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Siemens Solkor 7PG2113 Technical Manual Download Page 201

7PG2113/4/5/6 Commissioning & Maintenance  

©2012 Siemens Protection Devices Limited  

 

Chapter 6 Page 3 of 77  

2.11.1

 

Definite Time NPS Overcurrent    (46DT)................................................................................ 48

 

2.11.2

 

Inverse Time NPS Overcurrent   (46IT) .................................................................................. 48

 

2.12

 

Undercurrent   (37)................................................................................................................................ 50

 

2.13

 

Thermal Overload (49) .......................................................................................................................... 52

 

2.14

 

Over/Under Voltage .............................................................................................................................. 54

 

2.14.1

 

Phase Under/Over Voltage  (27/59)........................................................................................ 54

 

2.14.2

 

Undervoltage Guard (27/59UVG)............................................................................................ 56

 

2.15

 

NPS Overvoltage (47) ........................................................................................................................... 56

 

2.16

 

Neutral Overvoltage (59N) .................................................................................................................... 58

 

2.16.1

 

Definite Time (59NDT) ............................................................................................................ 58

 

2.16.2

 

Inverse Time (59NIT) .............................................................................................................. 59

 

Section 3: Supervision Functions........................................................................................................................... 60

 

3.1

 

CB Fail  (50BF) ..................................................................................................................................... 60

 

3.1.1

 

Element Blocking .................................................................................................................... 61

 

3.2

 

Voltage Transformer Supervision   (60VTS) ......................................................................................... 62

 

3.2.1

 

1 or 2 Phase VT fail ................................................................................................................ 62

 

3.2.2

 

3 Phase VT fail........................................................................................................................ 63

 

3.3

 

Current Transformer Supervision   (60CTS) ......................................................................................... 64

 

3.3.1

 

7PG2113 & 7PG2115 ............................................................................................................. 64

 

3.3.2

 

7PG2114 & 7PG2116 ............................................................................................................. 65

 

3.4

 

Broken Conductor   (46BC)................................................................................................................... 66

 

3.5

 

Trip/Close Circuit Supervision   (74T/CCS)........................................................................................... 68

 

3.6

 

Magnetising Inrush Detector   (81HBL) ................................................................................................. 69

 

Section 4: Control & Logic Functions ..................................................................................................................... 70

 

4.1

 

Autoreclose (79).................................................................................................................................... 70

 

4.2

 

Quick Logic ........................................................................................................................................... 70

 

Section 5: Testing and Maintenance...................................................................................................................... 71

 

5.1

 

Periodic Tests ....................................................................................................................................... 71

 

5.2

 

Maintenance ......................................................................................................................................... 71

 

5.3

 

Troubleshooting .................................................................................................................................... 71

 

Section 6: Pilot Supervision Equipment ................................................................................................................. 73

 

6.1

 

Introduction ........................................................................................................................................... 73

 

6.2

 

Description of equipment ...................................................................................................................... 73

 

6.3

 

Commissioning Tests............................................................................................................................ 73

 

6.3.1

 

Check of connections.............................................................................................................. 73

 

6.3.2

 

Secondary wiring insulation resistance tests........................................................................... 74

 

6.3.3

 

Pilot tests ................................................................................................................................ 74

 

6.3.4

 

C.T. ratio and polarity.............................................................................................................. 74

 

6.3.5

 

Overall fault setting tests......................................................................................................... 74

 

6.3.6

 

Check of pilots supervision receive relay ................................................................................ 74

 

6.3.7

 

Test of guard relays (where fitted) .......................................................................................... 74

 

6.3.8

 

Test of pilot supervision supply failure relay (where fitted)...................................................... 75

 

6.3.9

 

Overall tests of pilot supervision equipment............................................................................ 75

 

6.3.10

 

Stability tests........................................................................................................................... 76

 

6.3.11

 

Putting into service.................................................................................................................. 76

 

6.3.12

 

Notes ...................................................................................................................................... 76

 

 
 
 
 

Summary of Contents for Solkor 7PG2113

Page 1: ...Answers for energy 7PG2113 4 5 6 Solkor Feeder Protection Reyrolle Protection Devices ...

Page 2: ...ed nor shall any model or article be reproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is discl...

Page 3: ...e be reproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection De...

Page 4: ...onal Control of Derived Earth Fault Protection 67N 7PG2114 6 41 4 2 2 Instantaneous Derived Earth Fault Protection 50N 42 4 2 3 Time Delayed Derived Earth Fault Protection 51N 43 4 3 Current Protection Measured Earth Fault 67G 51G 50G 45 4 3 1 Directional Control of Measured Earth Fault Protection 67G 7PG2114 6 45 4 3 2 Instantaneous Measured Earth Fault Protection 50G 46 4 3 3 Time Delayed Measur...

Page 5: ...sh Restraint 81HBL2 phase elements only 76 6 7 Demand 76 Section 7 Other Features 77 7 1 Data Communications 77 7 2 CB Maintenance 77 7 2 1 Output Matrix Test 77 7 2 2 CB Counters 77 7 2 3 I2t CB Wear 77 7 3 Data Storage 78 7 3 1 General 78 7 3 2 Event Records 78 7 3 3 Waveform Records 78 7 3 4 Fault Records 78 7 4 Metering 79 7 5 Operating Mode 79 7 6 Control Mode 79 7 7 Real Time Clock 80 7 7 1 ...

Page 6: ...ative half cycle 31 Figure 3 2 9 Internal fault Rf mode positive half cycle 32 Figure 3 2 10 Internal fault Rf mode negative half cycle 32 Figure 3 2 11 Single End Fed fault Rf mode positive half cycle 33 Figure 3 2 12 Single End Fed fault Rf mode negative half cycle 33 Figure 4 1 1 Logic Diagram Directional Overcurrent Element 67 36 Figure 4 1 2 Logic Diagram Instantaneous Over current Element 37...

Page 7: ...T Supervision Function 60CTS 7PG2114 6 74 Figure 6 4 1 Logic Diagram Broken Conductor Function 46BC 74 Figure 6 5 1 Logic Diagram Trip Circuit Supervision Feature 74TCS 75 Figure 6 5 2 Logic Diagram Close Circuit Supervision Feature 74CCS 75 Figure 6 6 1 Functional Diagram for Harmonic Block Feature 81HBL2 76 List of Tables Table 1 1 7PG2113 5 Ordering Options 7 Table 1 2 7PG2114 6 Ordering Option...

Page 8: ...afety Precautions 1 1 1 Current Transformer Circuits The secondary circuit of a live CT must not be open circuited Non observance of this precaution can result in injury to personnel or damage to equipment 1 1 2 External Resistors Where external resistors are connected to the relay circuitry these may present a danger of electric shock or burns if touched 1 1 3 Front Cover The front cover provides...

Page 9: ... RS485 rear port 1 Protocol 12 IEC 60870 5 103 Modbus RTU and DNP3 user selectable setting 2 Spare 13 1 Protection Function Packages 14 For future development A For future development B Standard version included in all models C 37 Undercurrent 46BC Broken conductor load unbalance 46NPS Negative phase sequence overcurrent 49 Thermal overload 50BF Circuit breaker fail 50G 50N Instantaneous earth fau...

Page 10: ...7PG2113 4 5 6 Solkor Description of Operation Figure 1 1 1 Functional Diagram of 7PG2113 5 Relay with Autoreclose 2010 Siemens Protection Devices Limited Chapter 1 Page 8 of 80 ...

Page 11: ...7PG2113 4 5 6 Solkor Description of Operation Figure 1 1 2 Connections Diagram for 7PG2113 Relay 2010 Siemens Protection Devices Limited Chapter 1 Page 9 of 80 ...

Page 12: ...7PG2113 4 5 6 Solkor Description of Operation Figure 1 1 3 Connections Diagram for 7PG2115 Relay 2010 Siemens Protection Devices Limited Chapter 1 Page 10 of 80 ...

Page 13: ...tection Function Packages 14 For future development A For future development B Standard version included in all models C 27 59 Under Over Voltage 37 Undercurrent 46BC Broken conductor load unbalance 46NPS Negative phase sequence overcurrent 47 Negative phase sequence voltage 49 Thermal overload 50BF Circuit breaker fail 51V Voltage Controlled Overcurrent 59N Neutral voltage displacement 60CTS CT S...

Page 14: ...0 CTS 60 VTS I4 NOTE The use of some functions are mutually exclusive 67 50 x4 67 51 x4 67 50N x4 67 50 x4 67 50 x4 67 51 x4 67 51 x4 67 51N x4 67 50G x4 67 51G x4 27 59 x4 27 59 x4 27 59 x4 59N x2 50 BF 47 51V 51V 51V 79 74 CCS x3 74 TCS x3 64H 51c 86 81H BL2 81H BL2 37 Figure 1 1 4 Functional Diagram of 7PG2114 6 Relay with Autoreclose 2010 Siemens Protection Devices Limited Chapter 1 Page 12 of...

Page 15: ...7PG2113 4 5 6 Solkor Description of Operation 2010 Siemens Protection Devices Limited Chapter 1 Page 13 of 80 Figure 1 1 5 Connections Diagram for 7PG2114 Relay ...

Page 16: ...7PG2113 4 5 6 Solkor Description of Operation Figure 1 1 6 Connections Diagram for 7PG2116 Relay 2010 Siemens Protection Devices Limited Chapter 1 Page 14 of 80 ...

Page 17: ...ipping via pilot cores available The structure of the numeric guard module is based upon the Reyrolle Compact hardware platform The combined relay is supplied in a size E10 case where 1 x E width of approx 26mm The hardware design provides commonality between products and components across the Reyrolle Compact range of relays Table 1 3 Summary of Compact Relay Configurations Relay Current Inputs V...

Page 18: ...relay modules remove the front cover by rotating the six securing pins and withdraw using the module handles The relay modules should not be carried using these handles Figure 2 2 1 Relay shown withdrawn The rear terminal blocks comprise M4 female terminals for wire connections Each terminal can accept two 4mm crimps Figure 2 2 2 Rear view of 7PG2113 4 5 6 Relay Located at the top rear of the case...

Page 19: ...event of the supply voltage level falling below the relay minimum operate level the PSU will automatically switch itself off and latch out this prevents any PSU overload conditions occurring The PSU is reset by switching the auxiliary supply off and on 2 5 Operator Interface Fascia The operator interface is designed to provide a user friendly method of controlling entering settings and retrieving ...

Page 20: ...these provide the following information 1 Product Information Rating Label containing MLFB ordering code Nominal current rating Rated frequency Voltage rating Auxiliary supply rating Binary input supply rating Serial number 2 Purpose inscription label marked Solkor Figure 2 5 2 Close up of typical relay labels A template is available in Reydisp Software to allow users to create and print customise...

Page 21: ... display is completely de activated Pressing any key will re activate the display The LCD contrast can be adjusted using a flat blade screwdriver to turn the screw located below the contrast symbol Turning the screw clockwise increases the contrast anti clockwise reduces the contrast User defined indentifying text can be programmed into the relay using the System config Relay Identifier setting Th...

Page 22: ...s that are enabled will appear in the menu structure PROTECTION HEALTHY LED This green LED is steadily illuminated to indicate that DC voltage has been applied to the relay power supply and that the relay is operating correctly If the internal relay watchdog detects an internal fault then this LED will continuously flash Indication LEDs Relays have 9 user programmable LED indicators Each LED can b...

Page 23: ...f the relay use either the Fundamental Frequency RMS or the True RMS value of current appropriate to the individual function The waveform recorder samples and displays current input waveforms at 1600Hz 2 7 Voltage Inputs Three voltage inputs are provided on the Analogue Input module of the 7PG2114 6 relays Voltage is sampled at 1600Hz for both 50Hz and 60Hz system frequencies Protection and monito...

Page 24: ...IG BINARY INPUT CONFIG menu Event BI 1 Binary Input 1 1 Inverted Inputs BI 1 inverted BI 1 P U Delay Event BI n Binary Input n 1 BI n inverted BI n P U Delay INPUT CONFIG INPUT MATRIX Or gates Logic signals e g 51 1 Inhibit BI 1 D O Delay BI n D O Delay INPUT CONFIG BINARY INPUT CONFIG Figure 2 8 1 Binary Input Logic 2 9 Binary Outputs Output Relays The Solkor R Rf module provides 3 segregated vol...

Page 25: ...perated until current flow is interrupted by an upstream device When the current is removed the relay will then reset and attempt to interrupt trip coil current flowing via its output contact Where this current level is above the break rating of the output contact an auxiliary relay with heavy duty contacts should be utilised in the primary system to avoid damage to the relay Notes on Hand Reset O...

Page 26: ...is will result in de energisation of any binary output mapped to protection healthy and flashing of the protection healthy LED If a successful reset is achieved by the relay the LED and output contact will revert back to normal operational mode and the relay will restart 2 11 1 Protection Healthy Defective When the relay has an auxiliary DC supply and it has successfully passed its self checking p...

Page 27: ...o the relay on the rear terminal block to use the relay in Solkor R mode In addition to the basic components there are at each end three non linear resistors a tapped padding resistor and three diodes The non linear resistors are used to limit the voltage appearing across the pilots and the operating element The purpose of the padding resistors at each end is to bring the total pilot loop resistan...

Page 28: ...y external connections to the relay are those to the current transformers the pilots and the tripping and alarm circuits the installation and commissioning of the equipment is extremely simple To check the current in the operating element a test point is provided The 15kV arrangement is for applications where the voltage across the pilot insulation due to induction or a rise in station earth poten...

Page 29: ... to give an optimum balance between the demands of fault setting and stability The pilot is shown as a lumped resistor RP The rest of the pilot loop is made up of four resistors Ra and four diodes D1 D2 D5 and D6 The operating elements which are made unidirectional by diodes D3 D4 D7 and D8 are connected in shunt with the pilots During an external fault condition an alternating current circulates ...

Page 30: ... 500 ohm padding resistor in each relay and the 1000ohm sum in the pilot circuit is in one leg of the pilot circuit as shown RP Resistors Ra are of greater resistance than the pilot loop resistance Rp and this causes the point of zero potential to occur within the resistors Ra as shown in Figure 3 2 1 The voltage across each relaying point B X and C Y throughout the cycle is now always negative Th...

Page 31: ...gative half cycle At the other limiting condition the pilot resistance is a 1000 ohms loop and the circuit will be as shown in Figure 3 2 3 Figure 3 2 4 with 500 ohms in each leg of the pilot circuit and zero padding resistors As shown in Figure 3 2 3 Figure 3 2 4 the resultant voltage distribution of this maximum pilot arrangement gives identical voltages across the relay points B X and C Y 2010 ...

Page 32: ...nsidering now the equivalent Solkor Rf circuit with 1000 ohms in each leg of the pilots as shown in Figure 3 2 5 the voltage distribution shows that the bias voltage across the polarising diodes D3 D4 D7 and D8 with this arrangement are effectively identical with the minimum values obtained in the Solkor R arrangement In other words the balance of the full wave comparison gives the same value of b...

Page 33: ...e half cycle If the condition of zero pilots is then considered for Solkor Rf i e with 1000 ohms padding in each relay the circuit and voltage distribution are as shown in Figure 3 2 7 Figure 3 2 8 This shows that the same bias voltages are as obtained in Figure 3 2 5 Figure 3 2 6 2010 Siemens Protection Devices Limited Chapter 1 Page 31 of 80 ...

Page 34: ... shown in Figure 3 2 9 Figure 3 2 10 because the diodes in series with the pilots on the positive leg of the circuit will be out of circuit and the measuring element polarising diodes on this leg will be conducting The voltage distribution fore this arrangement shows how with the assumed balanced infeeds no current flows in the pilots and each measuring element is energised via the resistor Ra The...

