function commands generic for IEC60870 5 103 50 50 50 50 I103POSCMD IED commands with position and select...

Page 32: ...nt circuit supervision 0 1 1 1 1 SDDRFUF Fuse failure supervision 0 1 1 1 1 TCSSCBR Breaker close trip circuit monitoring 3 3 3 3 Logic SMPPTRC 94 Tripping logic common 3 phase output 1 1 1 1 TMAGGIO...

Page 33: ...with logic node representation 16 16 16 16 IB16A Integer to Boolean 16 conversion 16 16 16 16 IB16FCVB Integer to Boolean 16 conversion with logic node representation 16 16 16 16 TEIGGIO Elapsed time...

Page 34: ...tor 0 1 1 1 SPVNZBAT Station battery supervision 0 1 1 1 1 SSIMG 63 Insulation gas monitoring function 0 1 1 1 1 SSIML 71 Insulation liquid monitoring function 0 1 1 1 1 SSCBR Circuit breaker conditio...

Page 35: ...ection one time constant Fahrenheit 0 1 1 1 1 CCRBRF 50BF Breaker failure protection 3 phase activation and output 0 1 1 1 1 STBPTOC 50STB Stub protection 0 1 1 1 1 CCRPLD 52PD Pole discordance protec...

Page 36: ...TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 MST3TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 MST4TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 RS485GEN RS485 1 1 1 1 OPTICALPRO...

Page 37: ...4 64 2 2 4 Basic IED functions IEC 61850 Function block name Function description Basic functions included in all products INTERRSIG Self supervision with internal event list 1 SELFSUPEVLST Self super...

Page 38: ...main protection functionality and the bay control IED giving control functionality together with back up protection The IED is available in three different versions A01A for a single breaker bay conne...

Page 39: ...otections in the system Failure of the circuit beaker to interrupt fault current after protection trip The breaker failure protection function is essential in a protection system using local redundanc...

Page 40: ...ng to application examples given in previous sections Table 1 Functionality table Function Application 1 Application 2 Instantaneous phase overcurrent protection 3 phase output PHPIOC 50 Enabled Enabl...

Page 41: ...ication dependent Current circuit supervision CCSRDIF 87 Enabled Enabled Fuse failure supervision SDDRFUF Enabled Enabled Breaker close trip circuit monitoring TCSSCBR Enabled Enabled Synchrocheck ene...

Page 42: ...o ground faults In high impedance grounded networks the fault current at a single phase to ground fault is small For these faults the sensitive residual overcurrent protection should be used The sensi...

Page 43: ...n dependent Directional over power protection GOPPDOP 32 Application dependent Application dependent Negative sequence overcurrent protection DNSPTOC 46 Application dependent Application dependent Two...

Page 44: ...aker close trip circuit monitoring TCSSCBR Enabled Enabled Synchrocheck energizing check and synchronizing SESRSYN 25 Application dependent Application dependent Autorecloser for 3 phase operation SMB...

Page 45: ...he following data is assumed Item Data Transformer rated power SN 60 MVA Transformer high voltage side rated voltage VN1 145 kV 9 1 67 with on load tap changer Transformer low voltage side rated volta...

Page 46: ...tting guideline section in the Application manual for guidelines on how to set functions that are not presented in the setting examples Use the parameter setting tool in PCM600 to set the IED accordin...

Page 47: ...inputs 5 and 6 to the same values as for current input 4 5 Set the 145 kV neutral point current transformer input 7 5 1 Set CTStarPoint7 to ToObject The CT secondary is grounded towards the protected...

Page 48: ...o 60 MVA SBase 3 VBase IBase There are six instances of global base GBASVAL function each instance includes the three parameters IBase UBase SBase The GlobalBaseSel setting which can be found in the d...

Page 49: ...hing states in the system and different fault types The 145 kV phase overcurrent protection has the following tasks Backup protection for short circuits on the transformer Backup protection for short...

Page 50: ...he next requirement is that the protection shall be able to detect all short circuits within the defined protected zone In this case it is required if possible that the protection shall detect phase t...

Page 51: ...for the outgoing 22 kV feeders 2 Set TD1 to 0 15 The time setting must be coordinated with the feeder protections to assure selectivity It can be stated that there is no need for selectivity between...

Page 52: ...otection has the following purpose Main protection for short circuits on 22 kV busbar Backup protection for short circuits on outgoing 22 kV feeders if possible The reach of the phase overcurrent line...

Page 53: ...se As the step shall have an inverse time characteristic the step 4 function is used An inverse time characteristics is not available for step 2 and 3 3 1 5 1 Calculating general settings 1 Set Global...

Page 54: ...Calculating settings for step 4 The first requirement is that the phase overcurrent protection shall never trip for load current during extreme high load situations It is assumed that the transformer...

Page 55: ...r impedance referred to 22 kV level is The phase to phase fault current can be calculated as follows 2 3 22000 3 949 2 0 23 0 97 3 10 sc ph I A j j j GUID BAA8989B EF8F 4277 9B2B EBBCA35ED7C2 V1 EN Eq...

Page 56: ...000453 V1 EN Figure 9 Inverse time operation characteristics for selectivity 3 1 6 Calculating settings for four step residual overcurrent protection zero or negative sequence direction HV side EF4PTO...

Page 57: ...d series faults in the 145 kV network The reach of the residual overcurrent line protection is dependent on the operation state and the fault type Therefore the setting must be based on fault calculat...

Page 58: ...pes are applied phase phase ground short circuit and phase ground fault The source impedance both positive sequence and zero sequence at the 145 kV level gives the following residual current from the...

Page 59: ...42 3 5 2 2 15 42 net T net T net T net net T Z V j I kA Z Z j j Z Z j j j Z j j Z Z GUID CA17A1A5 E141 4F0B B7C0 74683F9F9AD1 ANSI V1 EN Equation 16 The residual current from the transformer during a...

Page 60: ...85 out on the line 3 1 6 3 Calculating settings for step 2 1 Set Pickup2 to 400 of IBase corresponding to 956 A To assure that step 2 detects all ground faults on the outgoing lines ground faults calc...

Page 61: ...oltage protection LV side ROV2PTOV 59N The residual overvoltage protection is fed from the open delta connected voltage transformer at the 22 kV side of the transformer The residual overvoltage protec...

Page 62: ...ith a resistance up to 5 000 shall be detected This gives 0 1 0 20 3 5000 1 3 1270 phase V V GUID 42D376ED 052F 4E9B B4D9 8D679127BC0C ANSI V1 EN Equation 20 Step 1 and step 2 is given the same voltag...

Page 63: ...larger than the set level to detect failure to break 2 out of 4 at least two of the three phase current and the residual current shall be larger than the set level to detect failure to break As the re...

Page 64: ...or measure the current going through the CT in order to detect correct breaker functioning For transformer protections it is most suitable to use current measurement as a circuit breaker failure check...

Page 65: ...the differential protection which is set 25 of IBase 5 Set the re tip time delay t1 to 0 s 6 Set t2 to 0 17 s The delay time of the breaker failure protection BuTrip is chosen according to figure 13 T...

Page 66: ...Section 3 1MRK 511 286 UUS A REC650 setting examples 60 Application manual...

Page 67: ...se angle will always be fixed to zero degrees and all other angle information will be shown in relation to this analog input During testing and commissioning of the IED the reference channel can be ch...

Page 68: ...largest rated CT primary current among all CTs involved in the protection scheme and installed on the same voltage level This will effectively make the protection scheme less sensitive however such me...

