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2.6 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In

43

7UM61 Manual
C53000-G1176-C127-3

Figure 2-4

Logic Diagram of the Overcurrent Stage I> with Undervoltage Seal-In

2.6.2

Setting Notes

General

Overcurrent protection is only effective and available if address 

112

 

O/C PROT. I>

 

is set to 

Enabled

 during configuration. If the function is not needed it is set to 

Disabled

.

Overcurrent Stage 
I> 

Address 

1201

 

O/C I>

 is used to switch the definite time-overcurrent stage I> 

ON

 and 

OFF

, or to block only the trip command (

Block relay

). For setting the 

I>

 overcurrent 

stage it is the maximum anticipated load current which is most relevant. Pickup due to 
overload should never occur since the protection may trip if short command times are 
set. For this reason, a setting between 20 % and 30 % over the expected peak load is 
recommended for generators, and a setting of about 40 % for transformers and 
motors.

The trip time delay (parameter 

1203

 

T I>

) must be coordinated with the time grading 

of the network in order to ensure that the protective equipment closest to the corre-
sponding fault location trips first (selectivity).

The selected time is only an additional time delay and does not include the operating 
time (measuring time, dropout time). The delay can be set to 

∞

. After pickup the 

element will then not trip. Pickup, however, will be signaled. If the I> stage is not re-
quired at all, address 

1201

 

O/C I>

  is set to 

OFF

. This prevents tripping and the gen-

eration of a pickup message.

www 

. ElectricalPartManuals 

. com

Summary of Contents for Siprotec 7UM611

Page 1: ...rator Protection Relay 7UM61 V4 1 Manual C53000 G1176 C127 3 Preface Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 2: ...the right to make technical improvements without notice Copyright Copyright Siemens AG 2003 All rights reserved Dissemination or reproduction of this document or evaluation and communication of its contents is not authorized except where expressly permitted Violations are liable for damages All rights reserved particularly for the purposes of patent application or trademark registration Registered...

Page 3: ...licability of this Manual This manual is valid for Multi Functional Generator Protection Relay with Local Control SIPROTEC 4 7UM61 firmware version V4 1 Indication of Con formity This product is UL certified according to the Technical Data This product complies with the directive of the Council of the European Commu nities on the approximation of the laws of the Member States relating to electro m...

Page 4: ...and maintenance by qualified personnel under observance of all warnings and hints contained in this manual In particular the general erection and safety regulations e g IEC DIN VDE EN or other national and international stan dards regarding the correct use of hoisting gear must be observed Instructions and Warnings The warnings and notes contained in this manual serve for your own safety and for a...

Page 5: ...r word for word in the display of the device or on the screen of a personal computer with op eration software DIGSI are marked in bold letters of a monospace type style This also applies to header bars for selection menus 1234A Parameter addresses have the same character style as parameter names Param eter addresses contain the suffix A in the overview tables if the parameter can only be set in DI...

Page 6: ...lence output is active if only one of the inputs is active Equivalence output is active if both inputs are active or in active at the same time Dynamic inputs edge triggered above with positive below with negative edge Formation of one analog output signal from a number of analog input signals Limit stage with setting address and parameter designator name Timer pickup delay T example adjustable wi...

Page 7: ...stem Data 1 34 2 3 1 Setting Notes 34 2 3 2 Settings 37 2 3 3 Information List 38 2 4 Change Group 39 2 4 1 Setting Notes 39 2 4 2 Settings 39 2 4 3 Information List 39 2 5 Power System Data 2 40 2 5 1 Functional Description 40 2 5 2 Setting Notes 40 2 5 3 Settings 40 2 5 4 Information List 40 2 6 Definite Time Overcurrent Protection I ANSI 50 51 with Undervoltage Seal In 42 2 6 1 Functional Descr...

Page 8: ...tion ANSI 46 70 2 10 1 Functional Description 70 2 10 2 Setting Notes 72 2 10 3 Settings 75 2 10 4 Information List 76 2 11 Underexcitation Loss of Field Protection ANSI 40 77 2 11 1 Function Description 77 2 11 2 Setting Notes 79 2 11 3 Settings 83 2 11 4 Information List 84 2 12 Reverse Power Protection ANSI 32R 85 2 12 1 Function Description 85 2 12 2 Setting Notes 86 2 12 3 Settings 88 2 12 4 ...

Page 9: ...n 113 2 18 2 Setting Notes 115 2 18 3 Settings 117 2 18 4 Information List 117 2 19 Rate of Frequency Change Protection df dt ANSI 81R 118 2 19 1 Functional Description 118 2 19 2 Setting Notes 119 2 19 3 Settings 121 2 19 4 Information List 122 2 20 Jump of Voltage Vector 123 2 20 1 Function Description 123 2 20 2 Setting Notes 125 2 20 3 Settings 126 2 20 4 Information List 127 2 21 90 Stator Ea...

Page 10: ... Failure Protection ANSI 50BF 157 2 26 1 Functional Description 157 2 26 2 Setting Notes 159 2 26 3 Settings 160 2 26 4 Information List 160 2 27 Inadvertent Energization ANSI 50 27 162 2 27 1 Functional Description 162 2 27 2 Setting Notes 163 2 27 3 Settings 164 2 27 4 Information List 165 2 28 Measurement Supervision 166 2 28 1 Functional Description 166 2 28 2 Setting Notes 174 2 28 3 Settings...

Page 11: ...e LEDs LCD 205 2 34 3 1 Functional Description 205 2 34 3 2 Setting Notes 205 2 34 4 Statistics 206 2 34 4 1 Functional Description 206 2 34 4 2 Information List 207 2 35 Ancillary Functions 208 2 35 1 Processing of Annunciations 208 2 35 1 1 Functional Description 208 2 35 2 Measurement 211 2 35 2 1 Functional Description 211 2 35 2 2 Information List 215 2 35 3 Set Points Measured Values 215 2 3...

Page 12: ...ting 253 3 1 3 3 Panel Surface Mounting 254 3 2 Checking Connections 255 3 2 1 Checking Data Connections of Serial Interfaces 255 3 2 2 Checking Device Connections 257 3 2 3 Checking System Incorporation 259 3 3 Commissioning 262 3 3 1 Test Mode and Transmission Block 263 3 3 2 Testing System Ports 263 3 3 3 Checking the Binary Inputs and Outputs 265 3 3 4 Testing Circuit Breaker Failure Protectio...

Page 13: ...erse Power Protection ANSI 32R 320 4 8 Forward Active Power Supervision ANSI 32F 321 4 9 Impedance Protection ANSI 21 322 4 10 Undervoltage Protection ANSI 27 323 4 11 Overvoltage Protection ANSI 59 324 4 12 Frequency Protection ANSI 81 325 4 13 Overexcitation Volt Hertz Protection ANSI 24 326 4 14 Rate of Frequency Change Protection df dt ANSI 81R 328 4 15 Jump of Voltage Vector 329 4 16 90 Stato...

Page 14: ...ing Information 352 A 1 1 1 7UM61 352 A 1 2 Accessories 354 A 2 Terminal Assignments 357 A 2 1 General Diagram 357 A 2 2 General Diagram Surface Mounting Version 358 A 2 3 General Diagram 359 A 2 4 General Diagram Surface Mounting Version 360 A 3 Connection Examples 361 A 3 1 Connection Examples 361 A 3 2 Connection Examples for Thermobox 370 A 3 3 Schematic Diagram of Accessories 371 A 4 Default ...

Page 15: ...Contents 15 7UM61 Manual C53000 G1176 C127 3 Literature 411 Glossary 413 Index 421 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 16: ...Contents 16 7UM61 Manual C53000 G1176 C127 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 17: ...UM61 devices are introduced in this section An overview of the 7UM61 is presented with its application areas features and scope of functions 1 1 Overall Operation 18 1 2 Application Scope 21 1 3 Characteristics 23 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 18: ... the currents and volt ages from the primary transformers and adapt them to the internal processing level of the device The device has 4 current and 4 voltage inputs Three inputs are used on each side of the protected object for measuring of the phase currents Figure 1 1 Hardware Structure of the Digital Machine Protection Device 7UM61 maximum configuration 1 current input is equipped with sensiti...

Page 19: ...l sampling frequency This ensures that the protection and mea surement functions produce correct results over a wide frequency range This ensures measuring accuracy in the frequency range from 11 Hz to 69 Hz The sampling frequency adaptation can however operate only when at least one a c measured quantity is present at one of the analog inputs with an amplitude of at least 5 of rated value operati...

Page 20: ...n be transferred to a central control or monitoring system via the serial system interface This interface may be provided with various protocols and physical transmission modes to suit the particular application A further interface is provided for time synchronization of the internal clock through ex ternal synchronization sources Further communication protocols can be implemented via additional c...

Page 21: ...Connections The scalable software allows a wide range of applications Corresponding function packages can be selected for each particular application For instance alone with the 7UM61 device it is possible to provide comprehensive and reliable protection of gen erators from small to medium capacity approx 0 5 5 MW Additionally the device forms the basis for the protection of medium to large size g...

Page 22: ...ter By means of the SIPROTEC operating software DIGSI all operational and evaluation tasks can be executed via this user interface such as specifying and modifying configuration parameters and settings configuring user specific logic func tions retrieving operational and fault messages and measured values readout and display of fault recordings querying of devices statuses and measured values Rear...

Page 23: ...f currents switched off last by the device as well as accumulated short circuit currents of each pole of the circuit breaker Operating Hours Counter Tracking of operating hours of the equipment under load being protected Commissioning aids such as connection check field rotation check status display of all binary inputs and outputs and test measurement recording Definite Time Over current Protecti...

Page 24: ...ositive sequence components Supervision of over power P and or under power P of active power output with individually adjustable power limits Optionally high speed or high accuracy measurement Impedance protec tion Overcurrent pickup with undervoltage seal in for synchronous machines which take their excitation voltage from the terminals 2 impedance zones 1 overreach zone switchable via binary inp...

Page 25: ... detection Measurement circuit monitoring for minimum current flow when used for rotor earth fault protection 100 Stator Earth Fault Protection with3rdHarmonic Detection of the 3rd harmonic of the voltage at the starpoint or broken delta winding of an earthing transformer In addition to the 90 stator earth fault protection there is a protection of the entire stator winding protective range 100 Mot...

Page 26: ...sh user defined logic functions All common logic functions AND OR NOT Exclusive OR etc Time delays and limit value interrogations Processing of measured values including zero suppression adding a knee charac teristic for a transducer input and live zero monitoring Breaker Control Circuit breakers can be opened and closed manually via programmable function keys via the system interface e g by SICAM...

Page 27: ... ANSI 50 51 67 with Direction Detection 46 2 8 Inverse Time Overcurrent Protection ANSI 51V 52 2 9 Thermal Overload Protection ANSI 49 59 2 10 Unbalanced Load Negative Sequence Protection ANSI 46 70 2 11 Underexcitation Loss of Field Protection ANSI 40 77 2 12 Reverse Power Protection ANSI 32R 85 2 13 Forward Active Power Supervision ANSI 32F 89 2 14 Impedance Protection ANSI 21 92 2 15 Undervolta...

Page 28: ...tor 149 2 26 Breaker Failure Protection ANSI 50BF 157 2 27 Inadvertent Energization ANSI 50 27 162 2 28 Measurement Supervision 166 2 29 Trip Circuit Supervision 176 2 30 Threshold supervision 183 2 31 External Trip Functions 189 2 32 RTD Box 192 2 33 Phase Rotation Reversal 201 2 34 Protection Function Control 203 2 35 Ancillary Functions 208 2 36 Command Processing 221 w w w E l e c t r i c a l ...

Page 29: ...rmation about the setting values 2 1 1 Functional Description Generator The calculation examples are based on two smaller capacity reference power systems with the two typical basic connections i e the busbar connection and the unit connec tion see following figure All default settings of the relay are adapted accordingly Figure 2 1 Reference Systems w w w E l e c t r i c a l P a r t M a n u a l s...

Page 30: ... that system indepen dent typical settings of the protective functions can be pre specified The data of the individual power system are updated in the Power System Data 1 or Power System Data 2 and conversion to secondary values is done by mouse clicking All necessary conversion formulas of the individual functions are stored in the operating program Generator SN T 5 27 MVA UN Gen 6 3 kV ING 483 A...

Page 31: ...figuration settings can be entered using a PC and the software program DIGSI and transferred via the front serial port or the rear service interface Operation is de scribed in the SIPROTEC System Description 1 For changing configuration parameters in the device password no 7 is required for parameter set Without the password the settings may be read but may not be mod ified and transferred to the ...

Page 32: ...able star point resistors The third option considers as a further criterion the direction of the earth fault current if with machines in busbar connection the magnitudes of displace ment voltage and earth fault current alone are not sufficient to distinguish between system earth faults and machine earth faults For trip circuit monitoring address 182 Trip Cir Sup is used to specify whether two bina...

Page 33: ...RESTART INHIBIT Disabled Enabled Enabled Restart Inhibit for Motors 170 BREAKER FAILURE Disabled Enabled Enabled Breaker Failure Protection 171 INADVERT EN Disabled Enabled Enabled Inadvertent Energisation 180 FUSE FAIL MON Disabled Enabled Enabled Fuse Failure Monitor 181 M V SUPERV Disabled Enabled Enabled Measured Values Supervision 182 Trip Cir Sup Disabled 2 Binary Inputs 1 Binary Input Disab...

Page 34: ...fini tion even in cases where there are no starpoint CTs Figure 2 2 Location of the CT Starpoints Nominal Values of the Transformers At addresses 211 CT PRIMARY and 212 CT SECONDARY information is entered re garding the primary and secondary current rating of the current transformers It is im portant to ensure that the rated secondary current of the current transformer matches the rated current of...

Page 35: ...ormer delivering the UE voltage With the exception of the rotor earth fault protection the 224 FACTOR UE has an impact on those protection functions which process the UE input directly as shown in Table 2 1 For this ratio224 FACTOR UE the following generally applies In this context UVT prim is the primary voltage generally phase ground voltage and UE sec is the secondary displacement voltage appli...

Page 36: ... quency The nominal frequency of the system is set in Address 270 Rated Frequency The factory setting of the model variant must only be changed if the device is to be used for a purpose other than intended when ordering PhaseRotation Address 271 PHASE SEQ is used to change the default phase sequence L1 L2 L3 for clockwise rotation if your power system permanently has an anti clockwise phase sequen...

Page 37: ...se of overload protection this criterion distinguishes between standstill and motion of the machine to be protected 2 3 2 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings The table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting...

Page 38: ... Minimum TRIP Command Duration 281 BkrClosed I MIN 1A 0 04 1 00 A 0 04 A Closed Breaker Min Current Threshold 5A 0 20 5 00 A 0 20 A No Information Type of In formation Comments 361 FAIL Feeder VT EM Failure Feeder VT MCB tripped 5002 Operat Cond AM Suitable measured quantities present 5145 Reverse Rot EM Reverse Phase Rotation 5147 Rotation L1L2L3 AM Phase Rotation L1L2L3 5148 Rotation L1L3L2 AM P...

Page 39: ...ng mode the applicable setting group is activated usually via a binary input If multiple setting groups are not required Group A is the default selection The rest of this section is not relevant 2 4 1 Setting Notes General If the changeover option is desired on function extent configuration group changeover must be set to Grp Chge OPTION Enabled address 103 When setting the func tion parameters yo...

Page 40: ...These values are important for pickup settings The allow the device to calculate operational values as percentage values For example if a CT ratio of 500 1 is selected and the rated current of the generator is 483 A a value of 500 A should be entered at address 211 and a value of 483 A under I PRIMARY OP 483 amps are now displayed as 100 in the percentage metering display Active Power Direc tion A...

Page 41: ...ary fault current IL3 5012 UL1E AM Voltage UL1E at trip 5013 UL2E AM Voltage UL2E at trip 5014 UL3E AM Voltage UL3E at trip 5015 P AM Active power at trip 5016 Q AM Reactive power at trip 5017 f AM Frequency at trip No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 42: ...n be disabled off and made ineffective via binary input 2 6 1 Functional Description I Stage Each phase current is compared individually with the I common setting value and signaled separately on overshoot A trip signal is transmitted to the matrix as soon as the corresponding T I time delay has expired On delivery the dropout value is set to 95 below the pickup value For special applications it i...

Page 43: ...verload should never occur since the protection may trip if short command times are set For this reason a setting between 20 and 30 over the expected peak load is recommended for generators and a setting of about 40 for transformers and motors The trip time delay parameter 1203 T I must be coordinated with the time grading of the network in order to ensure that the protective equipment closest to ...

Page 44: ...pecification 2 6 3 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings The table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Pick up thresh old 1 4 IN Mach Trip Time Delay 3 sec Undervoltage Seal In 0 8 IN Mach Holding time of U 4 sec Dropout Ratio 0 9...

Page 45: ...f In formation Comments 1722 BLOCK I EM BLOCK I 1811 I Fault L1 AM O C fault detection stage I phase L1 1812 I Fault L2 AM O C fault detection stage I phase L2 1813 I Fault L3 AM O C fault detection stage I phase L3 1815 I TRIP AM O C I TRIP 1950 Useal in BLK EM O C prot BLOCK undervoltage seal in 1965 I OFF AM O C prot stage I is switched OFF 1966 I BLOCKED AM O C prot stage I is BLOCKED 1967 I A...

Page 46: ... 1 Function Description I Stage Each phase current is compared individually with the I common pick up value and signaled on overshoot A trip signal is transmitted to the matrix as soon as the corre sponding T I time delays have expired The dropout value is 95 below the pick up value Direction Detection The I stage is equipped with a disconnectable direction element permitting a trip ping only for ...

Page 47: ... voltage has collapsed short circuit close to generator terminals After the expiration of the storage time period 2 cycles the detected direction is saved as long as no sufficient measuring voltage is available If a short circuit already exists at generator startup or for motors or transformers on connection so that no voltage is present in the memory and no direction can be determined a trip is i...

Page 48: ...isabled If direction acquisition is used make sure that the CT and VT sets are consistent High current Stage I Address 1301 O C I is used to switch the definite time I stage for phase currents ON and OFF or to block only the trip command Block relay The high current stage I Parameter 1302 and its associated delay time T I 1303 is used for current grading with large impedances existing for example ...

Page 49: ...ocking zone can be adapted to the network conditions by way of the LINE ANGLE parameter To do this the line angle of the network is set The direction straight line is perpendicular to the set direction angle Together with the parameter 1304 Phase Direction Forward or Reverse this parameter covers the entire impedance level This is the reverse direction provided that the protective relay has been c...

Page 50: ...tripping delay TI 0 05 s to 0 1 s is required to ensure that bal ancing procedures are finished Application Exam ple Motor Protec tion For motors that have no no separate current transformer in the starpoint the following figure shows how to use the I stage as differential protection The configuration of the protection function depends on the transformers Since this application is most likely to b...

Page 51: ...I Time Delay 1304 Phase Direction Forward Reverse Reverse Phase Direction 1305 LINE ANGLE 90 90 60 Line Angle No Information Type of In formation Comments 1720 BLOCK dir EM BLOCK direction I stage 1721 BLOCK I EM BLOCK I 1801 I Fault L1 AM O C fault detection stage I phase L1 1802 I Fault L2 AM O C fault detection stage I phase L2 1803 I Fault L3 AM O C fault detection stage I phase L3 1806 I forw...

Page 52: ... time curves the independent stages I and I are enabled see Section 2 6 2 8 1 Functional Description Pickup and Trip ping Each phase current is compared individually with the common Ip setting value If the current exceeds 1 1 times the setting value the stage picks up and is signaled phase related For pickup the rms values of the fundamental harmonic are used During the pickup of an Ip stage the t...