Page 35: ...end fed internal fault but only one summation transformer has any output Thus the other summation transformer acts only as an equalising transformer re circulating current through the measuring element as indicated in Figure 3 2 11 Figure 3 2 12 The voltage distribution shows diagrammatically how in each half cycle the measuring elements are energised via Ra at the energised end and the action of ...

Page 36: ... transformer it can also be used to reduce the burden imposed by the pilot circuit on the current transformers by changing the impedance levels In addition it provides isolation between the current transformers and the pilot circuit and makes it possible to have the current transformers earthed and the pilots unearthed Fault Type Effective Primary Ampere turns Relative Output A N I nx x x Ix n 2 n...

Page 37: ... the directional detector gives maximum sensitivity in the forward operate zone when the current is in phase with it The reverse operate zone is the mirror image of the forward zone Voltage polarisation is achieved for the phase fault elements using the quadrature voltage i e at unity power factor I leads V by 90 Each phase current is compared to the voltage between the other two phases IL1 V23 IL...

Page 38: ...ing voltage is below this level no directional control signal is given and operation of protection elements set as directional will be inhibited This prevents mal operation under fuse failure MCB tripped conditions where noise voltages can be present Figure 4 1 1 Logic Diagram Directional Overcurrent Element 67 2010 Siemens Protection Devices Limited Chapter 1 Page 36 of 80 ...

Page 39: ...tion can be set using 50 n Dir Control setting Directional logic is provided independently for each 50 n element e g giving the option of using two elements set to forward and two to reverse Operation of the instantaneous overcurrent elements can be inhibited from Inhibit 50 n A binary or virtual input 79 P F Inst Trips 50 n When delayed trips only are allowed in the auto reclose sequence 79 P F P...

Page 40: ...nce Specification The 51 n Reset setting can apply a definite time delayed reset or when configured as an ANSI characteristic an ANSI DECAYING reset If ANSI DECAYING reset is selected for an IEC characteristic the reset will be instantaneous The reset mode is significant where the characteristic has reset before issuing a trip output see Applications Guide A minimum operate time for the characteri...

Page 41: ... Fwd IL3 Rev 1 1 1 Non Dir 51 n VTS Action Off Inhibit VT Fail 51 n Min Operate Time IL1 IL2 IL3 50 51 Measurement See Voltage Controlled Overcurrent 51V L1 81HBL2 51c 51 n Inrush Action Off Inhibit L3 L2 L1 L2 81HBL2 L3 81HBL2 c Pickup trip c Pickup trip c Pickup trip Inhibit 51 n 51 n Element Enabled Disabled 79 P F Inst Trips 51 n 79 P F Prot n Trip n Delayed AUTORECLOSE Figure 4 1 3 Logic Diag...

Page 42: ... a multiplier 51 n Multiplier is applied to reduce the 51 n pickup current setting 51 n Multiplier is applied to each phase independently when its control phase phase voltage falls below VCO Setting The voltage levels used for each phase over current element are shown in the table below Relays with a Ph N connection automatically calculate the correct Ph Ph control voltage Current Element Control ...

Page 43: ...ional earth fault elements can use either zero phase sequence ZPS or negative phase sequence NPS polarising This is selected using the 67N Polarising Quantity setting Whenever a zero sequence voltage is available a five limb VT that can provide a zero sequence path or an open delta VT connection the earth fault element can use zero sequence voltage and current for polarisation If zero sequence pol...

Page 44: ...n the 7PG2114 6 relay 50N 1 50N 2 50N 3 50N 4 7PG2114 6 Each instantaneous element has independent settings for pick up current 50N n Setting and a follower time delay 50N n Delay The instantaneous elements have transient free operation Where directional elements are present the direction of operation can be set using 50N n Dir Control setting Directional logic is provided independently for each 5...

Page 45: ...when configured as an ANSI characteristic an ANSI DECAYING reset If ANSI DECAYING reset is selected for an IEC characteristic the reset will be instantaneous The reset mode is significant where the characteristic has reset before issuing a trip output see Applications Guide A minimum operate time for the characteristic can be set using the 51N n Min Operate Time setting A fixed additional operate ...

Page 46: ...7PG2113 4 5 6 Solkor Description of Operation Figure 4 2 3 Logic Diagram Derived Time Delayed Earth Fault Protection 2010 Siemens Protection Devices Limited Chapter 1 Page 44 of 80 ...

Page 47: ...ch that the directional detector gives maximum sensitivity in the forward operate zone when the current is in phase with it The reverse operate zone is the mirror image of the forward zone The measured directional earth fault elements use zero phase sequence ZPS polarising Voltage polarisation is achieved for the earth fault elements by comparison of the appropriate current with its equivalent vol...

Page 48: ...tion can be set using 50G n Dir Control setting Directional logic is provided independently for each 50G n element e g giving the option of using two elements set to forward and two to reverse Operation of the instantaneous measured earth fault elements can be inhibited from Inhibit 50G n A binary or virtual input 79 E F Inst Trips 50G n When delayed trips only are allowed in the auto reclose sequ...

Page 49: ...reset or when configured as an ANSI characteristic an ANSI DECAYING reset If ANSI DECAYING reset is selected for an IEC characteristic the reset will be instantaneous The reset mode is significant where the characteristic has reset before issuing a trip output see Applications Guide A minimum operate time for the characteristic can be set using 51G n Min Operate Time setting A fixed additional ope...

Page 50: ...7PG2113 4 5 6 Solkor Description of Operation Figure 4 3 3 Logic Diagram Measured Time Delayed Earth Fault Element 51G 2010 Siemens Protection Devices Limited Chapter 1 Page 48 of 80 ...

Page 51: ...must be connected in series with this input to ensure that this element provides a high impedance path 64H Current Setting sets the pick up current level An output is given after elapse of the 64H Delay setting External components a series stabilising resistor and a non linear resistor are used with this function See Applications Guide for advice in specifying suitable component values Operation o...

Page 52: ...elevant 51 n settings Where the Reduced Current setting is set to OFF reversion to 51 n settings will only occur at the end of the Drop Off Time If any element is picked up on expiry of Drop Off Time the relay will issue a trip and lockout if a recloser is present If the circuit breaker is re opened before expiry of the Drop Off Time the drop off timer is held but not reset Resetting the timer for...

Page 53: ... IEC and ANSI curves using 46IT Char A time multiplier is applied to the characteristic curves using the 46IT Time Mult setting Alternatively a definite time lag delay DTL can be chosen using 46ITChar When Definite Time Lag DTL is selected the time multiplier is not applied and the 46IT Delay DTL setting is used instead The 46IT Reset setting can apply a definite time delayed or ANSI DECAYING rese...

Page 54: ...ting sets the pick up current An output is given after elapse of the 37 n Delay setting Operation of the under current elements can be inhibited from Inhibit 37 n A binary or virtual input 1 c Figure 4 7 1 Logic Diagram Relays with 4 Current Inputs Undercurrent Detector 37 Figure 4 7 2 Logic Diagram Relays with 1 Current Inputs Undercurrent Detector 37 2010 Siemens Protection Devices Limited Chapt...

Page 55: ...ically the same as In k IB 49 Overload Setting Iθ Additionally an alarm can be given if the thermal state of the system exceeds a specified percentage of the protected equipment s thermal capacity 49 Capacity Alarm setting For the heating curve 100 e 1 I I θ τ t 2 θ 2 Where θ thermal state at time t I measured thermal current Iθ 49 Overload setting or k IB The final steady state thermal condition ...

Page 56: ... be inhibited from Inhibit 49 A binary or virtual input IL1 49 Alarm 49 Trip 49 Time Constant 49 Capacity Alarm 49 Overload Setting c cap alarm trip IL2 IL3 cap alarm trip cap alarm trip Inhibit 49 49 Therm Overload Enabled Disabled 1 1 Figure 4 7 3 Logic Diagram Thermal Overload Protection 49S 2010 Siemens Protection Devices Limited Chapter 1 Page 54 of 80 ...

Page 57: ...he sense of the element undervoltage or overvoltage is set by the 27 59 n Operation setting The 27 59 n O P Phases setting determines whether the time delay is initiated for operation of any phase or only when all phases have detected the appropriate voltage condition An output is given after elapse of the 27 59 n Delay setting The 27 59 n Hysteresis setting allows the user to vary the pick up dro...

Page 58: ...pick up voltage level for the element The 47 n Hysteresis setting allows the user to vary the pick up drop off ratio for the element An output is given after elapse of the 47 n Delay setting Operation of the negative phase sequence voltage elements can be inhibited from Inhibit 47 n A binary or virtual input Inhibit 47 n 47 n Element Enabled Disabled 47 n 47 n Delay c 47 n Hysteresis 47 n Setting ...

Page 59: ...sen using 59NITChar When Delay DTL is selected the time multiplier is not applied and the 59NIT Delay DTL setting is used instead An instantaneous or definite time delayed reset can be applied using the 59NIT Reset setting The 59NDT element has a DTL characteristic 59NDT Setting sets the pick up voltage 3V0 and 59NDT Delay the follower time delay Operation of the neutral overvoltage elements can b...

Page 60: ...Service Knowledge of the CB position status is integral to the auto reclose functionality CB auxiliary switches must be connected to CB Closed and CB Open binary inputs A circuit breaker s service status is determined by its position i e from the binary inputs programmed CB Open and CB Closed The circuit breaker is defined as being in service when it is closed The circuit memory functionality prev...

Page 61: ...79 Out edge triggered 79 In level detected CB Closed CB Open 79 Ext Trip 79 Ext Pickup 79 Block Reclose Block Close CB Close CB Open CB 79 Trip Reclose 79 Trip Lockout 79 Line Check 79 Reset Lockout 79 Lockout Hot Line In Hot Line Out Outputs Outputs are fully programmable to either binary outputs or LEDs Programmable outputs include 79 Out Of Service 79 In Service 79 In Progress 79 AR Close CB Ma...

Page 62: ... of Protection and associated Dead time for that fault type at that point in the sequence A typical sequence would consist of two Inst trips followed by at least one Delayed trip This sequence enables transient faults to be cleared quickly by the Inst trip s and permanent fault to be cleared by the combined Delayed trip The delayed trip must be graded with other Recloser CB s to ensure system disc...

Page 63: ...ckout 79 Sequence Fail Timer Sets the time that AutoReclose start can be primed Where this time expires before all the DAR start signals are not received i e the CB has opened protection pickups have reset and the trip relay has reset the Relay goes to Lockout 79 Minimum LO Delay Sets the time that the Relay s Lockout condition is maintained After the last allowed Trip operation in a specific sequ...

Page 64: ...ollowing will reset lockout By a Manual Close command from fascia comms or Close CB binary input By a 79 Reset Lockout binary input provided there is no signal present that will cause Lockout At the end of the 79 Minimum LO Delay time setting if 79 Reset LO by Timer is selected to ENABLED provided there is no signal present which will cause Lockout Where Lockout was entered by an A R Out signal du...

Page 65: ...can be set to either Inst or Delayed 79 P F HighSet Trips to Lockout Sets the number of allowed HighSet trips The relay will go to Lockout on the last HighSet Trip This function can be used to limit the duration and number of high current trips that the Circuit Breaker is required to perform if the fault is permanent and close to the Circuit Breaker then there is no point in forcing a number of De...

Page 66: ...otection s fourth Trip Output 79 P F Deadtime 4 Sets the fourth Reclose Delay Deadtime in the External sequence 79 P F Prot n Trip5 Not Blocked Blocked Blocked raises an output which can be mapped to a Binary output to Block an External Protection s fifth Trip Output 79 P F Extern Trips to Lockout Sets the number of allowed External protection trips Relay will go to Lockout on the last Trip These ...

Page 67: ...7PG2113 4 5 6 Solkor Description of Operation Figure 5 1 2 Basic Auto Reclose Sequence Diagram 2010 Siemens Protection Devices Limited Chapter 1 Page 65 of 80 ...

Page 68: ...ntrols for closing and tripping can be latched i e until confirmation that the action has been completed i e binary input is edge triggered when latched Close CB Delay The Close CB Delay is applicable to manual CB close commands received through a Close CB binary input or via the Control Menu Operation of the 79 MC Close CB binary output is delayed by the Close CB Delay setting Close CB Pulse The ...

Page 69: ... or via the Control Menu Operation of the Open CB binary output is delayed by the Open CB Delay setting Open CB Pulse The duration of the CB open Command pulse is user settable to allow a range of CBs to be used CB Failed To Open is taken from the Circuit Breaker Failure Element CB Travel Alarm DBI The CB Open CB Closed binary inputs are monitored The relay goes to Lockout and an output can be giv...

Page 70: ...1 F1 O2 L1 Equation 1 Binary Input 1 XOR Function Key 1 AND NOT Binary Output 2 OR LED 1 When the equation is satisfied 1 it is routed through a pick up timer En Pickup Delay a drop off timer En Dropoff Delay and a counter which instantaneously picks up and increments towards its target En Counter Target The counter will either maintain its count value En Counter Reset Mode OFF or reset after a ti...

Page 71: ...conditions are removed when En is instantaneously reset The output of En is assigned in the OUTPUT CONFIG OUTPUT MATRIX menu where it can be programmed to any binary output O LED L or Virtual Input Output V combination Protection functions can be used in Quick Logic by mapping them to a Virtual Input Output Refer to Section 7 Applications Guide for examples of Logic schemes 2010 Siemens Protection...

Page 72: ...p MENU INPUT CONFIG INPUT MATRIX 50BF Mech Trip CB Fail outputs will be issued providing any of the 3 phase currents are above the 50BF Setting or the current in the fourth CT is above 50BF I4 for longer than the 50BF n Delay setting or for a mechanical protection trip the circuit breaker is still closed when the 50BF n Delay setting has expired indicating that the fault has not been cleared Both ...

Page 73: ... conditions rated PPS voltage would be expected along with a PPS load current within the circuit rating Where PPS load current is detected without corresponding PPS voltage this could indicate a three phase VT failure To ensure these conditions are not caused by a 3 phase fault the PPS current must also be below the fault level The element has a 60VTS VPPS setting an 60VTS IPPS Load setting and a ...

Page 74: ...7PG2113 4 5 6 Solkor Description of Operation Figure 6 2 1 Logic Diagram VT Supervision Function 60VTS 2010 Siemens Protection Devices Limited Chapter 1 Page 72 of 80 ...

Page 75: ...nhibited from Inhibit 60CTS A binary or virtual input Figure 6 3 1 Logic Diagram CT Supervision Function 60CTS 7PG2113 5 6 3 2 60CTS 7PG2114 6 Normally the presence of negative phase sequence NPS current in a power system is accompanied by NPS voltage The presence of NPS current without NPS voltage is used to indicate a current transformer failure The element has a setting for NPS current level 60...

Page 76: ... calculates the ratio of NPS to PPS currents Where the NPS PPS current ratio is above 46BC Setting an output is given after the 46BC Delay The Broken Conductor function can be inhibited from Inhibit 46BC A binary or virtual input Figure 6 4 1 Logic Diagram Broken Conductor Function 46BC 2010 Siemens Protection Devices Limited Chapter 1 Page 74 of 80 ...

Page 77: ...eak in the trip circuit wiring or loss of supply an output is given The 74TCS n Delay setting prevents failure being incorrectly indicated during circuit breaker operation This delay should be greater than the operating time of the circuit breaker The use of one or two binary inputs mapped to the same Trip Circuit Supervision element e g 74TCS n allows the user to realise several alternative monit...

Page 78: ...en set as ENABLED configures the Demand Log Update Period see below equal to the DATA STORAGE Data Log Period setting The Gn Demand Log Update Period setting is used to define the time duration after which the instrument is updated The updated value indicates the maximum minimum and mean values for the defined period Note that this setting can be over ridden by the Gn Demand Log Time Sync setting ...