Page 69: ...sured quantity is positive when flowing towards the object Set parameter CTStarPoint Correct Setting is ToObject Set parameter CTStarPoint Correct Setting is FromObject en05000456 2 vsd ANSI05000456 V...

Page 70: ...tting is ToObject ANSI11000020 2 en vsd Is Is Ip Ip Ip IED IED ANSI11000020 V2 EN Figure 16 Example how to set CT_WyePoint parameters in the IED The figure 16 shows the most common case where the obje...

Page 71: ...IED IED ANSI05000460 V2 EN 1MRK 511 286 UUS A Section 4 Analog inputs 65 Application manual...

Page 72: ...s feeding just one line both line protection IED and transformer protection IED use the same CT The CT direction is set with different reference objects for the two IEDs though it is the same current...

Page 73: ...noted that depending on national standard and utility practices the rated secondary current of a CT has typically one of the following values 1A 5A However in some cases the following rated secondary...

Page 74: ...phase CT set to the three CT inputs of the IED 2 The current inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for the ex...

Page 75: ...required only for IEDs installed in power plants then the setting parameters DFTReference shall be set accordingly Section SMAI in this manual provides information on adaptive frequency tracking for...

Page 76: ...on the TRM item 2 in the figure CTprim 600A CTsec 5A CTWyePoint FromObject Inside the IED only the ratio of the first two parameters is used The third parameter as set in this example will negate the...

Page 77: ...VT terminals Where a is the symbol and terminal marking used in this document Terminals marked with a dot indicate the primary and secondary winding terminals with the same positive polarity b is the...

Page 78: ...view of required actions by the user in order to make this measurement available to the built in protection and control functions within the IED For correct terminal designations see the connection di...

Page 79: ...analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundament...

Page 80: ...the connection diagrams valid for the delivered IED A IED B C 1 2 3 4 13 8 120 kV V SMAI_20 ANSI11000032 2 en vsd ANSI11000032 V2 EN Figure 23 A Phase to phase connected VT Section 4 1MRK 511 286 UUS...

Page 81: ...input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one tak...

Page 82: ...76...

Page 83: ...LCD Buttons LED indicators Communication port for PCM600 The LHMI is used for setting monitoring and controlling 5 1 1 Display The LHMI includes a graphical monochrome display with a resolution of 320...

Page 84: ...utton panel shows on request what actions are possible with the function buttons Each function button has a LED indication that can be used as a feedback signal for the function button control action...

Page 85: ...ion buttons or the Multipage button Pressing the ESC button clears the panel from the display Both the panels have dynamic width that depends on the label string length that the panel contains 5 1 2 L...

Page 86: ...s of the circuit breaker 5 1 3 Keypad The LHMI keypad contains push buttons which are used to navigate in different views or menus With the push buttons you can give open or close commands to one prim...

Page 87: ...unction button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 User Log on 14 Enter 15 Remote Local 16 Uplink LED 17 Ethernet communication port RJ 45 18 Multipage 19 Menu 20 Clear 21 Help 22...

Page 88: ...A flashing yellow LED has a higher priority than a steady yellow LED The IED is in test mode and protection functions are blocked The indication disappears when the IED is no longer in test mode and b...

Page 89: ...S sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedAck S F sequence The indication has been acknowledged but the activation signal is still on 5 1...

Page 90: ...assigns an IP address to the computer if DHCPServer Enabled The default IP address for the front port is 10 1 150 3 Do not connect the IED front port to a LAN Connect only a single local PC with PCM6...

Page 91: ...ANSI11000181 V1 EN ANSI11000180 V1 EN Figure 30 Single line diagram example REC650 1MRK 511 286 UUS A Section 5 Local human machine interface 85 Application manual...

Page 92: ...86...

Page 93: ...depends mostly on three parameters at constant amount of transmitted electric power The type of the fault Three phase faults are the most dangerous because no power can be transmitted through the fau...

Page 94: ...e to ground conditions Also study transients that could cause a high increase of the line current for short times A typical example is a transmission line with a power transformer at the remote end wh...

Page 95: ...000023 V1 EN Figure 32 Through fault current from B to A IfA The IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA IfB...

Page 96: ...s given from this formula 100 Is Pickup IBase ANSIEQUATION1147 V1 EN Equation 25 6 1 3 2 Meshed network with parallel line In case of parallel lines the influence of the induced current from the paral...

Page 97: ...ation 26 Where IfA and IfB have been described in the previous paragraph Considering the safety margins mentioned previously the minimum setting Is for the instantaneous phase overcurrent protection 3...

Page 98: ...rs and others Back up short circuit protection of power generators If VT inputs are not available or not connected setting parameter DirModeSelx x step 1 2 3 or 4 shall be left to default value Non di...

Page 99: ...7 have a possibility of 2nd harmonic restrain if the level of this harmonic current reaches a value above a set percentage of the fundamental current 6 2 3 Setting guidelines When inverse time overcur...

Page 100: ...teristic angle 55 2 ROA Relay operating angle 80 3 Reverse 4 Forward 6 2 3 1 Settings for steps 1 to 4 n means step 1 and 4 x means step 1 2 3 and 4 DirModeSelx The directional mode of step x Possible...

Page 101: ...different characteristics are described in Technical manual Pickupx Operate phase current level for step x given in of IBase tx Definite time delay for step x The definite time tx is added to the inv...

Page 102: ...harmonic restrain function 2nd harmonic This function should be used when there is a risk if power transformer inrush currents might cause unwanted trip Can be set Disabled Enabled 6 2 3 2 2nd harmoni...

Page 103: ...l description is given below The pickup current setting of the inverse time protection or the lowest current step of the definite time protection must be defined so that the highest possible load curr...

Page 104: ...be chosen within the interval stated in equation 31 Imax 1 2 Ipu 0 7 Iscmin k EQUATION1264 V2 EN Equation 31 The high current function of the overcurrent protection which only has a short delay of th...

Page 105: ...short that protected equipment will not be destroyed due to thermal overload at the same time as selectivity is assured For overcurrent protection in a radial fed network the time setting can be chos...

Page 106: ...ection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protection operation time 15 60 ms Protec...

Page 107: ...ker The operation time of this protection is t1 t t2 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t2 t1 t t3 is when the overcurrent protection at IED A1 resets The...

Page 108: ...ion EFPIOC IN IEF V1 EN 50N 6 3 2 Application In many applications when fault current is limited to a defined value by the object impedance an instantaneous ground fault protection can provide fast an...

Page 109: ...ts shall be calculated as shown in figure 40 and figure 41 The residual currents 3I0 to the protection are calculated For a fault at the remote line end this fault current is IfB In this calculation t...

Page 110: ...um static inaccuracy and a safety margin of 5 for maximum possible transient overreach have to be introduced An additional 20 is suggested due to inaccuracy of instrument transformers under transient...

Page 111: ...ave been described for the single line case Considering the safety margins mentioned previously the minimum setting Is is m 1 3 I s in I EQUATION288 V2 EN Equation 37 Transformer inrush current shall...

Page 112: ...PTOC 51N_67N can have better sensitivity to detect resistive phase to ground faults compared to distance protection Back up ground fault protection of power transformers with ground source at substati...

Page 113: ...oice of time characteristics There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics The selectivity between different...

Page 114: ...se time delay and the set definite time delay Thus if only the inverse time delay is required it is important to set the definite time delay for that stage to zero The parameters for the four step res...