Page 53: ...n principle a distinction must be made between a unit connection and a busbar connection which must be communi cated to the device by the parameter 272 SCHEME As phase to phase voltages are referred to in any case faulty measurements during earth faults are avoided Table 2 3 Controlling voltages in relation to the fault currents In or to avoid unwanted operation during a voltage transformer fault ...

Page 54: ... Functions 54 7UM61 Manual C53000 G1176 C127 3 Figure 2 11 Logic Diagram of the Inverse Overcurrent Time Protection without Undervoltage Influencing w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 55: ...ure 2 12 Logic Diagram of the Voltage Controlled Inverse Overcurrent Time Protection The changeover to the lower current pickup value on decreasing voltage loop enable is performed on a phase by phase basis in accordance with Table 2 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 56: ...set to with IEC or with ANSI If the function is not needed it is set to Disabled Ip Overcurrent Stage The address 1401 O C Ip serves to switch the function ON or OFF or to block only the trip command Block relay It must be noted that for the inverse overcurrent time protection a safety factor of about 1 1 has been included between the pick up value and the setting value This means that a pickup wi...

Page 57: ... 1408 serves to predefine the U pick up value for the undervoltage trip of the Ip pickup value for voltage controlled inverse overcurrent time protection AMZ parameter 1407 VOLT INFLUENCE Volt controll The parameter is set to a value just below the lowest phase to phase voltage admissible during operation e g from 75 to 80 V In this context the same rules apply as for the undervoltage seal in of t...

Page 58: ...n 1891 O C Ip OFF AM O C protection Ip is switched OFF 1892 O C Ip BLOCKED AM O C protection Ip is BLOCKED 1893 O C Ip ACTIVE AM O C protection Ip is ACTIVE 1896 O C Ip Fault L1 AM O C fault detection Ip phase L1 1897 O C Ip Fault L2 AM O C fault detection Ip phase L2 1898 O C Ip Fault L3 AM O C fault detection Ip phase L3 1899 O C Ip pick up AM O C Ip picked up 1900 O C Ip TRIP AM O C Ip TRIP Add...

Page 59: ...mptote represents the final temperature ΘEnd After an initial settable over temperature threshold is reached an alarm is issued for e g load reduction mea sures If the second overtemperature threshold i e final overtemperature trip tem perature is reached the protected equipment is disconnected from the network It is also possible however to set the overload protection to Alarm Only In this case o...

Page 60: ...ermal capacitance In a self ven tilated machine however the thermal time constant at standstill can differ consider ably from the time constant of a continually running machine since then the ventilation provides for cooling whereas at standstill only natural convection takes place Therefore two time constants must be considered in such cases for setting In this context machine standstill is detec...

Page 61: ...ection ANSI 49 61 7UM61 Manual C53000 G1176 C127 3 The following figure shows the logic diagram for overload protection Figure 2 14 Logic Diagram of the Overload Protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 62: ...verload protection ON or OFF can be set the trip command blocked Block relay or the protection function set toAlarm Only In the latter case no fault record is created should an overload occur If overload protection is switched ON tripping is also possible K Factor The overload protection is set with quantities per unit The nominal current IN machine of the object to be protected generator motor tr...

Page 63: ...he admissible power up time corresponding to a certain over load value is indicated Alarm Stages By setting the thermal alarm level Θ ALARM address 1604 a alarm message can be issued before the tripping temperature is reached thus avoiding tripping by promptly reducing load This alarm level simultaneously represents the dropout level for the trip ping signal The tripping signal is interrupted only...

Page 64: ...N see margin heading Cur rent Flow Monitoring in section P System Data 1 If no distinction between time constants is necessary the prolongation factor Kτ FACTOR can be left as 1 0 default Current Limiting The parameter 1615 I MAX THERM specifies up to which current value the trip times are calculated in accordance with the prescribed formula In the trip characteristics of the following figure this...

Page 65: ...he thermal replica is again below the dropout threshold Ambient or Coolant Temperature The specifications given up to now are sufficient for modeling overtemperature In ad dition to this the machine protection can also process the ambient or coolant temper ature This temperature value must be communicated to the device as digitalized mea sured value via field bus e g Profibus DP Address 1607 TEMP ...

Page 66: ...s are performed with standardized quantities The ambient temperature must also be standardized The temperature at nominal machine current is used as standardization value If the nominal machine current deviates from the nominal CT current the temperature must be adapted according to the following formula At address 1605 or 1606 TEMP RISE I the temperature adapted to the nominal trans former curren...

Page 67: ...ulate the trip time with τ TIME CONSTANT address 1603 k K FACTOR address 1602 IN Nominal Device Current I Actually Flowing Secondary Current IPre Previous Load Current ΘN Temperature with Nominal Current IN Address 1605 ΘK Coolant Temperature Input Scaling with Address 1608 or 1609 Example Machine INMach 483 A ImaxMach 1 15 IN at ΘK 40 C τth 600 s thermal time constant of the machine Current trans...

Page 68: ...g secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 1601 Ther OVER LOAD OFF ON Block relay Alarm Only OFF Thermal Overload Protec tion 1602 K FACTOR 0 10 4 00 1 11 K Factor 1603 TIME CONSTANT 30 32000 sec 600 sec Thermal Time Constant 1604 Θ ALARM 70 100 90 Thermal Alarm Stage 1605 TEMP RISE I 40 200 C 100 C Temperature Rise at Rated Sec...

Page 69: ...verload EM BLOCK thermal overload protection 1506 RM th rep O L EM Reset memory for thermal replica O L 1507 Emer Start O L EM Emergency start O L 1508 Fail Temp inp EM Failure temperature input 1511 Th Overload OFF AM Thermal Overload Protection OFF 1512 Th Overload BLK AM Thermal Overload Protection BLOCKED 1513 Overload ACT AM Overload Protection ACTIVE 1514 Fail Temp inp AM Failure temperature...

Page 70: ... the continuously permissible negative phase sequence current I2 is exceeded after expiry of a set time T WARN a warning message I2 Warn is issued see Figure 2 16 Thermal Character istic The machine manufacturers indicate the permissible unbalanced load by means of the following formula The asymmetry factor depends on the machine and represents the time in seconds during which the generator can be...

Page 71: ...rip in a shorter time Tripping Stages Figure 2 16 Tripping Zone of the Unbalanced Load Protection Definite Time Trip ping Stage High negative phase sequence currents can only be caused by a phase to phase short circuit in the system which must be covered in accordance with the network grading plan For this reason the thermal characteristic is cut by a selectable definite time negative phase sequen...

Page 72: ...on salient pole rotors this typically amounts to a value in a range from 6 to 8 of the nominal machine current and with salient pole rotors at least 12 For larger machines and in cases of doubt please refer to the instructions of the machine manufacturer It is important to note that the manufacturer s data relate to the primary values of the machine for example the maximum permissible continuous i...

Page 73: ...Values The factor K can be derived from the unbalanced load characteristic according to the following figure by reading the time at point I2 IN 1 corresponding to FACTOR K Example tadm 20 s for I2 IN 1 The constant Kprimary 20 s determined in this way is valid for the machine side pri mary side The factor Kprimary can be converted to the secondary side by means of the following formula The calcula...

Page 74: ...nced load I2 to the initial value If the machine manufacturer does not provide this information the setting value can be cal culated by assuming an equal value for cool down time and heatup time of the object to be protected The formula below shows the relation between the K asymmetry factor and the cool down time Example The following cool down time results for a K 20 s and an admissible continua...

Page 75: ...ng of phase to phase short circuits Contrary to time overcurrent protection the I2 stage is able to detect fault currents at nominal current The following conditions apply A phase to ground fault with current I corresponds to a negative sequence current A phase to ground fault with current I corresponds to a negative sequence current With an isolated starpoint the I current value is particularly l...

Page 76: ... 5151 I2 OFF AM I2 switched OFF 5152 I2 BLOCKED AM I2 is BLOCKED 5153 I2 ACTIVE AM I2 is ACTIVE 5156 I2 Warn AM Unbalanced load Current warning stage 5158 RM th rep I2 AM Reset memory of thermal replica I2 5159 I2 picked up AM I2 picked up 5160 I2 TRIP AM Unbalanced load TRIP of current stage 5161 I2 Θ TRIP AM Unbalanced load TRIP of thermal stage 5165 I2 picked up AM I2 picked up Addr Parameter S...

Page 77: ...riterion the admittance is calculated from the positive sequence currents and voltages The admittance measurement always produces the physically appropriate stability limit independently of voltage deviations from rated voltage Even in such circumstances the protection characteristic can be thus optimally matched to the stability characteristic of the machine By virtue of the positive se quence sy...

Page 78: ...tation voltage Figure 2 20 Stator circuit criterion Pick Up Characteristic in Admittance Diagram A further characteristic 1 xd CHAR 3 α3 can be matched to the dynamic stability characteristic of the synchronous machine Since stable operation is impossible if this characteristic is exceeded immediate tripping is then required time stage T CHAR 3 Excitation Voltage Query With a faulty voltage regula...

Page 79: ...ctive and available if this function was set during protective function configuration Section 2 2 address 130 UNDEREXCIT is set to Enabled If the function is not required Disabled is set The address 3001 UNDEREXCIT serves to enable the function ON and OFF or to block only the trip command Block relay The correct power system data input according to Section 2 3 is another prerequisite for the param...

Page 80: ...characteristics are set in such a way that the underexcitation limiting of the voltage regulator will intervene before characteristic 1 is reached see figure 2 24 Figure 2 22 Underexcitation Protection Characteristics in the Admittance Plane Characteristic Curve Values If the generator capability diagram see the following Figure in its preferred represen tation abscissa positive reactive power ord...

Page 81: ...e protection setting is performed with the predefined synchronous direct reactance with xdsec related synchronous direct reactance secondary xd mach related synchronous direct reactance of the machine INMach Nominal Current of the Machine UNMach Nominal Voltage of the Machine UN VT prim Primary Nominal Voltage of the voltage transformers IN CT prim Nominal primary CT current Instead of 1 xd mach t...

Page 82: ...onding time delays T CHAR 1 and T CHAR 2 of both characteristics are set equally Characteristic 3 serves to adapt the protection to the dynamic machine stability limits If there are no precise indications the user must select a value 1 xd CHAR 3 ap proximately between the synchronous direct reactance xd and the transient reactance xd However it should be greater than 1 A value between 80 and 110 i...

Page 83: ...atic stability undelayed Annunciation Exc Anr Characteristic 1 and 2 static stability long time delayed T CHAR 1 T CHAR 2 10 s Trippings Err 1 TRIP Err 2 TRIP Characteristic 1 and 2 Excitation Voltage Failure short time delayed T SHRT Uex 1 5 s Tripping Err UPU TRIP Characteristic 3 dynamic stability short time delayed T CHAR 3 0 5 s Tripping Exc 3 TRIP Addr Parameter Setting Options Default Setti...

Page 84: ...t char 1 5330 Char 2 BLK EM BLOCK underexc prot char 2 5331 Excit OFF AM Underexc prot is switched OFF 5332 Excit BLOCKED AM Underexc prot is BLOCKED 5333 Excit ACTIVE AM Underexc prot is ACTIVE 5334 Exc U blk AM Underexc prot blocked by U 5336 Uexc failure AM Exc voltage failure recognized 5337 Exc picked up AM Underexc prot picked up 5343 Exc 3 TRIP AM Underexc prot char 3 TRIP 5344 Exc 1 TRIP A...

Page 85: ...ted active power value corresponds to the overall active power By taking the error angles of the instrument transformers into account the active power component is exactly calculated even with very high apparent powers and low power factor cos ϕ The correction is performed by a W0 constant correction angle determined during commissioning of the protection device in the system The correction angle ...

Page 86: ...put cooling effect or in case of a gas turbine set the motor load would be too heavy for the network Pickup Values The level of the active power input is determined by the friction losses to be overcome and is in the following ranges depending on the individual system Steam turbines PReverse SN 1 to 3 Gas turbines PReverse SN 3 to 5 Diesel drives PReverse SN 5 For the primary test the reverse powe...

Page 87: ... used a corresponding time delay must be implemented to bridge any short reverse power states after synchronization or power swings subsequent to system faults e g 3 pole short circuit Usually a delay time 3103 T SV OPEN approx 10 s is set Under emergency tripping conditions the reverse power protection performs a short time delayed trip subsequent to the emergency tripping via an oil pressure swi...

Page 88: ...Stop Valve 3104 T SV CLOSED 0 00 60 00 sec 1 00 sec Time Delay Short with Stop Valve 3105A T HOLD 0 00 60 00 sec 0 00 sec Pickup Holding Time No Information Type of In formation Comments 5083 Pr BLOCK EM BLOCK reverse power protection 5086 SV tripped EM Stop valve tripped 5091 Pr OFF AM Reverse power prot is switched OFF 5092 Pr BLOCKED AM Reverse power protection is BLOCKED 5093 Pr ACTIVE AM Reve...

Page 89: ...n a critical time the utility network and should be split or for example an industrial network decoupled from it As criteria for decoupling in addition to power flow direction are undervoltage overcurrent and frequency As a result the 7UM61 can also be used for network decoupling 2 13 1 Function Description Active Power Mea suring Depending on the application either slow high precision measurement...

Page 90: ...sec Secondary rated power 3 UNsec INsec PMach Machine power corresponding to setting value SN Mach Nominal apparent power of the machine UN Mach Nominal voltage of the machine IN Mach Nominal current of the machine UN prim Primary Nominal Voltage of the voltage transformers IN prim Nominal primary CT current Address 3202 serves to set the threshold of the forward power to an undershoot Pf and addr...

Page 91: ...60 00 sec 10 00 sec T P forw Time Delay 3206A MEAS METHOD accurate fast accurate Method of Operation No Information Type of In formation Comments 5113 Pf BLOCK EM BLOCK forward power supervision 5116 Pf BLOCK EM BLOCK forw power superv Pf stage 5117 Pf BLOCK EM BLOCK forw power superv Pf stage 5121 Pf OFF AM Forward power supervis is switched OFF 5122 Pf BLOCKED AM Forward power supervision is BLO...

Page 92: ... set value A signal is output for each phase where the set threshold has been exceeded These pickup signals are considered for choosing the measured values The pickup is reset when 95 of the pick up threshold is undershot unless maintained by the undervoltage seal in feature UndervoltageSeal In Feature With excitation systems powered from the network excitation voltage can drop during a local shor...

Page 93: ...ult model ing and the measuring errors Table 2 6 Fault Modeling and Measuring Errors on the Generator Side on System Faults Pickup Measuring Loop 1 pole L1 L2 L3 Phase earth L1 E L2 E L3 E 2 pole L1 L2 L2 L3 L3 L1 Phase phase Calculation of UI I and II I L1 L2 L2 L3 L3 L1 3 pole with different ampli tudes L1 2 L2 L3 L2 2 L3 L1 L3 2 L2 L3 Phase ground se lection of loop with the highest current UI ...

Page 94: ... is fully iden tified by one parameter impedance Z As long as the pickup criterion is met impedance calculation is done continuously using the current and voltage vectors derived from the loop selection measured values If the calculated impedance is within the trip characteristic the protection issues a trip command which may be delayed according to the relevant delay time Since the impedance prot...

Page 95: ...d overreach zone ZONE Z1B can be made effective see also Section 2 14 2 Grading of the Machine Impedance Protection figure Figure 2 28 Tripping Characteristics of the Impedance Protection Tripping Logic The T END time delay is started subsequent to the protection pickup establishing the the fault loop The loop impedance components are compared with the limit values of the zones previously set The ...

Page 96: ...ure 2 29 Logic Diagram of the Impedance Protection 2 14 2 Setting Notes General Machine impedance protection is only effective and available if enabled during config uration Section 2 2 address 133 IMPEDANCE PROT Enabled If the function is not required Disabled is set Address 3301 IMPEDANCE PROT serves to switch the function ON or OFF or to block only the trip command Block relay w w w E l e c t r...

Page 97: ...1 with parameters ZONE Z1 Reactance reach T Z1 0 or short delay if required Overreach zone Z1B externally controlled via binary input with parameters ZONE Z1B Reactance reach T Z1B T1B 0 or short delay if required 2 Zone zone Z2 with parameters ZONE Z2 Reactance reach ZONE2 T2 The user must select a value for T2 above the grading time of the network protection Non directional final stage with para...

Page 98: ...rted for the secondary side of the current and voltage transformers In general The nominal current of the protection device secondary nominal current of the current transformer is automatically considered by the device You have already com municated the transformation ratios of the current and voltage transformers to the device by entering the nominal transformer values see section 2 3 Example Tra...

Page 99: ...following secondary side setting value of zone 1 results at address 3306 ZONE Z1 Note The following ratio would result from the connection of a 5 A device to a 5 A current transformer Likewise the following primary reactance results for a 100 reach for zone 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 100: ...pedance protection pickup can only be due to a fault in the protection zone of the block since the power system is disconnected from the block Conse quently the fast tripping zone can be extended to between 100 and 120 of the protection zone without any loss of selectivity The Z1B zone is activated via a binary input controlled by the circuit breaker auxiliary contact see Figure 2 30 The overreach...

Page 101: ...ne Z1 Time Delay 3308 ZONE Z1B 1A 0 05 65 00 Ω 4 95 Ω Impedance Zone Z1B 5A 0 01 13 00 Ω 0 99 Ω 3309 T Z1B 0 00 60 00 sec 0 10 sec Impedance Zone Z1B Time Delay 3310 ZONE Z2 1A 0 05 65 00 Ω 4 15 Ω Impedanz Zone Z2 5A 0 01 13 00 Ω 0 83 Ω 3311 ZONE2 T2 0 00 60 00 sec 0 50 sec Impedance Zone Z2 Time Delay 3312 T END 0 00 60 00 sec 3 00 sec T END Final Time Delay No Information Type of In formation Co...

Page 102: ...M Imp O C with undervoltage seal in 3977 Imp Z1 TRIP AM Imp Z1 TRIP 3978 Imp Z1B TRIP AM Imp Z1B TRIP 3979 Imp Z2 TRIP AM Imp Z2 TRIP 3980 Imp T3 TRIP AM Imp T3 TRIP No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 103: ...tage failure each stage can be blocked individually or both stages together via binary input s e g using a voltage transformer mcb In addition to this the integrated fuse failure monitor FFM blocks both stages see Section 2 28 If a pickup occurs as the device changes to operational condition 0 i e no usable measured quantities are present or the admissible frequency range has been exited this pick...

Page 104: ...n stage is typically set to about 75 of the nominal machine voltage i e address 4002 U is set to 75 V The user must select a value for the 4003 T U time setting that ensures that voltage dips which would affect operating stability are disconnected On the other hand the time delay must be large enough to avoid disconnections during admissible short time voltage dips For the second stage a lower pic...

Page 105: ...0 60 00 sec 0 50 sec T U Time Delay 4006A DOUT RATIO 1 01 1 20 1 05 U U Drop Out Ratio No Information Type of In formation Comments 6503 BLOCK U V EM BLOCK undervoltage protection 6506 BLOCK U EM BLOCK undervoltage protection U 6508 BLOCK U EM BLOCK undervoltage protection U 6530 Undervolt OFF AM Undervoltage protection switched OFF 6531 Undervolt BLK AM Undervoltage protection is BLOCKED 6532 Und...

Page 106: ...h a short time delay whereas in case of lower overvoltages the switchoff is performed with a longer time delay to allow the voltage regulator to take the voltage back into the nominal range The user can specify the voltage limit values and the time delays individually for both stages Each stage can be blocked individually and or for both stages can be blocked via binary input s The following figur...

Page 107: ... 1 5 s and 5 s In case of a full load rejection of the generator the voltage increases first in relation to the transient voltage Only then the voltage regulator reduces it again to its nominal value The U stage is set generally as a short time stage in a way that the transient procedure for a full load rejection does not lead to a tripping For example for 4104 U about 130 UN with a delay 4105 T U...

