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Siemens 7SR18 Solkor, Manual

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Siemens 7SR18 Solkor Manual Download Page 57

7SR18 Description Of Operation

Unrestricted  Page 54 of 78

©2018 Siemens Protection Devices Limited

4.4

P/F Shots Sub-Menu

This menu allows the Phase fault trip/reclose sequence to be parameterized:-

79 P/F Prot’n Trip1

The first protection Trip in the P/F sequence can be set to either

Inst

 or

Delayed.

79 P/F Deadtime 1

Sets the first Reclose Delay (Dead time) in the P/F sequence.

79 P/F Prot’n Trip2

The second protection Trip in the P/F sequence can be set to either

Inst

 or

Delayed.

79 P/F Deadtime 2

Sets the second Reclose Delay (Dead time) in the P/F sequence.

79 P/F Prot’n Trip3

The third protection Trip in the P/F sequence can be set to either

Inst

 or

Delayed.

79 P/F Deadtime 3

Sets the third Reclose Delay (Dead time) in the P/F sequence.

79 P/F Prot’n Trip 4

The fourth protection Trip in the P/F sequence can be set to either

Inst

 or

Delayed.

79 P/F Deadtime 4

Sets the fourth Reclose Delay (Dead time) in the P/F sequence.

79 P/F Prot’n Trip5

The fifth and last protection Trip in the P/F sequence 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 Delayed
Trips before the Relay goes to Lockout – that sequence will be truncated.

79 P/F Delayed Trips to Lockout

Sets the number of allowed Delayed trips, Relay will go to Lockout on the last

Delayed Trip. This function limits the number of Delayed trips that the Relay can
perform when the Instantaneous protection Elements are externally inhibited for
system operating reasons - sequences are truncated.

4.5

E/F Shots Sub-Menu

This menu allows the Earth Fault trip/reclose sequence to be parameterized:-

As above but E/F settings.

Summary of Contents for 7SR18 Solkor

Page 1: ...Energy Management 7SR18 Solkor Line Differential Relay Reyrolle Protection Devices ...

Page 2: ...Siemens Protection Devices Limited 2 ...

Page 3: ...s 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 2016 Siemens Protection Devices Limited Contents T...

Page 4: ...out the permission of Siemens Protection Devices Limited 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 ...

Page 5: ...s issue 2018 07 2016 11 First Issue 2017 05 Typographical revisions amended drawings 2017 11 Typographical revisions added data 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 6: ...ent Protection Phase Overcurrent 67 50 51 32 3 3 1 Directional Control of Overcurrent Protection 67 32 3 3 2 Instantaneous Overcurrent Protection 50 33 3 3 3 Time Delayed Overcurrent Protection 51 35 3 3 4 Voltage Controlled Overcurrent 51V 37 3 4 Current Protection Derived Earth Fault 67N 51N 50N 38 3 4 1 Directional Control of Derived Easrth Fault Protection 67N 38 3 4 2 Instantaneous Derived Ea...

Page 7: ... Harmonic Block Inrush Restraint 81HBL2 phase elements only 69 Section 6 Other Features 70 6 1 Data Communications 70 6 2 IEC 61850 Communications 70 6 3 Maintenance 71 6 3 1 Output Matrix Test 71 6 3 2 CB Counters 71 6 3 3 I 2 t CB Wear 71 6 3 4 Start Count 71 6 4 Data Storage 72 6 4 1 General 72 6 4 2 Demand 72 6 4 3 Event Records 72 6 4 4 Waveform Records 72 6 4 5 Fault Records 73 6 4 6 Disk Ac...

Page 8: ...nications Signalling Supervision 31 Figure 3 3 1 1 Logic Diagram Directional Overcurrent Element 67 33 Figure 3 3 2 1 Logic Diagram Instantaneous Over current Element 34 Figure 3 3 3 1 Logic Diagram Time Delayed Overcurrent Element 36 Figure 3 3 4 1 Logic Diagram Voltage Controlled Overcurrent Element 37 Figure 3 4 1 1 Logic Diagram Derived Directional Earth Fault Protection 38 Figure 3 4 2 1 Logi...

Page 9: ...5 4 1 Logic Diagram Broken Conductor Function 46BC 67 Figure 5 5 1 Logic Diagram Trip Circuit Supervision Feature 74TCS 68 Figure 5 5 2 Logic Diagram Close Circuit Supervision Feature 74CCS 68 Figure 5 6 1 Functional Diagram for Harmonic Block Feature 81HBL2 69 Figure 6 4 7 1Energy Direction Convention 74 ...

Page 10: ...2 1 1 Summary of 7SR18 Relay Configuration 16 Table 2 4 1 Power Supply Unit PSU options 19 Table 6 6 1 Operating Mode 76 Symbols and Nomenclature The following notational and formatting conventions are used within the remainder of this document Setting Menu Location MAIN MENU SUB MENU Setting Elem name Setting Setting value value Alternatives 1st 2nd 3rd ...

Page 11: ...s live voltage before accesses to potentially hazardous live parts is affected 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 2 EXTERNAL RESISTORS Where external resistors are fitted to the circuit these may present a danger of electric shock or burns if touc...

Page 12: ...tical Ethernet Duplex x2 rear port 8 7 Protocol IEC 60870 5 103 and Modbus RTU and DNP 3 0 user selectable 2 IEC 60870 5 103 and Modbus RTU and DNP 3 0 user selectable and IEC61850 7 Spare 0 Protection Function Packages Standard version C 87L 3 Phase differential with variable settings 87HS 3 Phase Differential High Set 85 Inter Trip 50 Instantaneous phase fault overcurrent 50G 50N Instantaneous e...

Page 13: ... 50 x2 51 x2 50 x2 50 x2 51 x2 51 x2 50G x2 51G x2 50 BF NOTE The use of some functions are mutually exclusive 81HBL2 37G x2 87L Diff x2 87L Diff x2 87L Diff x2 81HBL2 60 CTS 51N x2 50N x2 51c x2 46 NPS x2 46 BC 81HBL2 81HBL2 51c x2 51c x2 74TCS x3 74CCS x3 86 79 Ordering Options Figure 1 4 1 Functional Diagram of 7SR18 Non Directional Three Phase and Earth ...

Page 14: ...7SR18 Description Of Operation Unrestricted 2018 Siemens Protection Devices Limited Page 11 of 78 Figure 1 4 2 Connections Diagram for 7SR18 Non Directional Relay 3BI and 5BO ...

Page 15: ...7SR18 Description Of Operation Unrestricted Page 12 of 78 2018 Siemens Protection Devices Limited Figure 1 4 3 Connections Diagram for 7SR18 Non Directional Relay 6BI and 8BO ...

Page 16: ...CTS 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 50 BF 51V 51V 51V 51c x4 81HBL2 81HBL2 37G x2 60 VTS 87L Diff x2 87L Diff x2 87L Diff x2 79 Ordering Options 74TCS x3 74CCS x3 86 81HBL2 81HBL2 51c x4 51c x4 Figure 1 4 4 Functional Diagram of 7SR18 Directional Three Phase and Earth ...

Page 17: ...7SR18 Description Of Operation Unrestricted Page 14 of 78 2018 Siemens Protection Devices Limited Figure 1 4 5 Connections Diagram for 7SR18 Directional Relay 3BI and 5BO ...

Page 18: ...7SR18 Description Of Operation Unrestricted 2018 Siemens Protection Devices Limited Page 15 of 78 Figure 1 4 6 Connections Diagram for 7SR18 Directional Relay 6BI and 8BO ...

Page 19: ...10 6 7SR1813 1 4 6 8 18 0 7SR1814 1 4 6 8 10 6 7SR1811 2 4 3 3 5 18 0 7SR1812 2 4 3 3 5 10 6 7SR1813 2 4 3 6 8 18 0 7SR1814 2 4 3 6 8 10 6 Relays are assembled from the following PCBs 1 Front Fascia order option CPU 9 configurable LEDs 1 Relay Healthy LED plus 8 configurable LEDs Option 9 configurable LEDs 1 Relay Healthy LED plus 6 Function Keys each with LED Option 2 Current Analogue Output modu...

Page 20: ... withdraw the relay remove the plastic fascia cover by rotating the two securing pins and withdraw using the plastic handles The relay should not be carried using these handles The relay should only be held by the top and bottom plates and the user should not touch the exposed PCB s Figure 2 2 1 Front View of Relay The rear terminal blocks comprise M4 female terminals for wire connections Each ter...

Page 21: ...d Page 18 of 78 2018 Siemens Protection Devices Limited 2 3 Front Cover As standard the relay is supplied with a transparent front cover The front cover is used to secure the relay assembly in the case Figure 2 3 1 Relay with transparent cover ...

Page 22: ...ary supply and binary inputs are made with the Live connection to the ve terminal and Neutral connection to ve If the auxiliary supply voltage falls below the relay minimum operate level the PSU will automatically switch itself off and latch out which prevents any PSU overload conditions occurring The PSU is reset by switching the auxiliary supply off and on The relay has a non serviceable interna...

Page 23: ... suffix Product name e g Solkor Nominal current rating In Rated frequency fn Auxiliary supply rating Vx Binary input supply rating BI Serial number F No 2 Blank label for user defined information Figure 2 5 2 Close up of Typical Relay Label A template is available in Reydisp Evolution Help Open Relay LED Template to allow users to create and print customised labels For information and safety reaso...

Page 24: ...tion General Alarms are user defined text messages displayed on the LCD when mapped to binary or virtual inputs Up to six general alarms of 16 characters can be programmed each triggered from one or more input Each general alarm will also generate an event If multiple alarms are activated simultaneously the messages are displayed on a separate page in a rolling display on the LCD The System Config...

Page 25: ...ther a Start Pickup or Operate condition exists LED s can be assigned to the pick up condition and colour selected in the OUTPUT CONFIG LED CONFIG menu Functions are assigned to the LEDs in the OUTPUT CONFIG OUTPUT MATRIX menu Each LED can be labelled by withdrawing the relay and inserting a label strip into the pocket behind the front fascia A template is available in the Reydisp software tool to...

Page 26: ... The user can assign any binary input to any of the available functions INPUT CONFIG INPUT MATRIX Pick up PU and drop off DO time delays are associated with each binary input Where no pick up time delay has been applied the input may pick up due to induced ac voltage on the wiring connections e g cross site wiring The default pick up time of 20 ms provides ac immunity Each input can be programmed ...

Page 27: ... be used to operate the trip coils of the circuit breaker directly where the trip coil current does not exceed the make and carry contact rating The circuit breaker auxiliary contacts or other in series auxiliary device must be used to break the trip coil current Any BO can be assigned as a Trip Contact in the OUTPUT CONFIG TRIP CONFIG menu Operation of a Trip Contact will operate any LED or virtu...

Page 28: ... hand reset outputs will reset When the auxiliary supply is re established the binary output will remain in the reset state unless the initiating condition is still present Notes on General Pickup An output General Pickup is available to indicate that the pickup level has been exceeded for one or more protection functions Any protection function can be mapped to trigger this output in the OUTPUT C...

Page 29: ...Various types of start up are monitored by the relay 1 power on starts auxiliary supply initiation 2 expected starts user initiated via comms language changes custom protection curve etc 3 unexpected starts caused by the relay watchdog Any combination of these can be selected for the start up count This is done in the MAINTENANCE MENU START COUNT menu using the Start Up Types setting All the start...

Page 30: ...3 Typical Start up Events Text 2 11 1 Protection Healthy Defective When the relay has an auxiliary DC supply and it has successfully passed its self checking procedure then the front facia Protection Healthy LED is turned on A changeover or open contact can be mapped via the binary output matrix to provide an external protection healthy signal A changeover or closed contact can be mapped via the b...

Page 31: ...nt current is calculated from the total current of IL and IR currents i e I restrain Within the relay the fundamental frequency RMS line currents are modified by the CT Multiplier settings before being applied to the biased differential elements The CT Multiplier setting is applied to the line currents the CT secondary currents The multiplier is used to correct any CT ratio mismatch so that ideall...

Page 32: ...c The phase independent reversal feature Gn Phase n Reversal in the CT VT Config Menu is defaulted to Disabled and is intended for use where CTs have been connected incorrectly c Pickup Operate 1 1 General Pickup 87L n 87L n 1st Bias Slope Limit Enable 87L n 1st Bias Slope 87L n Initial Setting IL1 IL2 IL3 Inhibit 87L n 87L n Element Enabled Disabled c Pickup Operate c Pickup Operate 87L n Delay 8...

Page 33: ...al highset characteristic The differential highset elements calculate the operate current for each phase from the vector sum of local relay and remote relay currents i e IOPERATE IL IR 87HS Setting defines the differential current required to operate the element The output of 87HS Delay can be mapped to relay outputs Operation of the highset differential elements can be inhibited from Inhibit 87HS...

Page 34: ...ts 87R n The line differential elements 87L 1 and 87L 2 each have their associated inter trip element e g 87R 1 87R 2 These are used to ensure both ends of a feeder are cleared when internal fault differential protection has operated When an internal fault occurs even if it is fed largely from one end the differential comparators at both ends operate identically and trip their respective circuit b...

Page 35: ... 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 i e for normal phase sequence 1 2 3 IL1 V23 IL2 V31 IL3 V12 When the device is applied to reverse sequence networks i e 1 3 2 the polarizing is corrected internally by the Gn Phase Rotation setting in the CT VT Config menu The chara...

Page 36: ...0 n Delay follower time delay The instantaneous elements have transient free operation Where directional elements are present the direction of operation 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 in...

Page 37: ...7SR18 Description Of Operation Unrestricted Page 34 of 78 2018 Siemens Protection Devices Limited Figure 3 3 2 1 Logic Diagram Instantaneous Over current Element ...

Page 38: ...me delayed reset or when the operation is configured as an IEC or ANSI or user characteristic if the reset is selected as IEC ANSI DECAYING reset the associated reset curve will be used 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 51 n Min Operate Time setting A fi...

Page 39: ...7SR18 Description Of Operation Unrestricted Page 36 of 78 2018 Siemens Protection Devices Limited Figure 3 3 3 1 Logic Diagram Time Delayed Overcurrent Element ...

Page 40: ...put Ph Ph control voltages below VCO Setting 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...

Page 41: ...enever 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 polarising voltage is not available e g when a two phase phase to phase connected VT is installed then negative sequence voltage and negative sequence currents must be used...

Page 42: ...ansient 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 50 n element Operation of the instantaneous earth fault elements can be inhibited from Inhibit 50N n A binary or virtual input 79 E F Inst Trips 50N n When delayed trips only are allowed in the auto reclose sequence...

Page 43: ... time multiplier is not applied and the 51N n Delay DTL setting is used instead The 51 n Reset setting can apply a definite time delayed reset or when the operation is configured as an IEC or ANSI or user characteristic if the reset is selected as IEC ANSI DECAYING reset the associated reset curve will be used The reset mode is significant where the characteristic has reset before issuing a trip o...

Page 44: ...c angle is the phase angle by which the polarising voltage must be adjusted such 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 f...

Page 45: ... n Setting and a follower time delay 50G n Delay The instantaneous elements have transient free operation 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 51N n When delayed trips only are allowed in the auto reclose sequence 79 E F Prot n Trip n Delayed 50 n Inrush Action Block Operation of the inrush curr...

Page 46: ...is selected as IEC ANSI DECAYING reset the associated reset curve will be used 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 operate time can be added to the characteristic using 51G n Follower DTL setting Where dire...

Page 47: ...directional settings applied in the Phase Overcurrent menu are still applicable A CB Don t Believe It DBI alarm condition see Section 4 3 is not acted on causing the element to remain operating in accordance with the relevant 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...

Page 48: ...definite minimum time IDMT characteristic is selected from 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 setti...

Page 49: ...ing sets the pick up current An output is given after elapse of the 37 n Delay setting when either any or all phases have operated depending upon setting An output is also given to indicate the operated phase All under current elements work with True RMS currents Operation of the under current elements can be inhibited from Inhibit 37 n A binary or virtual input 37U I Guard Setting 0 05 0 1 5xIn F...

Page 50: ...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 can be predicted for any st...

Page 51: ...A fault is detected if the measured current is above the LC n Setting level for a period greater than the LC n Delay Two line check elements are provided LC 1 and LC 2 for each fault type phase and earth in the CURRENT PROT N LINE CHECK menu The feature will remain enabled until the CB has been closed for a duration equal to the Close CB Pulse Reclaim Timer AR option settings in the CIRCUIT BREAKE...

Page 52: ...a 79 OUT binary input Note the 79 OUT binary input has priority over the 79 IN binary input if both are raised the auto reclose will be Out of 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 inp...

Page 53: ...onality need to be wired to the binary inputs Functions which can be mapped to these binary inputs include 79 Out edge triggered 79 In edge triggered CB Closed CB Open 79 Ext Trip 79 Ext Pickup 79 Block Reclose Block Close CB Close CB 79 Trip Reclose 79 Trip Lockout 79 Line Check Hot Line In Hot Line Out Outputs Outputs are fully programmable to either binary outputs or LEDs Programmable outputs i...

Page 54: ...nction recognizes developing faults and as the shot count advances automatically applies the correct type 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...

Page 55: ...Reclose Block is cleared before this time expires then the CB Close pulse will be issued at that point in time Dead Time Reclose Blocked Delay Lockout 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 Lo...

Page 56: ...is received while a Manual Close operation is in progress the feature is immediately locked out Once the Lockout condition has been reached it will be maintained until reset The following 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 ...

Page 57: ...e 4 Sets the fourth Reclose Delay Dead time in the P F sequence 79 P F Prot n Trip5 The fifth and last protection Trip in the P F sequence 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...

Page 58: ... which can be mapped to a Binary output to Block an External Protection 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 pr...

Page 59: ...7SR18 Description Of Operation Unrestricted Page 56 of 78 2018 Siemens Protection Devices Limited Figure 4 6 1 Basic Auto Reclose Sequence Diagram ...