Page 79: ... Matrix Test 7 2 2 CB Counters The following CB maintenance counters are provided CB Total Trip Count Increments on each trip command issued CB Delta Trip Count Additional counter which can be reset independently of the Total Trip Counter This can be used for example for recording trip operations between visits to a substation CB Count to AR Block Displays the number of CB trips experienced by the...

Page 80: ... relay operations from the relay fascia from a suitably programmed binary input or via the data comms channel s The stored analogue and digital waveforms illustrate the system and relay conditions at the time of trigger In total the relay provides 10 seconds of waveform storage this is user selectable to 1 x 10second 2 x 5 second 5 x 2 second or 10 x 1 second records When the waveform recorder buf...

Page 81: ...ting a Binary Input or Command Table 7 2 Operating Modes OPERATION REMOTE MODE LOCAL MODE SERVICE MODE Control Rear Ports Enabled Disabled Disabled Fascia Control Mode Disabled Enabled Disabled USB Disabled Enabled Disabled Binary Inputs Setting Option Setting Option Enabled Binary Outputs Enabled Enabled Disabled Reporting Spontaneous IEC Enabled Enabled Disabled DNP Enabled Enabled Disabled Gene...

Page 82: ...identified Where settings are group dependent this is indicated on the top line of the LCD by both the Active Group No and the View Group No being displayed A change of settings group can be achieved either locally at the relay fascia remotely over the data comms channel s or via a binary input When using a binary input an alternative settings group is selected only whilst the input is energised S...

Page 83: ... nor shall any model or article be reproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclai...

Page 84: ...1 Front USB connection 17 2 1 2 Rear RS485 connection 18 2 1 3 Configuring Relay Data Communication 18 2 1 4 Connecting to the Relay for setting via Reydisp 19 2 1 5 Configuring the user texts using Reydisp Language Editor 19 List of Figures Figure 1 1 1 Fascia Links 3 Figure 1 2 1 Menu 4 Figure 1 2 2 Fascia Contrast symbol 4 Figure 1 2 3 Fascia of a 7PG2113 4 5 6 relay 5 Figure 2 1 1 USB connecti...

Page 85: ...1 1 3 Test Link The test facility provided on the relay fascia can be shorted by a similar link to that used for Pilot Resistance settings but black in colour This link can be removed during testing but should be fitted to set the relay for normal operation 1 1 4 Pilot Supervision There are no variable settings associated with the Pilot Supervision system 1 2 Relay Menus And Display All relay fasc...

Page 86: ...ure when the relay is using the default files The user can programme the relay to use alternative text descriptions by installing user language files through the Reydisp Evolution software language configuration tool see 2 1 5 LCD Contrast To change the contrast on the LCD insert a flat bladed screwdriver into the screwhead below the contrast symbol turning the screwhead left anti clockwase lighte...

Page 87: ...7PG2113 4 5 6 Solkor Settings Figure 1 2 4 Fascia of a 7PG2113 4 5 6 relay 2010 Siemens Protection Devices Limited Chapter 2 Page 5 of 21 ...

Page 88: ...ata and to reset the output relays and LED s The five push buttons have the following functions READ DOWN READ UP Used to navigate the menu structure ENTER The ENTER push button is used to initiate and accept setting changes When a setting is displayed pressing the ENTER key will enter the edit mode the setting will flash and can now be changed using the or buttons When the required value is displ...

Page 89: ...olkor Settings Figure 1 3 2 Menu Structure 1 4 Setting Mode The Settings Mode is reached by pressing the READ DOWN button from the relay identifier screen 2010 Siemens Protection Devices Limited Chapter 2 Page 7 of 21 ...

Page 90: ...d on the screen the ENTER button can be pressed to edit the setting value If the relay is setting password protected the user will be asked to enter the password If an incorrect password is entered editing will not be permitted All screens can be viewed if the password is not known While a setting is being edited flashing characters indicate the edit field Pressing the or buttons will scroll throu...

Page 91: ...add this to the FAVOURITE METERS Sub menu To remove a meter from the FAVOURITE METERS sub menu go to that meter each in the FAVOURITE METERS sub menu or at its Primary location press ENTER and the message Remove From Favourites will appear press ENTER again and this meter will be removed from the FAVOURITE METERS sub group Current Meters to view This is the sub group that includes all the meters t...

Page 92: ...iew This is the sub group that includes all the meters that are associated with Voltage TEST RESET allows access to this sub group Prim Ph Ph Voltage Vab 0 00kV Vbc 0 00kV Vca 0 00kV This meter displays the Primary RMS Phase to Phase Voltage The value displayed will automatically adjust between V and kV Sec Ph Ph Voltage Vab 0 00V o Vbc 0 00V o Vca 0 00V o This meter displays the Secondary RMS Pha...

Page 93: ...voltage both primary and secondary which also shows the secondary angle POWER METERS to view This is the sub group that includes all the meters that are associated with Power TEST RESET allows access to this sub group Phase A 0 0MW Phase B 0 0MW Phase C 0 0MW P 3P 0 0MW Displays Real Power The value displayed will automatically adjust between W and MW Phase A 0 0MVAr Phase B 0 0MVAr Phase C 0 0MVA...

Page 94: ... Fwd PhA Rev PhB Fwd PhB Rev PhC Fwd PhC Rev Calc E F Dir 67N No Dir E F Fwd E F Rev Meas E F Dir 67G No Dir E F Fwd E F Rev THERMAL METERS to view This is the sub group that includes all the meters that are associated with Thermal TEST RESET allows access to this sub group Thermal Status Phase A 0 0 Phase B 0 0 Phase C 0 0 AUTORECLOSE METERS to view This is the sub group that includes all the met...

Page 95: ...his meter shows the number of CB Operations CB Wear Phase A 0 00MA 2s Phase B 0 00MA 2s Phase C 0 00MA 2s CB Trip Time 0 0ms GENERAL ALARM METERS to view Alarm 1 Raised Cleared The general alarm description set in the relay for each alarm will be displayed Alarm 2 Raised Cleared Alarm 3 Raised Cleared Alarm 4 Raised Cleared Alarm 5 Raised Cleared Alarm 6 Raised Cleared DEMAND METERS to view This i...

Page 96: ...ax 0 00A Min 0 00A Mean 0 00A I Phase C Demand Max 0 00A Min 0 00A Mean 0 00A V Phase A Demand Max 0 00V Min 0 00V Mean 0 00V V Phase B Demand Max 0 00V Min 0 00V Mean 0 00V V Phase C Demand Max 0 00V Min 0 00V Mean 0 00V V Phase AB Demand Max 0 00V Min 0 00V Mean 0 00V V Phase BC Demand Max 0 00V Min 0 00V Mean 0 00V V Phase CA Demand Max 0 00V Min 0 00V ...

Page 97: ...puts 1 to 6 The number of binary inputs may vary depending on model BINARY OUTPUT METERS to view This is the sub group that includes all the meters that are associated with the Binary Outputs TEST RESET allows access to this sub group BO 1 8 Displays the state of DC binary Outputs 1 to 8 The number of binary outputs may vary depending on model VIRTUAL METERS to view This is the sub group that show...

Page 98: ...01 2000 Time 22 41 44 Waveform Recs 0 Fault Recs 0 This meter displays the date and time and the number of Fault records and Event records stored in the relay Event Recs 0 1 6 Fault Data Mode The Fault Data Mode sub menu lists the time and date of the previous ten protection operations The stored data about each fault can be viewed by pressing the TEST RESET button Each record contains data on the...

Page 99: ...e This software requires windows 2000 service pack 4 or above or windows XP with service pack 2 or above and Microsoft NET framework for tools 2 1 Physical Connection The relay can be connected to Reydisp via any of the communication ports on the relay Suitable communication Interface cable and converters are required depending which port is being used 2 1 1 Front USB connection To connect your pc...

Page 100: ...ecting the relay to a pc using the front USB port the Reydisp setting software will automatically detect the relay without making any setting changes in the relay first as long as the USB is selected to IEC60870 5 103 When connecting the relay to a pc using the front USB port the Reydisp setting software will automatically detect the relay without making any setting changes in the relay first as l...

Page 101: ... Comm Port Selection The relay settings can now be configured using the Reydisp software Please refer to the Reydisp Evolution Manual for further guidance 2 1 5 Configuring the user texts using Reydisp Language Editor As default the relay uses the text descriptions in all menus as they appear in this manual These descriptions can be changed by installing a user language file in the relay allowing ...

Page 102: ...g the send file to relay function The communication properties in the software and on the relay must be set The relay must be restarted after the file is installed To activate the language file it must be selected in the relay configuration menu the Original file is the file labelled ENGLISH and the new file will be displayed using the file name allocated by the user Care should be taken to ensure...

Page 103: ...7PG2113 4 5 6 Solkor Settings Figure 2 1 5 Language File Editor Setting Texts 2010 Siemens Protection Devices Limited Chapter 2 Page 21 of 21 ...

Page 104: ... reproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Device...

Page 105: ...cal 13 Section 2 Protection Functions 15 2 1 27 59 Under over voltage 15 2 1 1 Reference 15 2 1 2 Operate and Reset Level 15 2 1 3 Operate and Reset Time 15 2 2 37 Undercurrent 15 2 2 1 Reference 15 2 2 2 Operate and Reset Level 15 2 2 3 Operate and Reset Time 16 2 3 46NPS Negative Phase Sequence Overcurrent 16 2 3 1 Reference 46DT 16 2 3 2 Operate and Reset Level 46DT 16 2 3 3 Operate and Reset T...

Page 106: ...te and Reset Time 59NIT 34 2 14 64H Restricted Earth Fault Protection 35 2 14 1 Reference 35 2 14 2 Operate and Reset Level 35 2 14 3 Operate and Reset Time 35 2 15 67 67N Directional Overcurrent Earth Fault 36 2 15 1 Reference 36 2 15 2 Operate Angle 36 2 15 3 Operate Threshold 36 2 15 4 Operate and Reset Time 36 2 16 87L Pilot Wire Current Differential 36 2 16 1 Operate Level 36 2 16 2 Operate T...

Page 107: ...s Figure 1 2 1 Binary Input Configurations Providing Compliance with EATS 48 4 Classes ESI 1 and ESI 2 9 Figure 2 5 1 Thermal Overload Protection Curves 20 Figure 2 9 1 IEC IDMTL Curves Time Multiplier 1 25 Figure 2 9 2 ANSI IDMTL Operate Curves Time Multiplier 1 26 Figure 2 9 3 ANSI Reset Curves Time Multiplier 1 27 ...

Page 108: ... has been tested under the following conditions unless specifically stated otherwise Parameter Value Auxiliary supply nominal Frequency nominal Ambient temperature 20 C 1 1 3 Dimensions Parameter Value Width E10 case 260 mm Height 177 mm Depth behind panel including clearance for wiring and fibre 241 5 mm Projection from front of panel 31 mm See appropriate case outline and panel drilling drawing ...

Page 109: ...and Period 50ms Dip Immunity Acquisition Period 5minutes Typical time after switch on to attain claimed immunity to dips NOTE Dips in supply that fall below the minimum voltage for a period greater than the 0 Dip With stand Period will invoke a relay reset During conditions of auxiliary input voltage variations which are not described 1 in section 1 4 3 1 the relay may enter a safety protection mo...

Page 110: ...1 Burden 1 2 2 2 Thermal Withstand EATS48 5 Overload Current Phase Earth and SEF Overload Period 1A 5A Continuous 2 0 xIn 10 minutes 3 5 xIn 5 minutes 4 0 xIn 3 minutes 5 0 xIn 2 minutes 6 0 xIn 3 seconds 57 7A 202A 2 seconds 70 7A 247A 1 second 100A 350A 1 cycle 700A 2500A 1 2 3 AC Voltage Nominal Operating Range Vn 63 5V 110 V 270 V fn 50 60Hz 47 to 52Hz 57 to 62Hz 1 2 3 1 Burden Attribute Value...

Page 111: ...Inputs EATS48 4 Nominal Operating Range 19 VDC 17 to 320 VDC VBI 88 VDC 74 to 320 VDC 1 2 6 1 Performance Attribute Value VBI 19 V 1 5mA Maximum DC current for operation VBI 88 V 1 5mA Reset Operate voltage ratio 90 Response time 9ms Response time when programmed to energise an output relay contact i e includes output relay operation 20ms The binary inputs have a low minimum operate current and ma...

Page 112: ...PG2113 4 5 6 Performance Specification 2010 Siemens Protection Devices Limited Chapter 3 Page 9 of 42 Figure 1 2 1 Binary Input Configurations Providing Compliance with EATS 48 4 Classes ESI 1 and ESI 2 ...

Page 113: ...ors 4mm Ring Crimp 1 3 4 Real Time Clock 1 3 4 1 Internal Clock The specification below applies only while no external synchronisation signal e g 60870 5 103 is being received Attribute Value Accuracy 10 to 55 o C 3 5 p p m 1 4 Current Differential Application Limits 1 4 1 Pilot Cable connection Number of Pilot cores required 2 Pilot Requirements R Mode Rf Mode Rf mode with 15kv Transf Tap 1 Tap 0...

Page 114: ...ype Level Operational test 56 days at 40 C and 93 relative humidity 1 5 1 3 Transient Overvoltage IEC 60255 5 Type Level Between all terminals and earth or between any two independent circuits 5 0 kV 1 2 50 μs 0 5j 1 5 1 4 Insulation IEC 60255 5 Type Level Between any terminal and earth Between independent circuits 2 5 kV AC RMS for 1 min Across normally open contacts 1 0 kV AC RMS for 1 min Betwe...

Page 115: ...t 2 Voltage Dips 70 RV 500ms Normal operation 1 except where Dip falls below the relay minimum voltage then Relay Restart 2 Voltage Interruptions 0 RV 5s Relay Reset 2 Alternating Component In DC Ripple 15 max and min RV Continuous Normal operation1 Max min RV to 0V 60s Relay Reset 0V 5minutes Relay Off Gradual Shut down Start up 0V to min max RV 60s Relay Restart 2 Reversal of DC Power Supply pol...

Page 116: ... 2 0 4 0 kV Between Line to Line 0 5 1 0 2 0 kV 1 5 3 7 Conducted Radio Frequency Interference IEC 60255 22 6 Type Level 0 15 to 80 MHz 10 V 1 5 3 8 Magnetic Field with Power Frequency IEC 6100 4 8 Level 5 100A m 0 126mT continuous 1000A m 1 26mT for 3s 50Hz 1 5 4 Mechanical 1 5 4 1 Vibration Sinusoidal IEC 60255 21 1 Class I Type Level Variation Vibration response 0 5 gn Vibration endurance 1 0 g...

Page 117: ...ification 2010 Siemens Protection Devices Limited Chapter 3 Page 14 of 42 Type Level Variation Y plane 1 5mm displacement below crossover freq 8 9Hz 0 5gn above 1 5 4 4 Mechanical Classification Type Level Durability 10 6 operations ...

Page 118: ... Vop 1 0 25V Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 1 3 Operate and Reset Time Attribute Value 0 to 1 1 x Vs 73 ms 10ms Overvoltage 0 to 2 0 xVs 63 ms 10ms tbasicE Element basic operate time Undervoltage 1 1 to 0 5 xVs 58 ms 10ms top Operate time following delay tbasic td 1 or 10ms Repeatability 1 or 10ms Disengaging time 80 ms 2 2 37 Undercurrent 2 2 1 Reference Param...

Page 119: ...perate and Reset Level 46DT Attribute Value Iop Operate level 100 Is 5 or 1 In Reset level 95 Iop Repeatability 1 Transient overreach X R 100 5 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 3 3 Operate and Reset Time 46DT Attribute Value 0 to 2 xIs 40 ms 10ms tbasic Element basic operate time 0 to 5 xIs 30 ms 10ms top Operate time following delay tbasic td 1 or 10ms Repeatability 1 or 10ms O...