Page 108: ... BLOCK U EM BLOCK overvoltage protection U 6565 Overvolt OFF AM Overvoltage protection switched OFF 6566 Overvolt BLK AM Overvoltage protection is BLOCKED 6567 Overvolt ACT AM Overvoltage protection is ACTIVE 6568 U picked up AM Overvoltage U picked up 6570 U TRIP AM Overvoltage U TRIP 6571 U picked up AM Overvoltage U picked up 6573 U TRIP AM Overvoltage U TRIP w w w E l e c t r i c a l P a r t M...

Page 109: ...ameter setting decides for what purpose the particular stage will be used For the f4 frequency stage the user can instead specify independently of the parametrized limit value whether this stage shall function as decrease or increase stage For this reason it can also be used for special appli cations if for example frequency undershoot below the nominal frequency is to be signaled Operating Ranges...

Page 110: ...threshold is con figured as above rated frequency overfrequency protection is implemented Note If the threshold is set equal to the nominal frequency the element is inactive For the f4 frequency stage the former applies only if the parameter 4214 THRESHOLD f4 is set to automatic default setting If desired this parameter can also be set to f or f in which case the evaluation direction increase or d...

Page 111: ...ed at addresses 4204 4207 4210 and 4213 allow the frequency stages to be graded The set times are additional time delays not including the operating times measuring time drop out time of the protective func tion Minimum Voltage Address 4215 Umin is used to set the minimum voltage which if undershot frequency protection is blocked A value of approx 65 UN is recommended The parameter value is based ...

Page 112: ...LOCK Freq EM BLOCK frequency protection 5206 BLOCK f1 EM BLOCK stage f1 5207 BLOCK f2 EM BLOCK stage f2 5208 BLOCK f3 EM BLOCK stage f3 5209 BLOCK f4 EM BLOCK stage f4 5211 Freq OFF AM Frequency protection is OFF 5212 Freq BLOCKED AM Frequency protection is BLOCKED 5213 Freq ACTIVE AM Frequency protection is ACTIVE 5214 Freq UnderV Blk AM Frequency protection undervoltage Blk 5232 f1 picked up AM ...

Page 113: ...inal voltage of the voltage transformers and the object to be protected is compensated by an internal correction factor UN VT prim UN Gen prim For this reason pickup values and characteristic do not need to be converted to secondary values However the system primary nominal transformer voltage and the nominal voltage of the object to be protected must be entered correctly see Sec tions 2 3 and 2 5...

Page 114: ...vice default settings is shown in the Technical Data Section Overexcitation Protection The following figure illustrates the behaviour of the protection if on pickup threshold configuration parameter 4302 U f lower or higher values than the first setting value of the thermal characteristic are selected Figure 2 34 Tripping Range of the Overexcitation Protection The following figure shows the logic ...

Page 115: ... respond fast enough or not at all to avoid related voltage increase Similarly a decrease in frequency speed e g in island systems can lead to an inad missible increase in induction In this way the U f protection monitors the correct functioning both of the voltage reg ulator and of the speed regulation in all operating states Independent Stages The limit value setting at address 4302 U f is based...

Page 116: ...nts To do this the trip times of the overexcitation values U f 1 05 1 10 1 15 1 20 1 25 1 30 1 35 and 1 40 are read out from the predefined characteristic and entered at addresses 4306 t U f 1 05 to 4313 t U f 1 40 The protection device interpolates linearly between the points Limitation The heating model of the object to be protected is limited to a 150 overshoot of the trip temperature Cooldown ...

Page 117: ... 25 Time Delay 4311 t U f 1 30 0 20000 sec 19 sec U f 1 30 Time Delay 4312 t U f 1 35 0 20000 sec 13 sec U f 1 35 Time Delay 4313 t U f 1 40 0 20000 sec 10 sec U f 1 40 Time Delay 4314 T COOL DOWN 0 20000 sec 3600 sec Time for Cooling Down No Information Type of In formation Comments 5353 U f BLOCK EM BLOCK overexcitation protection 5357 RM th rep U f EM Reset memory of thermal replica U f 5361 U ...

Page 118: ...ngle jumps etc help to avoid overfunctioning Frequency In crease Decrease The rate of frequency change protection has four stages from df1 dt to df4 dt This allows the function to be adapted variably to all power system conditions The stages can be set to detect either frequency decreases df dt or frequency increases df dt The df dt stage is only active for frequencies below the rated frequency or...

Page 119: ...t step it must be determined whether the stage is to monitor a frequency rise at f fN or a frequency drop at f fN For stage 1 for instance this setting is made at address 4502 df1 dt The pickup value is set as an absolute value at address 4503 STAGE df1 dt The setting of address 4502 informs the protection function of the applicable sign The pickup value depends on the application and is determine...

Page 120: ...ro wherever the protection function is supposed to respond very quickly This will be the case with high setting values For the monitoring of small changes 1Hz s on the other hand a small delay time can be useful to avoid overfunctioning The delay time for stage 1 is set at address 4504 T df1 dt and the time set there is added to the protection operating time Release by the Fre quency Protection Th...

Page 121: ...ault Setting Comments 4501 df dt Protect OFF ON Block relay OFF Rate of frequency change pro tection 4502 df1 dt df dt df dt df dt Mode of Threshold df1 dt 4503 STAGE df1 dt 0 1 10 0 Hz s 1 0 Hz s Pickup Value of df1 dt Stage 4504 T df1 dt 0 00 60 00 sec 0 50 sec Time Delay of df1 dt Stage 4505 df1 dt f1 OFF ON OFF AND logic with pickup of stage f1 4506 df2 dt df dt df dt df dt Mode of Threshold d...

Page 122: ...equency change prot 5504 df1 dt block EM BLOCK df1 dt stage 5505 df2 dt block EM BLOCK df2 dt stage 5506 df3 dt block EM BLOCK df3 dt stage 5507 df4 dt block EM BLOCK df4 dt stage 5511 df dt OFF AM df dt is switched OFF 5512 df dt BLOCKED AM df dt is BLOCKED 5513 df dt ACTIVE AM df dt is ACTIVE 5514 df dt U block AM df dt is blocked by undervoltage 5516 df1 dt pickup AM Stage df1 dt picked up 5517...

Page 123: ... the incoming feeder fails the abrupt current interruption causes a phase angle jump in the voltage This jump is detected by means of a delta process As soon as a preset threshold is exceeded an opening command for the generator or bus tie coupler circuit breaker is issued This means that the vector jump function is mainly used for network decoupling 2 20 1 Function Description Frequency Behav iou...

Page 124: ...ing Load Shedding The function features a number of additional measures to avoid spurious tripping such as Correction of steady state deviations from rated frequency Frequency operating range limited to fN 3 Hz Detection of internal sampling frequency changeover Sampling frequency adjust ment Minimum voltage for enabling Blocking on voltage connection or disconnection Logic Figure 2 40 shows the l...

Page 125: ... time thus preventing a pickup caused by the vector jump function If a short circuit causes the voltage to drop abruptly to a low value the reset input is immediately activated to block the function The vector jump function is thus prevented from causing a trip Figure 2 40 Logic Diagram of the Vector Jump Detection 2 20 2 Setting Notes General The vector jump protection is only effective and avail...

Page 126: ...the timer T RESET address 4604 the protection function is automat ically reset The reset time depends on the decoupling policy It must have expired before the circuit breaker is reclosed Where the automatic reset function is not used the timer is set to The reset signal must come in this case from the binary input cir cuit breaker auxiliary contact The timer T BLOCK with reset delay address 4607 h...

Page 127: ...BLOCK Vector Jump 5582 VEC JUMP OFF AM Vector Jump is switched OFF 5583 VEC JMP BLOCKED AM Vector Jump is BLOCKED 5584 VEC JUMP ACTIVE AM Vector Jump is ACTIVE 5585 VEC JUMP Range AM Vector Jump not in measurement range 5586 VEC JUMP pickup AM Vector Jump picked up 5587 VEC JUMP TRIP AM Vector Jump TRIP w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 128: ... in such cases If the displacement voltage can not be directly applied to the device as a measured value the device can calculate the displacement voltage from the phase to ground voltages Address 223 UE CONNECTION serves for notifying the device of the way the displace ment voltage is to be measured or calculated In all kinds of displacement voltage formation the components of the third harmonic ...

Page 129: ...r or a set of CTs in Holmgreen connection During a network earth fault the machine supplies only a neg ligible earth fault current across the measurement location which must be situated between the machine and the network During a machine earth fault the earth fault current of the network is available However since the network conditions generally vary according to the switching status of the netw...

Page 130: ...lacement voltage is needed for the secure detection of a machine earth fault with busbar connection The directional border between machine direction and network direction can be altered in the 7UM61 refer to following figure The protection then detects a machine earth fault if the following three criteria are ful filled Displacement voltage larger than set value U0 Earth fault current across the m...

Page 131: ...th Current Differential Protection with Tripping via Dis placementVoltage In the industrial sector busbar systems are designed with high or low resistance swit chable starpoint resistances For earth fault detection the starpoint current and the total current are detected via toroidal current transformers and transmitted to the pro tective device as current difference In this way the earth current ...

Page 132: ...lacement Voltage The criterion for the occurrence of an earth fault in the stator circuit is the emergence of a neutral displacement voltage Exceeding the set value 5002 U0 therefore causes pickup for stator earth protection The setting must be chosen such that the protection does not pick up because of op erational asymmetries This is particularly important for machines in busbar connec tion sinc...

Page 133: ...vent of an earth fault Instructions for dimensioning the earth current transformer and loading resistor are contained in the publication Planning Machine Protection Sys tems Order No E86010 K4500 A111 A1 Since the magnitude of earth fault current in this case is determined mainly by the loading resistor a small angle is set for 5004 DIR ANGLE e g 15 If the network capacitances in an isolated netwo...

Page 134: ... s The overload capacity of the earthing transformer must also be considered if it lies below that of the loading resistor 2 21 3 Settings 2 21 4 Information List Addr Parameter Setting Options Default Setting Comments 5001 S E F PROT OFF ON Block relay OFF Stator Earth Fault Protection 5002 U0 2 0 125 0 V 10 0 V U0 Pickup 5003 3I0 2 1000 mA 5 mA 3I0 Pickup 5004 DIR ANGLE 0 360 15 Angle for Direct...

Page 135: ... 5188 3I0 picked up AM Stator earth fault I0 picked up 5189 Uearth L1 AM Earth fault in phase L1 5190 Uearth L2 AM Earth fault in phase L2 5191 Uearth L3 AM Earth fault in phase L3 5193 S E F TRIP AM Stator earth fault protection TRIP 5194 SEF Dir Forward AM Stator earth fault direction forward No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 136: ...tion thereby uses the same mea sured values if address 150 S E F PROT is set to directional or non dir U0 I0 2 22 1 Functional Description Application as Rotor Earth Fault Protection Alternatively sensitive earth fault protection can be used as rotor earth fault protection when a system frequency bias voltage is applied to the rotor circuit see Figure 2 48 In this case the maximum earth current is...

Page 137: ...ure 2 47 Logic Diagram of the Sensitive Earth Fault Protection Figure 2 48 Application Case as Rotor Earth Fault Protection 7XR61 Series Device for Rotor Earth Fault Protection 3PP13 from Uexc 150 V Resistors in 7XR61 are then to be Shorted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 138: ... 42 V via 7XR61 series device in figure Application Case as Rotor Earth Fault Protection in Section 2 22 must be applied to the rotor circuit Because of this bias voltage with proper earth connection a current flows through the earth capacitance which can be used as a criterion for a closed measuring circuit ad dress 5106 IEE Approximately 2mA is a typical pickup value The monitoring stage is inef...

Page 139: ...s 2 22 4 Information List Addr Parameter Setting Options Default Setting Comments 5101 O C PROT Iee OFF ON Block relay OFF Sensitive Earth Current Protec tion 5102 IEE 2 1000 mA 10 mA Iee Pickup 5103 T IEE 0 00 60 00 sec 5 00 sec T Iee Time delay 5104 IEE 2 1000 mA 23 mA Iee Pickup 5105 T IEE 0 00 60 00 sec 1 00 sec T Iee Time Delay 5106 IEE 1 5 50 0 mA 0 0 0 mA Iee Pickup Interrupted Circuit No I...

Page 140: ...point decreases whereas the 3rd harmonic measured at the gen erator terminals increases see the following figure The 3rd harmonic forms a zero phase sequence system and can thus also be determined by means of the voltage transformer switched in wye delta or by calculating the zero phase sequence system from the phase earth voltages Figure 2 49 Profile of the 3rd Harmonic along the Stator Winding M...

Page 141: ... of the measured 3rd harmonic compared with the nonfault case the protective function is implemented as an under voltage stage 5202 U0 3 HARM This arrangement is the preferred case Broken Delta Winding If no neutral transformer exists the protection function is based on the zero compo nent of the 3rd harmonic of the terminal voltages This voltage increases in a fault case In this case the protecti...

Page 142: ...voltage available to the protection device as a measured quantity computed quantities are used and Not connected must be set The option any VT is selected if the voltage input of the 7UM61 is to be used for measuring any other voltage instead of for earth fault protection In this case the 100 stator earth fault protection function is ineffective Pickup Value for 3rd Harmonic Depending on the selec...

Page 143: ...time of the protective function 2 23 3 Settings 2 23 4 Information List Addr Parameter Setting Options Default Setting Comments 5201 SEF 3rd HARM OFF ON Block relay OFF Stator Earth Fault Protection 3rdHarm 5202 U0 3 HARM 0 2 40 0 V 1 0 V U0 3rd Harmonic Pickup 5203 U0 3 HARM 0 2 40 0 V 2 0 V U0 3rd Harmonic Pickup 5204 T SEF 3 HARM 0 00 60 00 sec 0 50 sec T SEF 3rd Harmonic Time Delay 5205 P min ...

Page 144: ...ettable current threshold I MOTOR START is assessed and used for enabling calculation of the tripping time The protection function consists of one definite time and one inverse time tripping characteristic Inverse Time Over current Character istic The inverse time tripping delay time operates only when the rotor is not blocked With decreased startup current resulting from voltage dips when startin...

Page 145: ...umed and in addition to the above inverse time delay a current independent delay time locked rotor time is start ed This happens every time the motor is started and is a normal operating condition that is neither entered in the operational annunciations buffer nor output to a control centre nor entered in a fault record The locked rotor delay time LOCK ROTOR TIME is ANDed with the binary input Rot...

Page 146: ...t calculated by the protection device is ex ceeded If the startup time is longer than the permissible blocked rotor time an external rpm counter can initiate the definite time tripping characteristic via binary input Rotor locked A locked rotor leads to a loss of ventilation and therefore to a reduced thermal load capacity of the machine For this reason the motor starting time supervi sion is to i...

Page 147: ...no other influencing factors are present peak loads the value for motor startup I MOTOR START set at address 6505 may be set to an average value The tripping time of the starting time monitoring is calculated as follows Under nominal conditions the tripping time is the maximum starting time TMax STARTUP For ratios deviating from nominal conditions the motor tripping time changes At 80 of nominal v...

Page 148: ... Motor 6504 LOCK ROTOR TIME 0 5 120 0 sec 6 0 sec Permissible Locked Rotor Time 6505 I MOTOR START 1A 0 60 10 00 A 1 60 A Current Pickup Value of Motor Starting 5A 3 00 50 00 A 8 00 A No Information Type of In formation Comments 6801 BLK START SUP EM BLOCK Motor Starting Supervision 6805 Rotor locked EM Rotor is locked 6811 START SUP OFF AM Starting time supervision switched OFF 6812 START SUP BLK...

Page 149: ...d This blocking signal must be allocated to a binary output of the device whose contact is in serted in the motor starting circuit 2 25 1 Functional Description Determining Rotor Overtemperature Because rotor current cannot be measured directly stator currents must be used The rms values of the currents are used for this Rotor overtemperature ΘR is calculated using the highest of the three phase c...

Page 150: ... number of cold ncold and warm nwarm startups No subsequent renewed startup is allowed A corresponding time the restart time must expire to allow the rotor to cool down This thermal behaviour is met as follows Each time the motor is shutdown a leveling timer is started address 6604 T EQUAL This takes into account the different temperatures of the individual motor components at the moment of shutdo...

Page 151: ...re a minimum inhibit time after the maximum number of permissible startup attempts has been exceeded The duration of the inhibit signal depends on which of the times T MIN INHIBIT or TReInhib time is longer Behaviour on Power Supply Failure Depending on the setting of parameter 274 ATEX100 the value of the thermal profile is either reset to zero on failure of the power supply voltage or cyclically...

Page 152: ...it 2 25 2 Setting Notes General Restart inhibit is only effective and available if address 166 RESTART INHIBIT was set to Enabled during configuration If the function is not required Disabled is set Address 6601RESTART INHIBIT serves to switch the function ON or OFF or to block only the trip command Block relay w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 153: ... ventilation factor Kτ at STOP As soon as the current no longer exceeds the setting value entered at address 281 BkrClosed I MIN motor standstill is detected and the time constant is increased by the extension factor configured If no difference between the time constants is to be used e g externally ventilated motors then the extension factor Kτ at STOP should be set to 1 Cooling with running moto...

Page 154: ...ctly An overview of the parameters and their default settings is given in parameter overviews Temperature Be haviour during Changing Operat ing States For better understanding of the above considerations two of the many possible oper ating states will be discussed in the following paragraph The examples use the set tings indicated above 3 cold and 2 warm startup attempts have resulted in a restart...

Page 155: ...the temperature This time the time constant τL Kτ at STOP 2 204 s 408 s is effective The fact that the restart limit is exceeded for a short time does not mean a thermal overload It rather indicates that a thermal overload of the rotor would result if the motor were shut down immediately and restarted Figure 2 56 Two Warm Restarts Followed by Continuous Running 2 25 3 Settings Addr Parameter Setti...

Page 156: ...LOCK Restart inhibit motor 4823 Emer Start ΘR EM Emergency start rotor 4824 Re Inhibit OFF AM Restart inhibit motor is switched OFF 4825 Re Inhibit BLK AM Restart inhibit motor is BLOCKED 4826 Re Inhibit ACT AM Restart inhibit motor is ACTIVE 4827 Re Inhib TRIP AM Restart inhibit motor TRIP 4828 RM th rep ΘR EM Reset thermal memory rotor 4829 RM th rep ΘR AM Reset thermal memory rotor 4830 Re Inhi...

Page 157: ...gher level circuit breaker can initiate disconnection see the following example Figure 2 57 Function Principle of the Breaker Failure Protection Function Initiation The breaker failure protection function can be initiated by two different sources Internal functions of the 7UM61 e g trip commands of protective functions or via CFC internal logic functions external start commands e g via binary inpu...

Page 158: ...o effective for an internal initiation Logic If breaker failure is initiated an alarm message is generated and a settable delay time is started If the pickup criteria are still fulfilled on expiration of this time a redundant source evaluation before fault clearing is initiated via a further AND combination through a higher level circuit breaker A pickup drops off and no trip command is produced b...

Page 159: ...ay BA3 provided for this 7002 TRIP INTERN BO3 or by a logic link created in CFC CFC message 1442 int start B F It can also be completely deactivated 7002 TRIP INTERN OFF In this case only external sources have effect Note Be aware that only the potential free binary output BO3 relay BO3 can be used for the breaker failure protection This means that trippings for the mains breaker or the particular...

Page 160: ... for Typical Fault Clearance and for Breaker Failure 2 26 3 Settings The table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer 2 26 4 Information List Addr Parameter C Setting Options Default Setting Comments 7001 BREAKER FAILURE OFF ON Block relay OFF Breaker Failure Protection 7002 TRIP INTERN OFF BO3 C...