Page 115: ...tions breaker opening time and protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protec...

Page 116: ...current of twenty times the set current pickup value Note that the operate time value is dependent on the selected setting value for time multiplier TDn 6 4 3 2 Common settings for all steps tx Defini...

Page 117: ...Current polarizing is useful when the local source is strong and a high sensitivity is required In such cases the polarizing voltage 3V0 can be below 1 and it is then necessary to use current polariz...

Page 118: ...rmonic restrain If a power transformer is energized there is a risk that the current transformer core will saturate during part of the period resulting in a transformer inrush current This will give a...

Page 119: ...rated when a three phase set of voltage transformers and current transformers are used xx05000149_ansi vsd 67N ANSI05000149 V1 EN Figure 45 Connection of polarizing voltage from an open ANSI broken de...

Page 120: ...be formulated according to equation 38 step1 0 I 1 2 3I remote busbar EQUATION1199 V3 EN Equation 38 As a consequence of the distribution of zero sequence current in the power system the current to t...

Page 121: ...und fault 67N 0 3I ANSI05000152 V2 EN Figure 48 Step 1 third calculation In this case the residual current out on the line can be larger than in the case of ground fault on the remote busbar step1 0 I...

Page 122: ...uation 41 To assure selectivity the current setting must be chosen so that step 2 does not operate at step 2 for faults on the next line from the remote substation Consider a fault as shown in figure...

Page 123: ...is to detect and initiate trip for ground faults with large fault resistance for example tree faults Step 4 shall also detect series faults where one or two poles of a breaker or other switching devic...

Page 124: ...heck of angle 3I0 and cos Directional residual power can also be used to detect and give selective trip of phase to ground faults in high impedance grounded networks The protection uses the residual p...

Page 125: ...capacitive ground fault current In some power systems a medium size neutral point resistor is used for example in low impedance grounded system Such a resistor will give a resistive ground fault curr...

Page 126: ...ence voltage and the ground fault current will be calculated at the desired sensitivity fault resistance The complex neutral point voltage zero sequence can be calculated as phase 0 f 0 V V 3 R 1 Z EQ...

Page 127: ...sformer neutral points In such a system the impedance Z0 can be calculated as n n c 0 c n n n c n n c 9R X X Z jX 3R j3X 3X X j3R 3X X EQUATION1947 V1 EN Equation 48 Where Xn is the reactance of the P...

Page 128: ...l fault current can be written phase 0 1 0 f 3V 3I 2 Z Z 3 R EQUATION2023 ANSI V1 EN Equation 49 Where Vphase is the phase voltage in the fault point before the fault Z1 is the total positive sequence...

Page 129: ...e written 0A prot 0A 0 A S 3V 3I cos j EQUATION2028 ANSI V1 EN Equation 54 0B prot 0B 0 B S 3V 3I cos j EQUATION2029 ANSI V1 EN Equation 55 The angles A and B are the phase angles between the residual...

Page 130: ...equal to the characteristic angleRCADir has the maximum sensitivity The characteristic for RCADir is equal to 0 is shown in figure 54 3V0 Vref 3I0 RCA 0 ROA 90 ang 3I0 ang 3Vref 3I0 cos en06000648_an...

Page 131: ...rent residual power component in the direction is measured When OpModeSel is set to 3I0 and fi the function will operate if the residual current is larger than the setting INDirPU and the residual cur...

Page 132: ...voltage to be detected tDef is the definite time delay given in s for the directional residual current protection if definite time delay is chosen The characteristic angle of the directional functions...

Page 133: ...EQUATION2030 ANSI V1 EN Equation 57 INDirPU is the operate current level for the directional function when OpModeSel is set 3I0 and fi The setting is given in of IBase The setting should be based on c...

Page 134: ...he trip function of the residual voltage protection tVN is the definite time delay for the trip function of the residual voltage protection given in s 6 6 Thermal overload protection one time constant...

Page 135: ...odel of the line cable based on the current measurement If the temperature of the protected object reaches a set warning level AlarmTemp a signal ALARM can be given to the operator This enables action...

Page 136: ...en given to 150 F 66 C Similar values are stated for overhead lines A suitable setting can be about 60 F 16 C below the trip value ReclTemp Temperature where lockout signal LOCKOUT from the protection...

Page 137: ...failure protection GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase Operation Disabled Enabled FunctionMode This parameter can be set Current or...

Page 138: ...f breaker failure set in of IBase This parameter should be set so that faults with small fault current can be detected The setting can be chosen in accordance with the most sensitive protection functi...

Page 139: ...ed as _ 2 1 cbopen BFP reset margin t t t t t EQUATION1430 V1 EN Equation 58 where tcbopen is the maximum opening time for the circuit breaker tBFP_reset is the maximum time for breaker failure protec...

Page 140: ...1850 identification IEC 60617 identification ANSI IEEE C37 2 device number Stub protection STBPTOC 3I STUB SYMBOL T V1 EN 50STB 6 8 2 Application Stub protection STBPTOC 50STB is a simple phase overcu...

Page 141: ...g guidelines The parameters for Stub protection STBPTOC 50STB are set via the local HMI or PCM600 The following settings can be done for the stub protection GlobalBaseSel Selects the global base value...

Page 142: ...e sequence currents that will give stress on rotating machines Zero sequence currents that might give unwanted operation of sensitive ground fault protections in the power system It is therefore impor...

Page 143: ...repancy protection Can be set Disabled CB oper monitor Continuous monitor In the alternative CB oper monitor the function is activated only directly in connection to breaker open or close command duri...

Page 144: ...must be set to avoid problem with asymmetry under minimum operating conditions Set the time delay tOper 5 60 seconds and reset time tReset 0 010 60 000 seconds 6 11 Directional over under power prote...

Page 145: ...steam supply the electric power consumption will be about 2 of rated power Even if the turbine rotates in vacuum it will soon become overheated and damaged The turbine overheats within minutes if the...

Page 146: ...tion with underpower protection and with overpower protection The underpower protection gives a higher margin and should provide better dependability On the other hand the risk for unwanted operation...

Page 147: ...measurement The setting possibilities are shown in table 11 For reverse power applications PosSeq or Arone modes are strongly recommended Table 11 Complex power calculation Set value Mode Formula use...

Page 148: ...2046 V1 EN Equation 67 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gives trip if the power component in...

Page 149: ...9 mA secondary N S 3 VBase IBase EQUATION2047 V1 EN Equation 68 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection function The setting is given in...

Page 150: ...Old Calculated 1 EQUATION1893 ANSI V1 EN Equation 69 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cyc...

Page 151: ...ge and current used for the power measurement The setting possibilities are shown in table 12 For reverse power applications PosSeq or Arone modes are strongly recommended Table 12 Complex power calcu...

Page 152: ...ion 77 C 3 C C S V I EQUATION2063 ANSI V1 EN Equation 78 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gi...

Page 153: ...is 1 0 of SN At the same time the minimum IED pickup current shall be at least 9 mA secondary N S 3 VBase IBase EQUATION2047 V1 EN Equation 79 The setting Angle1 2 gives the characteristic angle givi...

Page 154: ...lculated 1 EQUATION1893 ANSI V1 EN Equation 80 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SCa...

Page 155: ...nce is practically constant The directional function is current and voltage polarized The function can be set to forward reverse or non directional independently for each step Both steps are provided...

Page 156: ...er in reverse direction The OC1 stage is used to detect faults in forward direction and the OC2 stage is used to detect faults in reverse direction However the following must be noted for such applica...