Page 60: ...ked Close Delay The close command may be delayed by a Block Close CB signal applied to a binary input This causes the feature to pause before it issues the CB close command and can be used for example to delay CB closure until the CB energy has reached an acceptable level If the Block signal has not been removed before the end of the defined time Blocked Close Delay the relay will go to the lockou...

Page 61: ...p Time When this is set to Enabled the relay will measure the CB trip time following operation of either a CB control open output or a CB Trip output The trip time is displayed by the MAINTENANCE METERS CB Trip Time meter When this is set to Disabled the relay will measure the trip time following operation of a CB Trip output only Operation of a CB control open output will then not cause the trip ...

Page 62: ...een the trip being issued and the CB auxiliary contacts changing state If this measured time exceeds the Trip Time Alarm time a Trip Time Alarm output is issued Trip Time Adjust This allows for the internal delays caused by the relay especially the delay before a binary input operates to be subtracted from the measured CB trip time This gives a more accurate measurement of the time it took for the...

Page 63: ...l I O de energised Example Showing Use of Nomenclature E1 I1 V1 O2 L1 Equation 1 Binary Input 1 XOR Virtual I O 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...

Page 64: ... count value En Counter Target the output of the counter En 1 and this value is held until the initiating 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 Virtua...

Page 65: ...BF Mech Trip 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 cl...

Page 66: ...VTS Delay 3 Phase Failure Detection Under normal load 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...

Page 67: ...7SR18 Description Of Operation Unrestricted Page 64 of 78 2018 Siemens Protection Devices Limited Figure 5 2 1 Logic Diagram Circuit Breaker Fail Protection 50BF ...

Page 68: ...ents falls below the CT supervision current setting CTS I for more than 60CTS I Delay then a CT failure output 60CTS Operated is given If all three input currents fall below the setting CT failure is not raised An output is also given to indicate the faulted phase 60CTS I PhA 60CTS I PhB and 60CTS I PhC Operation of the CT supervision elements can be inhibited from Inhibit 60CTS I A binary or virt...

Page 69: ...te a current transformer failure The element has a setting for NPS current level 60CTS Inps and a setting for NPS voltage level 60CTS Vnps If the negative sequence current exceeds its setting while the negative sequence voltage is below its setting for more than 60CTS Delay then a CT failure output 60CTS Operated is given Operation of the CT supervision elements can be inhibited from Inhibit 60CTS...

Page 70: ...he 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 46BC U C Guard A minimum load current 46BC U C Guard Setting 0 05 0 1 5x In Figure 5 4 1 Logic Diagram Broken Conductor Function 46BC ...

Page 71: ...h that at least one input is energised when the trip circuit wiring is intact If all mapped inputs become de energised due to a break 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 ...

Page 72: ...to select between Phase Sum and Cross methods of measurement Phase Each phase is inhibited separately Sum With this method the square root of the sum of the squares of the second harmonic in each phase is compared to each operate current individually Cross All phases are inhibited when any phase detects an inrush condition An output is given where the measured value of the second harmonic componen...

Page 73: ...control functions Reydisp is compatible with IEC60870 5 103 6 2 IEC 61850 Communications The relay can optionally be provided with IEC61850 comms IEC61850 is provided with an added EN100 communication module The following EN100 output alarms are provided EN100 Life When the relay is powered up the EN100 Module initializes with the relay When initialization is successful this point becomes true EN1...

Page 74: ...een visits to a substation CB Frequent Ops Count Logs the number of trip operations in a rolling window period of one hour An output is available to reset this counter Binary outputs can be mapped to each of the above counters these outputs are energised when the user defined Count Target or Alarm Limit is reached 6 3 3 I2 t CB Wear An I 2 t counter is also included this can provide an estimation ...

Page 75: ...ent occurs the actual event condition is logged as a record along with a time and date stamp to a resolution of 1 millisecond There is capacity for a maximum of 1000 event records that can be stored in the relay and when the event buffer is full any new record will over write the oldest Stored events can be erased using the DATA STORAGE Clear Events setting or from Reydisp Evolution The following ...

Page 76: ... The fault type is then displayed with the date the fault occurred The fascia prompts the user to press the TEST RESET button to view the details of this fault 3 The information regarding the fault is then displayed The user then presses the TEST RESET button to return to the home screen 4 Pressing the TEST RESET button one further time will reset the relay With the Trip Alert setting disabled the...

Page 77: ...MPORT REACTIVE VAr EXPORT 0 90 180 90 POWER FACTOR LAGGING ACTIVE W EXPORT REACTIVE VAr EXPORT ACTIVE ENERGY EXPORT watts forward IEC CONVENTION ve watts Figure 6 4 7 1 Energy Direction Convention Setting either the Export Power W or Lag VAr VAr to be ve will reverse the Direction of the Energy transfer for these quantities So forward VAr will then be reported as Imported Reactive Energy and forwa...

Page 78: ... The text displayed in the relays Instruments Mode associated with each value can be changed from the default text using the Reydisp software tool The user can add the meters that are most commonly viewed to a Favourites window by pressing ENTER key when viewing a meter The relay will scroll through these meters at an interval set in the System Config Favourite Meters Timer menu The energy storage...

Page 79: ... Enabled Fascia Enabled Enabled Enabled USB Disabled Enabled Enabled Historical Information Waveform Records Enabled Enabled Enabled Event Records Enabled Enabled Enabled Fault Information Enabled Enabled Enabled Setting Information Enabled Enabled Enabled 6 7 Control Mode This mode provides convenient access to commonly used relay control and test functions When any of the items listed in the con...

Page 80: ...ydisp Evolution communications support software 6 8 2 Time Synchronisation Binary Input A binary input can be mapped Clock Sync from BI The seconds or minutes will be rounded up or down to the nearest value when the BI is energised This input is leading edge triggered 6 9 Settings Groups The relay provides four groups of settings Group number Gn 1 to 4 At any one time only one group of settings ca...

Page 81: ...e activated by using the password to gain access and by entering the password NONE Again this must be entered twice to de activate the security system As soon as the user attempts to change a setting or initiate control the password is requested before any changes are allowed Once the password has been validated the user is logged on and any further changes can be made without re entering the pass...

Page 82: ...ithout the permission of Siemens Protection Devices Limited 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 negligen...

Page 83: ... 2018 07 2016 11 First issue 2017 05 Typographical revisions drawing amendments 2017 11 Typographical revisions drawing amendments 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 84: ...l Rear EN100 Ethernet Module 9 3 1 4 Configuring Relay Data Communication 10 3 1 5 Configuring Relay Protection Communication Address 10 3 1 6 Optional Rear EN100 Ethernet Module COM3 11 3 1 7 Connecting to the Relay via Reydisp Evolution 11 List of Figures Figure 1 1 1 Menu Navigation 4 Figure 1 1 2 Contrast symbol 4 Figure 1 1 3 Relay Fascia Please note fascia may differ from illustration 5 Figu...

Page 85: ...de allows the user to view the relay meters e g current etc Fault Data Mode allows the user to view the type and data of any fault that the relay has detected Control Mode allows the user to control external plant under the relays control for example the CB if allowed via the control mode password The menus can be viewed via the LCD by pressing the access keys as below Figure 1 1 1 Menu Navigation...

Page 86: ...7SR18 Configuration Guide Unrestricted 2015 Siemens Protection Devices Limited Page 5 of 1 Figure 1 1 3 Relay Fascia Please note fascia may differ from illustration ...

Page 87: ...nd Fault data 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 valu...

Page 88: ...X BINARY INPUT CONFIG OUTPUT MATRIX BINARY OUTPUT CONFIG LED CONFIG PICKUP CONFIG CB COUNTERS I 2T CB WEAR CONTROL MODE CB TRAVELLING CLOSE I OPEN AR OUT OF SERVICE AR TRIP RECLOSE AR TRIP LOCKOUT E F IN HOTLINE WORKING OUT INST PROT N IN IN I OUT CONFIRM ACTION CONFIRM ACTION IN I OUT IN I OUT IN I OUT FAVOURITE METERS CURRENT METERS THERMAL METERS AUTORECLOSE METERS MAINTENANCE METERS GENERAL AL...

Page 89: ...e www energy siemens com and found under the submenu Software This software requires windows 2000 service pack 4 or above or windows XP with service pack 2 or above 3 1 Physical Connection The relay can be connected to Reydisp Evolution via any of the communication ports on the relay Suitable communication Interface cable and converters are required depending which port is being used 3 1 1 Front U...

Page 90: ...ctor 14 18 RS485 Screened twisted pair Rear terminals RS232 straight through cable or RS232 to USB converter cable Figure 3 1 2 1 Standard rear RS485 connection to a PC 3 1 3 Optional Rear EN100 Ethernet Module Connections are made on the rear underside of the relay either RJ45 sockets electrical or Duplex LC fibre optic connectors depending on the option ordered Figure 3 1 3 1 EN100 Ethernet Modu...

Page 91: ...tocol OFF IEC60870 5 103 MODBUS RTU DNP3 0 IEC60870 5 103 COM1 is the rear mounted RS485 port COM1 RS485 Baud Rate 75 110 150 300 600 1200 2400 4800 9600 19200 38400 19200 COM1 RS485 Parity NONE ODD EVEN EVEN COM2 USB Protocol OFF IEC60870 5 103 DNP3 0 MODBUS RTU ASCII IEC60870 5 103 COM2 is the front USB port COM2 USB Baud Rate 75 110 150 300 600 1200 2400 4800 9600 19200 38400 57600 115200 23040...

Page 92: ...and Reydisp Manager software via the Ethernet interface is not available 3 1 7 Connecting to the Relay via Reydisp Evolution When Reydisp Evolution software is running all available communication ports of the PC will automatically be detected On the start page tool bar open up the sub menu File Connect The Communication Manager window will display all available communication ports With the preferr...

Page 93: ...7SR18 Configuration Guide Unrestricted Page 12 of 12 2015 Siemens Protection Devices Limited ...

Page 94: ...ithout the permission of Siemens Protection Devices Limited 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 negligen...

Page 95: ...sue 2018 07 2016 11 First issue 2017 05 Typographical revisions drawing amendments 2017 11 Typographical revisions added data 2018 07 Revised data Comms drawings additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 96: ...urations 19 Section 6 Data Comms Connections 20 6 1 RS485 Connection 20 6 2 Protection Signalling Communication Connection 21 6 3 Additional Optional Ethernet Connection for IEC 61850 21 6 4 Ethernet Network Redundancy IEC 61850 22 6 4 1 RSTP Rapid Spanning Tree Protocol 22 6 4 2 PRP Parallel Redundancy Protocol 23 6 4 3 HSR High Availability Seamless Redundancy Protocol 24 List of Figures Figure ...

Page 97: ...7SR18 Installation Guide Unrestricted Page 4 of 24 2018 Siemens Protection Devices Limited List of Tables Table 1 EN100 Redundancy availability 22 ...

Page 98: ...uent repairs 1 3 Recommended Mounting Position The relay uses a liquid crystal display LCD for programming and operation The LCD has a vertical viewing angle of 30 and is back lit However the best viewing position is at eye level and this is particularly important given its control features The relay should be mounted on the circuit breaker or protection panel to allow the operator the best access...

Page 99: ...on the products packaging and or accompanying documents means that used electrical and electronic products and batteries must not be mixed with normal household waste According to national legislation penalties may be charged for incorrect disposal of such waste By disposing of these products correctly you will help to save valuable resources and prevent any potential negative effects on human hea...

Page 100: ...re external resistors are connected to the relay circuitry these may present a danger of electric shock or burns if touched 2 3 Fibre Optic Communication Where fibre optic communication ports are fitted the lasers are Class 1 devices but recommend they should not be viewed directly Optical power meters should be used to determine the operation or signal level of the device 2 4 Front Cover The fron...

Page 101: ...elay Dimensions and Weight Relays are supplied in the modular size E6 The following drawing which is available from the website gives panel cut out and mounting details Figure 3 1 1 Overall Dimensions and Panel Drilling for Size E6 Epsilon Case Hardware Model Net Weight Kg 7SR1811 4 26 kg 7SR1812 4 26 kg 7SR1813 4 26 kg 7SR1814 4 26 kg ...

Page 102: ...e recommended 3 2 2 Panel Fixings Typical mounting screw kit per Relay consists of the following 4 off M4x10 mm 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 the following 28 off M4 8 mm Screws 28 off M4 Lock Washer Relay rear retaining screw 1 off M3x8 mm Screw ...

Page 103: ...ewed from rear Typical Notes 1 Recommended terminations are pre insulated and must be crimped using approved tooling 2 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 ...

Page 104: ...7SR18 Installation Guide Unrestricted 2018 Siemens Protection Devices Limited Page 11 of 24 Figure 4 1 2 E6 Case Terminal Arrangement viewed from rear Typical ...

Page 105: ... Guide Unrestricted Page 12 of 24 2018 Siemens Protection Devices Limited Section 5 Connection Wiring Diagrams 5 1 Wiring Diagram 7SR18 Relay with 3BI 5BO Figure 5 1 1 Connection Diagram for Non Directional Relay 3BI 5BO ...

Page 106: ...7SR18 Installation Guide Unrestricted 2018 Siemens Protection Devices Limited Page 13 of 24 5 2 Wiring Diagram 7SR18 Relay with 6BI 8BO Figure 5 2 1 Connection Diagram for Non Directional Relay 6BI 8BO ...

Page 107: ...7SR18 Installation Guide Unrestricted Page 14 of 24 2018 Siemens Protection Devices Limited 5 3 Wiring Diagram 7SR18 Relay with 3BI 5BO Figure 5 3 1 Connection Diagram for Directional Relay 3BI 5BO ...

Page 108: ...7SR18 Installation Guide Unrestricted 2018 Siemens Protection Devices Limited Page 15 of 24 5 4 Wiring Diagram 7SR18 Relay with 6BI 8BO Figure 5 4 1 Connection Diagram for Directional Relay 6BI 8BO ...

Page 109: ...cal Current Transformer Configurations Relay Current Configuration Setting Description Connection In 50G 51G Measured E F IREF 64H Measured Restricted E F Ia Ib Ic In CT VT CONFIG Phase Current Input Phase CT Ratio 50 51 Phase Overcurrent 50N 51N Derived E F Selects 1 or 5A CT ratio for primary meters ...

Page 110: ...ns Protection Devices Limited Page 17 of 24 Ia Ib Ic In Ig CT VT CONFIG Phase Current Input Phase CT Ratio Earth Current Input Earth CT Ratio 50 51 Phase Overcurrent 50N 51N Derived E F 50G 51G Measured E F Selects 1 or 5A CT ratio for primary meters ...

Page 111: ... Unrestricted Page 18 of 24 2018 Siemens Protection Devices Limited Ia Ib Ic In Ig CT VT CONFIG Phase Current Input Phase CT Ratio Phase Overcurrent Derived E F Measured Standby E F Selects 1 or 5A CT ratio for primary meters ...

Page 112: ...lay Voltage Configuration Setting Description Connection Van Vbn Vcn 67 67N 67G 47 59N 27 59 81 Phase Neutral Phase Phase Calculated NPS ZPS Va Vb Vc 67 67N 67G 47 27 59 81 Phase Neutral Phase Phase Calculated NPS No ZPS available Vab Vbc 3Vo 67 67N 67G 47 59N 27 59 81 Phase Neutral Calculated Phase Phase Phase Vca Calculated NPS ZPS ...

Page 113: ...line with the RS485 standard The polarity is that when the bus is in the quiescent state and no communication is taking place the B terminal is more positive than A This can be used to identify the polarity of any equipment to be connected typically measured at each terminal in turn to ground Connection of the device to a termination network at the end of the bus will also be to suit the quiescent...

Page 114: ... Ch 2 comprises Duplex LC 100BaseF in acc With IEEE802 3 Fibre Optic or RJ45 100BaseF in acc With IEEE802 3 electrical connectors When installing fibre ensure that the fibres bend radii comply with the recommended minimum for the fibre used typically 50 mm is acceptable 62 5 125 µm glass fibre with Duplex LC connector recommended for all distances To Control System Switch Ch n Ch 2 Ch 1 62 5 125 µ...

Page 115: ...ng on the EN100 module type and Firmware version the following protocol options are available Interface Type EN100 Firmware Line Mode Switch Mode RSTP OSM PRP HSR Electrical RJ45 EN100 4 08 or earlier ü û û û û Electrical RJ45 EN100 4 21and later ü û û ü û Optical EN100 4 08 or earlier ü ü ü û û Optical EN100 4 21and later ü ü ü ü ü Table 1 EN100 Redundancy availability 6 4 1 RSTP Rapid Spanning T...

Page 116: ... is based on double transmission of message frames over ring topology networks in both directions In the case of an error the message frame will be transmitted without any delay No reconfiguration time is necessary for the network as is the case for RSTP PRP need to be enabled on the device within Reydisp Manager See Reydisp Manager userguide Figure 6 4 2 1 PRP Ethernet Network Configuration ...

Page 117: ...ased on double transmission of message frames over ring topology networks in both directions In the case of an error the message frame will be transmitted without any delay No reconfiguration time is necessary for the network HSR needs to be enabled on the device within Reydisp Manager See Reydisp Manager user guide Network rings with up to 50 devices is possible Figure 6 4 3 1 HSR Ethernet Networ...

Page 118: ...out the permission of Siemens Protection Devices Limited 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 ...

Page 119: ... and including this issue is 2016 11 First issue 2017 11 Typographical revisions drawing amendments added data 2018 02 Typographical revisions drawing amendments added data 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 120: ...otection 11 1 5 2 Protection Interfaces 11 1 6 Environmental Performance 13 1 6 1 General 13 1 6 2 Emissions 14 1 6 3 Immunity 15 1 6 4 Mechanical 17 Section 2 Protection Functions 18 2 1 37 Undercurrent 18 2 1 1 Reference 18 2 1 2 Operate and Reset Level 18 2 1 3 Operate and Reset Time 18 2 2 46 Negative Phase Sequence Overcurrent 19 2 2 1 Reference 46DT 19 2 2 2 Operate and Reset Level 46DT 19 2...