Page 161: ...Breaker fail started intern 1444 B F I AM Breaker failure I 1451 BkrFail OFF AM Breaker failure is switched OFF 1452 BkrFail BLOCK AM Breaker failure is BLOCKED 1453 BkrFail ACTIVE AM Breaker failure is ACTIVE 1455 B F picked up AM Breaker failure protection picked up 1471 BrkFailure TRIP AM Breaker failure TRIP No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u...

Page 162: ...blocking is delayed to avoid protection being blocked immediately in the event of an unintended connection Another pickup delay is necessary to avoid an unwanted operation during high current faults with heavy voltage dip A dropout time delay allows for a measurement limited in time As the inadvertent energizing protection must intervene very rapidly the instanta neous current values are monitored...

Page 163: ...vice is either in operational condition 0 or if no nominal conditions have been reached yet The param eter 7103 RELEASE U1 serves to define these nominal conditions The typical setting is about 50 to 70 of the nominal voltage The parameter value is based on phase to phase voltages A 0 V setting deactivates the voltage tripping However this should only be used if 7102 I STAGE shall be used as 3rd t...

Page 164: ...ion specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 7101 INADVERT EN OFF ON Block relay OFF Inadvertent Energisation 7102 I STAGE 1A 0 1 20 0 A 0 3 A I Stage Pickup 5A 0 5 100 0 A 1 5 A 7103 RELEASE U1 10 0 125 0 V 0 50 0 V Release Threshold U1 7104 PICK UP T U1 0 ...

Page 165: ...nadvertent energ prot 5541 I En OFF AM Inadvert Energ prot is swiched OFF 5542 I En BLOCKED AM Inadvert Energ prot is BLOCKED 5543 I En ACTIVE AM Inadvert Energ prot is ACTIVE 5546 I En release AM Release of the current stage 5547 I En picked up AM Inadvert Energ prot picked up 5548 I En TRIP AM Inadvert Energ prot TRIP w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 166: ...the ADC analog digital converter The protection is suspended if the voltages deviate outside an admissible range prolonged deviations are reported indication Error A D conv Battery The buffer battery which ensures operation of the internal clock and storage of counters and messages if the auxiliary voltage fails is periodically checked for charge status On its undershooting a minimum admissible vo...

Page 167: ...at Power System Data 1 address low resist Figure 2 62 Current sum monitoring Measured Value Ac quisition Voltages Four measuring inputs are available in the voltage path If three of them are used for phase earth voltages and one input for the displacement voltage e n voltage from the broken delta winding or neutral transformer of the same system a fault in the phase earth voltage sum is detected i...

Page 168: ... such a malfunction is not cleared by the restart an additional restart attempt is begun After three unsuccessful restarts within a 30 second window of time the device automatically removes itself from service and the red Fault LED lights up The operational readiness relay Life contact opens and issues an indication alter natively as NO or NC contact Monitoring External Transformer Circuits Interr...

Page 169: ...te values The smallest phase voltage is compared to the larg est Asymmetry is recognised if Umin Umax BAL FACTOR U as long as Umax BALANCE U LIMIT Thereby Umax is the highest of the three voltages and Umin the smallest The symmetry factor BAL FACTOR U is the measure for the asymmetry of the conductor voltages the limit BALANCE U LIMIT is the lower limit of the operating range of this monitoring se...

Page 170: ...of these indications Fail Ph Seq FNo 171 are signaled For applications where a counter clockwise measured values phase sequence ap pears this must be notified to the device via the parameter 271 PHASE SEQ or an accordingly allocated binary input If the phase sequence is thereby changed in the device phases L2 and L3 are reversed internally for calculation of the symmetrical components and the posi...

Page 171: ...e to inaccuracies of the measuring voltages failure detection the function is blocked below a minimum threshold of the positive sequence systems of U1 10 V and current I1 0 1 IN 3 pole Fuse Fault A 3 pole fuse fault of the voltage transformer cannot be detected by the positive and negative sequence system as previously described Here monitoring of the chronolog ical sequence of current and voltage...

Page 172: ...e positive phase sequence system of the voltages e g 7RW600 Voltage at UE Input Depending on how UE is connected it may be necessary to block the voltage mea surement of this input A blocking can be generated with the CFC tool and combined with the indication VT Fuse Failure Figure 2 66 Logic Diagram of the Measuring Voltage Fuse Failure Monitor w w w E l e c t r i c a l P a r t M a n u a l s c o ...

Page 173: ...re Watchdog internal processor failure Device not in operation 1 LED ERROR DOK2 drops out Software Watchdog internal processor failure Restart attempt 1 LED ERROR DOK2 drops out Working Memory ROM internal hardware Aborted restart Device not in operation LED flashes DOK2 drops out Program Memory RAM internal hardware during startup LED flashes DOK2 drops out during operation Restart attempt 1 LED ...

Page 174: ... determines the limit current above which the current sum monitor see also Current Sum Monitoring figure is activated absolute portion only relative to IN The relative portion relative to the maximum conductor current for activating the current sum monitor is set at address 8107 ΣI FACTOR Address 8108 SUM thres U determines the limit voltage above which current sum monitoring becomes active see al...

Page 175: ... Threshold 5A 0 25 10 00 A 0 50 A 8107 ΣI FACTOR 0 00 0 95 0 10 Summated Current Moni toring Factor 8108 SUM thres U 10 200 V 10 V Summation Thres for Volt Monitoring 8109 SUM Fact U 0 60 0 95 0 0 75 Factor for Volt Sum Mon itoring No Information Type of In formation Comments 161 Fail I Superv AM Failure General Current Supervision 162 Failure Σ I AM Failure Current Summation 163 Fail I balance AM...

Page 176: ...xiliary contacts on the other A precondition for use of trip circuit supervision is that the control voltage for the circuit breaker is higher than the sum of minimum voltage drops at the two binary inputs USt 2 UBImin Since at least 19 V is needed for each binary input monitoring can only be used with a system control voltage above 38 V Figure 2 67 Principle of Trip Circuit Monitor with Two Binar...

Page 177: ... that an alarm is output during short time transition periods After the fault in the trip circuit is removed the alarm is reset automatically after the same time Figure 2 68 Logic diagram of the trip circuit supervision with two binary inputs Monitoring with Two Binary Inputs connected to common potential If two binary inputs connected to common potential are used they are connected ac cording to ...

Page 178: ...nsecutive conditional checks detect an abnormality after 1 8 s an annunciation is reported see Figure 2 68 The repeated measure ments help to determine the delay of the alarm message and to avoid that an alarm is output during short time transition periods After the fault in the trip circuit is removed the alarm is reset automatically after the same time Monitoring with One Binary Input The binary...

Page 179: ...circuit monitor does not operate during system faults a closed trip ping contact does not lead to a fault message If however tripping contacts from other devices operate in parallel with the trip circuit then the fault annunciation must be delayed see also the following figure The conditions of the binary input are therefore checked 500 times before an annunciation is issued A condition check take...

Page 180: ...ot to be used at all then at address 182 Disabled is set Further parameters are not needed The indication of a trip circuit interruption is delayed by a fixed amount of time For two binary inputs the delay is about 2 seconds and for one binary input the delay is about 300 s This ensures that the longest possible duration of a trip signal expires and an indication occurs only if there is a real mal...

Page 181: ...ip contact is simultaneously opened This results in an upper limit for the resistance Rmax and a lower limit Rmin from which the optimal value of the arithmetic mean R should be selected In order that the minimum voltage for controlling the binary input is ensured the result for Rmax is So the circuit breaker trip coil does not remain energized in the above case Rmin is derived as with IBI HIGH Co...

Page 182: ...formation List Addr Parameter Setting Options Default Setting Comments 8201 TRIP Cir SUP OFF ON OFF TRIP Circuit Supervision No Information Type of In formation Comments 6851 BLOCK TripC EM BLOCK Trip circuit supervision 6852 TripC trip rel EM Trip circuit supervision trip relay 6853 TripC brk rel EM Trip circuit supervision breaker relay 6861 TripC OFF AM Trip circuit supervision OFF 6862 TripC B...

Page 183: ...values are queried once per cycle The following figure shows an overview of the logic Table 2 10 Measured Values Measured Value Scaling Explanation P Active power P SN sec 100 The positive sequence system quantities for U and I are formed once per cycle from the sampled values From the result P is calculat ed The measuring result is subject to the angle correction address 204 CT ANGLE W0 in the cu...

Page 184: ...on for symmetrical compo nents The calculation is performed once per cycle I2 Negative sequence current system I2 IN sec 100 The negative sequence current is determined from the phase currents on the basis of the definition equation for symmetrical compo nents The calculation is performed once per cycle ϕ Power angle ϕ 180 100 The power angle is calculated from the posi tive sequence voltage and t...

Page 185: ... The dropout ratio for the MVx stage is 0 95 or 1 Accordingly it is 1 05 or 1 for the MVx stage 2 30 2 Setting Notes General Threshold supervisions are only effective and available if addresses 185 THRESHOLD are set to enabled on configuration Pickup Values The pickup values are set as percentages Note the scaling factors listed in the Mea sured values table w w w E l e c t r i c a l P a r t M a n...

Page 186: ...measured value becomes less than 5 e g 8 The dropout value is then 5 0 95 4 75 Note The measured values U1 U2 I0 I1 and I2 are always greater than 0 Care should be taken here to use only positive threshold values which allow the indication to drop out With the power angle ϕ it should be kept in mind that this angle is only defined for 100 equivalent to 180 or less The threshold value should be cho...

Page 187: ...reshold MV3 8506 THRESHOLD MV3 200 200 100 Pickup Value of Measured Value MV3 8507 MEAS VALUE 4 Disabled P Q Delta P U1 U2 I0 I1 I2 PHI Disabled Measured Value for Threshold MV4 8508 THRESHOLD MV4 200 200 100 Pickup Value of Measured Value MV4 8509 MEAS VALUE 5 Disabled P Q Delta P U1 U2 I0 I1 I2 PHI Disabled Measured Value for Threshold MV5 8510 THRESHOLD MV5 200 200 100 Pickup Value of Measured ...

Page 188: ...nformation Type of In formation Comments 7960 Meas Value1 AM Measured Value MV1 picked up 7961 Meas Value2 AM Measured Value MV2 picked up 7962 Meas Value3 AM Measured Value MV3 picked up 7963 Meas Value4 AM Measured Value MV4 picked up 7964 Meas Value5 AM Measured Value MV5 picked up 7965 Meas Value6 AM Measured Value MV6 picked up Addr Parameter Setting Options Default Setting Comments w w w E l...

Page 189: ...e result An additional time delay 8602 T DELAY is available for the trip command The following figure shows the logic diagram for direct input trippings This logic is im plemented in all four times in the same manner the function numbers of the indications are each specified for the first external trip command channel Figure 2 74 Logic Diagram of Direct Input Trippings 2 31 2 Setting Notes General...

Page 190: ...l trip 1 is switched OFF 4532 Ext 1 BLOCKED AM External trip 1 is BLOCKED 4533 Ext 1 ACTIVE AM External trip 1 is ACTIVE 4536 Ext 1 picked up AM External trip 1 General picked up 4537 Ext 1 Gen TRP AM External trip 1 General TRIP 4543 BLOCK Ext 2 EM BLOCK external trip 2 4546 Ext trip 2 EM Trigger external trip 2 4551 Ext 2 OFF AM External trip 2 is switched OFF 4552 Ext 2 BLOCKED AM External trip...

Page 191: ...ernal trip 4 is switched OFF 4592 Ext 4 BLOCKED AM External trip 4 is BLOCKED 4593 Ext 4 ACTIVE AM External trip 4 is ACTIVE 4596 Ext 4 picked up AM External trip 4 General picked up 4597 Ext 4 Gen TRP AM External trip 4 General TRIP No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 192: ...e thermobox detects the coolant temperature of each measuring point from the resistance value of the temperature detectors Pt 100 Ni 100 or Ni 120 connected via a two or three wire line and converts it to a digital value The digital values are made available at a serial port Communication with the Protection Device The protection device can communicate with up to 2 thermoboxes via its service port...

Page 193: ...unit C or F was set in the Power System Data 1 at address 276 TEMP UNIT If the RTD boxes operate in half duplex mode it has to be selected for the Clear to Send function CTS using plug in jumpers see Subsection 3 1 2 CTS triggered by RTS must be selected Device Settings The settings are the same for each input and are here shown at the example of mea suring input 1 Set the type of temperature dete...

Page 194: ...ctor range 0 to 50 6 Ω If a 3 wire connection is used no further settings are required to this end A baudrate of 9600 bits s ensures communication Parity is even The factory setting of the bus number 0 Modifications at the RTD box can be made in mode 7 The fol lowing convention applies Table 2 11 Setting the bus address at the RTD box Further information is provided in the operating manual of the ...

Page 195: ...9016 RTD 1 STAGE 2 58 482 F 248 F RTD 1 Temperature Stage 2 Pickup 9021A RTD 2 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 2 Type 9022A RTD 2 LOCATION Oil Ambient Winding Bearing Other Other RTD 2 Location 9023 RTD 2 STAGE 1 50 250 C 100 C RTD 2 Temperature Stage 1 Pickup 9024 RTD 2 STAGE 1 58 482 F 212 F RTD 2 Temperature Stage 1 Pickup 9025 RTD 2 STAGE 2 50 250 C 120 C RTD 2 ...

Page 196: ...mperature Stage 2 Pickup 9046 RTD 4 STAGE 2 58 482 F 248 F RTD 4 Temperature Stage 2 Pickup 9051A RTD 5 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 5 Type 9052A RTD 5 LOCATION Oil Ambient Winding Bearing Other Other RTD 5 Location 9053 RTD 5 STAGE 1 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 58 482 F 212 F RTD 5 Temperature Stage 1 Pickup 9055 RTD 5 STAG...

Page 197: ... 7 Temperature Stage 1 Pickup 9075 RTD 7 STAGE 2 50 250 C 120 C RTD 7 Temperature Stage 2 Pickup 9076 RTD 7 STAGE 2 58 482 F 248 F RTD 7 Temperature Stage 2 Pickup 9081A RTD 8 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 8 Type 9082A RTD 8 LOCATION Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 50 250 C 100 C RTD 8 Temperature Stage 1 Pickup 9084 RTD 8...

Page 198: ... C 100 C RTD10 Temperature Stage 1 Pickup 9104 RTD10 STAGE 1 58 482 F 212 F RTD10 Temperature Stage 1 Pickup 9105 RTD10 STAGE 2 50 250 C 120 C RTD10 Temperature Stage 2 Pickup 9106 RTD10 STAGE 2 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD11 Type 9112A RTD11 LOCATION Oil Ambient Winding Bearing Other Other RTD11 Locatio...

Page 199: ...perature stage 2 picked up 14131 Fail RTD 3 AM Fail RTD 3 broken wire shorted 14132 RTD 3 St 1 p up AM RTD 3 Temperature stage 1 picked up 14133 RTD 3 St 2 p up AM RTD 3 Temperature stage 2 picked up 14141 Fail RTD 4 AM Fail RTD 4 broken wire shorted 14142 RTD 4 St 1 p up AM RTD 4 Temperature stage 1 picked up 14143 RTD 4 St 2 p up AM RTD 4 Temperature stage 2 picked up 14151 Fail RTD 5 AM Fail RT...

Page 200: ...1 p up AM RTD10 Temperature stage 1 picked up 14203 RTD10 St 2 p up AM RTD10 Temperature stage 2 picked up 14211 Fail RTD11 AM Fail RTD11 broken wire shorted 14212 RTD11 St 1 p up AM RTD11 Temperature stage 1 picked up 14213 RTD11 St 2 p up AM RTD11 Temperature stage 2 picked up 14221 Fail RTD12 AM Fail RTD12 broken wire shorted 14222 RTD12 St 1 p up AM RTD12 Temperature stage 1 picked up 14223 RT...

Page 201: ...et by a Power System Data parameter at address 271 PHASE SEQ Binary input Reverse Rot sets the phase rotation to the opposite of the parameter setting Figure 2 76 Message logic of the phase sequence reversal For safety reasons the device accepts phase rotation reversal only when no usable measured quantities are current The binary input is scanned only if operational con dition 1 is not current If...

Page 202: ...erating measurement values are not distorted Thus this function influences almost all protection functions and some of the monitoring func tions see Section 2 28 which issue an indication if the required and calculated phase rotations do not match 2 33 2 Setting Notes Programming Set tings The normal phase sequence is set at 271 see Subsection 2 3 If on the system side phase rotation is temporaril...

Page 203: ... the trip log Initialization of fault storage The storage and maintenance of fault values can also be made dependent on the occurrence of a tripping command Generation of Spontaneous messages in the device display Certain fault messag es are displayed in the device display as so called spontaneous messages see below Display Spontaneous Messages This display can be made dependent on the occurrence ...

Page 204: ...and is transmitted to the circuit breaker for a sufficient amount of time even if the function which issued the trip signal drops out quickly The trip com mands can only be terminated when the last protection function dropped out i e functions no longer pick up AND the minimum trip signal duration has expired Finally it is possible to latch the trip signal until it is manually reset lockout func t...

Page 205: ...4 3 1 Functional Description Creating a Reset Command The following figure illustrates the creation of the reset command for stored messages By the moment of the device dropout the stationary conditions fault indication with excitation with trip signal tripping no tripping decide whether the new fault remains stored or is reset Figure 2 78 Creation of the reset command for the memory of LED and LC...

Page 206: ...currents in all three phases in kA the three phase earth voltages in kV primary active power P in kW MW or GW precisely averaged power primary reactive power Q in kVA MVA or GVA precisely averaged power Frequency in Hz Operating Hours The accumulated operating hours under load are also stored current value in at least one phase is greater than the limit value 281 set under address BkrClosed I MIN ...

Page 207: ...IPs IPZW Number of TRIPs of TRIPs IPZW Number of TRIPs 409 BLOCK Op Count EM BLOCK Op Counter 1020 Op Hours AM Counter of operating hours 1021 Σ L1 AM Accumulation of interrupted current L1 1022 Σ L2 AM Accumulation of interrupted current L2 1023 Σ L3 AM Accumulation of interrupted current L3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 208: ...binary input configured for that purpose using one of the serial interfaces automatically at the beginning of a new pickup Status messages should not be stored Also they cannot be reset until the criterion to be reported is remedied This applies to indications from monitoring functions or sim ilar A green LED displays operational readiness RUN and cannot be reset It goes out if the self check feat...

Page 209: ...o indicates where each indication can be sent to If functions are not present in a not fully equipped version of the device or are configured to Disabled then the associated indications cannot appear Operational Indications The operational indications contain information that the device generates during oper ation and on operational conditions Up to 200 operational indications are recorded in chro...

Page 210: ...flect the present status of in coming current indications Each new incoming indication appears immediately i e the user does not have to wait for an update or initiate one Statistics The indications in statistics are counters for breaker switching operations instigated by the 7UM61 as well as for accumulation of short circuit currents involved in disconnec tions caused by the device protection fun...

Page 211: ... and voltage transformers in the earth paths in accordance with Subsections2 3 and 2 5 Table 2 12 lists the formulae for conversion of secondary into primary or percent age values Depending on the version ordered the type of device connection and the configured protection functions only a part of the operational measured values listed in the fol lowing table may be available The displacement volta...

Page 212: ...rmalized rotor temperature in of the tripping temperature TRe Inhib timet Time until the next admissible restart Ineg th Rotor overtemperature due to the negative phase sequence component of the current in of the tripping overtemperature U f th Overtemperature caused by overexcitation in of tripping overtemperature Coolant temperature P Q S Psec Qsec Ssec Angle PHI ϕ in el ϕ in el ϕ in el Power fa...