Page 120: ...NI IEC VI IEC EI IEC LTI Tm K t Is I op 1 α 5 absolute or 50 ms for char IEC NI K 0 14 α 0 02 IEC VI K 13 5 α 1 0 IEC EI K 80 0 α 2 0 IEC LTI K 120 0 α 1 0 char ANSI MI ANSI VI ANSI EI Tm B A t P Is I op 1 5 absolute or 50 ms for char ANSI MI A 0 0515 B 0 114 P 0 02 ANSI VI A 19 61 B 0 491 P 2 0 ANSI EI A 28 2 B 0 1217 P 2 0 top Operate time char DTL td 1 or 20ms ANSI DECAYING Tm R t Is I res 1 2 ...

Page 121: ...0 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 4 3 Operate and Reset Time 47 Attribute Value 0V to 2 0 xVs 80 ms 20ms tbasic Element basic operate time 0V to 10 xVs 70ms 20ms top Operate time following delay tbasic td 2 or 20ms Repeatability 1 or 20ms Overshoot time 40 ms Disengaging time 90 ms 2 5 49 Thermal Overload 2 5 1 Reference Parameter Value Is Overload setting 1 0 xIn i Applied Curren...

Page 122: ...rotection Devices Limited Chapter 3 Page 19 of 42 2 5 3 Operate and Reset Time Attribute Value top Overload trip operate time τ 2 2 2 P 2 I I I ln B I k t where IP prior current 5 absolute or 100ms Repeatability 100ms Note Fastest operate time is at 10 xIs ...

Page 123: ...010 Siemens Protection Devices Limited Chapter 3 Page 20 of 42 0 1 1 10 100 1000 10000 100000 0 1 2 3 4 5 6 7 8 9 10 Current multiple of setting Time sec τ 1000 mins τ 100 mins τ 10 mins τ 1 min Figure 2 5 1 Thermal Overload Protection Curves ...

Page 124: ... 3 Hz to fnom 2 Hz 5 2 6 3 Operate and Reset Time Attribute Value 0 to 2 xIs 35 ms 10ms tbasic Element basic operate time 0 to 5 xIs 25 ms 10ms top Operate time following delay tbasic td 1 or 10ms Repeatability 1 or 10ms Overshoot time 40 ms Disengaging time 50 ms 2 7 50G Instantaneous Measured Earth Fault 2 7 1 Reference Parameter Value Is Setting 0 05 0 06 2 5 2 55 25 0 25 5 50 xIn td Delay sett...

Page 125: ...8 1 Reference Parameter Value Is Setting 0 05 0 06 2 5 2 55 25 0 25 5 50 xIn td Delay setting 0 00 0 01 20 00 20 10 100 101 1000 1010 10000 10100 14400 s 2 8 2 Operate and Reset Level Attribute Value Iop Operate level 100 Is 5 or 1 In Reset level 95 Iop Repeatability 1 Transient overreach X R 100 5 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 8 3 Operate and Reset Time Attribute Value 0 to ...

Page 126: ...vel 95 Iop Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 9 3 Operate and Reset Time Attribute Value Starter operate time 2xIs 20 ms 20ms char IEC NI IEC VI IEC EI IEC LTI Tm K t Is I op 1 α 5 absolute or 30 ms for char IEC NI K 0 14 α 0 02 IEC VI K 13 5 α 1 0 IEC EI K 80 0 α 2 0 IEC LTI K 120 0 α 1 0 char ANSI MI ANSI VI ANSI EI Tm B A t P Is I op 1 5 absolute or 30 ms for ch...

Page 127: ... 2 9 1 shows the operate times for the four IEC IDMTL curves with a time multiplier of 1 Figure 2 9 2 and Figure 2 9 3 show the ANSI operate and reset curves These operate times apply to non directional characteristics Where directional control is applied then the directional element operate time should be added to give total maximum operating time ...

Page 128: ...rotection Devices Limited Chapter 3 Page 25 of 42 0 1 1 10 100 1000 1 10 100 Current multiples of setting Time sec 2 3 4 5 6 8 20 30 40 50 60 80 Long Time Inverse Normal Inverse Very Inverse Extremely Inverse Figure 2 9 1 IEC IDMTL Curves Time Multiplier 1 ...

Page 129: ... Protection Devices Limited Chapter 3 Page 26 of 42 0 1 1 10 100 1000 1 10 100 Current multiples of setting Time sec 2 3 4 5 6 8 20 30 40 50 60 80 Moderately Inverse Extremely Inverse Very Inverse Figure 2 9 2 ANSI IDMTL Operate Curves Time Multiplier 1 ...

Page 130: ...ns Protection Devices Limited Chapter 3 Page 27 of 42 1 10 100 1000 0 1 1 Current multiples of setting Time sec Moderately Inverse Extremely Inverse Very Inverse 0 2 0 3 0 4 0 5 0 6 0 8 0 9 0 7 5 50 500 Figure 2 9 3 ANSI Reset Curves Time Multiplier 1 ...

Page 131: ...5 xIn Char Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 1 0 td Delay setting DTL 0 0 01 20 s tres Reset setting ANSI DECAYING 0 1 60 s IDMTL 2 to 20 xIs I Applied current for operate time DTL 5 xIs 2 10 2 Operate and Reset Level Attribute Value Iop Operate level 105 Is 4 or 1 In Reset level 95 Iop Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 ...

Page 132: ... 0 02 ANSI VI A 19 61 B 0 491 P 2 0 ANSI EI A 28 2 B 0 1217 P 2 0 top Operate time char DTL td 1 or 20ms ANSI DECAYING Tm R t Is I res 1 2 5 absolute or 30 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 Reset time tres tres 1 or 20ms Repeatability 1 or 20ms Overshoot time 40 ms Disengaging time 50 ms Figure shows the operate times for the four IEC IDMTL curves with a time multiplier of 1...

Page 133: ...5 xIn char Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 1 0 td Delay setting 0 0 01 20 s tres Reset setting ANSI DECAYING 0 1 60 s IDMTL 2 to 20 x Is I Applied Current for operate time DTL 5 x Is 2 11 2 Operate and Reset Level Attribute Value Iop Operate level 105 Is 4 or 1 In Reset level 95 Iop Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz...

Page 134: ...02 ANSI VI A 19 61 B 0 491 P 2 0 ANSI EI A 28 2 B 0 1217 P 2 0 top Operate time char DTL td 1 or 20ms ANSI DECAYING Tm R t Is I res 1 2 5 absolute or 30 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 Reset time tres tres 1 or 20ms Repeatability 1 or 20ms Overshoot time 40 ms Disengaging time 50 ms Figure 2 10 1 shows the operate times for the four IEC IDMTL curves with a time multiplier ...

Page 135: ...tting 60V m multiplier 0 5 Is Setting 1xIn 2 12 2 Operate and Reset Level Attribute Value Vop Operate level 100 Vs 1 or 0 25V Reset level 105 Vop Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz harmonics to fcutoff 5 Operate and Reset Time As per Phase Fault Shaped Characteristic Element ANSI 51 Where Pickup Level Is for Voltage Vs Pickup Level Is x m for Voltage Vs ...

Page 136: ... to fnom 2 Hz 5 2 13 3 Operate and Reset Time 59NDT Attribute Value 0V to 1 5 xVs 76 ms 20ms tbasic Element basic operate time 0V to 10 xVs 63 ms 20ms top Operate time following delay tbasic td 1 or 20ms Repeatability 1 or 20ms Overshoot time 40 ms Disengaging time 100 ms 2 13 4 Reference 59NIT Parameter Value M Multiplier setting 1 Vs Setting 1 1 5 100V 3Vo Applied Current for Operate Time IDMTL ...

Page 137: ...set Time 59NIT Attribute Value tbasic Starter operate time 65 ms 20ms 3Vo Applied Current for Operate Time DTL 10 x Vs char IDMTL 1 M t Vs 0 V 3 op 5 or 65 ms top Operate time char DTL td 1 or 40ms char IDMTL tres 5 or 65ms Reset Time char DTL tres 1 or 40ms Repeatability 1 or 20ms Overshoot time 40 ms Disengaging time 100 ms ...

Page 138: ...00 10100 14400 s 2 14 2 Operate and Reset Level Attribute Value Iop Operate level 100 Is 5 or 1 xIn Reset level 95 Iop 5 or 0 1 xIn Repeatability 1 Transient overreach X R 100 5 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 2 14 3 Operate and Reset Time Attribute Value 0 to 2 xIs 45 ms 10ms tbasic Element basic operate time 0 to 5 xIs 35 ms 10ms top Operate time following delay tbasic td 1 or ...

Page 139: ...C 5 Variation in characteristic angle fnom 3 Hz to fnom 2 Hz 5 2 15 3 Operate Threshold Attribute Value I p f 5 In I e f 10 In V p f 1 V Minimum levels for operation V e f 1 V 2 15 4 Operate and Reset Time Attribute Value Operate time typically 32 40 ms at characteristic angle element operate time Reset time typically 65 ms at characteristic angle 2 16 87L Pilot Wire Current Differential 2 16 1 Op...

Page 140: ...x fault setting 5x fault setting 10x fault setting R Mode 60ms 45ms 5kV Rf mode 45ms tRfBasic Element typical basic operate time 15kV Rf mode 40ms 2 16 3 Stability Level Parameter Value IStabLimit Maximum Through fault Stability Level 50x In Fault settings In Without isolating transformers With isolating transformers R Mode Rf Mode R Mode Rf Mode Type of fault N1 tap N tap N1 tap N tap N1 tap N ta...

Page 141: ...ng 0 03 04 20 0 20 1 100 101 1000 1010 14400 s 3 1 2 Operate and Reset Level Attribute Value Icurr Operate level 100 Iset 5 Reset level 90 Icurr 5 Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz harmonics to fcutoff 5 3 1 3 Operate and Reset Time Attribute Value tbasic Basic operate time 1x In to 0 A 40 ms Operate time tf tbasic 1 or 20ms Repeatability 1 or 20ms Variation fnom 3 Hz...

Page 142: ...tCBF1 Stage 1 Delay setting 20 25 60000ms tCBF2 Stage 2 Delay setting 20 25 60000ms 3 2 2 Operate and Reset Level Attribute Value Iop Operate level 100 Is 5 or 1 In Ireset Reset level 100 Iop 5 or 1 In Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 3 2 3 Operate and Reset Time Attribute Value Stage 1 tCBF1 1 or 20ms top Stage 2 tCBF2 1 or 20ms Repeatability 1 or 20ms Overshoot 2...

Page 143: ...1000 1010 10000 10100 14400 s Directional Relays have additional VT settings Vthresh Voltage Threshold 7 8 110V 3 3 2 Current Voltage Threshold Attribute Value Iop CT failed current level 100 Ithresh 5 or 1 In Reset level 90 Iop 5 or 1 In Vop CT failed voltage level 100 Vthresh 2 or 0 5V Reset level 110 Vop 2 or 0 5V Repeatability 1 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz harmonics to fcut...

Page 144: ...PSop Voltage NPS operate level 100 Vnps 5 Vn Voltage NPS reset level 90 VNPSop 5 Vn VPPSop Voltage PPS operate level 100 Vpps 5 Vn Voltage PPS reset level 110 VPPSop 5 Vn INPSblk Current NPS operate level 100 Inps 5 xIn Current NPS reset level 90 INPSblk 5 xIn IPPSblk Current PPS operate level 100 IFpps 5 xIn Current PPS reset level 90 IPPSblk 5 xIn IPPSload Current PPS operate level 100 Ipps 5 xI...

Page 145: ...ate time following delay tbasic td 1 or 10ms Repeatability 1 or 10ms 10 C to 55 C 5 Variation fnom 3 Hz to fnom 2 Hz 5 3 6 81HBL2 Inrush Detector 3 6 1 Reference Parameter Value I Setting Ratio of 2nd Harmonic current to Fundamental component current 0 10 0 11 0 5 3 6 2 Operate and Reset Time Attribute Value tbasic Element basic operate time Will pick up before operation of any protection element ...

Page 146: ...eproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Devices ...

Page 147: ...finitions 6 3 1 Introduction 6 Section 4 Modbus Definitions 15 4 1 Introduction 15 Section 5 DNP3 0 Definitions 20 5 1 Device Profile 20 5 2 Implementation Table 23 5 3 Point List 30 5 4 Binary Output Status Points and Control Relay Output Blocks 33 5 5 Analogue Inputs 34 Section 6 Configuration 37 Section 7 Glossary 38 List of Figures Figure 7 1 1 Communication to Front USB Port 4 Figure 1 1 2 Co...

Page 148: ...ystem or interrogating computer Appropriate software within the control system or on the interrogating computer e g Reydisp Evolution is required to access the interface This section specifies connection details and lists the events commands and measurands available For further information regarding the IEC60870 5 103 interface reference should be made to the separate Informative Communications In...

Page 149: ...e used simultaneously on both ports SPDL can provide a range of interface devices please refer to product portfolio catalogue Full details of the interface devices can be found by referring to the website www siemens com energy 2 1 Communication ports 2 1 1 USB Interface The USB communication port is connected using a standard USB cable with a type B connection to the relay and type A to the PC Th...

Page 150: ...nge Default Setting Notes Station Address 0 254 IEC60870 5 103 0 247 MODBUS 0 65534 DNP3 0 1 An address must be given to identify the relay Each relay must have a unique address COM1 RS485 Protocol OFF IEC60870 5 103 MODBUS RTU DNP3 0 IEC60870 5 103 As Required Sets the protocol used to communicate on the RS485 connection COM1 RS485 Baud Rate 75 110 150 300 600 1200 2400 4800 9600 19200 38400 1920...

Page 151: ...ace Relay Address A relay with the default address of 0 will not be able to communicate Cause of Transmission The cause of transmission COT column of the Information Number and Function table lists possible causes of transmission for these frames The following abbreviations are used Abbreviation Description SE spontaneous event T test mode GI general interrogation Loc local operation Rem remote op...

Page 152: ...70 6 Binary Input 6 1 SE GI 1 SE GI 80 1 Binary Output 1 20 Ack Nak 1 SE GI 80 2 Binary Output 2 20 Ack Nak 1 SE GI 80 3 Binary Output 3 20 Ack Nak 1 SE GI 80 4 Binary Output 4 20 Ack Nak 1 SE GI 80 5 Binary Output 5 20 Ack Nak 1 SE GI 80 6 Binary Output 6 20 Ack Nak 1 SE GI 80 7 Binary Output 7 20 Ack Nak 1 SE GI 80 8 Binary Output 8 20 Ack Nak 160 2 Reset FCB 5 Reset FCB 160 3 Reset CU 5 Reset C...

Page 153: ...2 SE 160 70 Trip L2 2 SE 160 71 Trip L3 2 SE 160 74 Fault Forward Line 1 SE GI 160 75 Fault Reverse Busbar 1 SE GI 160 84 General Starter Pick Up 1 SE GI 160 85 Circuit breaker fail 2 SE 160 90 Trip I 2 SE 160 91 Trip I 2 SE 160 92 Trip In 2 SE 160 93 Trip In 2 SE 160 128 CB on by auto reclose 1 SE 183 0 Data lost 1 SE 183 10 51 1 2 SE GI 183 11 50 1 2 SE GI 183 12 51N 1 2 SE GI 183 13 50N 1 2 SE ...

Page 154: ...ine 2 SE GI 183 55 SEF Reverse Bus 2 SE GI 183 60 47 1 2 SE GI 183 61 47 2 2 SE GI 183 62 37 1 2 SE GI 183 63 37 2 2 SE GI 183 70 46BC 2 SE GI 183 81 27 59 1 2 SE GI 183 82 27 59 2 2 SE GI 183 83 27 59 3 2 SE GI 183 84 27 59 4 2 SE GI 183 85 59NIT 2 SE GI 183 86 59NDT 2 SE GI 183 101 Trip Circuit Fail 1 1 SE GI 183 102 Trip Circuit Fail 2 1 SE GI 183 103 Trip Circuit Fail 3 1 SE GI 183 114 Close C...