Page 121: ... 2 13 1 Reference 38 2 13 2 Operate Time 38 Section 3 Supervision Functions 39 3 1 46BC Broken Conductor 39 3 1 1 Reference 39 3 1 2 Operate and Reset Level 39 3 1 3 Operate and Reset Time 39 3 2 50BF Circuit Breaker Fail 40 3 2 1 Reference 40 3 2 2 Operate and Reset Level 40 3 2 3 Operate and Reset Time 40 3 3 60CTS 60CTS I Current Transformer Supervision 41 3 3 1 Reference 41 3 3 2 Current Volta...

Page 122: ...ter Value Auxiliary supply nominal Frequency nominal Ambient temperature 20 C 1 1 4 Dimensions Parameter Value Width 155 5 mm Height 177 mm Depth behind panel including clearance for Wiring Fibre Optic Ethernet enclosure Depth below Ethernet variant for cables 241 5 mm 286 5 mm 261 5 mm 75 mm Projection from front of panel 31 mm See appropriate case outline and panel drilling drawing as specified ...

Page 123: ...9 68 9 02 9 10 PROT HEALTHY LED all BI all BO all LEDs LCD on 12 38 11 47 11 34 11 00 10 34 10 45 PROT HEALTHY LED BO 1 on LCD on 9 60 8 93 8 76 8 58 7 92 7 98 PROT HEALTHY LED BO 1 on LCD off 8 30 7 87 7 74 7 48 7 04 7 15 Attribute VA AC 50 Hz Voltage V 100 110 115 120 200 230 Quiescent Relay inc PROT HEALTHY LED 18 20 19 36 20 01 20 64 26 60 28 29 PROT HEALTHY LED all BI all BO all LEDs LCD on 1...

Page 124: ...iary input voltage to zero volts for up to 30 seconds before re application of the auxiliary supply will cause the relay to power up and operate normally 1 Using fuses as on off switches or allowing batteries to run at very low cell voltages for extended periods and then attempting to re charge them are examples of such auxiliary supply conditions 1 2 2 AC Analogue Current Nominal Measuring Range ...

Page 125: ... of 10 mA or 5 V 1 2 5 Binary Digital Inputs DC operation Nominal Operating Range VBI 19 V DC 17 V DC to 320 V DC 88 V DC 74 V DC to 320 V DC AC operation Nominal Operating Range VBI 19 V DC 92 VRMS to 138 VRMS 1 2 5 1 DC Performance Attribute Value Maximum DC current for operation VBI 19 V 1 5 mA VBI 88 V 1 5 mA Reset Operate voltage ratio 90 Response time 9 ms Response time when programmed to en...

Page 126: ... ms For AC operation wiring should be less than 10 metres in length 1 3 Functional performance 1 3 1 Instrumentation Instrument Value Reference Typical accuracy I Current 0 1 xIn I 3 0 xIn 1 In V Voltage 0 8 xVn V 1 2 xVn 1 Vn W Var VA Power real and apparent V Vn I 0 1 xIn pf 0 8 3 Pn where Pn Vn x In pf Power factor V Vn I 0 1 xIn pf 0 8 0 05 F Frequency F 47 5 to 52 5Hz 50Hz and 57 to 63Hz 60Hz...

Page 127: ...e Optic Ethernet Data Communication Interface IEC61850 Option Attribute Value Physical layer Fibre optic Connectors Duplex LC 100BaseF in acc With IEEE802 3 Recommended fibre 62 5 125 µm glass fibre with Duplex LC connector Transmission Speed 100 MBits s Optical Wavelength 1300 nm Bridgeable distance 2 km 1 4 4 Electrical Ethernet Data Communication Interface IEC61850 Option Attribute Value Physic...

Page 128: ...ission Level max 10 dBmave min 15 dBmave Typical 12 dBmave Receiver Sensitivity 24 dBmave Optical Wavelength 820 nm Optical Budget 12 dB LED Class 1 Using multi mode fibre 62 5 µm 125 µm Range Assume a path attenuation of 3 5 dB km 5 6 dB mile for multi mode fibre For multi mode fibre you must additionally take the product of the bandwidth lengths into consideration 1 Based on fibre attenuations A...

Page 129: ...tenuation of 0 5 dB km 0 8 dB mile for single mode and multi mode fibre For multi mode fibre you must additionally take the product of the bandwidth lengths into consideration 1 Based on fibre attenuations Assumes no joins in the fibre but includes a 3 dB safety margin Actual losses for specific application should be calculated using cable manufacturers data or by direct measurement using speciali...

Page 130: ...sient Overvoltage IEC 60255 27 Type Level Between all terminals and earth or between any two independent circuits 5 0 kV 1 2 50 µs 0 5 j 1 6 1 4 Insulation Class IEC 60255 27 Type Level Insulation Class when mounted in normal position of use Class I Insulation IEC 60255 27 Type Level Between any terminal and earth 2 5 kV AC RMS for 1 min Between independent circuits Across normally open contacts 1...

Page 131: ...51 Installed with cover removed Rear IP 10 Front IP 20 1 6 2 Emissions 1 6 2 1 Radiated Emissions Enclosure Port IEC 60255 26 Type Limits at 10 m Quasi peak 30 MHz to 230 MHz 40 dB µV m 230 MHz to 1000 MHz 47 dB µV m 1 6 2 2 Conducted Emissions Auxiliary Supply Port IEC 60255 26 Type Limits Quasi peak Average 0 15 MHz to 0 5 MHz 79 dB µV 66 dB µV 0 5 MHz to 30 MHz 73 dB µV 60 dB µV ...

Page 132: ...2 cycles 50 Hz 60Hz Normal operation1 except where Dip falls below the relay minimum voltage then Relay Restart 2 70 RV 25 30 cycles 50 Hz 60 Hz Normal Operation 1 Voltage Interruptions DC auxiliary supply 0 RV 5 s Relay Restart 2 Voltage Interruptions AC auxiliary supply 0 RV 250 300 cycles 50 Hz 60 Hz Relay Reset 2 Alternating Component In DC Ripple DC auxiliary supply 15 max and min RV Continuo...

Page 133: ... Spot 10 V m 1 6 3 5 Fast Transients IEC 60255 26 Type Level Auxiliary Power I O Level Comms Port 5 50 ns 5 kHz repetitive 4 kV 2 kV Note 20 ms drop off delay applied to binary inputs 1 6 3 6 Surge Immunity IEC 60255 26 Type Level Variation Analogue Inputs Auxiliary Power Line to Earth 4 0 kV 10 I O Line to Earth 2 0 kV 10 RS485 Comms port Line to Earth 1 0 kV No Data Loss Analogue Inputs Auxiliar...

Page 134: ...6 4 2 Shock and Bump IEC 60255 21 2 Type Level Variation Shock response 5 gn 11 ms 5 Shock withstand 15 gn 11 ms Bump test 10 gn 16 ms 1 6 4 3 Seismic IEC 60255 21 3 Type Level Variation Seismic response X plane 3 5 mm displacement below crossover frequency 8 Hz to 9 Hz 1 0 gn above 5 Y plane 1 5 mm displacement below crossover frequency 8 Hz to 9 Hz 0 5 gn above 1 6 4 4 Mechanical Classification ...

Page 135: ...0 01 20 00 20 10 100 101 1000 1010 10000 10100 14400 s 2 1 2 Operate and Reset Level Attribute Value Iop Operate level 100 Is 5 or 1 In Reset level 105 Iop Repeatability 1 Variation 10 C to 55 C 5 fnom 5 5 2 1 3 Operate and Reset Time Attribute Value tbasic Element basic operate time 1 1 to 0 5 xIs 35 ms 10 ms top Operate time following delay tbasic td 1 or 10 ms Repeatability 1 or 10 ms Overshoot...

Page 136: ...ribute Value tbasic Element basic operate time Switched from 0 to 2 xIs 40 ms 10 ms Switched from 0 to 5 xIs 30 ms 10 ms top Operate time following delay tbasic td 1 or 10 ms Repeatability 1 or 10 ms Overshoot time 40 ms Disengaging time 60 ms 2 2 4 Reference 46IT Parameter Value char Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 0 025 0 05 1 6 1 7 5 6 100 Is...

Page 137: ... 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 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 char DTL td 1 or 20 ms Reset time ANSI DECAYING Tm R t Is I res 1 2 5 or 50 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 IEC DECAYING Tm R t Is I res 1 2 5 or 50 ms for char IEC NI R 9 7 IEC...

Page 138: ...time 1 2 to 10 x Is τ Time constant setting 1 10 100 1000 min 2 3 2 Operate and Reset Level Attribute Value Iol Overload level 100 Is 5 or 1 In Reset level 95 Iol Repeatability 1 Variation 10 C to 55 C 5 fnom 5 5 2 3 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 or 100 ms Repeatability 100 ms Note Fastest operate time ...

Page 139: ...icted Page 22 of 44 2018 Siemens Protection Devices Limited Figure 2 3 3 1 Thermal Overload Protection Curves 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 ...

Page 140: ...00 14400 s 2 4 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 Variation 10 C to 55 C 5 fnom 5 5 2 4 3 Operate and Reset Time Attribute Value tbasic Element basic operate time Switched from 0 to 2 xIs 35 ms 10 ms Switched from 0 to 5 xIs 25 ms 10 ms top Operate time following delay tbasic td 1 or 10 ms Re...

Page 141: ...0 10000 10100 14400 s 2 5 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 Variation 10 C to 55 C 5 fnom 5 5 2 5 3 Operate and Reset Time Attribute Value tbasic Element basic operate time Switched from 0 to 2 xIs 35 ms 10 ms Switched from 0 to 5 xIs 25 ms 10 ms top Operate time following delay tbasic td 1 ...

Page 142: ...10000 10100 14400 s 2 6 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 Variation 10 C to 55 C 5 fnom 5 5 2 6 3 Operate and Reset Time Attribute Value tbasic Element basic operate time Switched from 0 to 2 xIs 40 ms 10 ms Switched from 0 to 5 xIs 30 ms 10 ms top Operate time following delay tbasic td 1 or...

Page 143: ... Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 0 025 0 05 1 6 1 7 5 6 100 td Delay setting 0 0 01 20 s tres Reset setting ANSI DECAYING 0 1 60 s I Applied Current for operate time IDMTL 2 to 20 x ls DTL 5 x Is 2 7 2 Operate and Reset Level Attribute Value Iop Operate level 105 Is 4 or 1 In Reset level 95 Iop Repeatability 1 Variation 10 C to 55 C 5 fnom 5 5 ...

Page 144: ...28 2 B 0 1217 P 2 0 char DTL td 1 or 20 ms Reset time ANSI DECAYING Tm R t Is I res 1 2 5 or 30 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 IEC DECAYING Tm R t Is I res 1 2 5 or 50 ms for char IEC NI R 9 7 IEC VI R 43 2 IEC EI R 58 2 IEC LTI R 80 tres tres 1 or 20 ms Repeatability 1 or 20 ms Overshoot time 40 ms Disengaging time 50 ms Figure 2 7 3 1 and Figure 2 7 3 4 show the operate...

Page 145: ...of 44 2018 Siemens Protection Devices Limited Figure 2 7 3 1 IEC IDMTL Curves Time Multiplier 1 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 ...

Page 146: ... Siemens Protection Devices Limited Page 29 of Figure 2 7 3 2 ANSI IDMTL Operate Curves Time Multiplier 1 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 ...

Page 147: ...e 30 of 44 2018 Siemens Protection Devices Limited Figure 2 7 3 3 ANSI Reset Curves Time Multiplier 1 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 ...

Page 148: ...7SR18 Performance Specification Unrestricted 2018 Siemens Protection Devices Limited Page 31 of Figure 2 7 3 4 IEC Reset Curves Time Multiplier 1 ...

Page 149: ...xIn Char Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 1 0 0 025 0 05 100 td Delay setting DTL 0 0 01 20 s tres Reset setting ANSI DECAYING 0 1 60 s I Applied current for operate time IDMTL 2 to 20 xIs DTL 5 xIs 2 8 2 Operate and Reset Level Attribute Value Iop Operate level 105 Is 4 or 1 In Reset level 95 Iop Repeatability 1 Variation 10 C to 55 C 5 fnom 5 5...

Page 150: ...28 2 B 0 1217 P 2 0 char DTL td 1 or 20 ms Reset time ANSI DECAYING Tm R t Is I res 1 2 5 or 30 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 IEC DECAYING Tm R t Is I res 1 2 5 or 50 ms for char IEC NI R 9 7 IEC VI R 43 2 IEC EI R 58 2 IEC LTI R 80 tres tres 1 or 20 ms Repeatability 1 or 20 ms Overshoot time 40 ms Disengaging time 50 ms Figure 2 7 3 1 and Figure 2 7 3 4 show the operate...

Page 151: ...xIn char Characteristic setting IEC NI VI EI LTI ANSI MI VI EI DTL Tm Time Multiplier setting 1 0 0 025 0 05 100 td Delay setting 0 0 01 20 s tres Reset setting ANSI DECAYING 0 1 60 s I Applied Current for operate time IDMTL 2 to 20 x Is DTL 5 x Is 2 9 2 Operate and Reset Level Attribute Value Iop Operate level 105 Is 4 or 1 In Reset level 95 Iop Repeatability 1 Variation 10 C to 55 C 5 fnom 5 5 ...

Page 152: ...8 2 B 0 1217 P 2 0 char DTL td 1 or 20 ms Reset time ANSI DECAYING Tm R t Is I res 1 2 5 or 30 ms for char ANSI MI R 4 85 ANSI VI R 21 6 ANSI EI R 29 1 IEC DECAYING Tm R t Is I res 1 2 5 or 50 ms for char IEC NI R 9 7 IEC VI R 43 2 IEC EI R 58 2 IEC LTI R 80 tres tres 1 or 20 ms Repeatability 1 or 20 ms Overshoot time 40 ms Disengaging time 50 ms Figure 2 7 3 1 and Figure 2 7 3 4 shows the operate...

Page 153: ... Angle Attribute Value CA Characteristic angle I with respect to V θ s 5 Operating angle forward CA 85 5 to CA 85 5 reverse CA 180 85 5 to CA 180 85 5 Variation in characteristic angle 10 C to 55 C 5 fnom 5 5 2 10 3 Operate Threshold Attribute Value Minimum levels for operation I p f 5 In I e f 10 In V p f 1 V V e f 1 V 2 10 4 Operate and Reset Time Attribute Value Operate time typically 32 40 ms ...

Page 154: ...evel Attribute Value IOP Operate level 2 nd Bias Slope B I for I M I and I M I and I I RESTRAIN RESTRAIN 2 OPERATE RESTRAIN 1 OPERATE SETTING INITIAL 87 OPERATE Where I operate I restrain 2 B 87BD 1 st Bias slope limit M1 87BD 1 st Bias slope M2 87BD 2 nd Bias slope Operate Level 10 of IOP or 0 1In Reset level 90 of IOP Repeatability 2 Transient overreach 5 Variation 10 C to 55 C fnom 3 Hz to fnom...

Page 155: ...bute Value Iop Operate level 5 of setting or 0 01In Reset level 95 of IOP Repeatability 2 Transient overreach 5 Variation 10 C to 55 C fnom 3 Hz to fnom 2 Hz 2 12 3 Operate and Reset Time Attribute Value tbasic Element basic operate time 1 1 xIn 30 ms to 50 ms Typically 30 ms 2 13 85 Inter trip Element 2 13 1 Reference Attribute Value Delay setting 0 0 005 60 s 2 13 2 Operate Time Attribute Value ...

Page 156: ...Delay setting 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 Variation 10 C to 55 C 5 fnom 5 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 20 ms Repeatability 1 or 20 ms Variation fnom 5 harmo...

Page 157: ...n tCBF1 Stage 1 Delay setting 20 25 60000 ms tCBF2 Stage 2 Delay setting 20 25 60000 ms 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 Variation 10 C to 55 C 5 fnom 5 5 3 2 3 Operate and Reset Time Attribute Value top Stage 1 tCBF1 1 or 20 ms Stage 2 tCBF2 1 or 20 ms Repeatability 1 or 20 ms Overshoot 2 x 20 ms ...

Page 158: ...00 101 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 Variation 10 C to 55 C 5 fnom 5 harmonics to fcutoff 5 3 3...

Page 159: ...lue VNPSop 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 Ipp...

Page 160: ...Operate time following delay tbasic td 1 or 10 ms Repeatability 1 or 10 ms Variation 10 C to 55 C 5 fnom 5 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 due to mag...

Page 161: ...7SR18 Performance Specification Unrestricted Page 44 of 44 2018 Siemens Protection Devices Limited ...

Page 162: ...thout the permission of Siemens Protection Devices Limited 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 negligenc...

Page 163: ...t is issue 2018 07 2016 11 First Issue 2017 05 Typographical revisions drawing amendments 2017 11 Typographical revisions 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 164: ...Meters 6 1 4 Power Meters 7 1 5 Energy Meters 7 1 6 Directional Meters 8 1 7 Prot n Comms Meters 8 1 8 Differential Meters 9 1 9 Thermal Meters 9 1 10 Maintenance Meters 10 1 11 General Alarm Meters 11 1 12 Frequency Meters 11 1 13 Demand Meters 11 1 14 Binary Input Meters 12 1 15 Binary Output Meters 13 1 16 Virtual Meters 13 1 17 Miscellaneous Meters 13 1 18 Auto Reclose Meters 13 1 19 Communica...

Page 165: ... 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 1 2 Current Meters Instrument Description CURRENT METERS to view This is the sub group that includes all the meters that are associated with Current TEST RESET allows access to this sub group Primar...