Page 157: ...caused by abnormal operation or fault in the power system UV2PTUV 27 is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the two...

Page 158: ...VBase which normally is set to the primary rated voltage level phase to phase of the power system or the high voltage equipment under consideration The setting for UV2PTUV 27 is normally not critical...

Page 159: ...phase to ground RMS value or phase to phase RMS value Operation Disabled Enabled UV2PTUV 27 measures selectively phase to ground voltages or phase to phase voltage chosen by the setting ConnType This...

Page 160: ...t1Min Minimum operating time for inverse time characteristic for step 1 given in s When using inverse time characteristic for the undervoltage function during very low voltages can give a short opera...

Page 161: ...quency which can be caused by 1 Different kinds of faults where a too high voltage appears in a certain power system like metallic connection to a higher voltage level broken conductor falling down to...

Page 162: ...ectricum and the insulation The setting must be above the highest occurring normal voltage and below the highest acceptable voltage for the capacitor High impedance grounded systems In high impedance...

Page 163: ...g is highly dependent of the protection application Here it is essential to consider the Maximum voltage at non faulted situations Normally this voltage is less than 110 of nominal voltage tn time del...

Page 164: ...fault connected to ground Depending on the type of fault and fault resistance the residual voltage will reach different values The highest residual voltage equal to three times the phase to ground vol...

Page 165: ...oltage in the feeding transformer neutral Two step residual overvoltage protection ROV2PTOV 59N is used to trip the transformer as a backup protection for the feeder ground fault protection and as a b...

Page 166: ...in Non effectively grounded systems 7 3 3 3 Direct grounded system In direct grounded systems an ground fault on one phase indicates a voltage collapse in that phase The two healthy phases will have n...

Page 167: ...define IBase VBase and SBase Operation Disabled or Enabled VBase is used as voltage reference for the voltage The voltage can be fed to the IED in different ways 1 The IED is fed from a normal voltag...

Page 168: ...In non effectively grounded systems the residual voltage can be maximum the rated phase to ground voltage which should correspond to 100 In effectively grounded systems this value is dependent of the...

Page 169: ...le independent of the protection functions It requires to be set to open the circuit breaker in order to allow a simple system restoration following a main voltage loss of a big part of the network an...

Page 170: ...164...

Page 171: ...SAPTUF 81 detects such situations and provides an output signal suitable for load shedding generator boosting HVDC set point change gas turbine start up and so on Sometimes shunt reactors are automat...

Page 172: ...el are given below Equipment protection such as for motors and generators The setting has to be well below the lowest occurring normal frequency and well above the lowest acceptable frequency for the...

Page 173: ...d can also be used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough 8 2 3 Setting guidelines All the frequency and voltage magnitude c...

Page 174: ...ction SAPFRC 81 8 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Rate of change frequency protection SAPFRC df dt SYMBOL N V1 E...

Page 175: ...a frequency level closer to the primary nominal level if the rate of change frequency is large with respect to sign SAPFRC 81 PICKUP value is set in Hz s All voltage magnitude related settings are ma...

Page 176: ...170...

Page 177: ...ction functions concerned can be blocked and an alarm given In case of large currents unequal transient saturation of CT cores with different remanence or different saturation factor may result in dif...

Page 178: ...ion SDDRFUF 9 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fuse failure supervision SDDRFUF 9 2 2 Application Different prote...

Page 179: ...e added to the fuse failure supervision function in order to detect a three phase fuse failure This is beneficial for example during three phase transformer switching 9 2 3 Setting guidelines 9 2 3 1...

Page 180: ...e selector OpModeSel has been introduced for better adaptation to system requirements The mode selector makes it possible to select interactions between the negative sequence and zero sequence algorit...

Page 181: ...plus a margin of 10 20 IBase is the setting of base current for the function 9 2 3 4 Zero sequence based The relay setting value 3V0PU is given in percentage of the global parameter VBase The setting...

Page 182: ...y voltage for operation of dU dt and ISetprim the primary current for operation of dI dt the setting of DVPU and DIPU will be given according to equation 90 and equation 91 VSetprim DVPU 100 VBase EQU...

Page 183: ...ng is necessary to find out the vitality of the control circuits continuously Trip circuit supervision generates a current of approximately 1 0 mA through the supervised circuit It must be ensured tha...

Page 184: ...with an external resistor The TCSSCBR blocking switch is not required since the external resistor is used If the TCSSCBR is required only in a closed position the external shunt resistance may be omi...

Page 185: ...p circuit supervision without an external resistor The circuit breaker open indication is set to block TCSSCBR when the circuit breaker is open Trip circuit monitoring and other trip contacts It is ty...

Page 186: ...circuit monitoring with auxiliary relays Many retrofit projects are carried out partially that is the old electromechanical relays are replaced with new ones but the circuit breaker is not replaced Th...

Page 187: ...20 mA Rext external shunt resistance Rs trip coil resistance If the external shunt resistance is used it has to be calculated not to interfere with the functionality of the supervision or the trip coi...

Page 188: ...it is recommended to use the circuit breaker position to block unintentional operation of TCSSCBR The use of the position indication is described earlier in this chapter Section 9 1MRK 511 286 UUS A...

Page 189: ...he breaker are satisfied in order to avoid stress on the network and its components The systems are defined to be asynchronous when the frequency difference between bus and line is larger than an adju...

Page 190: ...uously Closing angle is the change in angle during the set breaker closing operate time tBreaker The reference voltage can be phase neutral A B C or phase phase A B B C C A or positive sequence The bu...

Page 191: ...insignificant or zero for manually initiated closing or closing by automatic restoration In steady conditions a bigger phase angle difference can be allowed as this is sometimes the case in a long an...

Page 192: ...FreqDiffM 3 1000 mHz FreqDiffA 3 1000 mHz ANSI10000195 2 en vsd ANSI10000195 V2 EN Figure 70 Principle for the synchronism check function 10 1 2 3 Energizing check The main purpose of the energizing...

Page 193: ...ineEnerg of the base voltage A disconnected line can have a considerable potential because of factors such as induction from a line running in parallel or feeding via extinguishing capacitors in the c...

Page 194: ...e signal BLKU from the internal fuse failure supervision function is then used and connected to the fuse supervision inputs of the energizing check function block In case of a fuse failure the SESRSYN...

Page 195: ...2SEL SYNPROGR SYNFAIL FRDIFSYN FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME VBUS VLINE MODEAEN MODEMEN ANSI08000023 V1 EN Figure 72 Selection of the energi...

Page 196: ...SYNFAIL FRDIFSYN FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN 189 BKR1 52 ANSI11000164 V2 EN Figure 73 Connection of SESRSYN 25...

Page 197: ...DIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN 52 ANSI11000165 V2 EN Figure 74 Connection of SESRSYN 25 function block in a single breaker double busbar ar...

Page 198: ...oltage transformer circuit connections are made according to figure 75 The voltage from busbar1 VT is connected to V3PB1 and the voltage from busbar2 VT is connected to V3PB2 The voltage from the line...

Page 199: ...arameters for selection of measuring phase of the voltage for the busbar 1 and 2 respectively which can be a single phase phase neutral or two phase phase phase voltage or positive sequence SelPhaseLi...

Page 200: ...e 14 Voltage settings examples Line voltage Bus voltage Bus voltage pre processing SESRSYN setting PhaseShift URatio UL1 UL1 Connect UL1 to channel 1 1 UL2 Connect UL2 to channel 1 120 1 UL3 Connect U...