Page 155: ...ent Ops Count 20 Ack Nak 183 140 Cold Load Active 1 SE GI 183 141 P F Inst Protection Inhibited 1 SE 183 142 E F Inst Protection Inhibited 1 SE 183 143 SEF Inst Protection Inhibited 1 SE 183 144 Ext Inst Protection Inhibited 1 SE 183 163 Trip Time Alarm 1 SE 183 164 Close Circuit Fail 1 1 SE 183 165 Close Circuit Fail 2 1 SE 183 166 Close Circuit Fail 3 1 SE 183 167 Close Circuit Fail 1 SE 1 SE GI...

Page 156: ... 2 4 x IL3 2 4 x VL1 1 2 x 7PG2114 6 only VL2 1 2 x 7PG2114 6 only VL3 1 2 x 7PG2114 6 only P 2 4 x 7PG2114 6 only Q 2 4 x 7PG2114 6 only F 1 2 x 7PG2114 6 only 9 Cyclic Refresh rate 5 seconds or value change greater than 1 Disturbance Recorder Actual Channel ACC Numbers Function ACC Number Description 182 0 Global 182 1 Va 7PG2114 6 only 182 2 Vb 7PG2114 6 only 182 3 Vc 7PG2114 6 only 182 4 Not U...

Page 157: ...ecords 60 140 Demand metering reset 70 5 Binary Input 5 70 6 Binary Input 6 80 1 Binary Output 1 80 2 Binary Output 2 80 3 Binary Output 3 80 4 Binary Output 4 80 5 Binary Output 5 80 6 Binary Output 6 80 7 Binary Output 7 80 8 Binary Output 8 183 0 Data Lost 160 2 Reset FCB 160 3 Reset CU 160 4 Start Restart 160 5 Power On 160 16 Auto reclose active 160 19 LED Reset 160 22 Settings changed 160 23...

Page 158: ... 16 51 2 183 17 50 2 183 18 51N 2 183 19 50N 2 183 20 51G 2 183 21 50G 2 183 34 50BF Stage 2 183 35 49 Alarm 183 36 49 Trip 183 40 60 CTS 183 41 183 42 183 43 183 44 183 49 183 50 46IT 183 51 46DT 183 52 64H 183 53 E F Out 183 62 37 1 183 63 37 2 183 70 46BC 183 101 Trip Circuit Fail 1 183 102 Trip Circuit Fail 2 183 103 Trip Circuit Fail 3 183 114 Close CB Failed 183 115 Open CB Failed 183 116 Re...

Page 159: ...79 AR In progress 183 132 CB Frequent Ops Count 183 133 Reset CB Frequent Ops Count 183 140 Cold Load Active 183 141 P F Inst Protection Inhibited 183 142 E F Inst Protection Inhibited 183 143 SEF Inst Protection Inhibited 183 144 Ext Inst Protection Inhibited 183 163 Trip Time Alarm 183 164 Close Circuit Fail 1 183 165 Close Circuit Fail 2 183 166 Close Circuit Fail 3 183 167 Close Circuit Fail 2...

Page 160: ...efinitions with shaded area are not available on all relay models Coils Read Write Binary values Address Description 00001 Binary Output 1 00002 Binary Output 2 00003 Binary Output 3 00004 Binary Output 4 00005 Binary Output 5 00006 Binary Output 6 00007 Binary Output 7 00008 Binary Output 8 00100 LED Reset Write only location 00101 Settings Group 1 00102 Settings Group 2 00103 Settings Group 3 00...

Page 161: ...18 Earth Fault Reverse Busbar 10119 Start Pick Up N 10120 Fault Forward Line 10121 Fault Reverse Busbar 10122 51 1 10123 50 1 10126 51G 1 10127 50G 1 10128 51 2 10129 50 2 10132 51G 2 10133 50G 2 10134 51 3 10135 50 3 10138 51G 3 10139 50G 3 10140 51 4 10141 50 4 10144 51G 4 10145 50G 4 10146 50BF Stage 2 10147 49 Alarm 10148 49 Trip 10149 60 CTS 10150 46IT 10151 46DT 10152 47 1 10153 47 2 10154 4...

Page 162: ...V 30012 Vbc Primary FP_32BITS_3DP 1 Vbc kV 30014 Vca Primary FP_32BITS_3DP 1 Vca kV 30016 Phase A Primary Volt FP_32BITS_3DP 1 Va kV 30018 Phase B Primary Volt FP_32BITS_3DP 1 Vb kV 30020 Phase C Primary Volt FP_32BITS_3DP 1 Vc kV 30022 Phase a Secondary Volt FP_32BITS_3DP 1 Va V 30024 Phase b Secondary Volt FP_32BITS_3DP 1 Vb V 30026 Phase c Secondary Volt FP_32BITS_3DP1 Vc V 30034 Phase ab Nomin...

Page 163: ...DP 1 B Phase MVA 30132 Apparent Power C FP_32BITS_3DP 1 C Phase MVA 30134 3P Apparent Power FP_32BITS_3DP 1 3 Phase MVA 30136 Power Factor A FP_32BITS_3DP 1 Phase A 30138 Power Factor B FP_32BITS_3DP 1 Phase B 30140 Power Factor C FP_32BITS_3DP 1 Phase C 30142 3P Power Factor FP_32BITS_3DP 1 3 Phase 30144 Active Energy Export FP_32BITS_3DP 1 3 Phase MWh 30146 Active Energy Import FP_32BITS_3DP1 3 ...

Page 164: ...tes of information whose format is described below When this record has been read it will be replaced by the next available record Event records must be read completely therefore the quantity value must be set to 8 before reading Failing to do this will result in an exception code 2 If no event record is present the exception code 2 will be returned The event address should be polled regularly by ...

Page 165: ...el Supported For Requests Level 2 For Responses Level 2 Device Function Master 7 Slave Notable objects functions and or qualifiers supported in addition to the Highest DNP Levels Supported the complete list is described in the attached table For static non change event object requests request qualifier codes 07 and 08 limited quantity and 17 and 28 index are supported Static object requests sent w...

Page 166: ...ECT OPERATE Never 7 Always Sometimes Configurable DIRECT OPERATE Never 7 Always Sometimes Configurable DIRECT OPERATE NO ACK Never 7 Always Sometimes Configurable Count 1 7 Never Always Sometimes Configurable Pulse On Never Always 7 Sometimes Configurable Pulse Off Never Always 7 Sometimes Configurable Latch On Never Always 7 Sometimes Configurable Latch Off Never Always 7 Sometimes Configurable Q...

Page 167: ... Table Section 5 2 Sends Multi Fragment Responses 7 Yes No Configurable Sequential File Transfer Support File Transfer Support Yes 7 No Append File Mode Yes 7 No Custom Status Code Strings Yes 7 No Permissions Field Yes 7 No File Events Assigned to Class Yes 7 No File Events Send Immediately Yes 7 No Multiple Blocks in a Fragment Yes 7 No Max Number of Files Open 0 ...

Page 168: ...ble below text shaded as 07 08 limited qty indicates functionality beyond Subset Level 3 OBJECT REQUEST Library will parse RESPONSE Library will respond with Object Number Variation Number Description Function Codes dec Qualifier Codes hex Function Codes dec Qualifier Codes hex 1 0 Binary Input Any Variation 1 read 22 assign class 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 inde...

Page 169: ...e 130 unsol resp 17 28 index 10 0 Binary Output Any Variation 1 read 22 assign class 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 1 read 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 129 response 00 01 start stop 17 28 index see note 1 10 1 Binary Output 1 write 00 01 start stop 10 2 default see note 1 Binary Output Status 1 read 00 01 start stop 06 n...

Page 170: ... 28 index 12 0 Control Relay Output Block 22 assign class 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 12 1 Control Relay Output Block 3 select 4 operate 5 direct op 6 dir op noack 17 28 index 129 response echo of request 12 2 Pattern Control Block 3 select 4 operate 5 direct op 6 dir op noack 7 limited quantity 129 response echo of request 12 3 Pattern Mask 3 select 4 oper...

Page 171: ... Bit Analog Input 1 read 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 129 response00 01 start sto 17 28 index see note 2 30 3 default see note 1 32 Bit Analog Input without Flag 1 read 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 129 response00 01 start sto 17 28 index see note 2 30 4 16 Bit Analog Input without Flag 1 read 00 01 start stop 06 no ran...

Page 172: ... response 130 unsol re 17 28 index 32 2 16 Bit Analog Change Event without Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol re 17 28 index 32 3 32 Bit Analog Change Event with Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol resp 17 28 index 32 4 16 Bit Analog Change Event with Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol res...

Page 173: ...d Date 1 read 07 limited qty 1 129 response 07 limited qty 1 50 1 default see note 1 Time and Date 2 write 07 limited qty 1 50 3 Time and Date Last Recorded Time 2 write 07 limited qty 51 1 Time and Date CTO 129 response 130 unsol resp 07 limited qty qty 1 51 2 Unsynchronized Time and Date CTO 129 response 130 unsol resp 07 limited qty qty 1 52 1 Time Delay Coarse 129 response 07 limited qty qty 1...

Page 174: ...index 7 No Object function code only 13 cold restart No Object function code only 14 warm restart No Object function code only 23 delay meas No Object function code only 24 record current time Note 1 A Default variation refers to the variation responded when variation 0 is requested and or in class 0 1 2 or 3 scans Default variations are configurable however default settings for the configuration ...

Page 175: ...tion 0 requested 2 Binary Input with flags Default Change Event Variation reported when variation 0 requested 2 Binary Input with absolute time Point Index Name Description Default Change Event Assigned Class 1 2 3 or none 1 Binary Input 1 2 2 Binary Input 2 2 3 Binary Input 3 2 4 Binary Input 4 2 5 Binary Input 5 2 6 Binary Input 6 2 35 Remote mode 2 36 Service mode 2 37 Local mode 2 38 Local Rem...

Page 176: ...time Point Index Name Description Default Change Event Assigned Class 1 2 3 or none 62 51G 2 2 63 50G 2 2 64 CTS Alarm 2 65 46IT 2 66 46DT 2 67 47 1 2 68 47 2 2 69 46BC 2 70 27 59 1 2 71 27 59 2 2 72 27 59 3 2 73 27 59 4 2 74 59NIT 2 75 59NDT 2 80 Auto reclose active 2 81 CB on by auto reclose 2 82 Reclaim 2 83 Lockout 2 86 51 3 2 87 50 3 2 88 51N 3 2 89 50N 3 2 90 51G 3 2 91 50G 3 2 92 51 4 2 93 ...

Page 177: ...ass 1 2 3 or none 102 SEF Inst Protection Inhibited 2 103 Ext Inst Protection Inhibited 2 117 51SEF 1 2 118 50SEF 1 2 119 51SEF 2 2 120 50SEF 2 2 121 51SEF 3 2 122 50SEF 3 2 123 51SEF 4 2 124 51SEF 4 2 125 SEF Out 2 126 Trip Circuit Fail 1 2 127 Trip Circuit Fail 2 2 128 Trip Circuit Fail 3 2 129 CB Total Trip Count 2 130 CB Delta Trip Count 2 131 CB Count to AR Block 2 132 CB Frequent Ops Count 2...

Page 178: ...Binary Inputs has several advantages it allows actual statuses to be included in class 0 polls it allows change event reporting of the actual statuses which is a more efficient and time accurate method of communicating control values and it allows reporting of time based information associated with controls including any delays before controls are actuated and any durations if the controls are pul...

Page 179: ... Total Trip Count 1 Pulse On Latch Off 49 Reset CB Delta Trip Count 1 Pulse On Latch Off 50 Reset CB Count to AR Block 1 Pulse On Latch Off 51 Reset Frequent Ops Count 1 Pulse On Latch Off 53 Reset I 2t CB Wear 1 Pulse On Latch Off 54 CB 1 1 Pulse On Pulse Off Latch On Latch Off 55 CB 1 Trip Reclose 1 Pulse On Latch Off 56 CB 1 Trip Lockout 1 Pulse On Latch Off 5 5 Analogue Inputs The following ta...

Page 180: ... 3 Vb Secondary 1 0 5 16 3 2 3 Vc Secondary 1 0 5 17 3 2 3 Vab Secondary 1 0 5 18 3 2 3 Vbc Secondary 1 0 5 19 3 2 3 Vab Secondary 1 0 5 21 3 2 3 Vzps 100 0 1 22 3 2 3 Vpps 100 0 1 23 3 2 3 Vnps 100 0 1 24 3 2 3 Vzps 1 0 5 25 3 2 3 Vpps 1 0 5 26 3 2 3 Vnps 1 0 5 31 3 2 3 Ia Primary 0 001 1000 32 3 2 3 Ib Primary 0 001 1000 33 3 2 3 Ic Primary 0 001 1000 34 3 2 3 Ia Secondary 100 0 1 35 3 2 3 Ib Se...

Page 181: ...2 3 Power Factor C 1 0 5 74 3 2 3 Power Factor 3P 1 0 5 75 3 2 3 Act Energy Exp 0 001 1000 76 3 2 3 Act Energy Imp 0 001 1000 77 3 2 3 React Energy Exp 0 001 1000 78 3 2 3 React Energy Imp 0 001 1000 81 3 2 3 Thermal Status Ph A 100 0 1 82 3 2 3 Thermal Status Ph B 100 0 1 83 3 2 3 Thermal Status Ph C 100 0 1 96 3 2 3 Fault Records 1 1 97 3 2 3 Event Records 1 1 98 3 2 3 Waveform Records 1 1 99 3 ...

Page 182: ... for the Binary Inputs Binary Outputs and Analogue Inputs Changing their assigned class and object variants Setting Binary points to be inverted before transmission Setting the Control Relay Output Block CROB commands that can be used with a Binary Output Specifying a dead band outside which Analogue Events will be generated Specifying a multiplier that will be applied to an analogue value before ...

Page 183: ...e at a time Hayes AT Modem command set developed by Hayes Microcomputer products Inc Line Idle Determines when the device is not communicating if the idle state transmits light Parity Method of error checking by counting the value of the bits in a sequence and adding a parity bit to make the outcome for example even Parity Bit Bit used for implementing parity checking Sent after the data bits RS23...

Page 184: ...produced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Devices L...

Page 185: ...edette Cases 9 3 2 3 Back of Panel cases 9 Section 4 Rear Terminal Drawings 10 4 1 E10 Case 10 Section 5 Connection Wiring Diagrams 11 5 1 Wiring Diagram 7PG2113 OC EF Relay with 3BI 5BO 11 5 2 Wiring Diagram 7PG2115 OC EF Relay with 6BI 8BO 12 5 3 Wiring Diagram 7PG2114 OC EF Relay with 3BI 5BO 13 5 4 Wiring Diagram 7PG2116 OC EF Relay with 6BI 8BO 14 Section 6 Data Comms Connections 15 6 1 RS485...

Page 186: ...ne testing Components which have 15kV isolated pilot connections are often mounted separately from the protection relay in a location more convenient for the connection to the incoming pilot cable and or in the interest of safety Connections to the relay can then be made at the lower 5kV insulation level with precautions and identification to suit The relay should be mounted on the circuit breaker...

Page 187: ...jury to personnel or damage to equipment 2 2 External Resistors Where external resistors are connected to the relay circuitry these may present a danger of electric shock or burns if touched 2 3 Front Cover The front cover provides additional securing of the relay element within the case The relay cover should be in place during normal operating conditions 2010 Siemens Protection Devices Limited C...