Page 166: ... o Ipps 0 00xIn o Inps 0 00xIn o Displays the Current Sequence components Nominal RMS values phase angles with respect to PPS current 2 nd Harmonic Current Ia 0 00xIn Ib 0 00xIn Ic 0 00xIn Displays the 3 phase currents 2 nd Harmonic components Nominal RMS values Last Trip P F Ia 0 00A Ib 0 00A Ic 0 00A Displays the 3 phase currents Last Trip RMS values Remote Last Trip P F Ia 0 00A Ib 0 00A Ic 0 0...

Page 167: ...ays the Phase to Phase Voltage Nominal RMS values Prim Ph N Voltage Va 0 00V Vb 0 00V Vc 0 00V Displays the Phase to Neutral Voltage Primary RMS values Sec Ph N Voltage Va 0 00V Vb 0 00V Vc 0 00V Displays the Phase to Neutral Voltage Secondary RMS values Angles with respect to PPS voltage Nom Ph N Voltage Va 0 00xVn o Vb 0 00xVn o Vc 0 00xVn o Displays the Phase to Neutral Voltage Nominal RMS valu...

Page 168: ...ower PF A 0 00 PF B 0 00 PF C 0 00 PF 3P 0 00 Displays Power factor P Phase A 0 00xSn P Phase B 0 00XSn P Phase C 0 00xSn 3P Displays Real Power Q Phase A 0 00xSn Q Phase B 0 00xSn Q Phase C 0 00xSn Q 3P Displays Reactive Power S Phase A 0 00xSn S Phase B 0 00xSn S Phase C 0 00xSn S 3P Displays Apparent Power 1 5 Energy Meters Instrument Description ENERGY METERS to view This is the sub group that...

Page 169: ... the meters that are associated with Current TEST RESET allows access to this sub group PROT N Info Status IN SYNC Displays the Protection Signalling Information PROT N Stats Frames OK 00000000 Errors 0000 Skew 0 000ms Displays the Protection Signalling Status PROT N 0 1s Quality Errors 00 Severe Errors 00 Performance 00 0 Displays the Protection Signalling 0 1 s Quality PROT N 1s Quality Errors 0...

Page 170: ...n o Ic 0 000xIn o Displays Relay currents Nominal RMS values phase angles with respect to PPS voltage Remote Relay Current Ia 0 000xIn o Ib 0 000xIn o Ic 0 000xIn o Displays Remote Relay currents Nominal RMS values phase angles with respect to PPS voltage Operate Current Ia 0 000xIn o Ib 0 000xIn o Ic 0 000xIn o Displays the 3 phase operate currents relevant to the Line differential 87L and highse...

Page 171: ...y the CB CB E F Trips Count 0 Target 100 Displays the number of CB Earth Fault trips experienced by the CB CB Delta Trips Count 0 Target 100 Displays the number of CB trips experienced by the CB CB Count To AR Block Count 0 Target 100 Displays the number of CB trips experienced by the CB When the target is reached the relay will only do 1 Delayed Trip to Lockout CB Freq Ops Count Count 0 Target 10...

Page 172: ...d with Thermal TEST RESET allows access to this sub group Frequency 0 000Hz Displays the power system frequency 2 km Frequency 0 000Hz Last Trip 0 000Hz Displays the power system frequency 40 km 1 13 Demand Meters Instrument Description DEMAND METERS to view This is the sub group that includes all the meters that are associated with the demand metering TEST RESET allows access to this sub group I ...

Page 173: ...Max Min and Mean for Power P 3P Demand Power Q 3P Demand Max 0 0VAr Min 0 0VAr Mean 0 0VAr Shows the Max Min and Mean for Power Q 3P Demand Power S 3P Demand Max 0 0VA Min 0 0VA Mean 0 0VA Shows the Max Min and Mean for Power S 3P Demand Frequency Demand Max 0 000Hz Min 0 000Hz Mean 0 000Hz Shows the Max Min and Mean for System Frequency Demand Power Factor Demand Max 0 00 Min 0 00 Mean 0 00 Shows...

Page 174: ...tion MISCELLANEOUS METERS to view This is the sub group that includes indication such as the relays time and date the amount of fault and waveform records stored in the relay TEST RESET allows access to this sub group Start Alarm Count 00 Target 000 Displays the number of Start Up operations experienced by the relay Date 01 01 2000 Time 22 41 44 Waveform Recs 0 Fault Recs 0 This meter displays the...

Page 175: ...0 000 000 EN100 NTP info EN100 Link status info EN100 Rx Tx Count Displays further EN100 61850 information En100 Rx Tx Error En100 Rx Tx 10s CPU Load EN100 Info Meters 1 n Displays further EN100 61850 information 1 20 Quick Logic Meters Instrument Description QUICK LOGIC METERS to view This is the sub group that includes all the meters that are associated with QuickLogic TEST RESET allows access t...

Page 176: ...trieval system without the permission of Siemens Protection Devices Limited 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 re...

Page 177: ...of revisions up to and including this issue is 2016 11 First issue 2017 05 Typographical revisions drawing amendments 2017 11 Typographical revisions 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 178: ...Solkor Settings Guide Unrestricted 2016 Siemens Protection Devices Limited Page 3 of 44 Function Diagram 2x 50 2x 51N 2x 50N 2x 46 2x 51 49 3I 46BC 50BF 60 CTS I TCS 2x 50G EF 2x 51G EF IEF 2x 37 2x 37 2x 37G ...

Page 179: ...7SR18 Solkor Settings Guide Unrestricted Page 4 of 44 2016 Siemens Protection Devices Limited Typical Menu Structure ...

Page 180: ...art Blocking Disabled Enabled Disabled Unexpected Restart Count 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 3 Unexpected Restart Period 1 2 99 100 1hrs Setting Password Password NONE Control Password Password AAAA Trip Alert Disabled Enabled Enabled General Alarm Alert Disabled Enabled Enabled Relay Identifier 16 Character String FINISHED Circuit Identifier 16 Character String 2 CT VT CONFI...

Page 181: ...Cont O C Enabled Disabled Disabled Gn Cold Load Enabled Disabled Disabled Gn Derived E F Enabled Disabled Disabled Gn Measured E F Enabled Disabled Enabled Gn NPS Overcurrent Enabled Disabled Disabled Gn Under Current Enabled Disabled Disabled Gn Thermal Enabled Disabled Disabled Gn Line Check Enabled Disabled Disabled Gn CB Fail Enabled Disabled Disabled Gn VT Supervision Enabled Disabled Disable...

Page 182: ... 3x Gn 87L 1 1st Bias Slope Limit 0 5 0 6 19 9 20 2xIn Gn 87L 1 2nd Bias Slope 0 5 0 55 1 95 2 1 5x Gn 87L 1 Delay 0 0 005 59 9 60 1s Gn 87L 1 Offset Disabled Enabled Enabled 5 1 2 87L 2 Description Range Default Gn 87L 2 Element Disabled Enabled Disabled Gn 87L 2 Initial Setting 0 1 0 15 2 45 2 5 0 3xIn Gn 87L 2 1st Bias Slope 0 1 0 15 0 2 0 25 0 3 0 35 0 4 0 45 0 5 0 55 0 6 0 65 0 7 0 3x Gn 87L ...

Page 183: ... RMS Fundamental RMS 8 1 1 51 1 Description Range Default Gn 51 1 Element Disabled Enabled Enabled Gn 51 1 Dir Control Non Dir Forward Reverse Non Dir Gn 51 1 Setting 0 05 0 06 2 49 2 5 1xIn Gn 51 1 Char DTL IEC NI IEC VI IEC EI IEC LTI ANSI MI ANSI VI ANSI EI IEC NI Gn 51 1 Time Mult IEC ANSI 0 025 0 03 99 100 1 Gn 51 1 Delay DTL 0 0 01 19 99 20 5s Gn 51 1 Min Operate Time 0 0 01 19 99 20 0s Gn 5...

Page 184: ...1 19 99 20 5s Gn 51 3 Min Operate Time 0 0 01 19 99 20 0s Gn 51 3 Follower DTL 0 0 01 19 99 20 0s Gn 51 3 Reset IEC ANSI Decaying 0 59 60 0s Gn 51 3 VTS Action Off Inhibit Non Dir Off Gn 51 3 Inrush Action Off Inhibit Off 8 1 4 51 4 Description Range Default Gn 51 4 Element Disabled Enabled Disabled Gn 51 4 Dir Control Non Dir Forward Reverse Non Dir Gn 51 4 Setting 0 05 0 06 2 49 2 5 1xIn Gn 51 4...

Page 185: ...ing 0 05 0 06 49 5 50 1xIn Gn 50 3 Delay 0 0 01 14300 14400 0s Gn 50 3 VTS Action Off Inhibit Non Dir Off Gn 50 3 Inrush Action Off Inhibit Off 8 1 8 50 4 Description Range Default Gn 50 4 Element Disabled Enabled Disabled Gn 50 4 Dir Control Non Dir Forward Reverse Non Dir Gn 50 4 Setting 0 05 0 06 49 5 50 1xIn Gn 50 4 Delay 0 0 01 14300 14400 0s Gn 50 4 VTS Action Off Inhibit Non Dir Off Gn 50 4...

Page 186: ...ng 0 59 60 0s Gn 51c 2 Setting 0 05 0 06 2 49 2 5 1xIn Gn 51c 2 Char DTL IEC NI IEC VI IEC EI IEC LTI ANSI MI ANSI VI ANSI EI IEC NI Gn 51c 2 Time Mult IEC ANSI 0 025 0 03 99 100 1 Gn 51c 2 Delay DTL 0 0 01 19 99 20 5s Gn 51c 2 Min Operate Time 0 0 01 19 99 20 0s Gn 51c 2 Follower DTL 0 0 01 19 99 20 0s Gn 51c 2 Reset IEC ANSI Decaying 0 59 60 0s Gn 51c 3 Setting 0 05 0 06 2 49 2 5 1xIn Gn 51c 3 C...

Page 187: ...Off Inhibit Non Dir Off Gn 51N 1 Inrush Action Off Inhibit Off 11 2 51N 2 Description Range Default Gn 51N 2 Element Disabled Enabled Disabled Gn 51N 2 Dir Control Non Dir Forward Reverse Non Dir Gn 51N 2 Setting 0 05 0 06 2 49 2 5 0 5xIn Gn 51N 2 Char DTL IEC NI IEC VI IEC EI IEC LTI ANSI MI ANSI VI ANSI EI IEC NI Gn 51N 2 Time Mult IEC ANSI 0 025 0 03 99 100 1 Gn 51N 2 Delay DTL 0 0 01 19 99 20 ...

Page 188: ...01 19 99 20 0s Gn 51N 4 Follower DTL 0 0 01 19 99 20 0s Gn 51N 4 Reset IEC ANSI Decaying 0 59 60 0s Gn 51N 4 VTS Action Off Inhibit Non Dir Off Gn 51N 4 Inrush Action Off Inhibit Off 11 5 50N 1 Description Range Default Gn 50N 1 Element Disabled Enabled Disabled Gn 50N 1 Dir Control Non Dir Forward Reverse Non Dir Gn 50N 1 Setting 0 05 0 06 49 5 50 0 5xIn Gn 50N 1 Delay 0 0 01 14300 14400 0s Gn 50...

Page 189: ... 2 5 3 0 33V Gn 50G Measurement RMS Fundamental RMS Gn 51G Measurement RMS Fundamental RMS 12 1 51G 1 Description Range Default Gn 51G 1 Element Disabled Enabled Enabled Gn 51G 1 Dir Control Non Dir Forward Reverse Non Dir Gn 51G 1 Setting 0 05 0 06 2 49 2 5 0 5xIn Gn 51G 1 Char DTL IEC NI IEC VI IEC EI IEC LTI ANSI MI ANSI VI ANSI EI IEC NI Gn 51G 1 Time Mult IEC ANSI 0 025 0 03 99 100 1 Gn 51G 1...

Page 190: ...9 99 20 5s Gn 51G 3 Min Operate Time 0 0 01 19 99 20 0s Gn 51G 3 Follower DTL 0 0 01 19 99 20 0s Gn 51G 3 Reset IEC ANSI Decaying 0 59 60 0s Gn 51G 3 VTS Action Off Inhibit Non Dir Off Gn 51G 3 Inrush Action Off Inhibit Off 12 4 51G 4 Description Range Default Gn 51G 4 Element Disabled Enabled Disabled Gn 51G 4 Dir Control Non Dir Forward Reverse Non Dir Gn 51G 4 Setting 0 05 0 06 2 49 2 5 0 5xIn ...

Page 191: ...ol Non Dir Forward Reverse Non Dir Gn 50G 3 Setting 0 05 0 06 49 5 50 0 5xIn Gn 50G 3 Delay 0 0 01 14300 14400 0s Gn 50G 3 VTS Action Off Inhibit Non Dir Off Gn 50G 3 Inrush Action Off Inhibit Off 12 8 50G 4 Description Range Default Gn 50G 4 Element Disabled Enabled Disabled Gn 50G 4 Dir Control Non Dir Forward Reverse Non Dir Gn 50G 4 Setting 0 05 0 06 49 5 50 0 5xIn Gn 50G 4 Delay 0 0 01 14300 ...

Page 192: ... 1 Start Option All Any All 14 2 37 2 Description Range Default Gn 37 2 Element Disabled Enabled Disabled Gn 37 2 Setting 0 05 0 1 4 95 5 0 25xIn Gn 37 2 Delay 0 0 01 14300 14400 0s Gn 37 2 U C Guarded No Yes Yes Gn 37 2 Start Option All Any All 14 3 37G 1 Description Range Default Gn 37G 1 Element Disabled Enabled Disabled Gn 37G 1 Setting 0 05 0 1 4 95 5 0 2xIn Gn 37G 1 Delay 0 0 01 14300 14400 ...

Page 193: ...Description Range Default Gn 50 LC 2 Element Disabled Enabled Disabled Gn 50 LC 2 Setting 0 05 0 06 49 5 50 1xIn Gn 50 LC 2 Delay 0 0 01 14300 14400 0s Gn 50 LC 2 Inrush Action Off Inhibit Off 16 3 50G LC 1 Description Range Default Gn 50G LC 1 Element Disabled Enabled Disabled Gn 50G LC 1 Setting 0 05 0 06 49 5 50 0 5xIn Gn 50G LC 1 Delay 0 0 01 14300 14400 0s Gn 50G LC 1 Inrush Action Off Inhibi...

Page 194: ...VTS Ipps Fault 0 05 0 1 19 95 20 10xIn Gn 60VTS Delay 0 03 0 04 14300 14400 0 03s 17 3 CT SUPERVISION Description Range Default Gn 60CTS I Element Disabled Enabled Disabled Gn 60CTS I Setting 0 05 0 1 1 95 2 0 05xIn Gn 60CTS I Delay 0 03 0 04 14300 14400 10s Gn 60CTS Element Disabled Enabled Disabled Gn 60CTS Inps 0 05 0 1 0 15 0 2 0 25 0 3 0 35 0 4 0 45 0 5 0 55 0 6 0 65 0 7 0 75 0 8 0 85 0 9 0 9...

Page 195: ...oreclose section of manual for detail of what elements can cause only Delayed protection to be used Combination of 51 1 51 2 51 3 51 4 50 1 50 2 50 3 50 4 Gn 79 E F Inst Trips Selects which earth fault protection elements are classed as Instantaneous elements and start an autoreclose sequence These will be blocked from operating during Delayed autoreclose sequences See autoreclose section of manua...

Page 196: ...elects the number of retries allowed per shot 0 1 2 3 4 5 6 7 8 9 10 1 Gn 79 Retry Interval Time delay between retries 0 1 599 600 60 s Gn 79 Reclose Blocked Delay Specifies the maximum time that the Autorecloser can be blocked before proceeding to the lockout state NOTE The block delay timer only starts after the Deadtime 0 1 599 600 60 s Gn 79 Sequence Fail Timer Time before lockout occurs on an...

Page 197: ...ed Trips To Lockout Selects how many Delayed trips are allowed before going to Lockout 1 2 3 4 5 5 18 2 2 E F SHOTS Description Range Default Gn 79 E F Prot n Trip 1 Selects whether the first earth fault trip is Instantaneous Fast or Delayed When set to Delayed all E F Inst Trips will be Inhibited for this shot Inst Delayed Inst Gn 79 E F Deadtime 1 Time period between the fault being cleared and ...

Page 198: ...antaneous or Delayed Not Blocked Blocked Not Blocked Gn 79 Extern Deadtime 2 Time period between the fault being cleared and the close pulse being issued 0 0 1 14300 14400 5 s Gn 79 Extern Prot n Trip 3 Selects whether the third external trip is Instantaneous or Delayed Not Blocked Blocked Not Blocked Gn 79 Extern Deadtime 3 Time period between the fault being cleared and the close pulse being iss...

Page 199: ...99 1 E1 Counter Reset Mode Off Multi shot Single shot Off E1 Counter Reset Time 0 0 01 14300 14400 0s E2 Equation Disabled Enabled Disabled E2 20 Character String E2 Pickup Delay 0 0 01 14300 14400 0s E2 Dropoff Delay 0 0 01 14300 14400 0s E2 Counter Target 1 2 998 999 1 E2 Counter Reset Mode Off Multi shot Single shot Off E2 Counter Reset Time 0 0 01 14300 14400 0s E3 Equation Disabled Enabled Di...

Page 200: ... Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 87L 2 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 87R Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit Cold Load Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 51 1 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 51 2 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 51 3 Combinatio...

Page 201: ...ion of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 50G 3 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 50G 4 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 49 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Reset 49 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 46IT Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 46DT Combination of BI1 BI2 BI3 V...

Page 202: ...BF Mech Trip Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 50BF Ext Trip Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Inhibit 60VTS Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Ext Trig 60VTS Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Ext Reset 60VTS Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Reset CB Total Trip Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Re...