Page 201: ...s normally are regulated to nominal frequency independent of each other so the frequency difference shall be small FreqRateChange The maximum allowed rate of change for the frequency tBreaker The tBre...

Page 202: ...g is preferable where the FreqDiffA setting is used A typical value for the FreqDiffM can 10 mHz and a typical value for the FreqDiffA can be 100 200 mHz when the synchronizing function is not used Ph...

Page 203: ...according to the setting GblBaseSelLine Both energizing can be done in both directions DLLB or DBLL ManEnergDBDL If the parameter is set to Enabled manual closing is enabled when line voltage is belo...

Page 204: ...thstand voltage at a somewhat variable rate Thus a certain dead time with a de energized line is necessary Line service can then be resumed by automatic reclosing of the line breakers The dead time se...

Page 205: ...uipment the auto reclosing open time expression is used This is the dead time setting for the Auto Recloser During simultaneous tripping and reclosing at the two line ends auto reclosing open time is...

Page 206: ...s such as shunt reactor cable or busbar protection are in operation Back up protection zones indicating faults outside the own line are also connected to inhibit the Auto Reclose Automatic reclosing s...

Page 207: ...n by applying a signal to the input RI Starting signals can be either General Trip signals or only the conditions for Differential Distance protection Zone 1 and Distance protection Aided trip In some...

Page 208: ...the starting principle General Trip or only Instantaneous trip adopted above the delayed and back up zones might not be required Breaker failure local and remote must however always be connected 10 2...

Page 209: ...he operating gear recharges The input signals 52a and CBREADY will be set 10 2 2 11 Permanent fault and reclosing unsuccessful signal If a new trip occurs and a new input signal RI or TRSOTF appears a...

Page 210: ...ions are Shall back up time delayed trip give Lock out normally yes Shall Lock out be generated when closing onto a fault mostly Shall Lock out be generated when the Auto Recloser was OFF at the fault...

Page 211: ...his is done by setting parameter AutoCont Enabled and tAutoContWait to the required delay for the function to proceed without a new start 10 2 2 14 Thermal overload protection holding the auto reclosi...

Page 212: ...ve from back up protection functions busbar protection trip or from breaker failure protection When the CB open position is set to start SMBRREC 79 then manual opening must also be connected here The...

Page 213: ...held back When the signal resets a reclosing cycle will continue Please observe that this have a considerable delay Input can also be used for other purposes if for some reason the Auto Reclose shot i...

Page 214: ...losing command READY Indicates that SMBRREC 79 function is ready for a new and complete reclosing sequence It can be connected to the zone extension of a line protection should extended zone reach bef...

Page 215: ...10 2 3 2 Auto recloser parameter settings The operation of the Autorecloser for 3 phase operation SMBRREC 79 function can be switched Enabled and Disabled The setting makes it possible to switch it E...

Page 216: ...ally the trip command and initiate auto reclosing signal reset quickly as the fault is cleared A prolonged trip command may depend on a CB failing to clear the fault A trip signal present when the CB...

Page 217: ...first of all at multi shot reclosing to ensure that the CB is ready for a C O sequence at shot 2 and further shots During single shot reclosing the OCO selection can be used A breaker shall according...

Page 218: ...e setting can be tAutoContWait 2 sec 10 3 Apparatus control 10 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Switch controller...

Page 219: ...ection function to prevent simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substitut...

Page 220: ...local IED HMI If the administrator has defined users with the UMT tool then the local remote switch is under authority control If not the default factory user is the SuperUser that can perform contro...

Page 221: ...value are shown in Table 15 Table 15 Accepted originator categories for each PSTO PermittdSourceToOperate Originator 0 Off 4 5 6 1 Local 1 4 5 6 2 Remote 2 3 4 5 6 3 Faulty 4 5 6 4 Not in use 1 2 3 4...

Page 222: ...s Execute and valid close conditions from the synchronism check At error the command sequence is cancelled The mid position of apparatuses can be suppressed at SCSWI by setting the tIntermediate at SX...

Page 223: ...s exchanged over the serial station bus between the distributed IEDs The problem that arises even at a high speed of communication is a time interval during which the information about the position of...

Page 224: ...SELECT13 SELECT14 SELECT15 SELECT16 RESERVED BAY 1 BAY 2 BAY 3 RESERVED OR ANSI11000169_1_en vsd ANSI11000169 V1 EN Figure 82 Reservations from own and other bays The reservation can also be realized...

Page 225: ...s either from Remote for example control centre or station HMI or from Local local HMI on the IED or from all Local and Remote The Local Remote switch position can also be set to Off which means no op...

Page 226: ...the position handling as well as the control of the position The Circuit breaker SXCBR is the process interface to the circuit breaker for the apparatus control function The Circuit switch SXSWI is th...

Page 227: ...The Synchronism energizing check and synchronizing SESRSYN 25 calculates and compares the voltage phasor difference from both sides of an open breaker with predefined switching conditions synchronism...

Page 228: ...control SXSWI Disconnector Open cmd Close cmd Position SESRSYN 25 Synchrocheck SCILO 3 SCILO 3 Synchrocheck OK SELGGIO Reservation Selected Reserved Enable close Enable open Open rel Close rel Open r...

Page 229: ...select and the execute command signal that is the time the operator has to perform the command execution after the selection of the object to operate When the time has expired the selected output sig...

Page 230: ...is set to 200 ms for a circuit breaker SXCBR and 200 ms for a disconnector or grounding switch SXSWI SuppressMidPos when Enabled will suppress the mid position during the time tIntermediate SwitchTyp...

Page 231: ...at switch interlock because of device alarms is not included in this section Disconnectors and grounding switches have a limited switching capacity Disconnectors may therefore only operate With basica...

Page 232: ...for a longer period the position indication will be interpreted as unknown If both indications stay high something is wrong and the state is again treated as unknown In both cases an alarm is sent to...

Page 233: ...B2 A2 BB_ES ABC_BC ANSI04000505 V1 EN Figure 88 Busbars divided by bus section disconnectors circuit breakers The interlocking functionality in 650 series cannot handle the transfer bus WA7 C To deri...

Page 234: ...nnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If no bus section disconnector exists the signal DCOPTR VPDCTR and EXDU_DC are set to 1 TRUE If the b...

Page 235: ...rounding switch these conditions from the A2 busbar section are valid 189OPTR bay 1 sect A2 BB_DC_OP VP_BB_DC EXDU_BB en04000507_ansi vsd 189OPTR bay n sect A2 VP189TR bay 1 sect A2 VP189TR bay n sect...

Page 236: ...ect B1 VPDCTR B1 B2 EXDU_BB bay n sect B1 AND AND AND DCOPTR B1 B2 EXDU_BB bay 1 sect B1 EXDU_DC B1 B2 ANSI04000508 V1 EN Figure 91 Signals from any bays in section B1 to a busbar grounding switch in...

Page 237: ...4000509 V1 EN Figure 92 Signals from any bays in section B2 to a busbar grounding switch in the same section For a busbar grounding switch on bypass busbar C these conditions are valid 789OPTR bay 1 B...

Page 238: ...formation These signals from each double breaker bay DB_BUS are needed Signal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is vali...

Page 239: ...r the logic for the double busbar configuration described in section Signals in single breaker arrangement Signal BB_DC_OP All disconnectors on this part of the busbar are open VP_BB_DC The switch sta...