Page 188: ...lay B75 and the B34 relay for Rf Intertripping are each supplied in an Epsilon size E2 case Mechanical diagrams of the Epsilon case dimensions and panel cut out requirements are shown in Figure 1 to Figure 3 15kV Send End and B75 Receive relays are supplied in Vedette size 1 1 2V case Mechanical diagrams of case dimensions and panel cut out requirements are shown in Figure 4 The 15Kv Isolation Tra...

Page 189: ... screws These are supplied as standard and are suitable for use in ferrous aluminium panels 1 6mm thick and above For other panels holes to be M4 clearance typically Ø4 5 and relays mounted using M4 machine screws nuts and lockwashers supplied in panel fixing kit 2010 Siemens Protection Devices Limited Chapter 5 Page 6 of 15 ...

Page 190: ...7PG2113 4 5 6 Installation Guide Figure 4 Vedette C1 Case 2010 Siemens Protection Devices Limited Chapter 5 Page 7 of 15 ...

Page 191: ...7PG2113 4 5 6 Installation Guide Figure 5 15kV Transformer Outline Mounting Arrangement 2010 Siemens Protection Devices Limited Chapter 5 Page 8 of 15 ...

Page 192: ...ting screw kit per Relay Consists of 4 off M4x10mm Screws 4 off M4 Nuts 4 off M4 Lock Washer Typical rear terminal block fixing kit 1kit per terminal block fitted to relay Consists of 28 off M4 8mm Screws 28 off M4 Lock Washer 3 2 2 Vedette Cases 3 2 2 1 Wiring Terminations M5 Ring tongued crimps are recommended 3 2 2 2 Panel Fixing Vedette case mounting arrangement is shown in Figure 4 3 2 3 Back...

Page 193: ... 1 RS485 Block B Terms 14 16 18 20 connection to this communication facility is by screened twisted pair cable On site when wiring other facilities ensure that these terminals are not obscured by other wiring runs Cable should be RS485 compliant 2010 Siemens Protection Devices Limited Chapter 5 Page 10 of 15 ...

Page 194: ...7PG2113 4 5 6 Installation Guide Section 5 Connection Wiring Diagrams 5 1 Wiring Diagram 7PG2113 OC EF Relay with 3BI 5BO 2010 Siemens Protection Devices Limited Chapter 5 Page 11 of 15 ...

Page 195: ...7PG2113 4 5 6 Installation Guide 5 2 Wiring Diagram 7PG2115 OC EF Relay with 6BI 8BO 2010 Siemens Protection Devices Limited Chapter 5 Page 12 of 15 ...

Page 196: ...7PG2113 4 5 6 Installation Guide 5 3 Wiring Diagram 7PG2114 OC EF Relay with 3BI 5BO 2010 Siemens Protection Devices Limited Chapter 5 Page 13 of 15 ...

Page 197: ...7PG2113 4 5 6 Installation Guide 5 4 Wiring Diagram 7PG2116 OC EF Relay with 6BI 8BO 2010 Siemens Protection Devices Limited Chapter 5 Page 14 of 15 ...

Page 198: ...correctly in accordance with the master driving the connection A terminating resistor is fitted in each relay when required this is connected in circuit using an external wire loop between terminals 18 and 20 of the power supply module Up to 64 relays can be connected to the RS485 bus The RS485 data communications link with a particular relay will be broken if the relay element is withdrawn from t...

Page 199: ...evices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2012 Siemens Protection Devices Limited 7PG2113 4 5 6 Feeder protection Document Release...

Page 200: ...k of secondary connections 17 1 5 AC Energising Quantities 18 1 6 Binary Inputs 18 1 6 1 Connections for use in Solkor R Mode 19 1 7 Binary Outputs 20 1 8 Relay Case Shorting Contacts 20 Section 2 Protection Functions 21 2 1 Current Differential 87 22 2 2 Phase Directional Polarity Check 22 2 2 1 2 out of 3 logic 24 2 3 Phase Overcurrent 67 50 67 51 24 2 3 1 Definite Time Overcurrent 50 25 2 3 2 I...

Page 201: ...G2115 64 3 3 2 7PG2114 7PG2116 65 3 4 Broken Conductor 46BC 66 3 5 Trip Close Circuit Supervision 74T CCS 68 3 6 Magnetising Inrush Detector 81HBL 69 Section 4 Control Logic Functions 70 4 1 Autoreclose 79 70 4 2 Quick Logic 70 Section 5 Testing and Maintenance 71 5 1 Periodic Tests 71 5 2 Maintenance 71 5 3 Troubleshooting 71 Section 6 Pilot Supervision Equipment 73 6 1 Introduction 73 6 2 Descri...

Page 202: ...60 Figure 3 2 1 Voltage Transformer Supervision 62 Figure 3 3 1 Current Transformer Supervision 7PG2113 5 64 Figure 3 3 2 Current Transformer Supervision 7PG2114 6 65 Figure 3 4 1 Broken Conductor 66 Figure 3 5 1 Trip Circuit Supervision 68 Figure 3 6 1 Magnetising Inrush Detector 69 List of Tables Table 1 3 1 C T ratio and polarity tests 10 Table 1 3 2 Resistance and capacitance limitations 11 Ta...

Page 203: ...s 49 Table 2 11 5 Reset Results 49 Table 2 11 6 Element Blocking 49 Table 2 12 1 37 Results 50 Table 2 12 2 Element Blocking 51 Table 2 13 1 Standard Timings 53 Table 2 13 2 49 Results 53 Table 2 13 3 Capacity Alarm 53 Table 2 13 4 Element Blocking 53 Table 2 14 1 27 59 Test Results 55 Table 2 14 2 Element Blocking 55 Table 2 14 3 Undervoltage Guard 56 Table 2 15 1 47 Test Results 57 Table 2 15 2 ...

Page 204: ...ilure or blowing of an instrument fuse or the operation of an instrument cut out could cause the secondary winding of the C T to become an open circuit Open circuit secondary windings on energised current transformers are a hazard that can produce high voltages dangerous to personnel and damaging to equipment test procedures must be devised so as to eliminate this risk 1 2 2 Sequence of Tests If o...

Page 205: ...rocedures or to provide documentation recording the test and test parameters One method is to clear both the waveform and event records before each test is started then after the test upload from the relay the settings events and waveform files generated as a result of application of the test These can then be saved off to retain a comprehensive record of that test Relay settings files can be prep...

Page 206: ...an be altered This allows the settings in one group to be altered from the relay fascia while the protection continues to operate on a different unaffected group The Active Settings Group and the Edit Settings Group are selected in the System Configuration Menu The currently Active Group and the group currently Viewed are shown at the top of the display in the Settings display screen If the View G...

Page 207: ...small due to the impedance of the transformer 1 3 3 Secondary wiring insulation resistance test This test should not include the pilots which should be tested separately as described in 1 3 5 With all earth connections earth links and supply fuses and links removed measure the resistance to earth of all the secondary wiring Satisfactory values for the various readings depend upon the amount of wir...

Page 208: ...1 Secondary current A Test condition Primary current amps Red phase Yellow phase Blue phase Neutral phase Feeder end 1 A B B C C only Feeder end 2 A B B C C only Table 1 3 1 C T ratio and polarity tests 1 3 5 Pilot Insulation resistance test The voltage for the insulation resistance test of the pilots should not exceed the nominal insulation level of the pilots and the test should be made as follo...

Page 209: ...ormer tapping F2 0 5 for isolating transformer tapping T2 0 25 for isolating transformer tapping T1 Table 1 3 2 shows the standard pilot loop resistance and maximum inter core capacitance permissible for the various arrangements of Solkor When isolating transformers are fitted it is recommended that as a general rule the tap chosen should be the one which allows the maximum value of pilot capacita...

Page 210: ...he tripping links the protection is then ready for service 1 4 Current Differential 87 If testing by single phase primary injection is not possible make the alternative tests described on page 4 The purpose of these tests is to establish the overall fault settings of the protection and also to establish that the secondary wiring between the current transformers and the summation transformer at eac...

Page 211: ...etting of the protection the circuit breaker should then operate thus proving the tripping circuit Repeat the tests at the other end of the feeder When all the tests have been completed at both ends of the feeder compare results between ends Check that the most sensitive earth fault setting at each end refers to the same phase i e the red phase the next sensitive the Yellow phase and the least sen...

Page 212: ... 2 Connections for Stability Tests on Load without Isolating Transformers E E Figure 1 4 3 Connections for Stability Tests on Load with Isolating Transformers The test should be made with the load current in the feeder equal to at least 10 15 of the rating of the feeder current Transformers Since in these tests all three phases of the primary circuits are energised take care that the current trans...

Page 213: ... unstabilise the protection Check that there is a large increase of d c current in the operating coils of the relays If required repeat these tests for the other phase to earth conditions Record the results for each end of the feeder as shown in 1 4 2 Alternative tests if primary injection equipment is not available If it is not possible to do the primary injection tests described under Overall Fa...

Page 214: ...eeder E E Figure 1 4 4 Connections for Overall Fault setting Tests by Secondary Injection 1 4 4 Current transformer ratio and polarity tests Remove the trip links at both ends of the feeder Connect ammeters in the current transformer secondary leads at each end in turn as shown in Figure 1 4 5 Pass three phase load current through the primary and check the ratio of each current transformer by comp...

Page 215: ...load current this condition can best be approached by taking readings for a given fault condition at each end in turn With this objective in view initially connect the secondary circuit at each end as shown in Figure 1 4 2 Solkor without isolating transformers or Figure 1 4 3 Solkor with isolating transformers For an A E fault condition remove the short circuiting connection from the A phase curre...

Page 216: ...n turn and check for correct operation Depending on the application each binary input may be programmed to perform a specific function each binary should be checked to prove that its mapping and functionality is as set as part of the Scheme Operation tests Where the pick up timers associated with a binary input are set these delays should be checked either as part of the scheme logic or individual...

Page 217: ...ine that it is correctly connected for the chosen mode of operation This is done by withdrawing the relay element from the case and inspecting four connections to a terminal block as shown in the following illustrations For earlier relays For later relays examples shows Rf R mode example shows R mode For Solkor R Mode Wires numbered 1 2 3 and 4 have to be connected to terminals 1a 2a 3a and 4a res...

Page 218: ...nfig menu for each output relay and may be too short to measure with a continuity tester An alternative method of energising an output permanently so that wiring can be checked is to temporarily map the relay being tested to the Protection Healthy signal in the Output Matrix as this signal is permanently energised the mapped relay will be held energised normally open contacts will be closed and vi...

Page 219: ...he table below indicates functions where function conflicts may occur during testing consideration should be given to disabling functions to avoid interference Table 1 8 1 Protection Function Conflicts Any LED can be assigned to be a General Pickup LED in the Output Matrix menu and used to assess operation of functions during testing if other functions are disabled or if the setting allocating Gen...

Page 220: ... P F Dir as forward or reverse based on the output states of the directional elements i e whether they see forward current reverse current or neither for each pole with respect to the 67 Char Angle setting in the Phase Overcurrent menu This display and the equivalent Measured and Calculated Earth Fault direction meters can be used as an aid to commissioning testing 1 Check the direction of each po...

Page 221: ...his reference Alternatively the instrument can be checked at the 4 points marked a b c d on Figure 2 1 only Forward Reverse Lag point C Lead point A Lead point B Lag point D Pick up Drop off Pick up Drop off Pick up Drop off Pick up Drop off MTA MTA 85 MTA 85 MTA 85 MTA 85 Phase A Phase B Phase C Table 2 2 3 Directional Limits Test Results Figure 2 2 1 Directional Phase Fault Boundary System Angle...

Page 222: ...he test with Phase A current as above but also with equal current in the B phase at 180º to that in the A phase 1 phase current 2 phase current No 50 51 n Operation 50 51 n operation Table 2 2 5 2 out of 3 Logic Test 2 3 Phase Overcurrent 67 50 67 51 Figure 2 3 1 Phase Overcurrent Voltage Inputs VL1 VA VL2 VB VL3 VC for directional elements Current Inputs IL1 IA IL2 IB IL3 IC Disable 51V 51C 46 49...

Page 223: ... waveform record Table 2 3 1 50 Results 2 3 2 Inverse Time Overcurrent 51 It will be advantageous to map the function being tested to temporarily drive the relevant Pickup output in the Pickup Config sub menu in the Output Config menu as this will allow the Pick up led to operate for the function Gradually increase current until Pickup LED operates Apply 2x setting current and record operating tim...

Page 224: ...condition to fully reset are as follows for zero applied current and Time multiplier TM 1 0 The reset curve characteristic type and TM is defined by the operating characteristic Curve Fully operated to reset with Zero current applied TM 1 secs ANSI MI 4 85 ANSI VI 21 6 ANSI EI 29 1 Table 2 3 5 ANSI reset standard values Apply current in the following sequence a 2x setting for a time to ensure elem...

Page 225: ...he effective 51V n setting Ensure that the thermal rating of the relay is not exceeded Gradually reduce the voltage until the a b voltage is less than the Voltage setting Pickup LED operation can be used to confirm the Voltage setting If the 51V n current setting is above the continuous rating of the relay an alternative procedure should be used apply test current in short duration shots with appl...

Page 226: ...l If this is the case the phase angle of the current must be set with respect to the voltage to produce operation of the elements Voltage Setting V p p Measured V p p Table 2 4 2 51V Operate Voltage I Setting Multiplier Calculated PU Measured Tolerance 51 1 Pickup 51 2 Pickup 51 3 Pickup 51 4 Pickup Table 2 4 3 51V Test Results 2 4 1 1 Element Blocking The Voltage Controlled Overcurrent function c...

Page 227: ... Load Pick up Time to allow testing of this function It may be convenient to reduce this setting to suit the test procedure If the CB is open throughout the tests the Cold Load protection settings can be tested provided that the current is not allowed to fall below the level of the Reduced Current Level for more than the Reduced Current Time during testing It may be convenient to set the Reduced C...

Page 228: ...educed Current Time Check the Cold Load Pick up Delay by applying or simulating CB Open Measure the time delay before Cold Load Active is raised Apply current above the Reduced Current Level if this functionality is Enabled before applying CB Closed Measure the time for Cold Load Active to reset 2 5 1 Inverse Time Overcurrent 51C It will be advantageous to map the function being tested to temporar...

Page 229: ...e reset curve characteristic type and TM is defined by the operating characteristic Curve Fully operated to reset with Zero current applied TM 1 secs ANSI MI 4 85 ANSI VI 21 6 ANSI EI 29 1 Table 2 5 3 Standard ResetCurve Timing Apply current in the following sequence a 2x setting for a time to ensure element operation b Zero current for the reset time above xTM c 2x setting for a time to ensure el...

Page 230: ...ph n voltage by 15º Alternatively a single phase voltage source can be used in the above test The polarity of this voltage applied to the faulted phase neutral alone must be reversed to produce the same residual voltage Vres phase direction as that produced by the 3P voltage simulation described above For the Phase Voltage Config of Vab Vbc Vo the single phase voltage applied to the Vo input is us...

Page 231: ...tions may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity Derived EF Measured EF Sensitive EF Restricted EF protections can be Enabled Disabled individually or as groups in the Function Config menu Derived EF elements can be separated from Measured Sensitive EF by arrangement of the secondary injection circuit by shorting disconnecting I4 I...

Page 232: ...t to BLOCK this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase 3P current and check that the element does not operate If VTS action is set to Non Directional this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element operates ...

Page 233: ...andard Timings Note that the operate time may be subject to the Minimum op time setting for the element and or may have a Follower DTL applied 2 7 3 1 Element Blocking The Derived Earth Fault elements can be blocked by Binary Input Inhibit VT Supervision and Inrush Detector operation The Characteristic can be made non directional by VT Supervision This functionality should be checked Element BI In...