Page 203: ...BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 E F In Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Trigger Wave Rec Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Trigger Fault Rec Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Select Group 1 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Select Group 2 Combination of BI1 BI2 BI3 V1 V2 V3 V4 V5 V6 V7 V8 Select Group 3 Combination of BI1 BI2 BI3...

Page 204: ...ropoff Delay 0 0 005 14300 14400 0s BI 3 Pickup Delay 0 0 005 14300 14400 0 02s BI 3 Dropoff Delay 0 0 005 14300 14400 0s Enabled In Local Combination of 1 2 3 1 2 3 Enabled In Remote Combination of 1 2 3 1 2 3 22 4 FUNCTION KEY CONFIG Description Range Default Function Key 1 Text 20 Character String Function Key 1 Function Key 2 Text 20 Character String Function Key 2 Function Key 3 Text 20 Chara...

Page 205: ...V5 V6 V7 V8 Active Setting Grp 4 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 ve P 3P Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 ve P 3P Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 ve Q 3P Combination o...

Page 206: ... L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L15 Prot n Comms Test Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 Prot n Comms In Sync Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 85R 1 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12...

Page 207: ...11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 87R 1 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 87R 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 Cold Load Active Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V...

Page 208: ...L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 51N 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 51N 3 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 51N 4 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 50N 1 Co...

Page 209: ... L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 50G 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 50G 3 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L6 50G 4 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V...

Page 210: ...L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 37G 1 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 37G 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 60CTS I Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 60CTS I PhA Co...

Page 211: ...L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 74CCS 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 74CCS 3 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 General Pickup Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 BO2...

Page 212: ...V4 V5 V6 V7 V8 50BF PhC Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 50BF EF Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 CB Total Trip Count Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 CB Ph A Trip Count...

Page 213: ...L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 CB Successful Close Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 CB Fail To Close Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 Close CB Blocked Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 ...

Page 214: ...4 L15 V1 V2 V3 V4 V5 V6 V7 V8 User Output 1 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 L7 User Output 2 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 BO4 L8 User Output 3 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 ...

Page 215: ...2 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 En100 Ch2 Link Down Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 E F Out Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 New Wave Stored Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 ...

Page 216: ... L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 E3 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 E4 Combination of BO1 BO2 BO3 BO4 BO5 L1 L2 L3 L4 L5 L6 L7 L8 L9 L10 L11 L12 L13 L14 L15 V1 V2 V3 V4 V5 V6 V7 V8 23 2 BINARY OUTPUT CONFIG Description Range Default Hand Reset Outputs Combination of 1 2 3 4 5 Mi...

Page 217: ... 50G 4 51N 1 51N 2 51N 3 51N 4 50N 1 50N 2 50N 3 50N 4 51G 1 51G 2 51G 3 51G 4 50G 1 50G 2 50G 3 50G 4 Gn Misc Pickups Combination of 46IT 46DT 37 1 37 2 37G 1 37G 2 46IT 46DT 37 1 37 2 37G 1 37G 2 Gn Line Check Pickups Combination of 50 1LC 50 2LC 50G 1LC 50G 2LC 50 1LC 50 2LC 50G 1LC 50G 2LC 23 5 TRIP CONFIG Description Range Default Trip Contacts Combination of BO1 BO2 BO3 BO4 BO5 Trip Triggere...

Page 218: ... START COUNT Description Range Default Start Type s Combination of Power On Expected Unexpected Power On Expected Unexpected Start Count Target 0 1 9999 10000 100 25 DATA STORAGE 25 1 DEMAND DATA LOG Description Range Default Gn Demand Window 1 2 23 24 24hrs Gn Demand Window Type Fixed Peak Rolling Fixed 25 2 WAVEFORM STORAGE Description Range Default Gn P F Trig Storage Combination of 51 1 51 2 5...

Page 219: ...gy Unit 1kWh 10kWh 100kWh 1MWh 10MWh 100MWh 10kWh Gn Active Imp Energy Unit 1kWh 10kWh 100kWh 1MWh 10MWh 100MWh 10kWh Gn Reactive Exp Energy Unit 1kVArh 10kVArh 100kVArh 1MVArh 10MVArh 100MVArh 10kVArh Gn Reactive Imp Energy Unit 1kVArh 10kVArh 100kVArh 1MVArh 10MVArh 100MVArh 10kVArh 26 COMMUNICATIONS Description Range Default COM1 RS485 Protocol OFF IEC60870 5 103 MODBUS RTU DNP3 IEC60870 5 103 ...

Page 220: ...ll 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 disclaimed 2016...

Page 221: ...7SR181 Solkor Technical Manual Chapter 4 Page 2 of 80 2016 Siemens Protection Devices Limited ...

Page 222: ...US Register Data Types 24 4 2 1 FLOAT_IEEE_754 24 4 2 2 FP_32BITS_3DP 25 4 2 3 UINT32 25 4 2 4 UINT16 25 4 2 5 EVENT 26 4 2 6 EVENTCOUNT 27 4 2 7 TIME_METER 27 4 2 8 STR32 STR64 27 4 2 9 BITSTRING 27 4 3 Point List 29 4 3 1 Coils Read Write Binary values 29 4 3 2 Inputs Read Only Binary values 30 4 3 3 Input Registers Read Only Registers 34 4 3 4 Holding Registers Read Write Registers 38 5 DNP3 De...

Page 223: ... 2 Connecting a Modem to the Relay s 73 8 3 Setting the Remote Modem 73 8 4 Connecting to the Remote Modem 73 9 Configuration 75 10 Glossary 77 Appendix 1 79 List of Figures Fig 2 1 Communication to Front USB Port 8 Fig 2 2 Communication to Multiple Devices using RS485 Standard Port 10 Fig A1 Operating Mode Table 79 ...

Page 224: ...nications protocols DNP3 IEC 60870 5 103 IEC 61850 and MODBUS RTU Note not all protocols are available on all devices Reydisp Evolution or Reydisp Manager Software is available for computers running Microsoft Windows to connect to devices to provide operational information post fault analysis setting interrogation and editing facilities etc Configuration software can be downloaded from our website...

Page 225: ...7SR181 Solkor Technical Manual Chapter 4 Page 6 of 80 2016 Siemens Protection Devices Limited ...

Page 226: ...I protocol is also available through this port the main use of this protocol is to allow the Relay firmware to be updated via the front connection MODBUS RTU or the optional DNP3 protocols are also available COM3 LAN When the Ethernet module is fitted in addition to IEC61850 a LAN connection is provided to allow the Reydisp software to connect to the Relay via the network This port only supports t...

Page 227: ...ithout the need to first change any settings Access to the communication settings for the USB port is only available from the relay front fascia via the key pad setting menu COMMUNICATIONS MENU Setting Name Range Options Default Setting Notes COM2 USB Protocol OFF IEC60870 5 103 MODBUS RTU ASCII DNP3 IEC60870 5 103 Reydisp software requires IEC60870 5 103 COM2 USB Station Address 0 254 for IEC6087...

Page 228: ...e connected in reverse communication to all devices will be disturbed but no damage will occur If problems are experienced during commissioning the connections should be tried in reverse The maximum number of relays that can be connected to the bus is 64 The RS485 data comms link will be broken for that particular relay element if it is withdrawn from the case but the chain of communication to the...

Page 229: ...6 18 RS485 Screened twisted pair Rear terminals Ext Wire loop terminating resistance added where permanent drive from master station available A RS485 GND B Term 14 16 18 20 A RS485 GND B Term 14 16 18 20 A RS485 GND B Term 14 16 18 20 RS 485 Twisted pair Cable To Control System Bus Termination Polarity 5V B A GND Fig 2 2 Communication to Multiple Devices using RS485 Standard Port ...

Page 230: ...operating as a slave responding to the master s commands The implementation provides event information time synchronising commands and measurands and also supports the transfer of disturbance records This protocol can be set to use any or all of the relays hardware interfaces USB Fibre Optic RS232 RS485 and Ethernet where fitted and is the standard protocol used by the USB port The relay can commu...

Page 231: ...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 operation Ack command acknowledge Nak Negative command acknowledge Note Events listing a GI cause of transmission can be raised and cleared other events are raised only ...

Page 232: ...t ASDU column of the Information Number and Function table lists the possible ASDUs returned for a point ASDU Description 1 Time tagged message monitor direction 2 Time tagged message relative time monitor direction 3 1 Measurands I 4 Time tagged measurands with relative time 5 Identification message 6 Time synchronisation 7 General Interrogation Initialization 9 Measurands II 20 General command ...

Page 233: ...1 SE GI 60 5 Out Of Service Mode 20 Ack Nak 1 SE GI 60 6 Local Mode 20 Ack Nak 1 SE GI 60 7 Local Remote 20 Ack Nak 60 12 Control Received 1 SE 60 13 Command Received 1 SE 60 128 Cold Start 1 SE 60 129 Warm Start 1 SE 60 130 Re Start 1 SE 60 131 Expected Restart 1 SE GI 60 132 Unexpected Restart 1 SE GI 1 SE 60 133 Reset Start Count 20 Ack Nak 60 135 Trigger Storage 1 SE 60 136 Clear Waveform Reco...

Page 234: ...E GI 75 8 Virtual Input 8 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 90 1 LED 1 1 SE GI 90 2 LED 2 1 SE GI 90 3 LED...

Page 235: ...LED PU 17 1 SE GI 91 18 LED PU 18 1 SE GI 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 GI 183 14 51G 1 2 SE GI 183 15 50G 1 2 SE GI 183 16 51 2 2 SE GI 183 17 50 2 2 SE GI 183 18 51N 2 2 SE GI 183 19 50N 2 2 SE GI 183 20 51G 2 2 SE GI 183 21 50G 2 2 SE GI 183 22 51 3 2 SE GI 183 23 50 3 2 SE GI 183 24 51N 3 2 SE GI 183 25 50N 3 2 SE GI 183 26 51G 3 2 SE GI 183 27 ...

Page 236: ...Line Working 20 Ack Nak 1 SE GI 183 122 Inst Protection Out 20 Ack Nak 183 123 CB Total Trip Count 1 SE GI 183 124 CB Delta Trip Count 1 SE GI 183 125 CB Count To AR Block 1 SE GI 1 SE 183 126 Reset CB Total Trip Count 20 Ack Nak 1 SE 183 127 Reset CB Delta Trip Count 20 Ack Nak 1 SE 183 128 Reset CB Count To AR Block 20 Ack Nak 183 129 I 2t CB Wear 1 SE GI 1 SE 183 130 Reset I 2t CB Wear 20 Ack N...

Page 237: ...E GI 183 225 50 LC 1 2 SE GI 183 226 50 LC 2 2 SE GI 183 227 50G LC 1 2 SE GI 183 228 50G LC 2 2 SE GI 183 231 50BF PhA 2 SE GI 183 232 50BF PhB 2 SE GI 183 233 50BF PhC 2 SE GI 183 234 50BF EF 2 SE GI 183 235 79 Last Trip Lockout 2 SE GI 183 237 CB DBI 1 SE GI 183 238 CB Travelling 1 SE GI 183 239 In Fault Current 4 SE 183 240 Ia Fault Current 4 SE 183 241 Ib Fault Current 4 SE 183 242 Ic Fault C...

Page 238: ...33 87 Ib Operate Fault Current 4 SE 186 34 87 Ic Operate Fault Current 4 SE 186 35 87 Ia Restrain Fault Current 4 SE 186 36 87 Ib Restrain Fault Current 4 SE 186 37 87 Ic Restrain Fault Current 4 SE 186 38 85S 1 1 SE GI 186 39 85S 2 1 SE GI 186 40 85S 3 1 SE GI 186 41 85S 4 1 SE GI 186 42 85S 5 1 SE GI 186 43 85S 6 1 SE GI 186 44 85R 1 1 SE GI 186 45 85R 2 1 SE GI 186 46 85R 3 1 SE GI 186 47 85R 4...

Page 239: ...p L2 2 SE GI 192 66 Start Pick up L3 2 SE GI 192 67 Start Pick up N 2 SE GI 192 68 General Trip 2 SE 192 69 Trip L1 2 SE 192 70 Trip L2 2 SE 192 71 Trip L3 2 SE 192 74 Fault Forward Line 2 SE GI 192 75 Fault Reverse Busbar 2 SE GI 192 84 General Start Pick up 2 SE GI 192 85 Breaker Failure 2 SE 192 90 Trip I 2 SE 192 91 Trip I 2 SE 192 92 Trip In 2 SE 192 93 Trip In 2 SE 192 128 CB on by auto recl...

Page 240: ...8 20 Ack Nak 1 SE 200 200 CB 1 Trip Reclose 20 Ack Nak 1 SE 200 201 CB 1 Trip Lockout 20 Ack Nak 200 255 Blocked By Interlocking 1 SE GI 255 0 General Interrogation GI Initiation 7 Init GI 255 0 General Interrogation GI End 8 End of GI 255 0 Time Synchronisation 6 Time Synch 3 4 2 Measurands The following Measurand EVT and INF numbers apply to this device FUN INF Description ASDU COT 183 148 Measu...

Page 241: ...ow 1 Vcn Max3 1 2x Window 1 P Max 2 4x Window 1 Q Max 2 4x Window 1 Vab Max 1 2x Window 1 Vbc Max 1 2x Window 1 Vca Max 1 2x Window 1 9 Cyclic Refresh rate 5 seconds or value change greater than Window x 3 4 3 Disturbance Recorder Actual Channel ACC Numbers The following Disturbance Recorder channel numbers apply to this device FUN ACC Description 182 1 V1 182 2 V2 182 3 V3 182 5 Ia 182 6 Ib 182 7...

Page 242: ...s USB Fibre Optic RS232 and RS485 where fitted The relay can communicate simultaneously on all ports regardless of protocol used The Station Address of the port being used must be set to a suitable address within the range 1 247 to enable communication This can be set by the Communications Menu COM n xxxxx Station Address setting Communication via MODBUS over Ethernet requires external devices Ple...

Page 243: ... instance xyz The mantissa represents the binary fraction of a number therefore the MSB represents 2 1 or 1 2 1 and its LSB 2 23 or 1 2 23 The following table shows a detailed layout of the mantissa 1 2 1 1 2 2 1 2 3 1 2 4 1 2 21 1 2 22 1 2 23 0 5 0 25 0 125 0 0625 4 768e 7 2 384e 7 1 192e 7 As an example 1 000 000 would be represented as follows hex 49742400 4 9 7 4 2 4 0 0 0 1 0 0 1 0 0 1 0 1 1 ...

Page 244: ...n reception these two registers should be interpreted in the correct order as a 32 bit integer 4 2 3 UINT32 The UINT32 is a signed 32 bit integer As it is an integer negative numbers are sent as 2 s complement UINT32 MODBUS In this MODBUS implementation the 32 bit value is stored in 2 16 bit registers in Big Endian format As an example if we take the hex representation of 123456 in 2 s complement ...

Page 245: ...er can be checked periodically to determine how many events are stored The format of the event record is defined by the zero byte It signifies the type of record which is used to decode the event information The zero byte can be one of the following Format The format of the event record is defined by the zero byte It signifies the type of record which is used to decode the event information The ze...

Page 246: ...bytes as follows The following table describes the fields in the time Key Description ms L Time Stamp Milliseconds low byte ms H Time Stamp Milliseconds high byte Mi Time Stamp Minutes MSB invalid time not set 23 hours Ho Time Stamp Hours MSB Summer time flag Da Time Stamp Days Mo Time Stamp Months Ye L Time Stamp Years low byte Ye H Time Stamp Years high byte Not Used The following table shows th...

Page 247: ...d in a 16 bit register in Big Endian format As an example assume bits 1 3 9 and 12 are set The binary representation of this would be 00001001000001012 giving a hex representation of 0905h Assume this is stored in the register 30001 it would look as follows Address Value 30001 0905 On reception this register should be interpreted as a 16 bit integer ...

Page 248: ...00101 Setting G1 selected 00102 Setting G2 selected 00103 Setting G3 selected 00104 Setting G4 selected 00109 CB 1 00112 Auto reclose active 00113 HotLine Working 00114 E F Out 00116 Inst Protection Out 00155 Remote Mode 00156 Out Of Service Mode 00157 Local Mode 00158 Local Remote 00165 Reset Start Count 00180 CB 1 Opened 00181 CB 1 Closed 00200 User SP Command 1 00201 User SP Command 2 00202 Use...

Page 249: ...0 General Trip 10111 Trip Circuit Fail 10112 Start Pick up L1 10113 Start Pick up L2 10114 Start Pick up L3 10115 General Start Pick up 10116 VT Fuse Failure 10117 Earth Fault Forward Line 10118 Earth Fault Reverse Busbar 10119 Start Pick up N 10120 Fault Forward Line 10121 Fault Reverse Busbar 10122 51 1 10123 50 1 10124 51N 1 10125 50N 1 10126 51G 1 10127 50G 1 10128 51 2 10129 50 2 10130 51N 2 ...

Page 250: ...ear 10181 79 AR In progress 10182 Cold Load Active 10183 E F Out 10184 P F Inst Protection Inhibited 10185 E F Inst Protection Inhibited 10187 Ext Inst Protection Inhibited 10211 Trip Circuit Fail 1 10212 Trip Circuit Fail 2 10213 Trip Circuit Fail 3 10214 CB Total Trip Count 10215 CB Delta Trip Count 10216 CB Count To AR Block 10217 CB Frequent Ops Count 10218 I 2t CB Wear 10219 CB 1 Opened 10220...

Page 251: ...LC 2 10378 50BF PhA 10379 50BF PhB 10380 50BF PhC 10381 50BF EF 10383 60 CTS I PhA 10384 60 CTS I PhB 10385 60 CTS I PhC 10390 Trip PhA 10391 Trip PhB 10392 Trip PhC 10410 CB Alarm 10501 Virtual Input 1 10502 Virtual Input 2 10503 Virtual Input 3 10504 Virtual Input 4 10505 Virtual Input 5 10506 Virtual Input 6 10507 Virtual Input 7 10508 Virtual Input 8 10601 LED 1 10602 LED 2 10603 LED 3 10604 L...