Page 240: ...ing of the circuit breaker must be blocked if a bus coupler connection exists between busbars on one bus section side and if on the other bus section side a busbar transfer is in progress en04000489_a...

Page 241: ...coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission erro...

Page 242: ...R bay n sect 1 VPBC12TR sect 2 VP1289TR bay 1 sect 1 VP1289TR bay n sect 1 AND EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC s...

Page 243: ...2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI04000491 V1 EN Figure 99 Signals from any bays for a bus section circuit breaker between...

Page 244: ...re described below 10 4 6 2 Signals in single breaker arrangement If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by...

Page 245: ...open ABC_BC VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid V22089TR The switch status of 289 and 2089 are valid EXDU_BB No transmission error from the bay that co...

Page 246: ...189TR bay n sect A1 EXDU_BB bay 1 sect A1 EXDU_BB bay n sect A1 AND AND ANSI04000494 V1 EN Figure 102 Signals from any bays in section A1 to a bus section disconnector For a bus section disconnector t...

Page 247: ...bays in section B1 to a bus section disconnector For a bus section disconnector these conditions from the B2 busbar section are valid en04000497_ansi vsd 289OPTR 22089OTR bay 1 sect B2 S2DC_OP VPS2_D...

Page 248: ...usbars divided by bus section disconnectors circuit breakers To derive the signals Signal S1DC_OP All disconnectors on bus section 1 are open S2DC_OP All disconnectors on bus section 2 are open VPS1_D...

Page 249: ...gnals from double breaker bays in section A1 to a bus section disconnector For a bus section disconnector these conditions from the A2 busbar section are valid en04000500_ansi vsd 189OPTR bay 1 sect A...

Page 250: ...y 1 sect B2 VP289TR bay n sect B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN Figure 110 Signals from double breaker bays in section B2 to a bus section disconnector 10 4 6...

Page 251: ...status of disconnectors on bus section 1 is valid VPS2_DC The switch status of disconnectors on bus section 2 is valid EXDU_BB No transmission error from breaker and a half BH that contains the above...

Page 252: ...busbar transfer is in progress concerning this bus coupler VP_BBTR The switch status is valid for all apparatuses involved in the busbar transfer EXDU_12 No transmission error from any bay connected...

Page 253: ...th bus section disconnectors are closed So for the basic project specific logic for BBTR above add this logic Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE ABC_BC WA1 A1 WA2 B1 WA...

Page 254: ...cuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 VPS1S2TR The switch status of bus section coupler BS is valid EXDU_BS No transmission e...

Page 255: ...us coupler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from any bus coupler bay BC These signals from each bus coupler bay A...

Page 256: ...h status of bus section coupler BS is valid EXDU_BS No transmission error from the bay containing the above information For a bus coupler bay in section 1 these conditions are valid AND BC_12_CL VP_BC...

Page 257: ...t to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE 289_OP 1 289_CL 0 2089_OP 1 2089_CL 0 2189G_OP 1 2189G_CL 0 BC_1...

Page 258: ...tions from a line to a busbar BH_CONN 3 is the connection between the two lines of the diameter in the breaker and a half switchyard layout For a breaker and a half arrangement the modules BH_LINE_A B...

Page 259: ...ge supervision then set the corresponding inputs as follows VOLT_OFF 1 VOLT_ON 0 10 4 9 Interlocking for double CB bay DB 3 10 4 9 1 Application The interlocking for a double busbar double circuit bre...

Page 260: ...earthing switches of this section DB_BUS_B 3 handles the circuit breaker QA2 that is connected to busbar WA2 and the disconnectors and earthing switches of this section For a double circuit breaker ba...

Page 261: ...line bay ABC_LINE 3 function is used for a line connected to a double busbar arrangement with a transfer busbar according to figure 120 The function can also be used for a double busbar arrangement wi...

Page 262: ...ese signals from each line bay ABC_LINE 3 except that of the own bay are needed Signal 789OPTR 789 is open VP789TR The switch status for 789 is valid EXDU_BPB No transmission error from the bay that c...

Page 263: ...ndle the transfer bus WA7 C To derive the signals Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 BC_17_OP No bus coupler connection between busbar WA1 and WA7 BC_17_CL A bu...

Page 264: ...ars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus secti...

Page 265: ...sect 2 VPBC27TR sect 1 VPDCTR B1B2 VPBC27TR sect 2 EXDU_BC sect 1 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 BC_12_CL VP_BC_12 BC_17_OP BC_17_CL VP_BC_17 BC_27_OP BC_27_CL VP_BC_27 EXDU_BC en04000480_a...

Page 266: ...OP 1 7189G_CL 0 BB7_D_OP 1 BC_17_OP 1 BC_17_CL 0 BC_27_OP 1 BC_27_CL 0 EXDU_BPB 1 VP_BB7_D 1 VP_BC_17 1 VP_BC_27 1 If there is no second busbar WA2 and therefore no 289 disconnector then the interlock...

Page 267: ...an also be used in single busbar arrangements 189 289 189G 289G WA1 A WA2 B 389G 489G 489 389 252 and 489G are not used in this interlocking AB_TRAFO en04000515_ansi vsd 252 152 ANSI04000515 V1 EN Fig...

Page 268: ...upler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar config...

Page 269: ...in order to have different functions operating on pre set values Hardware switches are however sources for maintenance issues lower system reliability and extended purchase portfolio The virtual selec...

Page 270: ...DOWN activation signal positive front and the output activation StopAtExtremes Sets the behavior of the switch at the end positions if set to Disabled when pressing UP while on first position the swit...

Page 271: ...E INV OUT INPUT ANSI07000112 V2 EN Figure 126 Control of Autorecloser from local HMI through Selector mini switch 10 6 3 Setting guidelines Selector mini switch VSGGIO function can generate pulsed or...

Page 272: ...ol 8 signals SPC8GGIO function block is a collection of 8 single point commands designed to bring in commands from REMOTE SCADA to those parts of the logic configuration that do not need complicated f...

Page 273: ...he DNP3 protocol AUTOBITS function block have 32 individual outputs which each can be mapped as a Binary Output point in DNP3 The output is operated by a Object 12 in DNP3 This object contains paramet...

Page 274: ...268...

Page 275: ...ers a simple solution and is often sufficient in well meshed transmission systems and in High Voltage HV systems One SMPPTRC 94 function block should be used for each breaker if the object is connecte...

Page 276: ...iate Lock out but not initiate trip this can be achieved by activating input SETLKOUT The setting AutoLock Disabled means that the internal trip will not activate lock out so only initiation of the in...

Page 277: ...sabled tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the breaker is tripped correctly Normal setting is 0 150s 11 2 Trip matrix logic TMAGGIO 11 2 1 Ide...

Page 278: ...where x 1 3 is Steady or Pulsed A steady signal follows the status of the input signals with respect to OnDelay and OffDelay A pulsed signal will give a pulse once when the Outputx rises from 0 to 1...

Page 279: ...Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Reset set with memory function block RSMEMORY Function description IEC 61850 identification IEC 60...

Page 280: ...I IEEE C37 2 device number INVALIDQT function block INVALIDQT Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Single indication signal combining fu...

Page 281: ...s are accessible via the local HMI or via the PST tool 11 3 3 1 Configuration Logic is configured using the ACT configuration tool in PCM600 Execution of functions as defined by the configurable logic...

Page 282: ...lly and always check the execution sequence for different functions In other cases additional time delays must be introduced into the logic schemes to prevent errors for example race between functions...