Page 234: ...NSI EI 29 1 Table 2 7 6 Standard ResetTiming Apply current in the following sequence a 2x setting for a time to ensure element operation b Zero current for the reset time above xTM c 2x setting for a time to ensure element operation Check that the second operation c is similar to the first a and in line with the expected operate time for the element at this current level Repeat the test with the r...

Page 235: ...ons may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity Derived EF Measured EF Sensitive EF Restricted EF protections can be Enabled Disabled individually or as groups in the Function Config menu Measured EF elements can be separated from Derived EF and Sensitive EF by secondary injection of current through the I4 input circuit only If any ...

Page 236: ... to BLOCK this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element does not operate If VTS action is set to Non Directional this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element opera...

Page 237: ...se a VTS condition Increase a phase current and check that the element does not operate If VTS action is set to Non Directional this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element operates at its normal setting Reverse the voltage phase direction whilst checking that the element does not...

Page 238: ... 6 ANSI EI 29 1 Table 2 8 6 Standard ResetTiming Apply current in the following sequence a 2x setting for a time to ensure element operation b Zero current for the reset time above xTM c 2x setting for a time to ensure element operation Check that the second operation c is similar to the first a and in line with the expected operate time for the element at this current level Repeat the test with t...

Page 239: ...tection functions may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity Derived EF Measured EF Sensitive EF Restricted EF protections can be Enabled Disabled individually or as groups in the Function Config menu Sensitive EF elements can be separated from Derived EF by secondary injection of current through the I4 input circuit only If any of...

Page 240: ...ctional If VTS action is set to BLOCK this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element does not operate If VTS action is set to Non Directional this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and ...

Page 241: ...ltage to cause a VTS condition Increase a phase current and check that the element does not operate If VTS action is set to Non Directional this option should be tested Apply balanced voltage and current Reduce a phase voltage to cause a VTS condition Increase a phase current and check that the element operates at its normal setting Reverse the voltage phase direction whilst checking that the elem...

Page 242: ... 6 ANSI EI 29 1 Table 2 9 6 Standard ResetTiming Apply current in the following sequence a 2x setting for a time to ensure element operation b Zero current for the reset time above xTM c 2x setting for a time to ensure element operation Check that the second operation c is similar to the first a and in line with the expected operate time for the element at this current level Repeat the test with t...

Page 243: ...rded Settings Data Resistor Value Measured Table 2 10 1 REF Resistance The high value of setting resistance R will often interfere with secondary current injection when using a digital test set It is normal practice in these cases to short out the series resistor to allow testing the shorting link should be removed after testing Since the DTL setting is generally small the pick up setting can be t...

Page 244: ...ersonnel are at risk of contact with any of the energised secondary wiring during the test Settings Data Voltage Setting Measured Table 2 10 3 64H Operating Voltage To complete testing of the REF requires primary injection through the phase and residual REF CT in series to simulate an out of zone fault and ensure stability of the relay The test can then be repeated with the REF CT secondary connec...

Page 245: ...re two NPS elements are being used with different settings it is convenient to test the elements with the highest settings first The elements with lower settings can then be tested without disabling the lower settings The Thermal withstand limitations of the current inputs stated in the Performance Specification should always be observed throughout testing NPS Overcurrent can be tested using a nor...

Page 246: ...ive the relevant Pickup output in the Pickup Config sub menu in the Output Config menu as this will allow the Pick up led to operate for the function Gradually increase current until Pickup LED operates Apply 2x setting current and record operating time Apply 5x setting current and record operating time Compare to calculated values for operating times Operate Current Operate Time Ph P U Amps D O A...

Page 247: ...ment operation b Zero current for the reset time above xTM c 2x setting for a time to ensure element operation Check that the second operation c is similar to the first a and in line with the expected operate time for the element at this current level Repeat the test with the reset time b reduced to 50 of the previous value Ensure that the second operate time c is 50 of the first a operate time Ta...

Page 248: ...erference from the other element Apply 3Phase balanced current or single phase current on the single pole relay models at a level above the Undercurrent 37 n setting until the element resets If DTL setting is small gradually reduce any phase current in turn until element operates If DTL is large apply 1 1x setting check for no operation apply 0 9x setting check operation Testing of this element ph...

Page 249: ... Chapter 6 Page 51 of 77 2 12 1 1 Element Blocking The Undercurrent elements can be blocked by Binary Input Inhibit This functionality should be checked Element BI Inhibits 37 1 37 2 Table 2 12 2 Element Blocking Check correct indication trip output alarm contacts waveform record ...

Page 250: ... or phase by phase from a 1P supply Alternatively the 3 phase current inputs can be connected in series and injected simultaneously from a single 1P source The Thermal Overload Setting and Time Constant Setting can be considered together to calculate the operating time for a particular applied current The following table lists operate times for a range of Time Constant Settings for an applied curr...

Page 251: ... the Overload Setting current Calculated Operate Time s Measured Operate Time s Table 2 13 2 49 Results If the Thermal Overload Capacity Alarm is used this can be tested by monitoring the Thermal Capacity in the instruments menu If the Thermal time constant is longer than a few minutes this can be assessed during the timing test above If the Time Constant is less than a few minutes a lower multipl...

Page 252: ...mally required to stabilise the relay during voltage element testing If the O P Phases is set to All the voltage on all phases must be reduced simultaneously Otherwise the 3 phases should be tested individually If the DTL is short starting from nominal voltage slowly decrease the applied 3P or VL1 test voltage until the Pickup LED temporarily mapped is lit Record the operate voltage The LED should...

Page 253: ...nominal Volts and the LED will extinguish Record the reset voltage to check the Hysteresis setting If the DTL setting is long the operate level can be checked by applying 100 of setting to cause operation followed by setting minus the Hysteresis setting to cause reset Connect the relevant output contact s to stop the test set Step the applied voltage to a level above the setting The test set shoul...

Page 254: ...et as Hand Reset in the Output matrix Starting from nominal voltage apply a step decrease to the applied voltage to a level below the 27 Undervoltage setting but above the 27UVG setting such that an Undervoltage element operation occurs Slowly reduce the applied voltage until the 27 Undervoltage element resets this can be detected by the General Pickup LED reset if no other element is operated thi...

Page 255: ... is Negative Phase Sequence If the 47 n delay is small gradually increased the applied balanced 3P voltage until element operates If DTL is large apply 0 9x setting check for no operation apply 1 1x setting check operation Apply 2x setting current if possible and record operating time Phase 27 59 setting Volts U O DTL sec Hyst D O calculated P U Volts D O Volts Op Time 2x Vs Tolerance NPS Table 2 ...

Page 256: ... be set as either Vn calculated from the applied 3 phase voltage inputs or Vx the V4 input Apply test voltage to 1 phase input or V4 input to suit 2 16 1 Definite Time 59NDT If DTL setting is small gradually increase single phase voltage until element operates If DTL is large apply 0 9x setting check for no operation apply 1 1x setting check operation Apply 2x setting voltage if possible and recor...

Page 257: ... higher multiple of setting voltage and record operating time Compare to calculated values for operating times from 1 1 sec Vs Vn op M t Where M Time multiplier and Vn Vs multiple of setting Operate Voltage Operate Time Ph Vs V TM P U Volts D O Volts Tol 2 x Vs sec x Vs sec Tol P U D O TIMING TESTS E Table 2 16 2 59NIT Test Results 2 16 2 1 Element Blocking The Neutral Overvoltage elements can be ...

Page 258: ... A binary input mapped as 50BF Mech Trip in the INPUT CONFIG INPUT MATRIX menu Apply a trip condition by injection of current to cause operation of a suitable protection element Allow current to continue after the trip at a level of 110 of the 50BF Setting current level on any phase Measure the time for operation of 50BF 1 Delay and 50BF 2 Delay Repeat the sequence with the 50BF CB Faulty input en...

Page 259: ... signal from a protection function where there is no increase in current this trip input should be mapped to 50BF Mech Trip in the INPUT CONFIG INPUT MATRIX menu Initiate this binary input and simulate the circuit breaker remaining closed by ensuring the CB Closed binary Input is energised and ensure operation of the 50BF 1 and 50BF 2 outputs after their programmed delays 50BF Mech Trip 50BF 1 Del...

Page 260: ... voltage Reduce 1 phase voltage until VTS operates record voltage reduction level 60VTS V Setting Setting x 3 Measured Voltage Reduction Table 3 2 1 60VTS Voltage Setting increase the voltage until VTS resets Increase current on 1 phase by 110 of 3x the 60VTS I setting Reduce voltage as above and check for no operation Return voltage to nominal Increase current on 1 phase by 90 of 3x the 60VTS I s...

Page 261: ...ease the 3P balanced current until the VTS operates Check that the thermal rating of the relay current inputs is not exceeded during the following test Increase the 3P balanced current to a level above the 60VTS Ipps Fault setting Reduce the 3P balanced voltage to a level below the operate level above Gradually reduce the 3P balanced current until the VTS operates Setting Measured 60VTS Vpps 60VTS...

Page 262: ...sion 7PG2113 5 Current Inputs IL1 IA IL2 IB IL3 IC Disable 51N 46IT 46DT 46BC Map Pickup LED 60CTS Self Reset Apply 3Phase balanced current to the relay reduce the current in any one or two phases to a level below 60CTS I setting Measure the delay to operation Gradually reduce the 3Phase current until the element resets Setting Measured 60CTS Delay 60CTS Inps 60CTS Vnps Table 3 3 1 7SR11 60CTS Tes...

Page 263: ...ent without NPS voltage is used to indicate a current transformer failure Apply normal 3P balanced current with a crossover of any two phases at a level above 60CTS Inps setting Measure the delay to operation Apply 3P balanced voltage with a similar phase crossover to the current Increase the applied 3P voltage until the CTS element resets Reduce the 3P voltage to cause CTS operation again Gradual...

Page 264: ...ntities can be produced directly from many advanced test sets but with limited equipment the following approach can be applied Apply 3P balanced current with normal phase rotation direction This current will consist of PPS alone no NPS or ZPS Increase 1 phase current magnitude in isolation to produce NPS The single phase unbalance current will contain equal quantities of ZPS NPS and PPS The NPS co...

Page 265: ...40 200 Table 3 4 1 46BC Test Currents 46BC Setting 3P balanced current A 1P unbalance current A Measured Unbalance current Table 3 4 2 46BC Test Results Apply 1A 1P unbalance current without 3P balanced current Measure 46BC operating time 46BC Delay setting Measured Table 3 4 3 46BC Operate Time 3 4 1 1 Element Blocking The Broken Conductor element can be blocked by Binary Input Inhibit This funct...

Page 266: ...S Figure 3 5 1 Trip Circuit Supervision Voltage Inputs n a Current Inputs n a Disable Map Pickup LED 74TCS n Self Reset The T CCS n Delay can be initiated by applying an inversion to the relevant status input and measured by monitoring of the alarm output Table 3 5 1 74T CCS Test Results TCS n Delay setting Measured CCS n Delay setting Measured ...

Page 267: ... 69 of 77 3 6 Magnetising Inrush Detector 81HBL Figure 3 6 1 Magnetising Inrush Detector Voltage Inputs n a Current Inputs IL1 IA IL2 IB IL3 IC Disable Map Pickup LED Logical operation of the harmonic blocking can be tested by current injection at 100Hz to cause operation of the blocking signals ...

Page 268: ...rovide a realistic simulation of the actual system conditions The Instruments Menu contains Autoreclose Meters for the Autoreclose State and the Shot No which are useful during sequence testing The time stamped Events listing can be downloaded from the relay to a pc to allow diagnosis of the sequence including measurements of sequence Dead Times and other timing without the use of external measuri...

Page 269: ...d The withdrawn relay should never be transported without the protection of the outer case 5 3 Troubleshooting Observation Action Relay does not power up Check that the correct auxiliary DC voltage is applied and that the polarity is correct Relay won t accept the password The Password being entered is wrong Enter correct password If correct password has been forgotten note down the Numeric Code w...

Page 270: ...the status input settings such as the pick up and drop off timers and the status inversion function are correctly set Relay instrument displays show small currents or voltages even though the system is dead This is normal The relay is displaying calculation noise This will not affect any accuracy claims for the relay Table 5 3 1 Troubleshooting Guide If the above checklist does not help in correct...

Page 271: ...f the circuit breaker should the Solkor protection operate under load conditions due to the pilots becoming open circuited The operating coils of the guard relays are connected in series with the summation transformer at each end of the feeder and the contacts of the guard relays are in series with the Solkor tripping contacts The setting of the phase fault guard relays should be lower than one ha...

Page 272: ...ng Overall fault setting tests should first of all be done without the pilot supervision in service This will not only check the basic fault setting but also confirm that the connections to the summation transformer at each end of the feeder are correct thus ensuring that the protection will stabilise correctly for external faults At the supervision receive end disconnect the supervision receive r...

Page 273: ...y failure relay from the transformer rectifier supervision supply unit Using a variable a c voltage supply check the pick up value of the relay Slowly reduce the voltage until the relay resets The pick up value of the relay should be approximately 80 of nominal rating 6 3 9 Overall tests of pilot supervision equipment Check that the pilot supervision equipment is connected correctly to the pilots ...

Page 274: ...e stability of the protection as described in the appropriate Operating Recommendations 6 3 11 Putting into service Make a final check of connections Ensure that the supervision supply is switched on that the pilot supervision receive relay and repeat relay are held operated and that all indications and alarms are reset Make the checks described under the heading Putting into service in the approp...

Page 275: ... 28 Pilots to Send End Receive Equipment AC Schematic Diagram 17 E 7 V 3 V 19 E 18 E 9 V D R R C 5 V 20 E B75 Figure 6 3 3 Pilot Supervision Receive Equipment Current transformer connections are typical only Earthing connections are typical only 5kV Solkor Rf schemes omit the 15kV isolating transformers Solkor R connections are shown in the relay Installation Recommendations An E above the connect...

Page 276: ...e reproduced from this document unless Siemens Protection Devices Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Devic...

Page 277: ...irectional Protection 67 24 3 5 1 2 Out of 3 Logic 26 3 6 Directional Earth Fault 50 51G 50 51N 51 51SEF 27 3 7 High Impedance Restricted Earth Fault Protection 64H 28 3 8 Negative Phase Sequence Overcurrent 46NPS 29 3 9 Undercurrent 37 30 3 10 Thermal Overload 49 30 3 11 Under Over Voltage Protection 27 59 31 3 12 Neutral Overvoltage 59N 32 3 12 1 Application with Capacitor Cone Units 33 3 12 2 D...

Page 278: ...re 3 5 1 Directional Characteristics 24 Figure 3 5 2 Phase Fault Angles 25 Figure 3 5 3 Application of Directional Overcurrent Protection 25 Figure 3 5 4 Feeder Fault on Interconnected Network 26 Figure 3 6 1 Earth Fault Angles 27 Figure 3 7 1 Balanced and Restricted Earth fault protection of Transformers 28 Figure 3 7 2 Composite Overcurrent and Restricted Earth fault Protection 29 Figure 3 10 1 ...

Page 279: ...ected to current transformers at each end of the feeder respectively The relay has an insulation level of 5kV between pilot connections and the local ground to withstand voltages induced on the pilot cable due to coupling with the fault current flowing in a parallel path and to withstand differential ground voltages caused by the flow of fault current This is generally adequate for distribution fe...

Page 280: ...upervision relay 1 per circuit 1 3 2 2 Receive End Pilot Supervision Receive End relay B74 B75 1 per circuit Note Although the 5kV scheme utilises a combined B75 B74 unit the additional isolation requirements at 15kV necessitate that separate units must be used 1 3 3 15kV Schemes 1 3 3 1 Send End 15kV Pilot Supervision Send End relay transformer rectifier 1 per circuit B22 AC Supply Supervision re...