Page 252: ...10717 LED PU 17 10718 LED PU 18 10800 Cold Start 10801 Warm Start 10802 Re Start 10803 Power On 10804 Expected Restart 10805 Unexpected Restart 10806 Reset Start Count 10900 User SP Command 1 10901 User SP Command 2 10902 User SP Command 3 10903 User SP Command 4 10904 User SP Command 5 10905 User SP Command 6 10906 User SP Command 7 10907 User SP Command 8 10908 User DP Command 1 10909 User DP Co...

Page 253: ...mary FP_32BITS_3DP 1 000000 Vbc V 30014 Vca Primary FP_32BITS_3DP 1 000000 Vca V 30016 Va Primary FP_32BITS_3DP 1 000000 Va V 30018 Vb Primary FP_32BITS_3DP 1 000000 Vb V 30020 Vc Primary FP_32BITS_3DP 1 000000 Vc V 30022 Va Secondary FP_32BITS_3DP 1 000000 Va V 30024 Vb Secondary FP_32BITS_3DP 1 000000 Vb V 30026 Vc Secondary FP_32BITS_3DP 1 000000 Vc V 30034 Vab Nominal FP_32BITS_3DP 1 000000 Va...

Page 254: ...s xIn 30104 Inps Nominal FP_32BITS_3DP 1 000000 Inps xIn 30106 Izps Nominal FP_32BITS_3DP 1 000000 Izps Degrees 30108 Ipps Nominal FP_32BITS_3DP 1 000000 Ipps Degrees 30110 Inps Nominal FP_32BITS_3DP 1 000000 Inps Degrees 30112 Active Power A FP_32BITS_3DP 0 000001 A Phase W 30114 Active Power B FP_32BITS_3DP 0 000001 B Phase W 30116 Active Power C FP_32BITS_3DP 0 000001 C Phase W 30118 P 3P FP_32...

Page 255: ...t Trip FP_32BITS_3DP 1 000000 Ic Fault 30307 Va Last Trip FP_32BITS_3DP 1 000000 Va Fault 30309 Vb Last Trip FP_32BITS_3DP 1 000000 Vb Fault 30311 Vc Last Trip FP_32BITS_3DP 1 000000 Vc Fault 30313 In Last Trip FP_32BITS_3DP 1 000000 In Fault 30315 Ig Last Trip FP_32BITS_3DP 1 000000 Ig Fault 30319 V Phase A Max FP_32BITS_3DP 1 000000 Va Max Demand 30321 V Phase B Max FP_32BITS_3DP 1 000000 Vb Max...

Page 256: ...3DP 1 000000 Restrain Ia Fault 30502 Res Ib Last Trip FP_32BITS_3DP 1 000000 Restrain Ib Fault 30504 Res Ic Last Trip FP_32BITS_3DP 1 000000 Restrain Ic Fault 30506 Remote Ia Primary FP_32BITS_3DP 1 000000 Remote Ia A 30508 Remote Ib Primary FP_32BITS_3DP 1 000000 Remote Ib A 30510 Remote Ic Primary FP_32BITS_3DP 1 000000 Remote Ic A 30512 Remote Ia Secondary FP_32BITS_3DP 1 000000 Remote Ia A 305...

Page 257: ...1 000000 Vb V 40020 Vc Primary FP_32BITS_3DP 1 000000 Vc V 40022 Va Secondary FP_32BITS_3DP 1 000000 Va V 40024 Vb Secondary FP_32BITS_3DP 1 000000 Vb V 40026 Vc Secondary FP_32BITS_3DP 1 000000 Vc V 40034 Vab Nominal FP_32BITS_3DP 1 000000 Vab Degrees 40036 Vbc Nominal FP_32BITS_3DP 1 000000 Vbc Degrees 40038 Vca Nominal FP_32BITS_3DP 1 000000 Vca Degrees 40040 Va Nominal FP_32BITS_3DP 1 000000 V...

Page 258: ... C VAr 40126 Q 3P FP_32BITS_3DP 0 000001 3 Phase VAr 40128 Apparent Power A FP_32BITS_3DP 0 000001 Phase A VA 40130 Apparent Power B FP_32BITS_3DP 0 000001 Phase B VA 40132 Apparent Power C FP_32BITS_3DP 0 000001 Phase C VA 40134 S 3P FP_32BITS_3DP 0 000001 3 Phase VA 40136 Power Factor A FP_32BITS_3DP 1 000000 Phase A 40138 Power Factor B FP_32BITS_3DP 1 000000 Phase B 40140 Power Factor C FP_32B...

Page 259: ...rip Count 40337 CB E F Trip Count UINT32 1 000000 CB EF Trip Count 40341 LED1 n BITSTRING 0 000000 Led 1 16 status 40342 LED1 n BITSTRING 0 000000 Led 17 32 status 40343 INP1 n BITSTRING 0 000000 Input 1 16 status 40344 INP1 n BITSTRING 0 000000 Input 17 32 status 40345 OUT1 n BITSTRING 0 000000 Output 1 16 status 40346 OUT1 n BITSTRING 0 000000 Output 17 32 status 40347 VRT1 n BITSTRING 0 000000 ...

Page 260: ...o 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 with qualifiers 07 or 08 will be responded with qualifiers 00 or 01 Output Event Object 11 is supported Maximum Data Link Frame Size octets Transmitted 256...

Page 261: ...nt 1 Never Always Sometimes Configurable Pulse On Never Always Sometimes Configurable Pulse Off Never Always Sometimes Configurable Latch On Never Always Sometimes Configurable Latch Off Never Always Sometimes Configurable Queue Never Always Sometimes Configurable Clear Queue Never Always Sometimes Configurable Attach explanation if Sometimes or Configurable was checked for any operation Reports B...

Page 262: ...so see the DNP 3 0 Implementation Table in Section 5 2 beginning on page 44 Sequential File Transfer Support File Transfer Support Yes No Append File Mode Yes No Custom Status Code Strings Yes No Permissions Field Yes No File Events Assigned to Class Yes No File Events Send Immediately Yes No Multiple Blocks in a Fragment Yes No Max Number of Files Open 0 ...

Page 263: ...x 129 response 00 01 start stop 17 28 index see note 2 2 0 Binary Input Change Any Variation 1 read 06 no range or all 07 08 limited qty 2 1 Binary Input Change without Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol resp 17 28 index 2 2 default see note 1 Binary Input Change with Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol resp 17 28 index 2 3 B...

Page 264: ...uest 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 operate 5 direct op 6 dir op noack 00 01 start stop 129 response echo of request 13 0 Binary Output Command Event Any Variation 1 read 06 no range or all 07 08 limited qty 13 1 default see note 1 Binary Output Command Event without Time 1 read 0...

Page 265: ...2 21 6 16 Bit Frozen Counter without Time Of Freeze 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 2 21 7 32 Bit Frozen Delta Counter with Time Of Freeze 21 8 16 Bit Frozen Delta Counter with Time Of Freeze 21 9 default see note 1 32 Bit Frozen Counter without Flag 1 read 00 01 start stop 06 no range or all 07 08 limit...

Page 266: ... 0 Analog Input Any Variation 1 read 22 assign class 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 30 1 32 Bit Analog Input 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 2 30 2 default see note 1 16 Bit Analog Input 1 read 00 01 start stop 06 no range or all 07 08 limited qty 17 27 28 index 129 ...

Page 267: ...ng point 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 8 long floating point Analog Change Event with Time 1 read 06 no range or all 07 08 limited qty 129 response 130 unsol resp 17 28 index 33 0 Frozen Analog Event Any Variation 33 1 32 Bit Frozen Analog Event without Time 33 2 16 Bit Frozen Analog Event without Time 33 3 32 B...

Page 268: ...ange or all 1 read 06 no range or all 07 08 limited qty 60 3 Class 2 Data 20 enbl unsol 21 dab unsol 22 assign class 06 no range or all 1 read 06 no range or all 07 08 limited qty 60 4 Class 3 Data 20 enbl unsol 21 dab unsol 22 assign class 06 no range or all 1 read 00 01 start stop 129 response 00 01 start stop 80 1 Internal Indications 2 write see note 3 00 start stop index 7 No Object function ...

Page 269: ...event buffer size is set to allow 100 events Binary inputs are by default returned in a class zero interrogation Note not all points listed here apply to all builds of devices Binary Input Points Static Steady State Object Number 1 Packed Format Change Event Object Number 1 w o Time Static Variation reported when variation 0 requested 1 Binary Input w o status or 2 Binary Input with status Change ...

Page 270: ...ault Forward Line 0 2 2 2 51 Fault Reverse Busbar 0 2 2 2 52 51 1 0 2 2 2 53 50 1 0 2 2 2 54 51N 1 0 2 2 2 55 50N 1 0 2 2 2 56 51G 1 0 2 2 2 57 50G 1 0 2 2 2 58 51 2 0 2 2 2 59 50 2 0 2 2 2 60 51N 2 0 2 2 2 61 50N 2 0 2 2 2 62 51G 2 0 2 2 2 63 50G 2 0 2 2 2 64 60 CTS 0 2 2 2 65 46IT 0 2 2 2 66 46DT 0 2 2 2 69 46BC 0 2 2 2 80 Auto reclose active 0 2 2 2 81 CB on by auto reclose 0 2 2 2 82 Reclaim 0...

Page 271: ...nt To AR Block 0 2 2 2 132 CB Frequent Ops Count 0 2 2 2 133 I 2t CB Wear 0 2 2 2 207 Close Circuit Fail 1 0 2 2 2 208 Close Circuit Fail 2 0 2 2 2 209 Close Circuit Fail 3 0 2 2 2 210 Close Circuit Fail 0 2 2 2 211 50BF Stage 1 0 2 2 2 212 50BF Stage 2 0 2 2 2 213 49 Alarm 0 2 2 2 214 49 Trip 0 2 2 2 217 37 1 0 2 2 2 218 37 2 0 2 2 2 219 CB Alarm 0 2 2 2 225 General Alarm 1 0 2 2 2 226 General Al...

Page 272: ...288 60 CTS I PhA 0 2 2 2 289 60 CTS I PhB 0 2 2 2 290 60 CTS I PhC 0 2 2 2 291 Trip PhA 0 2 2 2 292 Trip PhB 0 2 2 2 293 Trip PhC 0 2 2 2 411 Setting G1 selected 0 2 2 2 412 Setting G2 selected 0 2 2 2 413 Setting G3 selected 0 2 2 2 414 Setting G4 selected 0 2 2 2 420 79 AR In progress 0 2 2 2 422 HotLine Working 0 2 2 2 425 Inst Protection Out 0 2 2 2 427 CB 1 0 2 2 2 501 Virtual Input 1 0 2 2 2...

Page 273: ...2 705 LED PU 5 0 2 2 2 706 LED PU 6 0 2 2 2 707 LED PU 7 0 2 2 2 708 LED PU 8 0 2 2 2 709 LED PU 9 0 2 2 2 710 LED PU 10 0 2 2 2 711 LED PU 11 0 2 2 2 712 LED PU 12 0 2 2 2 713 LED PU 13 0 2 2 2 714 LED PU 14 0 2 2 2 715 LED PU 15 0 2 2 2 716 LED PU 16 0 2 2 2 717 LED PU 17 0 2 2 2 718 LED PU 18 0 2 2 2 801 Binary Output 1 0 2 2 2 802 Binary Output 2 0 2 2 2 803 Binary Output 3 0 2 2 2 804 Binary ...

Page 274: ...mmand 7 0 2 2 2 907 User SP Command 8 0 2 2 2 1063 CB DBI 0 2 2 2 1064 CB Travelling 0 2 2 2 1065 Close CB Failed 0 2 2 2 1066 Open CB Failed 0 2 2 2 1067 Start Count Alarm 0 2 2 2 1088 87L 1 0 2 2 2 1089 87L 2 0 2 2 2 1090 87HS 1 0 2 2 2 1091 87HS 2 0 2 2 2 1092 85S 1 0 2 2 2 1093 85S 2 0 2 2 2 1094 85S 3 0 2 2 2 1095 85S 4 0 2 2 2 1096 85S 5 0 2 2 2 1097 85S 6 0 2 2 2 1098 85R 1 0 2 2 2 1099 85R...

Page 275: ...ts are included here for completeness they are not often polled by DNP 3 0 Masters Binary Output Status points are not recommended to be included in class 0 polls As an alternative it is recommended that actual status values of Control Relay Output Block points be looped around and mapped as Binary Inputs The actual status value as opposed to the commanded status value is the value of the actuated...

Page 276: ...ct 11 Default Command Event Object 13 Assigned Class 1 2 3 or none Default Variation Command Event Object 13 CROB Supported Operations Default CROB Operations 1 RL 1 0 2 2 0 1 Pulse On Latch On Close Pulse On 2 RL 2 0 2 2 0 1 Pulse On Latch On Close Pulse On 3 RL 3 0 2 2 0 1 Pulse On Latch On Close Pulse On 4 RL 4 0 2 2 0 1 Pulse On Latch On Close Pulse On 5 RL 5 0 2 2 0 1 Pulse On Latch On Close ...

Page 277: ...rations Default CROB Operations Trip 43 Hot Line Working on off 0 2 2 0 1 Pulse On Pulse Off Latch On Latch Off Close Trip Pulse On Pulse Off Latch On Latch Off 44 E F off on 0 2 2 0 1 Pulse On Pulse Off Latch On Latch Off Close Trip Pulse On Pulse Off Latch On Latch Off 46 Inst Protection off on 0 2 2 0 1 Pulse On Pulse Off Latch On Latch Off Close Trip Pulse On Pulse Off Latch On Latch Off 48 Re...

Page 278: ...iation Command Event Object 13 CROB Supported Operations Default CROB Operations 59 Demand metering reset write only location 0 2 2 0 1 Pulse On Latch On Close Pulse On 88 Remote mode 0 2 2 0 1 Pulse On Latch On Close Pulse On 89 Service mode 0 2 2 0 1 Pulse On Latch On Close Pulse On 90 Local mode 0 2 2 0 1 Pulse On Latch On Close Pulse On 91 Local Remote 0 2 2 0 1 Pulse On Latch On Close Pulse O...

Page 279: ...Default Command Event Object 13 Assigned Class 1 2 3 or none Default Variation Command Event Object 13 CROB Supported Operations Default CROB Operations Latch Off Close Trip 108 User DP Command 2 0 2 2 0 1 Pulse On Pulse Off Latch On Latch Off Close Trip Pulse On Pulse Off 109 User DP Command 3 0 2 2 0 1 Pulse On Pulse Off Latch On Latch Off Close Trip Pulse On Pulse Off 110 User DP Command 4 0 2 ...

Page 280: ...Event Object 13 Assigned Class 1 2 3 or none Default Variation Command Event Object 13 CROB Supported Operations Default CROB Operations Latch On Close Latch On 5 3 4 Counters The following table lists both Binary Counters Object 20 and Frozen Counters Object 21 When a freeze function is performed on a Binary Counter point the frozen value is available in the corresponding Frozen Counter point The...

Page 281: ...or 6 16 Bit Frozen Counter Event with Flag and Time Counter Frozen Counter Point Index Description Default Change Event Assigned Class 1 2 3 or none Default Variation Static Object 20 Default Variation Event Object 22 Deadband Is Resettable IsFreezable Default Change Event Assigned Class 1 2 3 or none Default Variation Static Object 21 Default Variation Event Object 23 0 Waveform Records 0 3 5 1 1...

Page 282: ... w o Time or 3 32 Bit Analog Input with Time or 4 16 Bit Analog Input with Time or 5 Single Precision floating point Analog Input w o Time or 7 Single Precision floating point Analog Input with Time Analog Input Reporting Deadband Variation reported when variation 0 requested 1 16 Bit or 2 32 Bit or 3 Single Precision floating point Point Index Description Default Change Event Assigned Class 1 2 3...

Page 283: ... 1 000 100 000 47 Ig Secondary 0 3 2 4 1000 000 0 100 48 Ig Nominal 0 3 2 4 1000 000 0 100 51 Izps Nominal 0 3 2 4 100 000 0 100 52 Ipps Nominal 0 3 2 4 100 000 0 100 53 Inps Nominal 0 3 2 4 100 000 0 100 57 Active Power A 0 3 2 4 0 000 1000000 000 58 Active Power B 0 3 2 4 0 000 1000000 000 59 Active Power C 0 3 2 4 0 000 1000000 000 60 P 3P 0 3 2 4 0 000 1000000 000 61 Reactive Power A 0 3 2 4 0...

Page 284: ...2 4 0 010 100 000 103 Vn Secondary 0 3 2 4 10 000 1 000 108 I Phase A Max 0 3 2 4 1 000 100 000 109 I Phase B Max 0 3 2 4 1 000 100 000 110 I Phase C Max 0 3 2 4 1 000 100 000 111 P 3P Max 0 3 2 4 0 000 1000000 000 112 Q 3P Max 0 3 2 4 0 000 1000000 000 135 CB Total Trip Count 0 3 1 3 1 000 1 000 136 CB Delta Trip Count 0 3 1 3 1 000 1 000 137 CB Count To AR Block 0 3 1 3 1 000 1 000 138 CB Freque...

Page 285: ...mum 0 3 1 3 1 000 1 000 192 Freq Last Trip 0 3 5 7 1 000 1 000 196 Frequency Max 0 3 2 4 100 000 1 000 197 S 3P Max 0 3 2 4 0 000 1000000 000 330 CB Trip Time Meter 0 3 2 4 1000 000 0 010 338 Remote Ia Last Trip 0 3 1 3 1 000 Disabled 339 Remote Ib Last Trip 0 3 1 3 1 000 Disabled 340 Remote Ic Last Trip 0 3 1 3 1 000 Disabled 341 Remote In Last Trip 0 3 1 3 1 000 Disabled 342 Remote Ig Last Trip ...