Page 283: ...mers When used for auto transformers information from both windings parts together with the neutral point current needs to be available to the function This means that three inputs are needed I3PW1CT1...

Page 284: ...ion B16I 11 5 2 Application Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary logical signals into an integer It can be used for example to connect logical output...

Page 285: ...hes or voltage controllers by inputting an integer number B16IFCVI has a logical node mapping in IEC 61850 11 6 3 Setting guidelines The function does not have any parameters available in the local HM...

Page 286: ...binary logical signals IB16FCVB function can receive an integer from a station computer for example over IEC 61850 8 1 These functions are very useful when the user wants to generate logical commands...

Page 287: ...econds The achievable resolution of the settings depends on the level of the values defined A resolution of 10 ms can be achieved when the settings are defined within the range 1 00 second tAlarm 99 9...

Page 288: ...282...

Page 289: ...output to other systems or equipment in the substation It has one visible input that should be connected in ACT tool 12 1 3 Setting guidelines The function does not have any parameters available in L...

Page 290: ...n analog signal to other systems or equipment in the substation It can also be used inside the same IED to attach a RANGE aspect to an analog value and to permit measurement supervision on that value...

Page 291: ...Application Measurement functions is used for power system measurement supervision and reporting to the local HMI monitoring tool within PCM600 or to station level for example via IEC 61850 The possi...

Page 292: ...lamping of U12 is handled by VLZeroDB in VMMXU zero clamping of I1 is handled by ILZeroDb in CMMXU Dead band supervision can be used to report measured signal value to station level when change in mea...

Page 293: ...the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base val...

Page 294: ...ibrate angle measurements at Y of In where Y is equal to 5 30 or 100 The following general settings can be set for the Phase phase voltage measurement VMMXU VMagCompY Amplitude compensation to calibra...

Page 295: ...m Low limit XLowLowLim Low low limit XLimHyst Hysteresis value in of range and is common for all limits All phase angles are presented in relation to defined reference channel The parameter PhaseAngle...

Page 296: ...xamples in connection to Measurement function CVMMXN are provided Measurement function CVMMXN application for a 380kV OHL Measurement function CVMMXN application on the secondary side of a transformer...

Page 297: ...ed in figure 133 it is necessary to do the following 1 Set correctly CT and VT data and phase angle reference channel PhaseAngleRef see settings for analog input modules in PCM600 using PCM600 for ana...

Page 298: ...ement V and I 0 00 Typically no additional filtering is required Table 18 Settings parameters for level supervision Setting Short Description Selected value Comments PMin Minimum value 100 Minimum exp...

Page 299: ...libration for current at 30 of In 0 00 IAngComp100 Angle pre calibration for current at 100 of In 0 00 12 5 Event counter CNTGGIO 12 5 1 Identification Function description IEC 61850 identification IE...

Page 300: ...unction It is also possible to initiate the counter from a non zero value by resetting the function to the wanted initial value provided as a setting If applicable the counter can be set to stop or ro...

Page 301: ...bance report function DRPRDRE and facilitate a better understanding of the power system behavior and related primary and secondary equipment during and after a disturbance An analysis of the recorded...

Page 302: ...t number and the fault locator information are available as GOOSE or Report Control data 12 7 3 Setting guidelines The setting parameters for the Disturbance report function DRPRDRE are set via the lo...

Page 303: ...function there are a number of settings which also influences the sub functions Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED Green...

Page 304: ...umber The sequence number is automatically increased by one for each new recording and is reset to zero at midnight The maximum number of recordings stored in the IED is 100 The oldest recording will...

Page 305: ...and indications might be saved in the previous report too due to overlap new trip value calculations if installed in operation and started Operation in test mode If the IED is in test mode and OpModeT...

Page 306: ...ig level Trig high low level relative nominal value for analog input M in percent of nominal value 12 7 3 3 Sub function parameters All functions are in operation as long as Disturbance report is in o...

Page 307: ...st valuable disturbances and to maximize the number that is possible to save in the IED The recording time should not be longer than necessary PostFaultrecT and TimeLimit Should the function record fa...

Page 308: ...gh limit The measure value expander block MVEXP has been introduced to be able to translate the integer output signalfrom themeasuringfunctionsto5binarysignals thatisbelowlow lowlimit below low limit...

Page 309: ...een the faulted phases for phase to ground faults the phase to ground loop LMBRFLO function indicates the distance to fault as a percentage of the line length in kilometers or miles as selected on the...

Page 310: ...Z0m Z0m jX0m R1A jX1A R0L jX0L R1L jX1L R0L jX0L R1L jX1L R1B jX1B DRPRDRE LMBRFLO ANSI05000045_2_en vsd ANSI05000045 V2 EN Figure 135 Simplified network configuration with network data required for...

Page 311: ...V1 EN Figure 136 Example of connection of parallel line IN for Fault locator LMBRFLO 12 10 Station battery supervision SPVNZBAT 12 10 1 Identification Function description IEC 61850 identification IE...

Page 312: ...ufficient charging current to offset internal losses resulting in a gradual loss of capacity If a lead acid battery is subjected to a continuous undervoltage heavy sulfation occurs on the plates which...

Page 313: ...s based on received information 12 13 Circuit breaker condition monitoring SSCBR 12 13 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device nu...

Page 314: ...ceeds the set limit helps preventive maintenance This can also be used to indicate the requirement for oil sampling for dielectric testing in case of an oil circuit breaker The change of state can be...

Page 315: ...ber of closing opening operations allowed for the circuit breaker Ia the current at the time of tripping of the circuit breaker Calculation of Directional Coefficient The directional coefficient is ca...

Page 316: ...fter one operation of 10 kA the remaining life of the circuit breaker is 15 000 60 14 940 at the rated operating current Spring charging time indication For normal circuit breaker operation the circui...

Page 317: ...tion automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function i...

Page 318: ...inputs not connected to the pulse counter it will not influence the inputs used for pulse counting 13 2 Energy calculation and demand handling EPTMMTR 13 2 1 Identification Function description IEC 6...

Page 319: ...sQty and ERRAccPlsQty of the energy metering function and then the pulse counter can be set up to present the correct values by scaling in this function Pulse counter values can then be presented on t...

Page 320: ...100 ms tEnergyOffPls gives the OFF time between pulses Typical value can be 100 ms EAFAccPlsQty and EARAccPlsQty gives the MWh value in each pulse It should be selected together with the setting of th...

Page 321: ...orrect co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a pub...

Page 322: ...09000135_en v sd KIOSK 1 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IEC09000135 V1 EN Figure 139 Example of a communication system with IEC 61850 8 1 Figure 140 shows the GOOSE peer to peer...

Page 323: ...g breaker failure protection busbar voltage selection and so on The simplified principle is shown in Figure 141 and can be described as follows When IED1 has decided to transmit the data set it forces...

Page 324: ...n block as output signals for application functions in the application configuration Different GOOSE receive function blocks are available for the specific tasks SMT links the different data object at...

Page 325: ...e used within the application configuration Crosses in the SMT matrix connect received values to the respective function block signal in SMT see Figure 143 The corresponding quality attribute is autom...

Page 326: ...otocol Operation User can set IEC 61850 communication to Enabled or Disabled GOOSE has to be set to the Ethernet link where GOOSE traffic shall be send and received IEC 61850 8 1 specific data logical...

Page 327: ...ntation IEC 60870 5 103 protocol can be configured to use either the optical serial or RS485 serial communication interface on the COM03 or the COM05 communication module The functions Operation selec...