Page 281: ...ust be the same This applies to any of the arrangements shown Figure 1 4 1 Installation with Existing Solkor R Rf or R Rf relay Figure 1 4 2 Standard 5kV Solkor R Rf with Guard Figure 1 4 3 Installation with existing 15kV Plain Solkor Rf with Guard 2010 Siemens Protection Devices Limited Chapter 7 Page 6 of 49 ...

Page 282: ...PG2113 4 5 6 Solkor Applications Guide Figure 1 4 4 5kV Solkor Rf with Pilot Supervision Figure 1 4 5 15kV Solkor Rf with Pilot Supervision 2010 Siemens Protection Devices Limited Chapter 7 Page 7 of 49 ...

Page 283: ...e module should be wired into the numeric module to provide an alarm signal which is used to provide auxiliary functions This signal is used to drive indication raise an event on the comms protocol initiate a waveform record and can be used to drive additional repeat contacts and as an input to additional user logic Similarly the Guard relay contact which is driven from Overcurrent and Earth Fault...

Page 284: ... cause nuisance indications E2 I1 V1 I1 I2 Indication of trip condition 87L and Guard operation or 87L when Guard Override is raised This is an indication of trip condition it is used to start Waveform Recorder and Fault Record It is also operates the Trip output contact used by Backup OC EF although it is expected that the main trip will be direct from the Solkor R Rf module output contactor via ...

Page 285: ...eset Phase leds are illuminated for Guard and Backup and are self reset led state is stored in the Fault display for Backup and 87L trips i e Guard operated phase leds are shown for Solkor trips L7 Earth Yellow self reset Operated by Backup EF Guard EF Self reset to match A B C indications L8 Guard Override Yellow Self reset follows binary input L9 Backup inhibited Yellow Self reset follows binary...

Page 286: ... earth fault current which returns through the cable sheath and armouring however with overhead line systems the earth shift voltage can be as significant as the induced longitudinal voltage The 7PG2113 4 5 6 relay will withstand 5kV rms voltage This can be increased to 15kV by the addition of an isolation transformer 5kV isolation is usually acceptable for 11kV cable distribution systems where ze...

Page 287: ...ng resistance must be set in series with the pilot resistance to achieve a standard value There is therefore a maximum value for the pilot resistance for which the padding should be set to zero The maximum value of pilot LOOP resistance for the Solkor R mode is 1000Ω and for the Solkor Rf mode the maximum LOOP resistance is 2000Ω When 15kV isolation transformers in the Rf mode the maximum LOOP res...

Page 288: ...his may be particularly desirable for the 15kV scheme where all settings are naturally raised by the increase in energy required to drive the additional isolation transformers It must be noted that the use of the N1 tap will increase the burden on the CT and therefore should only be used if the CT knee point voltage Vk easily exceeds the minimum requirements stated below which is often the case wi...

Page 289: ...ect alternate settings group Local Generation Industrial system draws power from grid system during normal operation Relays normally use settings group 1 On loss of mains Local generation switched in Non essential loads tripped Relays on essential circuits switched to settings group 2 to reflect new load and fault currents Non essential loads Trip non essential loads Figure 2 1 1 Example Use of Al...

Page 290: ...binary inputs is to provide indication of alarm or fault conditions e g transformer Buchholz Gas or Buchholz Surge conditions The Binary Inputs are mapped to LED s waveform storage trigger and binary outputs Note that transformer outputs which require high speed tripping such as a Buchholz Surge should be wired to a binary input to provide LED indication and also have a parallel connection wired t...

Page 291: ...o mal operate if they 1 Have both the positive and negative switched double pole switched 2 Do not have extensive external wiring associated with them e g if the wiring is confined to the relay room Where a binary input is both used to influence a control function e g provide a tripping function and it is considered to be susceptible to mal operation the external circuitry can be modified to provi...

Page 292: ...PG2113 4 5 6 Solkor Applications Guide Figure 2 2 2 Binary Input Configurations Providing Compliance with EATS 48 4 Classes ESI 1 and ESI 2 2010 Siemens Protection Devices Limited Chapter 7 Page 17 of 49 ...

Page 293: ...ed by an upstream device The relay will then reset and attempt to interrupt trip coil current flowing through an output contact Where this level is above the break rating of the output contact an auxiliary relay with heavy duty contacts should be utilised 2 4 LEDS In the Output Configuration menu LEDs can be mapped to output functions by means of settings These could be used to display such digita...

Page 294: ...eristics are defined as Inverse because their tripping times are inversely proportional to the Fault Current being measured This makes them particularly suitable to grading studies where it is important that only the Relay s closest to the fault operate Discrimination can be achieved with minimised operating times To optimise the grading capability of the relay additional time multiplier Follower ...

Page 295: ...ghly arid areas or where the system uses high values of earthing resistor reactance and the fault current detected in the phase conductors will be limited 3 1 1 Selection of Overcurrent Characteristics Each pole has two independent over current characteristics Where required the two curves can be used To produce a composite curve To provide a two stage tripping scheme Where one curve is to be dire...

Page 296: ...e insulation fails again The same phenomenon has occurred in compound filled joint boxes or on clashing overhead line conductors The repeating occurrence of the fault can cause electromechanical disc relays to ratchet up and eventually trip the faulty circuit if the reset time of the relay is longer than the time between successive faults To mimic an electromechanical relay the relay can be user p...

Page 297: ...nd this must be above the protection over current settings Close in short circuit faults may also cause the AVR to reach its safety limits for supplying maximum excitation boost in the order of several seconds and this will result in AVR internal protection devices such as diode fuses to start operating The generator excitation will then collapse and the situation will be the same as when no AVR w...

Page 298: ... difference between the fault current levels at different relay point The Instantaneous element is set to pick up at a current level above the maximum Fault Current level at the next downstream relay location and below its own minimum fault current level The protection is set to operate instantaneously and is often termed Highset Overcurrent A typical application is the protection of transformer H...

Page 299: ...e Characteristic Angle setting This is the expected fault angle sometimes termed the Maximum Torque Angle MTA as an analogy to older Electro mechanical type relays Example Expected fault angle is 30º Current lagging Voltage so set Directional Angle to 90 30 60 A fault is determined to be in the selected direction if its phase relationship lies within a quadrant 85 either side of the Characteristic...

Page 300: ...at A B E and G have directional overcurrent relays fitted since fault current can flow in both directions at these points The forward direction is defined as being away from the busbar and against the direction of normal load current flow These forward looking IDMTL elements can have sensitive settings applied i e low current and time multiplier settings Note that the relays may be programmed with...

Page 301: ... reverse directions closed ring circuits can be set to grade correctly whether fault current flows in a clockwise or counter clockwise direction i e it may be practical to use only one relay to provide dual directional protection 3 5 1 2 Out of 3 Logic Sensitive settings can be used with directional overcurrent relays since they are directionalised in a way which opposes the flow of normal load cu...

Page 302: ...ctated by the system impedances Example Expected fault angle is 45 i e residual current lagging residual voltage therefore 67G Char Angle 45 However directional earth elements can be selectable to use either ZPS or NPS Polarising This is to allow for the situation where ZPS voltage is not available perhaps because a 3 limb VT is being used Care must be taken as the Characteristic Angle will change...

Page 303: ...ricted Earth Fault Figure 3 7 1 Balanced and Restricted Earth fault protection of Transformers The calculation of the value of the Stability Resistor is based on the worst case where one CT fully saturates and the other balancing CT does not saturate at all A separate Siemens Protection Devices Limited Publication is available covering the calculation procedure for REF protection To summarise this...

Page 304: ... system is 6 to 9 times the charging current per phase High impedance differential protection is suitable for application to auto transformers as line currents are in phase and the secondary current through the relay is balanced to zero by the use of CTs ratios at all three terminals High impedance protection of this type is very sensitive and fast operating for internal faults 3 8 Negative Phase ...

Page 305: ...ipment and θ 100 for maximum thermal withstand of equipment or the Trip threshold Figure 3 10 1 Thermal Overload Heating and Cooling Characteristic For given current level the Thermal State will ramp up over time until Thermal Equilibrium is reached when Heating Effects of Current Thermal Losses The heating cooling curve is primarily dependant upon the Thermal Time Constant This must be matched ag...

Page 306: ... voltage elements should be set to values safely above below that where a normal system voltage excursion can be expected The switchgear plant design should be considered The Dead level may be very near to the live level or may be significantly below it The variable hysteresis setting allows the relay to be used with all types of switchgear System over voltages can damage component insulation Exce...

Page 307: ...t would be present to cause a trip but residual voltage would increase significantly reaching up to 3 times the normal phase earth voltage level If Neutral Overvoltage protection is used it must be suitably time graded with other protections in order to prevent unwanted tripping for external system earth faults Figure 3 12 1 NVD Application Typically NVD protection measures the residual voltage 3V...

Page 308: ...rotecting rotating plant such as motors and generators However such protection is almost universally based on detecting NPS Current rather than Voltage This is because the NPS impedance of motors etc is much less than the Positive Phase Sequence PPS impedance and therefore the ratio of NPS to PPS Current is much higher than the equivalent ratio of NPS to PPS Voltage NPS Voltage is instead used for...

Page 309: ...ally not differ by more than IN 20 amperes for output voltages up to 50 IN volts where IN rated current of Solkor Rf relay This criteria is applied to quantify matching of the transient response of the two CTs so that relay operations do not occur due to differing responses of the CTs to normal load switching or the incidence and clearance of out of zone faults This condition is usually easily sat...

Page 310: ...T wiring resistance RL 30m long 7 0 67mm 2 5mm sq at 7 4 ohms km 0 22 ohms VT ratio 33000 110V Maximum X R ratio at source busbar 20 Maximum 3P fault level at busbar 1000MVA Consider 3P fault level based on maximum busbar levels VPh 33000 3 19 05kV Fault level per phase 1000 3 333MVA 17 5kA 19 05x10 333x10 I 3 6 F Ω 089 1 10 5 17 10 05 19 3 3 x x ZS Also since X R at the busbar 20 We can evaluate ...

Page 311: ...Total impedance for a through fault at the remote busbar ZS ZL RS RL XS XL 0 0544 0 7765 j 1 0876 2 8978 ZF 0 8309 j3 9854 ohms 2 2 X R Z 2 2 9854 3 8309 0 Z ZF 4 071 ohms Through Fault Current 4 68kA 4 071 19 05x10 I 3 F Through fault current 4 68kA compared to 17 5kA Busbar fault current due to the effect of the line impedance 19 05kV Zs 17 5kA Z 4 68kA L 2010 Siemens Protection Devices Limited ...

Page 312: ... settings are to be used then the overcurrent factor must be raised accordingly by increasing the kneepoint voltage requirement 4 2 2 Earth Fault Protection CTs Considerations and requirements for earth fault protection are the same as for Phase fault Usually the relay employs the same CT s e g three phase CTs star connected to derive the residual earth fault current The accuracy class and overcur...

Page 313: ... so long that two separate faults could occur in the same Autoreclose ARC sequence and cause unnecessary lockouts The Sequence Fail Timer provides an overall maximum time limit on the ARC operation It should therefore be longer than all the set delays in a complete cycle of ARC sequences trip delays Deadtimes Reclaim Time etc Generally this will only be exceeded if the circuit breaker has either f...

Page 314: ...1 Requirement Settings shall provide four phase fault recloses two instantaneous and two delayed and only two delayed recloses for faults detected by the E F protection Proposed settings include CONTROL LOGIC AUTORECLOSE PROT N 79 P F Inst Trips 50 1 79 P F Delayed Trips 51 1 79 E F Delayed Trips 51N 1 CONTROL LOGIC AUTORECLOSE CONFIG 79 Num Shots 4 CONTROL LOGIC AUTORECLOSE CONFIG P F SHOTS 79 P ...

Page 315: ...1 Inst 79 P F Prot n Trip 2 Inst 79 P F Prot n Trip 3 Delayed 79 P F Prot n Trip 4 Delayed The above settings are suitable at values of fault current above I2 however were a fault to occur with a current value between I1 and I2 this would be detected by the 51 1 element only As Prot n Trip 1 Inst then the relay would trip and reclose whereas it is required to lockout for this occurrence To provide...

Page 316: ...t 2 that CB 1 has opened e g Binary Input 1 and that no current flows in the circuit e g 37 1 Virtual 1 Incomer 1 Relay is Configured CB1 Open auxiliary switch wired to BI 1 Trip output to CB1 BO 2 OUTPUT CONFIG OUTPUT MATRIX 37 1 V1 OUTPUT CONFIG OUTPUT MATRIX E1 BO3 CONTROL LOGIC QUICK LOGIC E1 O2 I1 V1 The output from Incomer 1 Binary Output 3 relay is input to the relay on CB 3 Binary Input 1 ...

Page 317: ...sed to re trip the local CB to minimise potential disruption to the system if possible via a secondary trip coil and wiring The second CB Failure stage will then be used to back trip the adjacent CB s If the CB is faulty and unable to open a faulty contact can be wired to the CB faulty input of the relay and if a trip occurs while this input is raised the CB fail delay timers may be by passed to a...

Page 318: ...s as below CB Backtrip Sucessful 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 System Fault ms from fault occuring Relay Operation and CBF Timer Started Main Trip Relay Operation Failure of CB to trip Reset of CBF elements does not occur Backtrip Operation Backtrip Trip Relay CB Operate Time Stage 1 CBF Timer Backtrip 120ms Figure 6 1 2 Single Stage Circuit Breaker Fail Timing St...

Page 319: ...or Current Transformer Supervision 60CTS 7PG2114 6 When a CT fails the current levels seen by the protection become unbalanced A large level of NPS current is therefore detected around 0 3 x In for one or two CT failures However this condition would also occur for a system fault To differentiate between the two conditions the element uses NPS voltage to restrain the CTS algorithm as shown in the a...

Page 320: ... possible problems with using NPS quantities due to load imbalances These would also generate significant levels of NPS current and so possibly cause a VT failure to be missed This problem can be overcome by careful selection of settings however setting the NPS current threshold above the level expected for imbalance conditions If a failure occurs in all 3 Phases of a Voltage Transformer then ther...

Page 321: ...essages while the circuit breaker is operating the input is given a 0 4s Drop off Delay in the INPUT CONFIG BINARY INPUT CONFIG menu To provide an alarm output a normally open binary output is mapped to 74TCS n or 74CCS n 6 4 1 Trip Circuit Supervision Connections The following circuits are derived from UK ENA S15 standard schemes H5 H6 and H7 For compliance with this standard Where more than one ...

Page 322: ...it Supervision of trip coil with the circuit breaker Open or Closed It does cheme 3 Comprehensive S not provide pre closing supervision of the connections and links between the tripping contacts and the circuit breaker and may not therefore be suitable for some circuits which include an isolating link S BI ve ve BO BI ve ve TRIP COIL 52a 52b Circuit Breaker TRIP CCT n FAIL BO 1 BO n Remote Alarm 7...

Page 323: ... Overcurrent protection There are 3 methods of detection and blocking during the passage of magnetising inrush current Phase Blocking only occurs in those phases where Inrush is detected Large Single Phase Transformers Auto transformers Cross All 3 phases are blocked if Inrush is detected in any phase Traditional application for most Transformers but can give delayed operation for Switch on to Ear...

Page 324: ...ion Counters along with an I2 t Counter to estimate the amount of wear and tear experienced by a Circuit Breaker Alarm can be provided once set levels have been exceeded Typically estimates obtained from previous circuit breaker maintenance schedules or manufacturers data sheets are used for setting these alarm levels The relay instrumentation provides the current values of these counters ...

Page 325: ...r Phone 49 180 524 70 00 Fax 49 180 524 24 71 Charges depending on provider E mail support energy siemens com Power Distribution Division Order No C53000 G7076 C45 2 Printed in Fürth Printed on elementary chlorine free bleached paper All rights reserved Trademarks mentioned in this document are the property of Siemens AG its affili ates or their respective owners Subject to change without prior no...

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