Page 213: ...h or GVARh primary separately according to the input and output or capacitive and inductive The calculation of the operational measured values is also executed during fault The values are updated at intervals of 0 3 s and 1 s Power Metered Values only with version 7UM61 _ _ 3 Transfer of Mea sured Values Measured values can be transferred via the interfaces to a central control and storage system ...

Page 214: ...trical around the reactive power axis and the interpretation of active power changes This effect must be considered when evaluat ing the metered energy values If for instance positive power values are to be obtained with an asynchronous motor the current direction at the allocated CT set e g parameter 210 CT Starpoint must be reversed Parameter 1108 ACTIVE POWER remains in the default setting Gene...

Page 215: ... the set limit value has been transgressed several times these monitoring functions cannot respond immediately before a protection trip With the 7UM61 only the limit value of the undercurrent protection IL is configured when the device is delivered from the factory Further limit values can be configured if No Information Type of In formation Comments 601 IL1 MW I L1 602 IL2 MW I L2 603 IL3 MW I L3...

Page 216: ... are the pos itive sequence impedances For a fault the data are stored for an adjustable period of time but not more than 80 seconds Up to 8 fault records can be recorded in this buffer The fault record memory is auto matically updated with every new fault so no acknowledgment is required The fault record buffer can also be started with protection pickup via binary input operator in terface or ser...

Page 217: ...normal recording time and the post fault time POST REC TIME address 405 after the storage criterion has reset The maximum length of time of a fault record MAX LENGTH is entered in Address 403 The setting depends on the criterion for storage the delay time of the protective functions and the desired number of stored fault events The largest value here is 5 s for fault recording of instantaneous val...

Page 218: ...e SIPROTEC 4 System Description 405 POST REC TIME 0 05 0 50 sec 0 10 sec Captured Waveform after Event 406 BinIn CAPT TIME 0 10 5 00 sec 0 50 sec Capture Time via Binary Input No Information Type of In formation Comments FltRecSta IE Fault Recording Start 4 Trig Wave Cap EM Trigger Waveform Capture 203 Wave deleted AM_W Waveform data deleted Addr Parameter Setting Options Default Setting Comments ...

Page 219: ... site test mode This identification prevents the messages from being incorrectly interpreted as resulting from an actual power system disturbance or event As another option all messages and measured values normally transferred via the system interface can be blocked during the testing block data transmission Data transmission block can be accomplished by controlling binary inputs by using the oper...

Page 220: ...During commissioning energization sequences should be carried out to check the sta bility of the protection also during closing operations Oscillographic event recordings contain the maximum information about the behaviour of the protection Along with the capability of storing fault recordings via pickup of the protection func tion the 7UM61 also has the capability of capturing the same data when ...

Page 221: ...rerequisites The number of devices to be controlled is limited by the binary inputs present binary outputs present 2 36 1 1 Functional Description Operation using the SIPROTEC 4 Device Using the navigation keys W X the control menu can be accessed and the switchgear to be operated selected After entering a password a new window is dis played where multiple control options ON OFF ABORT are availabl...

Page 222: ...ate changes of state or to acknowledge changes of state Manual overriding commands to manually update information on process depen dent objects such as indications and switching states e g if the communication with the process is interrupted Manually overridden objects are flagged as such in the information status and can be displayed accordingly Tagging commands for Setting for internal object in...

Page 223: ...n initiation of the command and its completion Configuration in Process if configuration is in process commands are rejected or delayed Equipment available as output if a resource was configured but not allocated to a binary input the command is rejected Output Blocking if output blocking has set object specifically and the command is currently active then the command is rejected Module hardware e...

Page 224: ...ar in spontaneous messages The plus appearing in the message is a confirmation of the command execution The command execution was as expected in other words positive The minus sign means a negative confirmation the command was rejected Possible command feedbacks and their causes are dealt with in the SIPROTEC 4 System Description The follow ing figure shows the messages relating to command executi...

Page 225: ...ection can create and maintain a fault condition status and can therefore block CLOSE commands If the interlocking is removed consider that on the other hand the restart inhibit for motors will not automatically reject a CLOSE command to the motor Restarting would then have to be interlocked in some other way One method would be to use a specific interlocking in the CFC logic Double Operation Bloc...

Page 226: ...226 7UM61 Manual C53000 G1176 C127 3 Figure 2 82 Standard interlockings The following figure shows the configuration of the interlocking conditions using DIGSI w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 227: ...he following figure shows all interlocking conditions which usually appear in the display of the device for three switchgear items with the relevant abbreviations ex plained in the previous table All parameterized interlocking conditions are indicated Figure 2 84 Example of configured interlocking conditions Interlocking Commands Abbrev Message Switching authority L L System interlocking S S Zone ...

Page 228: ... by means of CFC also via binary input and function key The Switching authority DIGSI is used for interlocking or allows commands to be initiated using DIGSI Commands are allowed for both a remote and a local DIGSI connection When a local or remote DIGSI PC logs on to the device it enters its Virtual Device Number VD The device only accepts commands having that VD with switching authority OFF or R...

Page 229: ...tion of interlocking is accomplished via a separate command For commands from CFC SC Auto please observe the notes in the CFC manual component BOOL to command Zone Controlled Field Interlocking Zone controlled field interlockings e g via CFC includes the verification that prede termined switchgear position conditions are satisfied to prevent switching errors e g disconnector vs ground switch groun...

Page 230: ...cks TRIP signals Switching operations in progress will immediately be aborted by the pickup of a protective element Device Status Check set actual For switching commands a check takes place whether the selected switching device is already in the set desired position set actual comparison This means if a circuit breaker is already in the CLOSED position and an attempt is made to issue a closing com...

Page 231: ...it is done with the local command but by ordinary command and feedback in formation recording Monitoring of Feed back Information The processing of commands monitors the command execution and timing of feed back information for all commands At the same time the command is sent the moni toring time is started monitoring of the command execution This time controls whether the device achieves the req...

Page 232: ...2 Functions 232 7UM61 Manual C53000 G1176 C127 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 233: ...system network and with the safety rules and regulations Certain adaptations of the hardware to the power system specifications may be necessary For primary testing the object to be protected generator motor transformer must be started up and in put into service 3 1 Mounting and Connections 234 3 2 Checking Connections 255 3 3 Commissioning 262 3 4 Final Preparation of the Device 291 w w w E l e c...

Page 234: ...ircuits are given in Appendix A 3 It must be checked that the setting configuration of the Power System Data 1 Section 2 3 corresponds with the connections Currents Voltages Connection diagrams are shown in the Appendix Current and voltage transformer connection possibilities for busbar connection address 272 SCHEME Busbar and for unit connection address 272 Unit transf are given in the appendix A...

Page 235: ... earth faults in the power system The UE input of the device is connected via a voltage divider to the broken delta winding of an earthing transformer address 223 UE CONNECTION broken delta Factor 225 Uph Udelta is determined by the transformation ratio of the secondary side volt ages The resulting factor between the secondary windings is 3 3 1 73 For other trans formation ratios e g where the dis...

Page 236: ...s Changing Setting Groups If binary inputs are used to switch setting groups the following must be observed If the configuration is performed from the operator panel or using DIGSI at address 302 CHANGE the option must be set using Binary Input One binary input is sufficient for controlling 2 setting groups Param This is Param Selection1 since the nonallocated binary input Param Selection2 is cons...

Page 237: ... input transformer and addition ally the common jumper X60 If nominal current ratings are changed exceptionally then the changes must be set in parameters 212 CT SECONDARY in the Power System Data see Section 2 3 Note The jumper settings must correspond to the secondary device currents configured at address 212 Otherwise the device is blocked and issues an alarm Control Voltage for Binary Inputs W...

Page 238: ...minating resistors are disabled on unit delivery Spare Parts Spare parts can be the battery for storage of data in the battery buffered RAM in case of a power failure and the internal power supply miniature fuse Their spacial alloca tion is shown in Figures 3 3 and 3 4 The ratings of the fuse are printed on the board next the fuse itself When replacing the fuse please observe the guidelines given ...

Page 239: ... personal injury or material damage Electrostatic discharges through the connections of the components printed conduc tors and connector pins must be avoided by touching with earthed metal parts before hand Do not plug or unplug interface connectors under voltage The following must be observed Release the connector of the ribbon cable between B CPU processor module 1 and front cover at the front c...

Page 240: ...e 3 1 7UM611 Front view with housing size 1 3 after removal of the front cover sim plified and scaled down Figure 3 2 7UM612 Front view with housing size 1 2 after removal of the front cover sim plified and scaled down w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 241: ...nt layout and setting of the jumpers The following figure depicts the layout of the PCB for processor board version up to 7UM61 BB The location and ratings of the miniature fuse F1 and of the buffer battery G1 are shown in the following figure Figure 3 3 Processor module CPU with representation of the jumpers required for checking the settings w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 242: ...PCB for 7UM61 BB Table 3 3 Jumper settings for the control voltages of binary inputs BI1 through BI7 on the B CPU processor PCB for 7UM61 BB 1 Factory settings for devices with rated power supply voltages 24 VDC to 125 VDC 2 Factory settings for devices with rated power supply voltages 110 VDC to 220 VDC and 115 230 VAC Jumper Rated voltage 60 110 125 VDC 110 125 220 250 V DC 115 V AC 24 48 VDC X5...

Page 243: ...ure 3 4 B CPU processor PCB for devices from version CC with jumper settings required for checking configu ration settings For devices from version 7UM61 CC the jumpers for the set nominal voltage of the integrated power supply are checked in accordance with Table 3 4 the quiescent state of the life contact in accordance with Table 3 5 and the selected control voltages of binary inputs BI1 through...

Page 244: ... PCB for 7UM61 CC 1 Factory settings for devices with rated power supply voltages 24 VDC to 125 VDC 2 Factory settings for devices with power supply voltages of 220 VDC to 250 VDC and 115 230 VAC Jumper Rated voltage 60 110 125 VDC 220 250 VDC 115 230 VAC 24 48 VDC X51 1 2 2 3 1 2 X52 1 2 and 3 4 2 3 none X53 1 2 2 3 none Jumper Open in the quiescent state Closed in the quiescent state Presetting ...

Page 245: ... the jumper settings required for the board configuration In the version 7UM612 for the Input Output module C I O 1 binary output BO 4 can be configured as normally open or normally closed see also overview diagrams in Ap pendix A 2 Table 3 7 Jumper Setting for Relay Contact for Binary Output BO4 Jumper Normally open contactor Normally closed contact Presetting X40 1 2 2 3 1 2 w w w E l e c t r i ...

Page 246: ...umpers X71 X72 and X73 on the C I O 1 board serve to set the bus address The jumpers must not be changed The following table lists the jumper presettings The installation locations of the boards are shown in Figures 3 1 to 3 2 Table 3 9 Module address jumper setting of input output module C I O 1 for 7UM612 Binary Inputs Jumper 19 V Threshold 1 88 V Threshold 2 176 V Threshold 3 BI8 X21 X22 L M H ...

Page 247: ...sentation of jumper settings required for checking configuration settings The relay contact for binary output BO17 can be configured as normally open or nor mally closed see overview diagrams in Appendix A 2 Table 3 10 Jumper Setting for Relay Contact for Binary Output BO17 Jumper Normally open contactor Normally closed contact Presetting X41 1 2 2 3 1 2 w w w E l e c t r i c a l P a r t M a n u a...

Page 248: ...nsform ers and also the common jumper X60 However In the version with sensitive earth fault current input input transformer T8 there is no jumper X64 Jumpers X71 X72 and X73 on the Input Output C I O 2 board are used to set the bus address and may not be changed The following Table shows the factory setting of the jumpers Table 3 11 Module address jumper settings of input output modules C I O 2 Ju...

Page 249: ...ules Please note the following Exchange of interface modules is possible only with panel flush mounting and cubicle mounting devices as well as of mounting devices with detached or with no operator panel Devices in surface mounting housings with double level terminals can be changed only in our manufacturing centre Only interface modules can be used with which the device can be ordered from the fa...

Page 250: ... c b of the B_CPU processor PCB see under margin heading Processor module B CPU Table 3 2 Figure 3 7 shows the B CPU PCB with location of the modules The module for the RS485 interface is shown in Figure 3 8 the module for the Profibus interface in Figure 3 9 On delivery the jumpers are set so that the termination resistors are disconnected Both jumpers of a module must always be plugged in the sa...

Page 251: ...n ordered 3 1 2 5 Reassembly The device is assembled in the following steps Insert the modules carefully in the housing The installation locations of the boards are shown in Figures 3 1 to 3 2 For the surface mounting device press the metal lever when inserting the B CPU processor PCB This facilitates connector inser tion First plug the connector of the ribbon cable onto the input output module I ...

Page 252: ...must correspond to the maximum cross section area connection but be at least 2 5 mm 2 Connections use the plug terminals or screw terminals on the rear side of the device in accordance the circuit diagram For screw connections with forked lugs or direct connection before inserting wires the screws must be tightened so that the screw heads are flush with the outer edge of the connection block A rin...

Page 253: ... proection and system earthing to the rear of the unit with at least one M4 screw The cross section of the wire must be equal to the maximum connection cross section area but be at least 2 5 mm 2 Make connections at the device rear using plug or screw terminals in accordance with the circuit diagram When using spade lugs or directly connecting wires to threaded terminals before cable insertion the...

Page 254: ...he ground wire must be equal to the cross sectional area of any other control conductor connected to the device The cross section of the ground wire must be at least 2 5 mm 2 Connect solid low impedance operational grounding cross sectional area 2 5 mm2 to the grounding surface on the side Use at least one M4 screw for the device ground Connect the threaded terminals on the top and bottom of the d...

Page 255: ... serial interface of the device is connected to a central substation control system the data connection must be checked A visual check of the transmit channel and the receive channel is important With RS232 and fibre optic interfaces each con nection is dedicated to one transmission direction The data output of one device must be connected to the data input of the other device and vice versa With ...

Page 256: ...on the bus has the terminating resistors switched in and that all other devices on the bus do not Time Synchroniza tionInterface It is optionally possible to process 5 V 12 V or 24 V time synchronization sig nals provided that they are carried to the inputs named in the following table Table 3 15 D SUB socket assignment of the time synchronization interface 1 assigned but not used Connections for ...

Page 257: ...connected for the first time to voltage it should be have been at least 2 hours in its operating room in order to attain temperature equilibrium and to avoid dampness and condensation Note If a redundant supply is used there must be a permanent i e uninterruptible connec tion between the minus polarity connectors of system 1 and system 2 of the DC voltage supply no switching device no fuse because...

Page 258: ... values in earth paths of voltage or current IEE UE can not adapt the scan ning frequency To check them a sufficiently high value measured value should be present in one of the phases Wiring Important is in particular checking of the correct wiring and allocation of all interfaces of the device The test function described in section 3 3 for checking the binary inputs and outputs is a help here The...

Page 259: ...g of protection parametrization allocations and settings in accordance with the power system requirements is an important test step here The interface wide incorporation check in the power system results on the one hand in testing of cubicle wiring and drawing records in accordance with functionality and on the other hand the correctness of cabling between transducer or transformer and protection ...

Page 260: ...mer circuits includes the following items Acquisition of technical data Visual check of transformers e g for damage assembly position connections Check of transformer earthing especially earthing of the broken delta winding in only one phase Check cabling in accordance with circuit diagram Check of the short circuiters of the plug connectors for current circuits Further checks may be required depe...

Page 261: ...g with the voltage circuits Switch off voltage transformer protection switches Check in the operational messages that the VT mcb trip was entered indication FAIL Feeder VT ON A requirement for this is that the auxiliary contact of the VT mcb is connected and correspondingly allocated Close the VT mcb again The above indications appear under the going operational indications i e with the comment OF...

Page 262: ...nimum of 10 seconds before re energizing the power supply This wait allows the initial conditions to be firmly es tablished before the device is re energized The limit values given in Technical Data Chapter 10 must not be exceeded neither during testing nor during commissioning When testing the device with secondary test equipment make sure that no other mea surement quantities are connected and t...

Page 263: ...ansmission block that no indications at all are transmitted via the system interface during test mode The SIPROTEC System Description 1 describes how to activate and deactivate test mode and blocked data transmission Note that when DIGSI is being used the program must be in the Online operating mode for the test features to be used 3 3 2 Testing System Ports Prefacing Remarks If the device feature...

Page 264: ...located to the system interface in the matrix In the column Status SETPOINT the user has to define the value for the messages to be tested Depending on indication type several input fields are offered e g Indication coming Indication going By click ing on one of the fields you can select the desired value from the pull down menu Figure 3 14 System interface test with dialog box Generate annunciati...

Page 265: ...precisely controlled using DIGSI This feature is used to verify control wiring from the device to plant equipment during commissioning This test option should however definitely not be used while the device is in service on a live system DANGER Danger evolving from operating the equipment e g circuit breakers discon nectors by means of the test function Non observance of the following measure will...

Page 266: ...dware components Figure 3 15 Test of the Binary Inputs and Outputs Example Changing the Oper ating State To change the condition of a hardware component click on the associated switching field in the Scheduled column Password No 6 if activated during configuration will be requested before the first hardware modification is allowed After entry of the correct password a condition change will be exec...

Page 267: ...ut any switch ing in the plant it is possible to trigger individual binary inputs with the hardware test function As soon as the first state change of any binary input is triggered and the pass word no 6 has been entered all binary inputs are separated from the plant and can only be activated via the hardware test function Test of the LEDs The LEDs may be tested in a similar manner to the other in...

Page 268: ...ciated conditions must be known and verified Of particular importance are possible interlocking conditions of the switchgear circuit breakers isolators etc 3 3 6 Trip Close Tests for the Configured Operating Devices Control by Local Command If the configured operating devices were not switched sufficiently in the hardware test already described all configured switching devices must be switched on ...

Page 269: ...pplicable safety steps safety regulations and precautionary measures During the commissioning procedure switching operations must be carried out The tests described require that they can be done without danger They are accordingly not meant for operational checks WARNING Warning of dangers evolving from improper primary tests Non observance of the following measures can result in death personal in...

Page 270: ...ntial material damage Short circuit the current transformer secondary circuits before current connections to the device are opened If a test switch is available that short circuits automatically the secondary lines of the current transducer it will be sufficient to set it to Test position provided the short cir cuiters have been checked previously All secondary test equipment should be removed and...

Page 271: ...ta However this requires that measurement values be present before a dynamic test can take place so that the sampling frequency adaption can operate If a measurement value is switched from 0 to the device without a differ ent measurement value having been present beforehand an additional time delay of approximately 120 ms is incurred since the device must firstly calculate the frequency from the m...

Page 272: ... with generator currents of more than 20 are not normally required for digital protection Operation of the generator at rated current during commissioning may only be necessary when the short circuit characteristic is measured for the first time Amplitude Values The currents can be read out from the device front panel or from the PC via the oper ator interface under operational measured values and...

Page 273: ...nnections and the operational measured values If the relative short circuit voltage of the transformer is small the voltage values measured are very low so that it may be necessary to increase the generator current somewhat A test with rated generator current is only required for the quantitative calibration of the imped ance protection e g if it is necessary to calibrate the transformer uK The pr...

Page 274: ... machine are checked to ensure the correct cabling polarity phase sequence transformer ratio etc of the voltage transformers not to check indi vidual protection functions of the device Earthing of the Voltage Transform ers When checking the voltage transformers particular attention should be paid to the broken delta windings because these windings may only be earthed in one phase Preparation Set t...

Page 275: ...ge Start up the generator and excite it to rated voltage Apply measurement brushes if necessary Inject a test voltage between the rotor circuit and the earth by interpos ing the additional source device 7XR61 The earth current IEE that is flowing now can be read out on the device under the earth fault measured values The value ob tained is the capacitive spill current flowing in fault free operati...