Page 286: ...riation Event Object 32 Default Multiplier Default Deadband 368 Line Ib 0 3 2 4 100 000 0 100 369 Line Ic 0 3 2 4 100 000 0 100 370 Relay Ia 0 3 2 4 100 000 0 100 371 Relay Ib 0 3 2 4 100 000 0 100 372 Relay Ic 0 3 2 4 100 000 0 100 373 Remote Line Ia 0 3 2 4 100 000 0 100 374 Remote Line Ib 0 3 2 4 100 000 0 100 375 Remote Line Ic 0 3 2 4 100 000 0 100 376 Remote Relay Ia 0 3 2 4 100 000 0 100 37...

Page 287: ...7SR181 Solkor Technical Manual Chapter 4 Page 68 of 80 2016 Siemens Protection Devices Limited Setting Name Range Options Default Setting Notes Protocol is set to DNP3 ...

Page 288: ...Chapter 4 7SR181 Solkor Data Communications Definitions 2016 Siemens Protection Devices Limited Chapter 4 Page 69 of 80 6 Not Applicable This section intentionally left blank ...

Page 289: ...7SR181 Solkor Technical Manual Chapter 4 Page 70 of 80 2016 Siemens Protection Devices Limited ...

Page 290: ...80 7 IEC61850 Protocol Support 7 1 Introduction The relay can optionally be provided with IEC61850 comms For further details refer to the following publications Model Implementation Conformance Statement MICS Protocol Implementation Conformance Statement PICS Protocol Implementation Extra Information for Testing PIXIT ...

Page 291: ...7SR181 Solkor Technical Manual Chapter 4 Page 72 of 80 2016 Siemens Protection Devices Limited ...

Page 292: ...t be configured as auto answer This will allow it to initiate communications with the relays Next the user should set the data configuration at the local port i e baud rate and parity so that communication will be at the same rate and format as that set on the relay and the error correction is disabled Auto answer usually requires two parameters to be set The auto answer setting should be switched...

Page 293: ...7SR181 Solkor Technical Manual Chapter 4 Page 74 of 80 2016 Siemens Protection Devices Limited ...

Page 294: ...o and loaded from disc to work offline The protocols will be stored in a Reyrolle Protection Device Comms file RPDC which will be stored locally so that the editor can be used when the relay is not connected DNP3 The tool will allow Data Points to be enabled or disabled Changing the point numbers for the Binary Inputs Double Bit Inputs Binary Outputs Counters and Analogue Inputs Changing their ass...

Page 295: ...r can check if the relay contains user configured communication files via a meter in the relay menus Pressing the Enter and down arrow buttons on the fascia then scrolling down the number of files stored in the relay is displayed The file name can also be viewed by pressing the Cancel and Test Reset buttons together when in the relay Instruments menu The user must ensure when naming the file they ...

Page 296: ...rections simultaneously Half Duplex Asynchronous Communications Communications in two directions but only one at a time Hayes AT Modem command set developed by Hayes Microcomputer products Inc LAN Local Area Network A computer network covering a small geographic area LC Fibre optic connector type designed by Lucent Technologies Inc Line Idle Determines when the device is not communicating if the i...

Page 297: ...Devices Limited Start Bit Bit logical 0 sent to signify the start of a byte during data transmission Stop Bit Bit logical 1 sent to signify the end USB Universal Serial Bus standard for the transfer of data WAN Wide Area Network A computer network covering a large geographic area ...

Page 298: ...ration Mode Function Local Remote Service Control Com1 when Com1 Mode Local when Com1 Mode Remote Com2 USB when Com2 Mode Local when Com2 Mode Remote Fascia Control Mode Function Key n when F Key n Mode Remote Binary Input n when BI n Mode Local when BI n Mode Remote Binary Outputs Reporting Spontaneous IEC DNP3 General Interrogation IEC DNP3 MODBUS Change Settings Com1 when Com1 Mode Local when C...

Page 299: ...ices Limited Siemens Protection Devices Ltd SPDL P O Box 8 Hebburn Tyne and Wear NE31 1TZ United Kingdom For enquiries please contact our Customer Support Centre Tel 49 180 524 8437 24hrs Fax 49 180 524 2471 E Mail support ic siemens com www siemens com reyrolle Template Revision 16 ...

Page 300: ...he permission of Siemens Protection Devices Limited 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 an...

Page 301: ... up to and including this issue is 2016 11 First Issue 2017 05 Typographical revisions drawing amendments 2017 11 Typographical revisions added data 2018 07 Typographical revisions text and drawing amendments additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 302: ...fferential Highset 87HS 15 2 6 Primary Injection Tests 16 2 7 End to end Signalling 18 2 8 On Load Tests 18 Section 3 Putting Into Service 20 3 1 Phase Overcurrent 50 51 21 3 2 Definite Time Overcurrent 50 22 3 3 Inverse Time Overcurrent 51 22 3 3 1 Element Blocking 23 3 3 2 ANSI Reset 23 3 3 3 IEC Reset 24 3 4 Cold Load 51C 25 3 4 1 Inverse Time Overcurrent 51C 27 3 4 2 ANSI Reset 27 3 4 3 IEC Re...

Page 303: ...t Blocking 43 Section 4 Supervision Functions 44 4 1 CB Fail 50BF 44 4 1 1 Element Blocking 45 4 2 Current Transformer Supervision 60CTS 46 4 3 Broken Conductor 46BC 47 4 3 1 Element Blocking 48 4 4 Trip Close Circuit Supervision 74T CCS 49 4 5 Magnetising Inrush Detector 81HBL2 50 Section 5 Control Logic Functions 51 5 1 Quick Logic 51 Section 6 Testing and Maintenance 52 6 1 Periodic Tests 52 6 ...

Page 304: ...to Phase 17 Figure 3 1 1 Phase Overcurrent 21 Figure 3 4 1 Cold Load 25 Figure 3 4 2 Cold Load Logic diagram 26 Figure 3 5 1 Derived Earth Fault 29 Figure 3 6 1 Measured Earth Fault 33 Figure 3 7 1 Negative Phase Sequence Overcurrent 37 Figure 3 8 1 Undercurrent 40 Figure 3 9 1 Thermal Overload 42 Figure 4 1 1 CB Fail 44 Figure 4 2 1 Current Transformer Supervision 46 Figure 4 3 1 Broken Conductor...

Page 305: ...d test leads should not be used where the measurement of a current transformer CT secondary current is involved the failure of an instrument fuse or the operation of an instrument cut out could cause the secondary winding of the CT 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 damag...

Page 306: ...or printing or for record purposes can be produced from Reydisp as follows From the File menu select Save As change the file type to Export Default Actual Setting RTF and input a suitable filename When testing is completed the event and waveform records should be cleared and the settings file checked to ensure that the required in service settings are being applied 1 2 5 PRECAUTIONS Before electri...

Page 307: ...tion on programming the relay 1 2 9 SECONDARY INJECTION TESTS Select the required relay configuration and settings for the application Isolate the auxiliary D C supplies for alarm and tripping from the relay and remove the trip and inter trip links Carry out injection tests for each relay function as described in this document For all high current tests it must be ensured that the test equipment h...

Page 308: ...ing and functionality is as set as part of the Scheme Operation tests Where the pick up timers associated with a binary input are set for DC operation these delays should be checked either as part of the scheme logic or individually To check a binary pick up time delay temporarily map the binary input to an output relay that has a normally open contact This can be achieved in the Output Matrix sub...

Page 309: ...ified in the Output Config Binary Output Config 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 n...

Page 310: ...sed to assess operation of functions during testing if other functions are disabled or if the setting allocating General Pickup is temporarily modified It should be considered that where several overlapping elements are used simultaneously the overall protection operate time may be dependent on the operation of different individual elements at the various levels of applied current The resulting co...

Page 311: ...b Rest Ia Rest Ic Rest Local Relay Remote Relay Figure 2 1 1 Biased Differential Current Inputs IA IB IC Disable 46 49 50 51 50N 51N 50BF Map Pickup LED 87BD 87HS Self Reset The differential elements are subjected to CT multipliers Vector Group Compensation and Zero Sequence filters when applied to power transformers The complexity of these features can cause confusion during testing and lead to i...

Page 312: ...Reset 95 of pick up Phase A Phase B Phase C a Normal Connection This test requires both relays to be powered up settings applied and a healthy communications channel between them Inject single phase or three phase current into the current inputs of each relay in turn Slowly increase the current until the TRIP LED operates and record the pick up current The remote relay will also operate on current...

Page 313: ... press ENTER to confirm The relay in Line Test mode can now be tested as in the Loop Test mode i e injection will simulate a single end fed fault The pickup and drop off accuracy of the differential elements of the relay in Line Test can be performed in a similar way to the Loop Test above Only the relay injected will operate for that level Figure 2 3 2 Line Test Mode Secondary testing of the bias...

Page 314: ...08 1 62 2 15 2 69 Selected Settings Test Results 0 00 1 00 1 50 2 00 2 50 Phase A Pickup Phase B Pickup Phase C Pickup 2 5 DIFFERENTIAL HIGHSET 87HS Differential Highset can be tested by single phase secondary current injection These settings will usually be higher than the continuous thermal rating of the relay current inputs and equipment or test procedure should be arranged in such a way that t...

Page 315: ... 6 1 to check the current transformer ratio and the phase to earth connections Inject a current of sufficient magnitude for the relay ammeters to display These values should be compared with the ammeters connected in series with the relay Primary current The secondary current is Is C T ratio Use the circuit shown in Figure 2 6 2 to check the current transformer ratio and the phase to phase connect...

Page 316: ...7SR18 Commissioning Maintenance Guide Unrestricted 2018 Siemens Protection Devices Limited Page 17 of Figure 2 6 2 Primary Injection Phase to Phase ...

Page 317: ... load current to flow Both relays should be stable and the Signal Healthy LED on both relays should be permanently illuminated i e not flashing Test 1 Where Load Current is High This test applies when the load current is high enough to ensure that the restraint current is higher than half of P F Differential setting The restraint current is the average of the load current measured at each end Sinc...

Page 318: ... the relay to reset Test 2 Where Load Current is Low This test applies when the restraint current is below the P F differential settings 2 The connections are correct if the relay indicates an increase in differential current when the Phase Reversal applied to one relay only The Phase Reversal Setting is found in the CT VT Config Menu In this state the differential current should be approximately ...

Page 319: ...ge can be triggered either by the trip initiation i e Test No 1 or by energising a status input which has been programmed to trigger a waveform record i e Test No 2 These records can be used as part of the protection commissioning report for the relay under test Section 3 Putting Into Service After tests have been performed satisfactorily the relay should be put back into service as follows Remove...

Page 320: ...VTS 87L Diff x2 87L Diff x2 87L Diff x2 79 Ordering Options 74TCS x3 74CCS x3 86 81HBL2 81HBL2 51c 51c Figure 3 1 1 Phase Overcurrent Current Inputs IL1 IA IL2 IB IL3 IC Disable 51C 46 49 50CBF Map Pickup LED 51 n 50 n Self Reset Other protection functions may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity It should be particularly noted t...

Page 321: ...ut 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 Gradually reduce current until the element drops off and record the level ...

Page 322: ...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 seconds ANSI MI 4 85 ANSI VI 21 6 ANSI EI 29 1 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...

Page 323: ...ied TM 1 seconds IEC NI 9 7 IEC VI 43 2 IEC EI 58 2 IEC LTI 80 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 t...

Page 324: ... 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 Current setting to Disabled for the ...

Page 325: ...closed for more than the Cold Load Drop off Time or current less than the Reduced Current Level for greater than the Reduced 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 A...

Page 326: ...DTL applied 3 4 2 ANSI RESET If the element is configured as an ANSI characteristic it may have a reset delay applied If ANSI reset is selected for an IEC characteristic element the reset will be instantaneous ANSI reset times from operated condition to fully reset are as follows for zero applied current and TM 1 0 The reset curve characteristic type and TM is defined by the operating characterist...

Page 327: ...C EI 58 2 IEC LTI 80 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 reset time b reduced to 5...

Page 328: ...I 46BC Map Pickup LED 51N n 50N n Self Reset Other protection functions may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity Derived EF Measured EF protections can be Enabled Disabled individually or as groups in the Function Config menu Derived EF elements can be separated from Measured EF by arrangement of the secondary injection circuit b...

Page 329: ... 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 time Apply 5x setting current and record operating time Compare to calculated values for operating times P U D O TIMING ...

Page 330: ...n Devices Limited Page 31 of 3 5 3 ELEMENT BLOCKING The Derived Earth Fault elements can be blocked by Binary Input Inhibit and Inrush Detector operation This functionality should be checked Element BI Inhibits Inrush Detector 51N 1 51N 2 51N 3 51N 4 50N 1 50N 2 50N 3 50N 4 ...

Page 331: ... 3 5 5 IEC RESET If the element is configured as an IEC characteristic it may have an IEC decaying reset delay applied If IEC reset is selected for an IEC characteristic element the reset will be instantaneous IEC reset times from operated 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 operati...

Page 332: ...p LED 51G n 50G n Self Reset Other protection functions may overlap with these functions during testing it may be useful to disable some functions to avoid ambiguity Derived EF Measured 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 by secondary injection of current through the I4 inpu...

Page 333: ...t indication trip output alarm contacts waveform record 3 6 2 INVERSE TIME OVERCURRENT 51G 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 rec...

Page 334: ...EC LTI 120 00 30 00 ANSI MI 3 80 1 69 ANSI VI 7 03 1 31 ANSI EI 9 52 1 30 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 3 6 3 ELEMENT BLOCKING The Measured Earth Fault elements can be blocked by Binary Input Inhibit and Inrush Detector operation This functionality should be checked Element BI Inhibits Inrush Detector...

Page 335: ... 3 6 5 IEC RESET If the element is configured as an IEC characteristic it may have an IEC decaying reset delay applied If IEC reset is selected for an IEC characteristic element the reset will be instantaneous IEC reset times from operated 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 operati...

Page 336: ...urrent Current Inputs IL1 IA IL2 IB IL3 IC Disable 51 51C 37 49 50CBF 60CTS 46BC Map Pickup LED 46IT 46DT Self Reset Where 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...

Page 337: ...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 time Apply 5x setting current and record operating time Compare to calculated values for operating times P U D O TIMING TESTS Ph Dir Char...

Page 338: ... 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 reset time b reduced to 50 of the previous value Ensure that the second operate time c is 50 of the first a oper...

Page 339: ...e used with different settings it is convenient to test the element with the lowest setting first The higher setting element can then be tested without interference from the other element Apply 3Phase balanced current or single phase current on the single pole relay models and earth fault function 37G 37SEF at a level above the Undercurrent 37 n setting until the element resets Check operation wit...

Page 340: ...BLOCKING The Undercurrent elements can be blocked by Binary Input Inhibit This functionality should be checked Element BI Inhibits 37 1 37 2 37G 1 or 37SEF 1 37G 2 or 37SEF 2 3 8 2 ELEMENT BLOCKING FROM CURRENT GUARD The elements can be blocked by undercurrent guard function This functionality should be checked Element Guard Setting Blocked 37 1 37 2 Check correct phase indication trip output alar...

Page 341: ... IL1 IA IL2 IB IL3 IC Disable 51 50 37 50CBF Map Pickup LED 49Alarm The current can be applied from a 3P balanced supply 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 part...

Page 342: ...he thermal State then apply 2x the Overload Setting current Calculated Operate Time s Measured Operate Time s 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 m...

Page 343: ... 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 energised a...

Page 344: ...o receive a trip 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...

Page 345: ...nsformer Supervision Current Inputs IL1 IA IL2 IB IL3 IC Disable 51N 46IT 46DT 46BC Map Pickup LED 60CTS Self Reset Apply 3 Phase 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 current until the element resets Setting Measured 60CTS Delay 60CTS Inps 60CTS Vnps ...

Page 346: ... 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 component will be 1 3 of ...

Page 347: ...129 35 161 40 200 46BC Setting 3P balanced current A 1P unbalance current A Measured Unbalance current Apply 1 A 1P unbalance current without 3P balanced current Measure 46BC operating time 46BC Delay setting Measured 4 3 1 ELEMENT BLOCKING The Broken Conductor element can be blocked by Binary Input Inhibit This functionality should be checked Element BI Inhibits 46BC ...

Page 348: ... 2 I4 IG 74 T CCS NOTE The use of some functions are mutually exclusive 50 x2 51 x2 50N x2 50 x2 50 x2 51 x2 51 x2 51N x2 50G x2 51G x2 60 CTS 50 BF 51c 51c 51c Figure 4 4 1 Trip Circuit Supervision 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 TCS ...

Page 349: ...2 37 x2 49 50 BF IL3 IC 81 HBL 2 I4 IG 74 T CCS NOTE The use of some functions are mutually exclusive 50 x2 51 x2 50N x2 50 x2 50 x2 51 x2 51 x2 51N x2 50G x2 51G x2 60 CTS 50 BF 51c 51c 51c Figure 4 5 1 Magnetising Inrush Detector 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 100 Hz to cause operation of...

Page 350: ...nctionality is used the logic equations may interfere with testing of other protection functions in the relay The function of the Quick Logic equations should be tested conjunctively with connected plant or by simulation to assess suitability and check for correct operation on an individual basis with tests specifically devised to suit the particular application ...

Page 351: ...ering display 1 Operation of output contacts 2 Secondary injection of each element 6 2 MAINTENANCE Relay failure will be indicated by the Protection Healthy LED being off or flashing A message may also be displayed on the LCD The relay should be returned as a complete unit No attempt should be made to disassemble the unit to isolate and return only the damaged sub assembly It may however be conven...

Page 352: ...user intervention This is normal operation default instruments are enabled Remove all instruments from the default list and only add those that are required See Instrumentation Guide Cannot communicate with the relay Check that all of the communications settings match those used by Reydisp Evolution Check that all cables modems and fibre optic cables work correctly Ensure that IEC 60870 5 103 is s...