Page 328: ...ome reason PRPSTATUS provides redundant communication over the station bus running IEC 61850 8 1 protocol The redundant communication uses port L1_A and L1_B on the COM3 module Switch A Switch B 1 2 D...

Page 329: ...onfiguration ETHLAN1_AB where OperationMode can be set to Off NonRedundant A or PRP A B The redundant communication will be activated when this parameter is set to PRP A B The ETHLAN1_AB in the Parame...

Page 330: ...IEC13000008 1 en vsd IEC13000008 V1 EN Figure 147 PST screen OperationMode is set to PRP A B Section 14 1MRK 511 286 UUS A Station communication 324 Application manual...

Page 331: ...e possible faults through a hardware contact on the power supply module and or through the software communication Internal events are generated by the built in supervisory functions The supervisory fu...

Page 332: ...ime synchronization TIMESYNCHGE N Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Time system summer time begins DSTBEGIN Function description IEC...

Page 333: ...ine ends can be compared during evaluation In the IED the internal time can be synchronized from a number of sources SNTP IRIG B DNP IEC60870 5 103 Micro SCADA OPC server should not be used as a time...

Page 334: ...n is needed for example when no other synchronization is available First set the IED to be synchronized via IEC 60870 5 103 either from IED Configuration Time Synchronization TIMESYNCHGEN 1 in PST or...

Page 335: ...se masters that are really bad in time sync the EvalTimeAccuracy can be set to Disabled According to the standard the Bad Time flag is reported when synchronization has been omitted in the protection...

Page 336: ...selected with configured input to the function block ACTVGRP The parameter MaxNoSetGrp defines the maximum number of setting groups in use to switch between Only the selected number of setting groups...

Page 337: ...5 2 Application Change lock function CHNGLCK is used to block further changes to the IED configuration once the commissioning is complete The purpose is to make it impossible to perform inadvertent IE...

Page 338: ...nput If such a situation would occur in spite of these precautions then please contact the local ABB representative for remedial action 15 5 3 Setting guidelines The Change lock function CHNGLCK does...

Page 339: ...Product identifiers The following identifiers are available IEDProdType Describes the type of the IED like REL REC or RET Example REL650 ProductVer Describes the product version Example 1 2 3 1 is the...

Page 340: ...g has no specific meaning except that it is used for internal identification purposes within ABB ProductionDate states the production date in the YYYY MM_DD format 15 8 Primary system values PRIMVAL 1...

Page 341: ...og signals acquired phase angle RMS value frequency and frequency derivates and so on 244 values in total Besides the block group name the analog inputs type voltage or current and the analog input na...

Page 342: ...to negate the 3ph signal it is possible to choose to negate only the phase signals Negate3Ph only the neutral signal NegateN or both Negate3Ph N MinValFreqMeas The minimum value of the voltage for wh...

Page 343: ...n with adaptive frequency tracking with one reference selected for all instances In practice each instance can be adapted to the needs of the actual application The adaptive frequency tracking is need...

Page 344: ...ence For task time group 2 this gives the following settings SMAI_20_2 2 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI_20_7 1 DFTRefExtOut ExternalDFTRef even if the output SPCFOU...

Page 345: ...AL is used to provide global values common for all applicable functions within the IED One set of global values consists of values for current voltage and apparent power and it is possible to have six...

Page 346: ...ATHCHCK 15 12 2 Application To safeguard the interests of our customers both the IED and the tools that are accessing the IED are protected by means of authorization handling The authorization handli...

Page 347: ...er created an attempt to log on will display a message box No user defined If one user leaves the IED without logging off then after the timeout set in Main menu Configuration HMI Screen SCREEN 1 elap...

Page 348: ...sword three times that user will be blocked for ten minutes before a new attempt to log in can be performed The user will be blocked from logging in both from the local HMI and PCM600 However other us...

Page 349: ...e primary functionality of the device All inbound network traffic will be quota controlled so that too heavy network loads can be controlled Heavy network load might for instance be the result of malf...

Page 350: ...344...

Page 351: ...magnetic core CTs are usually specified and manufactured according to some international or national standards which specify different protection classes as well There are many different standards an...

Page 352: ...function phase to ground phase to phase and three phase faults have been tested for different relevant fault positions for example close in forward and reverse faults zone 1 reach faults internal and...

Page 353: ...the circuit For ground faults the loop includes the phase and neutral wire normally twice the resistance of the single secondary wire For three phase faults the neutral current is zero and it is just...

Page 354: ...actual unwanted residual current during the commissioning 16 1 6 Rated equivalent secondary e m f requirements With regard to saturation of the current transformer all current transformers of high re...

Page 355: ...ive time phase and residual overcurrent protection The CTs must have a rated equivalent secondary e m f Eal that is larger than or equal to the required secondary e m f Ealreq below sn R al alreq CT L...

Page 356: ...rated primary CT current A Isn The rated secondary CT current A In The nominal current of the protection IED A RCT The secondary resistance of the CT W RL The resistance of the secondary cable and ad...

Page 357: ...current input channel VA Sr 0 010 VA channel for Ir 1 A and Sr 0 250 VA channel for Ir 5 A 16 1 7 Current transformer requirements for CTs according to other standards All kinds of conventional magnet...

Page 358: ...Eknee that fulfills the following 1 Old Calculated S TD S TD S EQUATION1893 ANSI V1 EN Equation 100 16 1 7 3 Current transformers according to ANSI IEEE Current transformers according to ANSI IEEE are...

Page 359: ...7 110 2007 IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes 16 2 Voltage transformer requirements The performance of a protection function will depend on th...

Page 360: ...task or at least equipped with a real time operating system that is not a PC with SNTP server software The SNTP server should be stable that is either synchronized from a stable source like GPS or lo...

Page 361: ...ection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BOS Binary outputs status BR External bistable relay BS British Standards CB Circuit breaker CCITT Consulta...

Page 362: ...rojects Agency The US developer of the TCP IP protocol etc DBDL Dead bus dead line DBLL Dead bus live line DC Direct current DFC Data flow control DFT Discrete Fourier transform DHCP Dynamic Host Conf...

Page 363: ...nication interface module with carrier of GPS receiver module GDE Graphical display editor within PCM600 GI General interrogation command GIS Gas insulated switchgear GOOSE Generic object oriented sub...

Page 364: ...referred to as instances of that function One instance of a function is identical to another of the same kind but has a different number in the IED user interfaces The word instance is sometimes defin...

Page 365: ...term used to describe how the relay behaves during a fault condition For example a distance relay is overreaching when the impedance presented to it is smaller than the apparent impedance to the faul...

Page 366: ...rding to standard IEC 61850 SDU Service data unit SMA connector Subminiature version A A threaded connector with constant impedance SMT Signal matrix tool within PCM600 SMS Station monitoring system S...

Page 367: ...is module transforms currents and voltages taken from the process into levels suitable for further signal processing TYP Type identification UMT User management tool Underreach A term used to describe...

Page 368: ...n the phonetic alphabet stands for Z which stands for longitude zero UV Undervoltage WEI Weak end infeed logic VT Voltage transformer 3IO Three times zero sequence current Often referred to as the res...

Page 369: ...363...

Page 370: ...ce ABB AB does not accept any responsibility whatsoever for potential errors or possible lack of information in this document We reserve all rights in this document and in the subject matter and illus...

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Summary of Contents for REC650 ANSI

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