Page 276: ...f the rated transformer voltage and once with a network earth fault Unit Connection In the event of an external high voltage side short circuit an interference voltage is transmitted via the coupling capacitance CK which induces a displacement voltage on the generator side To ensure that this voltage is not interpreted by the protection as an earth fault within the generator it is reduced by a sui...

Page 277: ...agram Equivalent circuit and vector diagram Since the reactance of the coupling capacitance is much larger than the referred resistance of the loading resistor RB UC UNO 3 can be set see also vector diagram Figure 3 17 where UNO 3 is the neutral dis placement voltage with a full displacement of the network voltage starpoint The fol lowing applies With the voltage transformation ratio TR of the ear...

Page 278: ... V has been chosen as the setting value for 5002 in address U0 which corre sponds to a protective zone of 90 see the following Figure Note For use as a neutral transformer the voltage transformation ratio TR instead of TR 3 should be used As this has only one winding the result is the same Figure 3 18 Displacement voltage during earth faults Network UNU 110 kV fNom 50 Hz CC 0 01 µF Voltage transfo...

Page 279: ... personal injury or substantial property damage Primary measurements must only be carried out on disconnected and grounded equipment of the power system Start up generator and slowly excite to about 20 UN Read out UE from the operational measured values and check for plausibility If the plant has more voltage transformers with broken delta windings the voltage UE must be measured on them as well F...

Page 280: ...ge see example in Figure 3 18 The fault value thus calculated should correspond at the most to half the pickup value U0 address 5002 in order to achieve the desired safety margin Shut down and de excite the generator Remove earth fault bridge If the starpoint of the high voltage side of the unit transformer is to be earthed during normal operation re establish starpoint earthing Activate the stato...

Page 281: ... Start up generator and slowly excite until the stator earth fault protection picks up In dication U0 picked up not allocated when delivered from factory At the same time the indication 3I0 picked up should appear not allocated when delivered from factory Read out operational measured values UE and IEE If the connections are correct this value corresponds to the machine terminal voltage percentage...

Page 282: ... restarting and exciting the generator above the pickup value of the displacement voltage U0 picked up picks up LED 2 for group indication of a device pickup when delivered from factory however the 3I0 picked up indication does not appear and tripping does not occur The measured value IEE should be negligible and on no account at nominal excitation should it be larger then half the setting value 3...

Page 283: ...RIP LED 6 Figure 3 20 Directional Check with Toroidal Transformers Directional Check with Holmgreen Connection If the current is supplied from a Holmgreen connection the displacement voltage is obtained in the same manner as in the above circuit Only the current of that current transformer which is in the same phase as the by passed voltage transformer in the delta connection is fed via the curren...

Page 284: ...For calibration to the spill current a three pole short circuit bridge that is able to with stand rated current is installed at the circuit breaker Start up generator and slowly excite until the rated machine current is reached Read out the operational measured value IEE This measured values determines the setting value of address 5003 3I0 Parameter 3I0 should be about twice that mea sured value t...

Page 285: ...e read out on the protection device under the operational measured values Check that this measured earth fault current is roughly equal to the pickup value 5102 for sensitive earth fault detection that has been set in address IEE However it must not be set to less than double the value of the spill current that has been determined for healthy insulation For generators with excitation via slip ring...

Page 286: ...ed The angle errors caused by the device internal input transformers have already been compensated in the factory This check is recommended if the reverse power protection is set to sen sitive Reduce driving power to zero by closing the regulating valves The generator now takes motoring energy from the network Caution Overheating on input of reverse power by the generator Operating the turbine wit...

Page 287: ...heir correct polarity as read out Oth erwise faulty result This angle ϕcorr is entered with reversed sign as the new correction angle under address 204 CT ANGLE W0 Setting value CT ANGLE W0 ϕcorr A quarter of the sum of the measured values P1 P2 is set as pickup value of the reverse power protection P REVERSE under address 3102 Calibrating the Reverse Power Pro tection If a generator is connected ...

Page 288: ...gle error correction value W0 determined and configured with regard to reverse power protection under address 204 applies also for the underexcitation protection In this section the measured values of the reactive power have been read out and thus a plausibility check of that measured value with directional check has been carried out No further checks are required If nevertheless by an additional ...

Page 289: ...c or ohmic inductive above the pickup value and as soon as the pickup indication FNo 1801 to 1803 appear query the indications 1806 I forward and 1807 I backward Compare the indicated direction with the setpoint setting value and address 1304 Phase Direction In the standard application with terminal side current trans formers address 1304 Phase Direction must be set to reverse and indication I for...

Page 290: ...st of the window Figure 3 23 Triggering oscillographic recording with DIGSI Example Test measurement recording is immediately started During the recording an indica tion is output in the left area of the status line Bar segments additionally indicate the progress of the procedure For display and evaluation of the recording you require one of the programs SIGRA or ComtradeViewer w w w E l e c t r i...

Page 291: ...N MENU Annunciation Set Reset so that in the future they only contain information on actual events and states see also 1 The counters in the switching statistics should be reset to the values that were existing prior to the testing see also SIPROTEC System Description 1 The counters of the operational measured values e g operation counter if available are reset under Main Menu Measurement Reset Pr...

Page 292: ...3 Mounting and Commissioning 292 7UM61 Manual C53000 G1176 C127 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 293: ...e Power Protection ANSI 32R 320 4 8 Forward Active Power Supervision ANSI 32F 321 4 9 Impedance Protection ANSI 21 322 4 10 Undervoltage Protection ANSI 27 323 4 11 Overvoltage Protection ANSI 59 324 4 12 Frequency Protection ANSI 81 325 4 13 Overexcitation Volt Hertz Protection ANSI 24 326 4 14 Rate of Frequency Change Protection df dt ANSI 81R 328 4 15 Jump of Voltage Vector 329 4 16 90 Stator E...

Page 294: ...4 Technical Data 294 7UM61 Manual C53000 G1176 C127 3 4 25 Operating Ranges of the Protection Functions 343 4 26 Dimensions 345 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 295: ...bility Input for Sensitive Earth Fault Detection IEE Thermal rms 300 A for 1 s 100 A for 10 s 15 A continuous Dynamic peak value 750 A Half cycle Secondary nominal voltage 100 V to 225 V Measuring range 0 V to 170 V Burden at 100 V Approx 0 3 VA Voltage path overload capacity Thermal rms 230 V continuous Voltage supply using integrated converter Rated auxiliary DC voltage UAux 24 48 V DC 60 110 12...

Page 296: ...1 7 configurable 7UM612 15 configurable Rated Voltage Range 24 V DC to 250 V DC bipolar Current Consumption Energized approx 1 8 mA independent of control voltage Switching Thresholds adjustable with jumpers Binary Inputs BI1 to BI7 for rated voltages 24 48 60 110 125 V DC Uhigh 19 V DC Ulow 10 V DC for rated voltages 110 125 220 250 V DC Uhigh 88 V DC Ulow 44 V DC Binary Inputs BI8 to BI15 for ra...

Page 297: ...s 5 A continuous 30 A 0 5 s 1 UL listed with the following nominal values 120 V AC Pilot duty B300 240 V AC Pilot duty B300 240 V AC 5 A General Purpose 24 V DC 5 A General Purpose 48 V DC 0 8 A General Purpose 240 V DC 0 1 A General Purpose 120 V AC 1 6 hp 4 4 FLA 240 V AC 1 2 hp 4 9 FLA Number RUN green 1 ERROR red 1 allocatable LEDs red 7UM611 7UM612 7 14 Connection front side non isolated RS 2...

Page 298: ...idgeable distance 1 000 m IEC 60 870 5 103 RS232 RS485 acc to ordered version isolated interface for data transfer to a master terminal RS232 Connection for flush mounted case rear panel slot B 9 pin D SUB socket for surface mounted case in console housing at case bottom Test voltage 500 VAC Transmission Speed min 4 800 Baud max 200 Baud Factory setting 38 400 Baud bridgeable distance 15 m RS485 C...

Page 299: ...anel slot B 9 pin D SUB socket for surface mounted case in console housing at case bottom Test voltage 500 VAC Transmission Speed up to 12 MBd bridgeable distance 1 000 m 3300 feet at 93 75 kBd 500 m 1666 feet at 187 5 kBd 200 m 660 feet at 1 5 MBd 100 m 330 feet at 12 MBd DPN3 0 RS485 Connection for flush mounted case rear panel slot B 9 pin D SUB socket for surface mounted case in console housin...

Page 300: ...ush mounted case rear panel mounting location B for surface mounted case in console housing at case bottom Transmission Speed up to 19 200 Bd optical wavelength λ 820 nm Laser Class 1 according to EN 60825 1 2 Using glass fibre 50 125 µm or using glass fibre 62 5 125µm admissible link signal at tenuation max 8 dB with glass fibre 62 5 125 µm bridgeable distance max 1 5 km 0 94 miles MODBUS Fibre O...

Page 301: ... at UI 17 V 640 Ω at UI 6 V 1700 Ω at UI 15 8 V 3560 Ω at UI 31 V Standards IEC 60 255 product standards IEEE C37 90 0 1 2 UL 508 DIN 57 435 Part 303 See also standards for individual tests Standards IEC 60 255 5 IEC 60 870 2 1 High voltage test routine test current inputs voltage inputs output relays 2 5 kV rms 50 Hz High voltage test routine test auxiliary voltage and binary inputs 3 5 kV DC Hig...

Page 302: ...polarities R i 50 Ω Test duration 1 min High energy impulse voltages SURGE IEC 61 000 4 5 Installation class 3 Impulse 1 2 50 µs Auxiliary Voltage common mode 2 kV 12 Ω 9 µF diff mode 1 kV 2 Ω 18 µF Measuring Inputs Binary Inputs Relay Outputs common mode 2 kV 42 Ω 0 5 µF diff mode 1 kV 42 Ω 0 5 µF Line conducted HF amplitude modulated IEC 61 000 4 6 Class III 10 V 150 kHz to 80 MHz 80 AM 1 kHz Po...

Page 303: ... 5 mm amplitude horizontal axis 1 Hz to 8 Hz 1 5 mm amplitude vertical axis 8 Hz to 35 Hz 1 g acceleration horizontal axis 8 Hz to 35 Hz 0 5 g acceleration vertical axis frequency sweep rate 1 octave min 1 cycles in 3 orthogonal axes Standards IEC 60 255 21 and IEC 60 068 2 Vibration IEC 60255 21 1 Class 2 IEC 60068 2 6 sinusoidal 5 Hz to 8 Hz 7 5 mm Amplitude 8 Hz to 15 Hz 2 g acceleration freque...

Page 304: ... up to 93 relative humid ity CONDENSATION MUST BE AVOIDED IN OPERATION Siemens recommends that all devices be installed so that they are not exposed to direct sun light nor subject to large fluctuations in temperature that may cause condensation to occur The protection device is designed for installation in normal relay rooms and plants so that elec tromagnetic compatibility EMC is ensured if inst...

Page 305: ... approx in flush mounting housing size 1 3 about 12 pounds 5 5 kg in flush mounting housing size 1 2 about 12 pounds 7 kg in surface mounting housing size 1 3 about 17 pounds 7 5 kg in surface mounting housing size 1 2 about 27 pounds 12 kg Protection class acc to IEC 60 529 for surface mounting case equipment IP 51 in flush mounted case Front IP 51 Rear IP 50 for personnel protection IP 2x with c...

Page 306: ... Seal In 0 10 s to 60 00 s Increments 0 01 s Directional limit line angle tolerance I 90 el to 90 el Increments 1 The set times are pure delay times Pickup times without inrush restraint with restraint add 10 ms I I Current 2 Pickup Value Current 10 Pickup Value approx 35 ms approx 25 ms Dropout Times I I approx 50 ms Dropout ratio overcurrent I approx 0 95 for I IN 0 3 Dropout ratio overcurrent I...

Page 307: ...7 3 Influencing Variables for Pickup Values Auxiliary direct voltage in range 0 8 UA UAN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 05 1 Harmonics Up to 10 3rd harmonic Up to 10 5th harmonic 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 308: ...Ip ANSI curves 0 50 to 15 00 or ineffective Increments 0 01 Undervoltage enableU 10 0 V to 125 0 V Increments 0 1V As per IEC 60255 3 Section 3 5 2 or BS 142 see also Figure 4 1 The trip times for I Ip 20 are identical to those for I Ip 20 Pickup Threshold approx 1 10 Ip Dropout Threshold Approx 1 05 Ip for Ip IN 0 3 Pickup Currents Ip for IN 1 A 1 of setting value or 10 mA for IN 5A 5 of setting ...

Page 309: ...ncing Variables for Pickup Values Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in range 0 95 f fN 1 05 1 Harmonics Up to 10 3rd harmonic Up to 10 5th harmonic 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 310: ...4 Technical Data 310 7UM61 Manual C53000 G1176 C127 3 Figure 4 1 Trip Characteristics of the Inverse time Overcurrent Protection as per IEC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 311: ...eshold approx 1 10 Ip Dropout Threshold Approx 1 05 Ip for Ip IN 0 3 this corresponds to approx 0 95 pickup value Pickup and Dropout Thresholds Ip for IN 1 A 1 of setting value or 10 mA for IN 5A 5 of setting value or 50 mA Pickup Threshold U 1 of setting value or 0 5 V Time for 2 I Ip 20 5 of reference calculated value 1 current tol erance respectively 40 ms Auxiliary DC voltage in range 0 8 UAux...

Page 312: ... Technical Data 312 7UM61 Manual C53000 G1176 C127 3 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in range 0 95 f fN 1 05 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 313: ...Overcurrent Protection ANSI 51V 313 7UM61 Manual C53000 G1176 C127 3 Figure 4 2 Trip Time Characteristics of the Inverse time Overcurrent Protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 314: ... Technical Data 314 7UM61 Manual C53000 G1176 C127 3 Figure 4 3 Trip Time Characteristics of the Inverse time Overcurrent Protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 315: ...A to 20 00 A Increments 0 05 A Nominal Overtemperature for INom 40 to 200 C 104 F to 392 F Increments 1 C Increments 1 8 F Coolant Temperature for Scaling 40 to 300 C 104 F to 572 F Increments 1 C Increments 1 8 F Limit current ILimit for IN 1 A 0 50 A to 8 00 A Increments 0 01 A for IN 5 A 2 00 A to 40 00 A Increments 0 05 A Dropout Time after Emergency Start ing TEmergency Start 10 s to 15000 s ...

Page 316: ...eferred to k IN Figure 4 4 Tripping Characteristics for Overload Protection Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 05 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 317: ...ineffective Increments 0 01 s Asymmetry factor FACTOR K 2 0 s to 100 0 s or ineffective Increments 0 1 s Cooling time factor TCool 0 s to 50 000 s Increments 1 s see also Figure 4 5 Pickup Times Stage characteristic Dropout Times Stage characteristic approx 50 ms approx 50 ms Warning StageI2 adm Tripping stage I2 Approx 0 95 Thermal tripping stage Dropout on undershoot of I2 Adm Pickup Values I2 A...

Page 318: ... the Thermal Characteristic for Unbalanced Load Protection Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 05 1 Harmonics Up to 10 3rd harmonic Up to 10 5th harmonic 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 319: ... Conductance Sections 1 xd Char approx 60 ms Rotor circuit criterion Uexc approx 60 ms Undervoltage Blocking approx 50 ms Conductance Sections 1 xd Char α approx 0 95 Rotor circuit criterion Uexc approx 1 05 or pickup value 0 5 V Undervoltage Blocking approx 1 1 Stator criterion 1 xd Char 3 of setting value Stator Criterion α 1 electrical Undervoltage Blocking 1 of setting value or 0 5 V Delay tim...

Page 320: ...360 ms at f 50 Hz approx 300 ms at f 60 Hz Dropout Times Reverse power Preverse approx 360 ms at f 50 Hz approx 300 ms at f 60 Hz Reverse power Preverse approx 0 6 Reverse power Preverse 0 25 SN 3 of setting value for Q 0 5 SN SN Rated apparent power Q Reactive power Delay times T 1 or 10 ms Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5...

Page 321: ...60 ms at f 50 Hz approx 50 ms at f 60 Hz Dropout Times Active power P P with high accuracy measurement approx 360 ms at f 50 Hz approx 300 ms at f 60 Hz with high speed measurement approx 60 ms at f 50 Hz approx 50 ms at f 60 Hz Active power PAct approx 1 10 or 0 5 of SN Active power PAct approx 0 90 or 0 5 of SN Active power P P 0 25 SN 3 of set value with high accuracy measurement 0 5 SN 3 of se...

Page 322: ... Ω Impedance Z1B secondary Based on IN 1 A 0 05 Ω up to 65 00 Ω Increments 0 01 Ω Impedance Z1B secondary Based on IN 5 A 0 01 Ω up to 13 00 Ω Impedance Z2 secondary Based on IN 1 A 0 05 Ω up to 65 00 Ω Increments 0 01 Ω Impedance Z2 secondary Based on IN 5 A 0 01 Ω up to 13 00 Ω Measuring Tolerances as per VDE0435 part 303 with Sinusoidal Quantities Z Z 5 for 30 ϕK 90 or 10 mΩ Delay Times 0 00 s ...

Page 323: ...o RV U only stages U U 1 01 to 1 20 Increments 0 01 Time Delays T U T U 0 00 s to 60 00 s or ineffective Increments 0 01 s The set times are pure delay times Pickup Times approx 50 ms Dropout Times approx 50 ms Pickup voltages U U 1 of setting value or 0 5 V Delay times T 1 of setting value or 10 ms Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 5 C Θamb 55 C 0 5 10 K Fre...

Page 324: ... 90 to 0 99 Increments 0 01 Time Delays T U T U 0 00 s to 60 00 s or ineffective Increments 0 01 s The set times are pure delay times Pickup Times U U approx 50 ms Dropout times U U approx 50 ms Pickup Voltage Limits 1 of setting value or 0 5 V Delay times T 1 of setting value or 10 ms Power Supply DC Voltage in Range 0 8 UPS UPSN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K...

Page 325: ...g Positive Sequence Component U1 10 0 V to 125 0 V and 0 V no blocking Increments 0 1V The set times are pure delay times Pickup Times f f Dropout Times f f approx 100 ms approx 100 ms f I Pickup Value Dropout Value I approx 20 mHz Dropout Ratio for Undervoltage Blocking approx 1 05 Frequencies f f Undervoltage Blocking Time Delays T f f 10 mHz at U UN f fN 1 of setting value or 0 5 V 1 of setting...

Page 326: ... s Characteristic value pairs U f 1 05 1 10 1 15 1 20 1 25 1 30 1 35 1 40 Associated Time Delay for t U f Thermal Replica 0 s to 20 000 s Increments 1 s Cooling time TCOOL 0 s to 20 000 s Increments 1 s Alarm and Stage Characteristic Pickup times for 1 1 Setting value approx 60 ms Dropout Times approx 60 ms Dropout Pickup approx 0 95 thermal replica default setting and stage characteristic see Fig...

Page 327: ...ng Characteristic from Thermal Replica and Stage Characteris tic of the Overexcitation Protection Default Setting Auxiliary DC voltage in range 0 8 UAux UAuxN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Harmonics Up to 10 3rd harmonic Up to 10 5th harmonic 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 328: ... 25 cycles Pickup Times df dt Approx 150 ms to 500 ms dep on window length Dropout Times df dt approx 150 ms to 500 ms dep on window length Dropout Difference f dt 0 02 to 0 99 Hz s settable Dropout Ratio approx 1 05 Frequency Rise Measuring Window 5 approx 5 or 0 15 Hz s at U 0 5 UN Measuring Window 5 approx 3 or 0 1 Hz s at U 0 5 UN Undervoltage Blocking 1 of setting value or 0 5 V Delay Times 1...

Page 329: ...ments 0 01 s or ineffective Undervoltage Blocking U1 10 0 to 125 0 V Increments 0 1V Pickup Times ϕ approx 75 ms Dropout Times ϕ approx 75 ms Angle Jump 0 5 at U 0 5 UN Undervoltage Blocking 1 of setting value or 0 5 V Delay times T 1 or 10 ms Power Supply DC Voltage in Range 0 8 UPS UPSN 1 15 1 Temperature in Range 23 F or 5 C Θamb 131 F or 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 05 1 Harmon...

Page 330: ...ickup Times UEarth IEarth directional approx 50 ms approx 50 ms approx 70 ms Dropout Times UEarth IEarth directional approx 50 ms approx 50 ms approx 70 ms Displacement voltage UEarth approx 0 70 Earth current IEarth approx 0 70 Angle criterion dropout difference 10 towards network Displacement Voltage 1 of setting value or 0 5 V Earth current 1 of setting value or 0 5 mA Delay times T 1 of settin...

Page 331: ...to 50 0 mA or 0 0 mA ineffective Increments 0 1 mA Pickup Times approx 50 ms Dropout Times approx 50 ms Measuring Circuit Supervision Delay approx 2 s Pickup currents IEE IEE approx 0 95 or 1 mA Measuring Circuit Supervision IEE approx 1 10 or 1 mA Pickup current 1 of setting value or 0 5 mA Time Delay 1 of setting value or 10 ms Power Supply DC Voltage in Range 0 8 UPS UPSN 1 15 1 Temperature in ...

Page 332: ...Increments 0 01 s Enabling conditions P Pmin 0 to 100 or ineffective Increments 1 U U1 min 50 0 V to 125 0 V or ineffective Increments 0 1V Pickup Times approx 80 ms Dropout Times approx 80 ms Undervoltage stage U0 3rd Harmon approx 1 10 or 0 1 mA Overvoltage stage U0 3rd Harmon approx 0 90 or 0 1 mA Enabling conditions P Pmin approx 0 90 U U1 min approx 0 95 Displacement Voltage 3 of setting valu...

Page 333: ... 0 A Increments 0 01 A for IN 5 A 3 00 A to 50 00 A Increments 0 05 A Maximum Startup Time TMax STARTUP 1 0 s to 180 0 s Increments 0 1 s Admissible Locked Rotor Time TLOCKED ROTOR 0 05 s to 120 0 s or in effective Increments 0 1 s Irms ISTARTUP DETECT approx 0 95 Pickup Threshold for IN 1 A 1 of setting value or 10 mA for IN 5 A 1 of setting value or 50 mA Time Delay 5 or 30 ms Power Supply DC Vo...

Page 334: ...tor at Standstill kτ STANDSTILL 1 0 to 100 0 Increments 0 1 Extension Factor on Motor Operation kτ OPERATION 1 0 to 100 0 Increments 0 1 Minimum Restart Inhibit Time 0 2 to 120 0 min Increm 0 1 min Significance ΘRe Inh Temperature limit below which a restart is possible ΘL max adm maximum admissible rotor overtemperature 100 of operational value ΘL ΘL from ncold number of admissible starts from co...

Page 335: ... 06 s to 60 00 s or Increments 0 01 s Pickup Times On Internal Start Using Controls For external Start Dropout Time approx 50 ms approx 50 ms approx 50 ms approx 50 ms Pickup Threshold BF I for IN 1 A 1 of setting value or 10 mA for IN 5 A 1 of setting value or 50 mA Delay Time BF T 1 or 10 ms Power Supply DC Voltage in Range 0 8 UPS UPSN 1 15 1 Temperature in Range 5 C Θamb 55 C 0 5 10 K Frequenc...

Page 336: ...s 0 01 s Dropout time T U1 DROPOUT 0 00 s to 60 00 s or ineffective Increments 0 01 s Response time approx 25 ms Dropout Time approx 35 ms I for IN 1 A Approx 0 80 or 50 mA for IN 5 A Approx 0 80 or 250 mA Tripping enabling U1 approx 1 05 Pickup Current I for IN 1 A 5 of setting value or 20 mA for IN 5 A 5 of setting value or 100 mA Tripping Enabling U1 1 of setting value or 0 5 V Delay Time T 1 o...

Page 337: ...Measuring Method Pt 100 Ω or Ni 100 Ω or Ni 120 Ω Mounting Identification Oil or Ambient or Winding or Bearing or Other for each measuring point Stage 1 50 C to 250 C 58 F to 482 F or no indication in increments of 1 C in increments of 1 8 F Stage 2 50 C to 250 C 50 00 C to 250 00 C or no indication in increments of 1 C in increments of 1 8 F w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 338: ... or in of UN UL1 L2 UL2 L3 UL3 L1 in kV primary in V secondary or in of UN UE or 3U0 in kV primary in V secondary or in of UN Positive sequence component U1 and negative sequence component U2 in kV primary in V secondary or in of UN Range 10 to 120 of UN Tolerance 0 2 of measured value or 0 2 mA 1 digit Operating Measured Values for Impedanc es R X in Ω primary and secondary Tolerance 1 Operationa...

Page 339: ...ction Θi2 Θtrip of the Overexcitation Protection ΘU f Θtrip Coolant temperature depends on connected temperature sensor Range 0 to 400 Tolerance 5 Report of Measured Values with date and time Reset manual using binary input using keypad using communication Min Max Values for Current Positive Se quence Components I1 Min Max Values for Voltage Positive Se quence Components U1 Min Max Values for 3rd ...

Page 340: ... battery also through auxiliary voltage failure Instantaneous Values Recording Time total 5 s Pre event and post event recording and memory time adjustable Scanning Rate with 50 Hz Scanning Rate with 60 Hz 1 sample 1 25 ms each 1 sample 1 04 ms each Channels uL1 uL2 uL3 uE iL1 iL2 iL3 iEE rms values Recording Time total 80 s Pre event and post event recording and memory time adjustable Scanning Ra...

Page 341: ...BSVALUE Amplitude formation X ADD Addition X X X X AND AND Gate X X X BOOL_TO_CO Boolean to Command Conversion X X BOOL_TO_DI Boolean to Double Point Indication Conversion X X X BOOL_TO_IC Boolean to Internal Single Point Indication Conversion X X X BUILD_DI Create a Double Point In dication X X X CMD_CHAIN Switching sequence X X CMD_INF Command Information X CONNECT Connection X X X D_FF D Flipfl...

Page 342: ...ollowing table shows the number of required TICKS for the individual elements of a CFC chart A generic module is one where the number of inputs can be changed typical are the logic functions AND NAND OR NOR Processing times in TICKS required by the individual elements Individual Element Number of TICKS Module basic requirement 5 each input from the 3rd additional input for generic modules 1 Connec...

Page 343: ...ANSI 24 inactive 1 active active inactive 1 Rate of Frequency Change Protection df dt ANSI 81R inactive active 4 active inactive Jump of Voltage Vector inactive active 5 active 5 inactive 90 Stator Earth Fault Protection ANSI 59N 64G 67G active active active active Sensitive Earth Fault Protection ANSI 51GN 64R inactive active active inactive 100 Stator Earth Fault Protection with 3rd Harmonics AN...

Page 344: ...egisters cooling down 2 a pickup if already present is maintained 3 a pick up if already present is maintained if the measured voltage is not too small 4 25 Hz f Hz 40 Hz 5 The function is only active at rated frequency 3 Hz w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 345: ...00 G1176 C127 3 4 26 Dimensions 4 26 1 Panel Flush and Cubicle Mounting 7UM611 Figure 4 7 Dimensions of a 7UM611 for panel flush mounting or cubicle installation Housing type 7XP2030 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 346: ... Manual C53000 G1176 C127 3 4 26 2 Panel Flush and Cubicle Mounting 7UM612 Figure 4 8 Dimensions of a 7UM612 for panel flush mounting or cubicle installation housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 347: ... 3 Panel Flush Mounting 7UM611 Figure 4 9 Dimensions of a 7UM611 for panel surface mounting 4 26 4 Panel Flush Mounting 7UM611 Figure 4 10 Dimensions of a 7UM621 for panel surface mounting housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 348: ...anual C53000 G1176 C127 3 4 26 5 Dimensions of Coupling Unit 7XR6100 0CA0 for Panel Flush Mounting Figure 4 11 Dimensions of Coupling Unit 7XR6100 0CA0 for Panel Flush Mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 349: ...ual C53000 G1176 C127 3 4 26 6 Dimensions of Coupling Unit 7XR6100 0BA0 for Panel Flush Mounting Figure 4 12 Dimensions of Coupling Unit 7XR6100 0BA0 for Panel Surface Mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 350: ... Dimension diagrams 3PP13 Figure 4 13 Dimension diagrams 3PP13 3PP132 for voltage divider 3PP1326 0BZ 012009 20 10 1 3PP133 for voltage divider 3PP1336 1CZ 013001 5 2 1 for series resistor 3PP1336 0DZ 013002 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 351: ...ctions of the devices to primary equipment in many typical power system configurations Tables with all set tings and all information available in this device equipped with all options are provided Default settings are also given A 1 Ordering Information and Accessories 352 A 2 Terminal Assignments 357 A 3 Connection Examples 361 A 4 Default Settings 373 A 5 Protocol dependent Functions 377 A 6 Fun...

Page 352: ... 5 Construction Pos 9 Surface mounting case for panel 2 tier terminals top bottom B Flush mounting case plug in terminals 2 3 pole connector D Flush mounting case screw type terminals direct connection ring and spade lugs E Region specific Default Language Settings and Function Versions Pos 10 Region DE 50 Hz IEC Language German Language can be changed A Region World 50 60 Hz IEC ANSI Language Eng...

Page 353: ...functions Pos 13 without extended measuring functionality 0 Min Max values energy metering 3 Functionality Pos 14 Generator Basis comprising ANSI No A Stator Earth Fault Protection undirected directed U0 3I0 U0 3I0 59N 64G 67G Sensitive earth fault detection also as rotor earth fault protec tion IEE 50 51GN 64R Overload protection I2 t 49 Overcurrent protection with Undervoltage Seal In I U 51 Ove...

Page 354: ... Breaker Failure Protection Imin 50BF Generator Full comprising ANSI No C Generator Standard and in addition Inadvertent Energizing Protection I U 50 27 100 Stator Earth Fault Protection with 3rd Harmonic U0 3rd Harm 59TN 27TN 3 H Impedance Protection with I U Excitation Z 21 Asynchronous Motor comprising ANSI No F Generator Standard and in addition Motor startup time supervision Ist 2t 48 Restart...

Page 355: ...der No Coupling unit 7XR6100 0CA00 Series Resistor Series resistor for rotor earth fault protection Order No Series resistor 2 x 105 Ω 3PP1336 0DZ 013002 Voltage divider Voltage divider Order No Voltage divider 5 1 5 2 3PP1336 1CZ 013001 Voltage divider 10 1 20 1 3PP1326 0BZ 012009 Interface Cable Interface cable between PC and SIPROTEC device Order No Cable with 9 pole male female connector 7XV51...

Page 356: ...using DIGSI 4 option package of the complete version of DIGSI 4 Order No DIGSI REMOTE 4 Full version with license for 10 comput ers Language German 7XS5440 1AA0 SIMATIC CFC 4 Graphical software for setting interlocking latching condi tions and creating extended functions option package of the complete version of DIGSI 4 Order No SIMATIC CFC 4 Full version with license for 10 computers7XS5450 0AA0 ...

Page 357: ... 2 Terminal Assignments 357 7UM61 Manual C53000 G1176 C127 3 A 2 Terminal Assignments A 2 1 General Diagram 7UM611 Figure A 1 General Diagram 7UM611 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 358: ...dix 358 7UM61 Manual C53000 G1176 C127 3 A 2 2 General Diagram Surface Mounting Version 7UM611 B Figure A 2 General diagram 7UM611 B panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 359: ...A 2 Terminal Assignments 359 7UM61 Manual C53000 G1176 C127 3 A 2 3 General Diagram 7UM612 Figure A 3 General diagram 7UM612 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 360: ...dix 360 7UM61 Manual C53000 G1176 C127 3 A 2 4 General Diagram Surface Mounting Version 7UM612 B Figure A 4 General diagram 7UM612 B panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 361: ...ection Current and voltage connections to three transformers phase earth voltages and in each case three current transformers earth current from additional summation current transformer for sensitive earth fault detection Displacement voltage detection at broken delta winding e n w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 362: ... to three voltage transformers phase to ground voltages and in each case three current transformers earth fault detection as differential current measuring of two CT sets detection of displacement voltage at broken delta winding e n as an additional criterion w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 363: ...nnection to three current transformers and three voltage transformers phase to ground voltages earth fault detection as differential current measuring between star point current and summation current measured via toroidal CTs detection of displacement voltage at open delta winding e n w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 364: ...nt transformers and three voltage transformers phase to earth voltages with series device 7XR61 for rotor circuit injection and with super vision of the rotor ground insulation by sensitive earth fault detection detection of displacement voltage at open delta winding e n w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 365: ...ction with Isolated Starpoint CT connections to three voltage transformers phase to earth voltages and three voltage transformers each Loading resistor connected either directly to starpoint circuit or via intermediate transformer w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 366: ...76 C127 3 Figure A 10 Rotor earth fault protection with series device 7XR61 for injection of a rated frequency voltage into the rotor circuit if the sensitive earth current input is used w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 367: ...A 3 Connection Examples 367 7UM61 Manual C53000 G1176 C127 3 Figure A 11 Generator with Neutral Conductor w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 368: ...tor Connection to three voltage transformers phase to earth voltages usually from the busbar Displacement voltage detection at broken delta winding three current transformers Earth fault di rection detection by toroidal CTs w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 369: ...ctions for Two Voltage Transformers in Open Delta Connection V Connection Figure A 14 Current Transformer Connections with only Two System Side Current Transformers Figure A 15 Voltage Transformer Connection with L2 Earthed on the Secondary Side w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 370: ... A 3 2 Connection Examples for Thermobox Figure A 16 Simplex operation with one Thermobox Figure A 17 Semiduplex operation with one thermobox Figure A 18 Semiduplex operation with two thermoboxes w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 371: ...ries Figure A 19 Schematic Diagram of Coupling Unit 7XR6100 0 A00 for Rotor Earth Fault Pro tection Figure A 20 Schematic Diagram of Series Resistor 3PP1336 0DZ 013002 Figure A 21 Schematic Diagram of Voltage Divider 5 1 5 2 3PP1336 1CZ 013001 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 372: ...A Appendix 372 7UM61 Manual C53000 G1176 C127 3 Figure A 22 Schematic Diagram of Voltage Divider 10 1 20 1 3PP1326 0BZ 012009 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 373: ... Stator earth fault U0 stage TRIP S E F TRIP 5193 Stator earth fault protection TRIP LED7 Error PwrSupply 147 Error Power Supply Fail Battery 177 Failure Battery empty LED8 List Empty 1 Binary Input Short Text Function No Description BI1 SV tripped 5086 Stop valve tripped BI2 Uexc fail 5328 Exc voltage failure recognized BI3 BLOCK f1 5206 BLOCK stage f1 BLOCK U 6506 BLOCK undervoltage protection U...

Page 374: ...3 TRIP Exc U TRIP 5346 Underexc prot char Uexc TRIP BO17 f1 TRIP 5236 f1 TRIP2 f2 TRIP 5237 f2 TRIP2 I TRIP 1815 O C I TRIP2 U TRIP 6573 Overvoltage U TRIP2 Pr TRIP 5097 Reverse power TRIP2 Pr SV TRIP 5098 Reverse power TRIP with stop valve2 S E F TRIP 5193 Stator earth fault protection TRIP2 I2 Θ TRIP 5161 Unbalanced load TRIP of thermal stage2 Exc 3 TRIP 5343 Underexc prot char 3 TRIP2 Exc U TRI...

Page 375: ...lt data after general pickup of the 7UM61 automatically and without any operator action on its LCD display in the sequence shown in the following figure Figure A 24 Display of spontaneous messages in the device display Function Keys Presetting F1 Display of Operational Annunciations F2 Display of Primary Operational Values F3 Jumping to heading for last eight fault annunciations F4 Jumping to the ...

Page 376: ...nal single point indication IntSP and assigned to an output This would not be possible directly i e without the additional block Figure A 25 Link between Input and Output for Transmission Block Limit value han dling MW Using modules on the running sequence measured value processing an undercur rent monitor for the three phase currents is implemented The output indication is issued as soon as one o...

Page 377: ...message in CFC Pre defined User defined message in CFC Yes Time synchroni zation Via protocol DCF77 IRIG B Interface Binary input Via protocol DCF77 IRIG B Interface Binary input Via DCF77 IRIG B Interface Binary input Via protocol DCF77 IRIG B Interface Binary input Via protocol DCF77 IRIG B Interface Binary input Protocol Messages with time stamp Yes Yes No Yes No Yes Commissioning tools Measure...

Page 378: ...wer Protection 132 FORWARD POWER Disabled Enabled Enabled Forward Power Supervision 133 IMPEDANCE PROT Disabled Enabled Enabled Impedance Protection 140 UNDERVOLTAGE Disabled Enabled Enabled Undervoltage Protection 141 OVERVOLTAGE Disabled Enabled Enabled Overvoltage Protection 142 FREQUENCY Prot Disabled Enabled Enabled Over Underfrequency Protection 143 OVEREXC PROT Disabled Enabled Enabled Over...

Page 379: ...t Disabled Trip Circuit Supervision 185 THRESHOLD Disabled Enabled Enabled Threshold Supervision 186 EXT TRIP 1 Disabled Enabled Enabled External Trip Function 1 187 EXT TRIP 2 Disabled Enabled Enabled External Trip Function 2 188 EXT TRIP 3 Disabled Enabled Enabled External Trip Function 3 189 EXT TRIP 4 Disabled Enabled Enabled External Trip Function 4 190 RTD BOX INPUT Disabled Port C Port D Po...

Page 380: ...ase Sequence 272 SCHEME P System Data 1 Busbar Unit transf Busbar Scheme Configuration 273 STAR POINT P System Data 1 low resist high resist high resist Earthing of Machine Starpoint 274A ATEX100 P System Data 1 YES NO NO Storage of th Replicas w o Power Supply 276 TEMP UNIT P System Data 1 Celsius Fahrenheit Celsius Unit of temperature measure ment 280 TMin TRIP CMD P System Data 1 0 01 32 00 sec...

Page 381: ...Definite Inv Very Inverse ANSI Curve 1407 VOLT INFLUENCE O C Prot Ip without Volt controll Volt restraint without Voltage Influence 1408 U O C Prot Ip 10 0 125 0 V 75 0 V U Threshold for Release Ip 1601 Ther OVER LOAD Therm Overload OFF ON Block relay Alarm Only OFF Thermal Overload Protection 1602 K FACTOR Therm Overload 0 10 4 00 1 11 K Factor 1603 TIME CONSTANT Therm Overload 30 32000 sec 600 s...

Page 382: ...125 0 V 25 0 V Undervoltage blocking Pickup 3101 REVERSE POWER Reverse Power OFF ON Block relay OFF Reverse Power Protection 3102 P REVERSE Reverse Power 30 00 0 50 1 93 P Reverse Pickup 3103 T SV OPEN Reverse Power 0 00 60 00 sec 10 00 sec Time Delay Long without Stop Valve 3104 T SV CLOSED Reverse Power 0 00 60 00 sec 1 00 sec Time Delay Short with Stop Valve 3105A T HOLD Reverse Power 0 00 60 0...

Page 383: ...f2 PICKUP Frequency Prot 40 00 65 00 Hz 57 00 Hz f2 Pickup 4207 T f2 Frequency Prot 0 00 100 00 sec 6 00 sec T f2 Time Delay 4208 f3 PICKUP Frequency Prot 40 00 65 00 Hz 49 50 Hz f3 Pickup 4209 f3 PICKUP Frequency Prot 40 00 65 00 Hz 59 50 Hz f3 Pickup 4210 T f3 Frequency Prot 0 00 100 00 sec 20 00 sec T f3 Time Delay 4211 f4 PICKUP Frequency Prot 40 00 65 00 Hz 52 00 Hz f4 Pickup 4212 f4 PICKUP F...

Page 384: ...65 0 V Minimum Operating Voltage Umin 4519A df1 2 HYSTERES df dt Protect 0 02 0 99 Hz s 0 10 Hz s Reset Hysteresis for df1 dt df2 dt 4520A df1 2 M WINDOW df dt Protect 1 25 Cycle 5 Cycle Measuring Window for df1 dt df2 dt 4521A df3 4 HYSTERES df dt Protect 0 02 0 99 Hz s 0 40 Hz s Reset Hysteresis for df3 dt df4 dt 4522A df3 4 M WINDOW df dt Protect 1 25 Cycle 5 Cycle Measuring Window for df3 dt d...

Page 385: ...le Number of Warm Starts 6607 COLD WARM Restart Motor 1 2 1 Number of Cold Starts Warm Starts 6608 Kτ at STOP Restart Motor 1 0 100 0 5 0 Extension of Time Constant at Stop 6609 Kτ at RUNNING Restart Motor 1 0 100 0 2 0 Extension of Time Constant at Running 6610 T MIN INHIBIT Restart Motor 0 2 120 0 min 6 0 min Minimum Restart Inhibit Time 7001 BREAKER FAILURE Breaker Failure OFF ON Block relay OF...

Page 386: ...U2 I0 I1 I2 PHI Disabled Measured Value for Threshold MV1 8502 THRESHOLD MV1 Threshold 200 200 100 Pickup Value of Measured Value MV1 8503 MEAS VALUE 2 Threshold Disabled P Q Delta P U1 U2 I0 I1 I2 PHI Disabled Measured Value for Threshold MV2 8504 THRESHOLD MV2 Threshold 200 200 100 Pickup Value of Measured Value MV2 8505 MEAS VALUE 3 Threshold Disabled P Q Delta P U1 U2 I0 I1 I2 PHI Disabled Mea...

Page 387: ...1 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Pt 100 Ω RTD 1 Type 9012A RTD 1 LOCATION RTD Box Oil Ambient Winding Bearing Other Winding RTD 1 Location 9013 RTD 1 STAGE 1 RTD Box 50 250 C 100 C RTD 1 Temperature Stage 1 Pickup 9014 RTD 1 STAGE 1 RTD Box 58 482 F 212 F RTD 1 Temperature Stage 1 Pickup 9015 RTD 1 STAGE 2 RTD Box 50 250 C 120 C RTD 1 Temperature Stage 2 Pickup 9016 RTD 1 ST...

Page 388: ...ot connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 5 Type 9052A RTD 5 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 5 Location 9053 RTD 5 STAGE 1 RTD Box 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 RTD Box 58 482 F 212 F RTD 5 Temperature Stage 1 Pickup 9055 RTD 5 STAGE 2 RTD Box 50 250 C 120 C RTD 5 Temperature Stage 2 Pickup 9056 RTD 5 STAGE 2 RTD Box...

Page 389: ...Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 9 Type 9092A RTD 9 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 9 Location 9093 RTD 9 STAGE 1 RTD Box 50 250 C 100 C RTD 9 Temperature Stage 1 Pickup 9094 RTD 9 STAGE 1 RTD Box 58 482 F 212 F RTD 9 Temperature Stage 1 Pickup 9095 RTD 9 STAGE 2 RTD Box 50 250 C 120 C RTD 9 Temperature Stage 2 Pickup 9096 RTD 9 STAGE 2 RTD Bo...

Page 390: ...ure Stage 2 Pickup 9121A RTD12 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD12 Type 9122A RTD12 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD12 Location 9123 RTD12 STAGE 1 RTD Box 50 250 C 100 C RTD12 Temperature Stage 1 Pickup 9124 RTD12 STAGE 1 RTD Box 58 482 F 212 F RTD12 Temperature Stage 1 Pickup 9125 RTD12 STAGE 2 RTD Box 50 250 C 120 C RTD12 Temperat...

Page 391: ...ble not preset allocatable blank neither preset nor allocatable No Description Function Type of In for matio n Log Buffers Configurable in Matrix IEC 60870 5 103 Event Log ON OFF Trip Fault Log ON OFF Ground Fault Log ON OFF Marked in Oscill Record LED Binary Input Function Key Relay Chatter Suppression Type Information Number Data Unit General Interrogation Back Light on Light on Device EM ON OFF...

Page 392: ...60 Reset LED Reset LED Device AM_ W ON LED BO 70 19 1 No 67 Resume Resume Device AM ON LED BO 68 Clock Synchronization Error Clock SyncError Device AM ON OFF LED BO 69 Daylight Saving Time DayLight SavTime Device AM ON OFF LED BO 70 Setting calculation is running Settings Calc Device AM ON OFF LED BO 70 22 1 Yes 71 Settings Check Settings Check Device AM LED BO 72 Level 2 change Level 2 change Dev...

Page 393: ...87 Error Board 5 Error Board 5 Device AM ON OFF LED BO 188 Error Board 6 Error Board 6 Device AM ON OFF LED BO 189 Error Board 7 Error Board 7 Device AM ON OFF LED BO 190 Error Board 0 Error Board 0 Device AM ON OFF LED BO 191 Error Offset Error Offset Device AM ON OFF LED BO 192 Error 1A 5Ajumper different from setting Error1A 5Awrong Device AM ON OFF LED BO 193 Alarm NO calibration data avail ab...

Page 394: ...mary fault current IL3 IL3 P System Data 2 AM ON OFF 150 179 4 No 545 Time from Pickup to drop out PU Time Device AM 546 Time from Pickup to TRIP TRIP Time Device AM 916 Increment of active energy Wp Energy 917 Increment of reactive energy Wq Energy 1020 Counter of operating hours Op Hours Statistics AM 1021 Accumulation of interrupted current L1 Σ L1 Statistics AM 1022 Accumulation of interrupted...

Page 395: ...reaker Failure AM ON OFF LED BO 166 155 2 Yes 1471 Breaker failure TRIP BrkFailure TRIP Breaker Failure AM ON m LED BO 166 171 2 Yes 1503 BLOCK thermal overload pro tection BLK ThOverload Therm Overload EM LED BI BO 1506 Reset memory for thermal replica O L RM th rep O L Therm Overload EM ON OFF LED BI BO 1507 Emergency start O L Em er Start O L Therm Overload EM ON OFF LED BI BO 167 7 1 Yes 1508 ...

Page 396: ... Ip OFF O C Prot Ip AM ON OFF LED BO 60 180 1 Yes 1892 O C protection Ip is BLOCKED O C Ip BLOCKED O C Prot Ip AM ON OFF ON OFF LED BO 60 181 1 Yes 1893 O C protection Ip is ACTIVE O C Ip ACTIVE O C Prot Ip AM ON OFF LED BO 60 182 1 Yes 1896 O C fault detection Ip phase L1 O C Ip Fault L1 O C Prot Ip AM ON OFF LED BO 60 184 2 Yes 1897 O C fault detection Ip phase L2 O C Ip Fault L2 O C Prot Ip AM ...

Page 397: ... Imp Z2 TRIP Imp Z2 TRIP Impedance AM ON m LED BO 28 242 2 Yes 3980 Imp T3 TRIP Imp T3 TRIP Impedance AM ON m LED BO 28 243 2 Yes 4523 Block external trip 1 BLOCK Ext 1 External Trips EM LED BI BO 4526 Trigger external trip 1 Ext trip 1 External Trips EM ON OFF LED BI BO 51 126 1 Yes 4531 External trip 1 is switched OFF Ext 1 OFF External Trips AM ON OFF LED BO 51 131 1 Yes 4532 External trip 1 is...

Page 398: ...ernal Trips AM ON OFF LED BO 51 196 2 Yes 4597 External trip 4 General TRIP Ext 4 Gen TRP External Trips AM ON LED BO 51 197 2 Yes 4822 BLOCK Restart inhibit motor BLK Re Inhib Restart Motor EM LED BI BO 4823 Emergency start rotor Emer Start ΘR Restart Motor EM ON OFF LED BI BO 168 51 1 Yes 4824 Restart inhibit motor is switched OFF Re Inhibit OFF Restart Motor AM ON OFF LED BO 168 52 1 Yes 4825 R...

Page 399: ...ward Power EM ON OFF LED BI BO 70 102 1 Yes 5117 BLOCK forw power superv Pf stage Pf BLOCK Forward Power EM ON OFF LED BI BO 70 103 1 Yes 5121 Forward power supervis is switched OFF Pf OFF Forward Power AM ON OFF LED BO 70 106 1 Yes 5122 Forward power supervision is BLOCKED Pf BLOCKED Forward Power AM ON OFF ON OFF LED BO 70 107 1 Yes 5123 Forward power supervision is ACTIVE Pf ACTIVE Forward Powe...

Page 400: ...on is ACTIVE S E F ACTIVE Stator E Fault AM ON OFF LED BO 70 158 1 Yes 5186 Stator earth fault U0 picked up U0 picked up Stator E Fault AM ON OFF LED BO 70 159 2 Yes 5187 Stator earth fault U0 stage TRIP U0 TRIP Stator E Fault AM ON m LED BO 70 160 2 Yes 5188 Stator earth fault I0 picked up 3I0 picked up Stator E Fault AM ON OFF LED BO 70 168 2 Yes 5189 Earth fault in phase L1 Uearth L1 Stator E F...

Page 401: ...itation EM ON OFF LED BI BO 71 64 1 Yes 5330 BLOCK underexc prot char 2 Char 2 BLK Underexcitation EM ON OFF LED BI BO 71 65 1 Yes 5331 Underexc prot is switched OFF Excit OFF Underexcitation AM ON OFF LED BO 71 55 1 Yes 5332 Underexc prot is BLOCKED Excit BLOCKED Underexcitation AM ON OFF ON OFF LED BO 71 56 1 Yes 5333 Underexc prot is ACTIVE Ex cit ACTIVE Underexcitation AM ON OFF LED BO 71 57 1...

Page 402: ...dt Protect EM ON OFF LED BI BO 72 4 1 Yes 5511 df dt is switched OFF df dt OFF df dt Protect AM ON OFF LED BO 72 5 1 Yes 5512 df dt is BLOCKED df dt BLOCKED df dt Protect AM ON OFF ON OFF LED BO 72 6 1 Yes 5513 df dt is ACTIVE df dt ACTIVE df dt Protect AM ON OFF LED BO 72 7 1 Yes 5514 df dt is blocked by undervoltage df dt U block df dt Protect AM ON OFF ON OFF LED BO 72 8 1 Yes 5516 Stage df1 dt...

Page 403: ...FF LED BO 72 74 1 Yes 5585 Vector Jump not in measurement range VEC JUMP Range Vector Jump AM ON OFF LED BO 72 75 1 Yes 5586 Vector Jump picked up VEC JUMP pickup Vector Jump AM ON OFF LED BO 72 76 2 Yes 5587 Vector Jump TRIP VEC JUMP TRIP Vector Jump AM ON LED BO 72 77 2 Yes 6503 BLOCK undervoltage protection BLOCK U V Undervoltage EM LED BI BO 6506 BLOCK undervoltage protection U BLOCK U Undervo...

Page 404: ...ion is ACTIVE START SUP ACT Start Motor AM ON OFF LED BO 169 53 1 Yes 6821 Starting time supervision TRIP START SUP TRIP Start Motor AM ON LED BO 169 54 2 Yes 6822 Rotor is LOCKED after Locked Rotor Time Rotor locked Start Motor AM ON LED BO 169 55 2 Yes 6823 Starting time supervision picked up START SUP PU Start Motor AM ON OFF LED BO 169 56 1 Yes 6851 BLOCK Trip circuit supervision BLOCK TripC T...

Page 405: ...141 Fail RTD 4 broken wire shorted Fail RTD 4 RTD Box AM ON OFF LED BO 14142 RTD 4 Temperature stage 1 picked up RTD 4 St 1 p up RTD Box AM ON OFF LED BO 14143 RTD 4 Temperature stage 2 picked up RTD 4 St 2 p up RTD Box AM ON OFF LED BO 14151 Fail RTD 5 broken wire shorted Fail RTD 5 RTD Box AM ON OFF LED BO 14152 RTD 5 Temperature stage 1 picked up RTD 5 St 1 p up RTD Box AM ON OFF LED BO 14153 R...

Page 406: ...2 p up RTD Box AM ON OFF LED BO 14211 Fail RTD11 broken wire short ed Fail RTD11 RTD Box AM ON OFF LED BO 14212 RTD11 Temperature stage 1 picked up RTD11 St 1 p up RTD Box AM ON OFF LED BO 14213 RTD11 Temperature stage 2 picked up RTD11 St 2 p up RTD Box AM ON OFF LED BO 14221 Fail RTD12 broken wire short ed Fail RTD12 RTD Box AM ON OFF LED BO 14222 RTD12 Temperature stage 1 picked up RTD12 St 1 p...

Page 407: ... 6575 193 177 Fail I Superv Fail U Superv Fail Ph Seq Error PwrSupply VT Fuse Failure Alarm NO calibr Fail Battery 161 Fail I Superv 162 163 Failure Σ I Fail I balance 164 Fail U Superv 165 167 Fail Σ U Ph E Fail U balance 171 Fail Ph Seq 175 176 Fail Ph Seq I Fail Ph Seq U 181 Error A D conv 192 194 190 185 188 Error1A 5Awrong Error neutralCT Error Board 0 Error Board 3 Error Board 6 w w w E l e ...

Page 408: ...r CFC CD DD 640 UE 3rd Harmonic Voltage Maximum UE3h Max Min Max meter CFC CD DD 641 P active power P Measurement 134 147 No 9 12 CFC CD DD 642 Q reactive power Q Measurement 134 147 No 9 13 CFC CD DD 644 Frequency Freq Measurement 134 147 No 9 15 CFC CD DD 645 S apparent power S Measurement CFC CD DD 650 UE 3rd harmonic UE3h Measurement CFC CD DD 660 Remaining Time for Switch ON T Rem Meas Therma...

Page 409: ...rward Wq Energy CD DD 928 Wp Reverse Wp Energy 133 53 No 205 CD DD 928 Wp Reverse Wp Energy CD DD 929 Wq Reverse Wq Energy 133 54 No 205 CD DD 929 Wq Reverse Wq Energy CD DD 1068 Temperature of RTD 1 Θ RTD 1 Meas Thermal 134 146 No 9 1 CFC CD DD 1069 Temperature of RTD 2 Θ RTD 2 Meas Thermal 134 146 No 9 2 CFC CD DD 1070 Temperature of RTD 3 Θ RTD 3 Meas Thermal 134 146 No 9 3 CFC CD DD 1071 Tempe...

Page 410: ...A Appendix 410 7UM61 Manual C53000 G1176 C127 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 411: ...tion E50417 H1176 C151 A2 2 SIPROTEC DIGSI Start UP E50417 G1176 C152 A2 3 DIGSI CFC Manual E50417 H1176 C098 A4 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A2 5 Planning Machine Protection Systems E50400 U0089 U412 A1 7600 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 412: ...Literature 412 7UM61 Manual C53000 G1176 C127 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 413: ... CFC blocks Blocks are parts of the user program delimited by their function their structure or their purpose Chatter blocking A rapidly intermittent input for example due to a relay contact fault is switched off after a configurable monitoring time and can thus not generate any further signal changes The function prevents overloading of the system when a fault arises Combination devices Combinati...

Page 414: ...clock unit of the PTB transmits this time via the long wave time signal transmitter in Mainflingen near Frank furt Main The emitted time signal can be received within a radius of approx 1 500 km from Frankfurt Main Device container In the Component View all SIPROTEC 4 devices are assigned to an object of type Device container This object is a special object of DIGSI Manager However since there is ...

Page 415: ...Double point indication ExDP_I External double point indication via an ETHERNET connection intermediate position 00 device specific Double point indication ExMV External metered value via an ETHERNET connection device specific ExSI External single point indication via an ETHERNET connection device specific Single point indication ExSI_F External single point indication via an ETHERNET connection d...

Page 416: ...his also includes for example information detailing which fields exist in this project This file is called a HV project description file ID Internal double point indication Double point indication ID_S Internal double point indication intermediate position 00 Double point indication IEC International Electrotechnical Commission IEC address Within an IEC bus a unique IEC address has to be assigned ...

Page 417: ... usually as an integrated value In power supply companies the electrical work is usually recorded as a metered value energy purchase supply energy transportation MLFB number MLFB is the abbreviation for MaschinenLesbare FabrikateBezeichnung machine readable product designation This is the equivalent of an order number The type and version of a SIPROTEC 4 device are coded in the order number Modem ...

Page 418: ...us Devices with a process bus interface allow direct communication with SICAM HV mod ules The process bus interface is equipped with an Ethernet module PROFIBUS PROcess FIeld BUS the German process and field bus standard as specified in the standard EN 50170 Volume 2 PROFIBUS It defines the functional electrical and mechanical properties for a bit serial field bus PROFIBUS address Within a PROFIBU...

Page 419: ...upts and indications archives the network data offers the possibility of intervening manually in the process and manages the system rights of the individual employee Single command Single commands are process outputs which indicate 2 process states for example ON OFF at one output Single point indica tion Single indications are items of process information which indicate 2 process states for examp...

Page 420: ...der tree This area is called the tree view TxTap Transformer Tap Indication User address A user address comprises the name of the station the national code the area code and the user specific phone number Users Up to 16 compatible SIPROTEC 4 devices can communicate with one another in an Inter Relay Communication combination The individual participating devices are called users VD A VD Virtual Dev...

Page 421: ...cking Operator Interface 255 Checking Overexcitation 275 Checking Phase Rotation 272 Checking Rotor Earth Fault Protection Current Measurement 285 Checking Stator Earth Fault Protection 276 Checking Switching Configured Operating Devices 268 Checking System Interface 255 Checking Termination 256 Checking Time Synchronization Interface 256 Checking Voltage Circuits 274 Climatic Stress Tests 304 Clo...

Page 422: ...ifications 236 Hardware Monitoring 166 Humidity 304 I IEC 60 870 5 103 22 Impedance Protection 322 Impedance protection 24 Impedance Stages 97 Inadvertent Energizing Protection 26 162 336 Indications 209 210 Initial Start 206 Installation Panel Surface Mounting 254 Instantaneous values 216 Insulation Test 301 Interface Modules 249 Interlocked switching 224 Introduction 17 Introduction Reference Po...

Page 423: ...anel Interfaces 22 Reference Voltages 166 Regulations 301 Replacing Interfaces 238 Restart 206 Restart inhibit for motors 149 Restart Threshold 150 Reverse Power Protection 24 85 Rotor Earth Fault Protection 138 Rotor Earth Fault Protection Measuring Circuit Su pervision 275 Rotor Overtemperature 149 RS232 298 298 RS485 298 RTD 192 RTD Box 337 r rms values 216 R Rated System Frequency 37 Rear Pane...

Page 424: ...308 Tripping Logic 204 Type of Contact for Output Relays 237 U UE Transformation Ratio 35 Unbalanced Load Negative Sequence Protection ANSI 46 70 Underexcitation protection 24 77 Undervoltage Blocking 78 Undervoltage Consideration 52 Undervoltage Protection 24 103 323 Undervoltage Seal In 42 Undervoltage Seal In Feature 92 Uph Uen Adaption Factor 36 User Defined Functions 341 V Vector Jump 123 Vib...

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