Page 353: ...7SR18 Commissioning Maintenance Guide Unrestricted Page 54 of 54 2018 Siemens Protection Devices Limited ...

Page 354: ...ithout the permission of Siemens Protection Devices Limited 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 negligen...

Page 355: ...e 2018 07 2016 11 First Issue 2017 05 Typographical revisions amended drawings 2017 11 Typographical revisions amended drawings 2018 07 Amended connection diagrams additional disposal information Software Revision History 2016 11 2436H80016R4d 1b First Release 2018 07 2436H80016R4i 1c Software maintenance to address production SW upload ...

Page 356: ... Ratio of a Through fault 24 5 3 Step 3 Estimate of Total Resistance of the CT Secondary Circuit 25 5 3 1 Example CT Requirement Solidly Earthed 10 km 132 kV Feeder 26 5 3 2 Fault Level and X R for a Phase Through fault 28 Section 6 Relay Functions Settings 30 6 1 Current Differential Protection 30 6 2 Backup Over Current and Earth fault Protection 32 6 3 Line Differential Enabled with Overcurrent...

Page 357: ...age 4 of 63 2018 Siemens Protection Devices Limited 9 3 2 Close Circuit Supervision Connections 62 9 4 Inrush Detector 81HBL2 62 9 5 Broken Conductor Load Imbalance 46BC 63 9 5 1 Broken Conductor example 63 9 6 Circuit Breaker Maintenance 63 ...

Page 358: ...ary Output Mapping for Local CB Control 37 Figure 6 6 2 3 Local Relay Quick Logic E1 E2 Programming 38 Figure 6 6 2 4 Local Relay Suitable Text for Function Key Operation Description 38 Figure 6 6 2 5 Local Relay E1 E2 Output Matrix Mapping to Virtual Connections 39 Figure 6 6 2 6 Local Relay Input Matrix Mapping Inter trip 85S 5 85S 6 to Remote Relay 39 Figure 6 6 2 7 Remote Relay Output Matrix I...

Page 359: ...vices Limited Figure 9 3 1 2 Trip Circuit Supervision Scheme 2 H6 61 Figure 9 3 1 3 Trip Circuit Supervision Scheme 3 H7 61 Figure 9 3 2 1 Close Circuit Supervision Scheme 62 List of Tables Table 2 1 1 1 Application of IDMTL Characteristics 14 Table 9 4 1 Magnetic Inrush Bias 62 ...

Page 360: ... Switchable earthing connections Loss of Grid connection see below Figure 1 1 1 Example Use of Alternative Settings Groups RADIAL SUBSTATION Start generators Select 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 e...

Page 361: ...m and Tripping Inputs A common use of 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 a...

Page 362: ...ceptible to mal operation the external circuitry can be modified to provide immunity to such disturbances see Figure 1 2 4 1 1 2 3 AC Rejection The default pick up time delay of 20 ms provides immunity to ac current for dc applications e g induced from cross site wiring Binary inputs can be configured for intentional operation from an ac power supply by setting pickup PU and drop off DO timers for...

Page 363: ... is to switch both positive and negative connections however this is often not possible or desirable As a guide to suitable degrees of enhanced immunity we have adopted the parameters laid down in U K standard EATS 48 4 This standard identifies two levels of immunity 1 Category ESI 1 may be adopted for connections which do not include significant wiring runs or cabling outside the relay enclosure ...

Page 364: ...7SR18 Applications Guide Unrestricted 2018 Siemens Protection Devices Limited Page 11 of 63 Figure 1 2 4 1 Binary Input Configurations Providing Compliance with EATS 48 4 Classes ESI 1 and ESI 2 ...

Page 365: ...used to display such digital signals as trips a general pick up plant control signals etc Each LED can be defined as Self or Hand Reset Hand reset LEDs are used where the user is required to expressly acknowledge the change in status e g critical operations such as trips or system failures Self reset LEDs are used to display features which routinely change state such as Circuit Breaker open or clo...

Page 366: ... 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 DTL Figu...

Page 367: ...ctors will be limited 2 1 1 Selection of Over current 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 The characteristic curve shape is selected to be the same type as the other relays on the same circuit or to grade with items of plant e g fuses or earthing resi...

Page 368: ...s For protection of cable feeders it is recommended that a 60 second DTL reset be used On overhead line networks particularly where reclosers are incorporated in the protected system instantaneous resetting is desirable to ensure that on multiple shot reclosing schemes correct grading between the source relays and the relays associated with the reclosers is maintained Figure 2 1 2 1 Reset Delay 2 ...

Page 369: ... A combination of instantaneous and DTL elements can be used in blocked over current protection schemes These protection schemes are applied to protect substation busbars or interconnectors etc Blocked over current protection provides improved fault clearance times when compared against normally graded over current relays The blocked over current scheme of busbar protection shown in Figure 2 3 2 i...

Page 370: ...dicates an unbalance in the phase currents either due to a fault or unbalanced load NPS current presents a major problem for 3 phase rotating plant It produces a reaction magnetic field which rotates in the opposite direction and at twice the frequency to the main field created by the DC excitation system This induces double frequency currents into the rotor which cause very large eddy currents in...

Page 371: ... both past and present current levels θ 0 for unheated equipment and θ 100 for maximum thermal withstand of equipment or the Trip threshold Figure 2 6 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 depende...

Page 372: ... only a minimal effect However this must be taken into account in establishing the appropriate setting to ensure proper grading c For dtl applications utilities as for b above a class 5P10 or 20 with rated burden to suit the load Note Over current factors do not need to be high for definite time protection because once the setting is exceeded magnitude accuracy is not important Often however there...

Page 373: ...rated CT s at one end and 5 A rated CT s at the other end CT ratio correction is provided in the range of 0 25 to 3 0 to cater for retrofit applications whereby the ratio at one end may be different to that of the other This setting operates on the secondary level of current from the line CT s The setting range of the CT ratio correction factor of 0 25 to 3 0 must be taken into account when consid...

Page 374: ... In can be ignored as this term would be a low value CT ratio selection would typically be e g Ifmax 50000 2500 1 ALF 20 A ALF of 20 means the CT is accurate to 20 x the primary CT current i e 20 x 2500 50000 e g Ifmax 25000 1250 1 ALF 20 Select a ratio of 1500 1 from Standard CT Series A ALF of 20 means the CT is accurate to 20 x the primary CT current i e 20 x 1500 30000 Alternately for 5P20 15 ...

Page 375: ...ee phase through fault current referred to the secondary side RS is the total resistive burden of the secondary circuit including CT secondary winding relay phase input and lead loop resistance The above formulae include a minimum safety margin in excess of 120 This may be utilised if the CT s calculated above are too large to fit in the Circuit Breaker chamber Therefore a 120 reduction may be mad...

Page 376: ...on and CB Figure 4 4 1 Relay Amplitude for CT Saturation for an external Phase Fault The above demonstrates that decreasing the Bias Break Point B2 setting has the effect of lowering the Minimum CT requirements The reduction in Bias Break Point setting must be balanced against making sure the relay will operate for load bias due to arc resistance and non effectively earth systems for single end fe...

Page 377: ...ults and detection of low level internal earth faults with load bias dictate the best setting to adopt 5 2 Step 2 Determine the Fault Level and X R Ratio of a Through fault This maximum level for a three phase through fault can be calculated if the source and feeder primary resistance R and reactance X values are known Sometimes only the source fault level at the busbars will be known The system p...

Page 378: ...XS and resistance RS will be fixed but the feeder reactance XF and resistance RF will increase with the length of the circuit This means the line impedance dominating the overall X R for the external fault as the circuit length increases Several sources feeding the busbar will have the affect of magnifying the feeder impedance For example four transformers feeding the busbar in parallel will have ...

Page 379: ... level of earth fault will always produce a large differential current and a fast and definite relay operation If the circuit were resistance or reactance earthed a higher setting would be required Differential Current 15000 1000 A 15 x IN Bias Current 15 0 2 7 5 x IN This fault would appear in the operate region of the bias characteristic at a percentage slope of approximately 200 If we assume th...

Page 380: ...s being set to 0 5 xIN the following CT formula is applicable 20 1 R X for Rs I Vk FM CT Requirements Case 1 Source X R 50 FL 14 kA Case 2 Source X R 17 5 FL 40 kA Vk 1 x 11312 1000 x RLL RPH RCT Vk 1 x 23741 1000 x RLL RPH RCT From the above Case 2 requirements are more onerous and should be used to calculate the Vk minimum required CT s for Substation A CT s for Substation B Vk 1 x 23741 1000 x ...

Page 381: ... set to provide fast tripping for close up faults if say a flexible earth clamp was inadvertently left connected when the circuit is energised 5 3 2 Fault Level and X R for a Phase Through fault Combinations of X R and Fault level will rarely exceed a maximum of 1000 on any power system This is because a high X R will tend to reduce the fault level System X R and fault level therefore have an inve...

Page 382: ...rds the lower end of this range If the cable feeder is longer than a few miles then it is fairly safe to use the X R of the cable Using more than one cable per phase will of course reduce this affect and increase charging current In all cases it is better to calculate the X R and fault level of the through fault if the data is available Where multiple sources are present to feed the fault this has...

Page 383: ...ines the minimum sensitivity of the internal fault that the protection can detect This setting also defines the bias current The feeder charging current must be assessed when defining the lowest setting that could be applied to a feeder The accuracy and correct ratio of the CT s is the main consideration when setting this This setting is default at 30 1 st Bias Slope this is used to allow the rela...

Page 384: ...7SR18 Applications Guide Unrestricted 2018 Siemens Protection Devices Limited Page 31 of 63 Figure 6 1 1 Relay Protected Zones ...

Page 385: ... caused by charging current under normal load and under fault conditions 6 3 Line Differential Enabled with Overcurrent Inhibited Overcurrent Enabled when Line Differential Inhibited Switch Over The relay can be configured to switch between Line Differential Protection only and Overcurrent Protection only in the event of Protection Communication Signalling failure i e have Line Differential only a...

Page 386: ...Page 33 of 63 Figure 6 3 3 Quick Logic Equation E1 Programming Figure 6 3 4 Output Matrix Equation E1 Virtual 2 LED Mapping Figure 6 3 5 Input Matrix Equation Virtual Overcurrent Inhibit 51 1 50 1 with Alarm 1 Mapping Figure 6 3 6 General Alarm 1 Overcurrent Inhibit suitable text ...

Page 387: ...Guard feature and hence avoid any unwanted relay operation This can be achieved by utilising a Quick Logic equation This example uses a 50 1 DTL element and also an 87L 1 differential element to logically AND together in an equation The current has to be above the 50 1 setting and there must also be a difference between local and remote current to produce an 87L 1 differential output These two par...

Page 388: ...al relay The output relay s assigned to trip the circuit breaker of the remote end relay must be allocated to the corresponding 85R n in the OUTPUT CONFIG menu or the OUTPUT MATRIX b Internally Initiated Inter tripping 87R Incorporates 87L n and 87HS n signals Internal inter tripping is a situation where one relay issues a command to the other relay to perform some action e g to trip a circuit bre...

Page 389: ... Guide Unrestricted Page 36 of 63 2018 Siemens Protection Devices Limited Figure 6 6 1 1 Local Relay Output Matrix Mapping Figure 6 6 1 2 Local Relay Input Matrix Mapping Figure 6 6 1 3 Remote Relay Output Matrix Mapping ...

Page 390: ...ut in the Output Matrix when a Function Key is pressed The equation E1 is set up as in Figure 6 6 2 3 such that when Function Key F3 is pressed E1 is True producing an output which is mapped in the Output Matrix to V1 see Figure 6 6 2 5 Similarly with F4 pressed E2 is True producing an output which is mapped in the Output Matrix to V2 These Virtuals connect to the Input Matrix and are mapped to In...

Page 391: ...restricted Page 38 of 63 2018 Siemens Protection Devices Limited Figure 6 6 2 3 Local Relay Quick Logic E1 E2 Programming for Remote Relay CB control Figure 6 6 2 4 Local Relay Suitable Text for Function Key Operation Description ...

Page 392: ... Limited Page 39 of 63 Figure 6 6 2 5 Local Relay E1 E2 Output Matrix Mapping to Virtual Connections Figure 6 6 2 6 Local Relay Input Matrix Mapping Inter trip 85S 5 85S 6 to Remote Relay Figure 6 6 2 7 Remote Relay Output Matrix Inter trip Mapping 85R 5 85R 6 to BO4 BO5 ...

Page 393: ...erential settings that may be used The relay must be set with a P F Differential setting that must be minimum multiple of the steady state charging current The steady state charging current may be calculated from the cable data and the circuit length This multiple of charging current is necessary to accommodate transient charging current steady state charging current and rises in phase to neutral ...

Page 394: ...educing the CT requirements 7 3 Single Phase Cable Feeders The major difference between this type of circuit and poly phase cable circuits is that the transient and steady state charging current will be higher The charging current will rise with rated voltage and the length of the circuit The variable setting relay is recommended for this type of circuit as it offers the flexibility to cope with a...

Page 395: ...y to ensure that the current transformer primary rating and ratio is compatible with the earth fault current or is of a lower value Example maximum fault current 800 A CT ratio 800 1 or 5 For low impedance earthed networks it is recommended that the differential sensitivity be no more than 80 of the minimum earth fault current The relay with variable differential settings should allow this to be m...

Page 396: ...wo transformers Minimum Feeder Earth Fault Level 400 A one transformer Charging Current per cable 4 5 A per km At the fault point the phase to neutral voltage may not fall significantly and therefore load current will continue to flow through the radial cable to the load during the earth fault The load will usually reduce but the full circuit rating is used to calculate the fault position on the r...

Page 397: ...an be compared graphically with the relay default P F Diff Setting of 0 3xIn and 30 Slope Figure 7 5 2 2 Setting of P F Diff Setting for Load Bias It is clear that the relay will not operate for this fault To detect this level of fault the relay P F Differential and or Slope 1 setting must be reduced This setting must be set in excess of the multiple of steady state charging current required by th...

Page 398: ...hed systems It also shows the fault point for the above example Where the relay is used on interconnected systems and the fault current is fed from both ends of the feeder double end fed the phase comparator will generally operate D ifferential C urrent x I N Restraint Current x IN MAGNITUDE COMPARITOR STABLE Bias Break Point Settings 0 5 1 0 1 5 MAGNITUDE COMPARITOR OPERATION Fault Sensitivity fo...

Page 399: ...ge 46 of 63 2018 Siemens Protection Devices Limited Figure 7 5 2 6 10 P F Differential and Bias Break Point of 0 5 1 0 1 5 and 2 0 Operate or Differential Current xIn Figure 7 5 2 7 15 Differential and Bias Break Point of 0 5 1 0 1 5 and 2 0 ...

Page 400: ...lts where the arc is extinguished and the fault re seals The reset of the relays may become out of step as the pulses of fault current usually are not long enough to allow relays to time out and eventually this will often lead to loss of grading Where circuits have pilot wires often this grading problem may be overcome by the use of this relay type For industrial networks employing the isolated ne...

Page 401: ...sequence and cause unnecessary lockouts The Sequence Fail Timer provides an overall maximum time limit on the AR operation It should therefore be longer than all the set delays in a complete cycle of AR sequences trip delays Deadtimes Reclaim Time etc Generally this will only be exceeded if the circuit breaker has either failed to open or close Since large fault currents could potentially damage t...

Page 402: ...k up followed by current switch off as AR sequences They would therefore also step to their Delayed Trip to retain co ordination with the respective downstream devices The next Trip would be subject to current grading and Lockout the AR sequence such that the fault is cleared by the correct CB 8 1 1 Basic Scheme Simple auto reclose scheme with different local and remote dead times If local relay f...

Page 403: ...7SR18 Applications Guide Unrestricted Page 50 of 63 2018 Siemens Protection Devices Limited Figure 8 1 1 3 Function Selection Figure 8 1 1 4 Protection Comms Intertrip Enable Configuration ...

Page 404: ...icted 2018 Siemens Protection Devices Limited Page 51 of 63 Figure 8 1 1 5 Overcurrent 51 1 Element Parameterisation Figure 8 1 1 6 Overcurent 50 1 Element Parameterisation Figure 8 1 1 7 Autoreclose Overcurrent Element Configuration ...

Page 405: ...estricted Page 52 of 63 2018 Siemens Protection Devices Limited Figure 8 1 1 8 Autoreclose Sequence Configuration Figure 8 1 1 9 Line Differential Element Parameterisation Figure 8 1 1 10 Auto Reclose Line Differential Protection ...

Page 406: ...7SR18 Applications Guide Unrestricted 2018 Siemens Protection Devices Limited Page 53 of 63 Figure 8 1 1 11 Auto Reclose Configuration Figure 8 1 1 12 P F Shot Configuration ...

Page 407: ...emote deadtime If Local fails to Close Remote will not close Local Remote Local CB Position Remote CB Position Local Trip Remote Trip Local Close Pulse Remote Close Pulse BI 1 CB Open 85S 1 85R 1 85S 1 85R 1 V2 79 Deadtime Inhibit 50 1 87L 1 BO2 85S 1 87L 1 BO2 BO5 85R 4 85S 4 Open Closed Closed Remote Deadtime Local Deadtime Open Closed Closed Local CB Position Source Figure 8 1 2 1 Scheme with R...

Page 408: ...7SR18 Applications Guide Unrestricted 2018 Siemens Protection Devices Limited Page 55 of 63 Figure 8 1 2 3 Remote CB Output Mapping Figure 8 1 2 4 Remote CB Output Mapping ...

Page 409: ...3 2018 Siemens Protection Devices Limited 8 1 3 Guarded Scheme Guarded Auto reclose scheme Added Blocking and LO Guard blocks local protection Remote is end which trips local and starts the local s AR Figure 8 1 3 1 Scheme with Guard Sequence of events ...

Page 410: ... adjacent CB s On other systems however this output will be used 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 i...

Page 411: ...e for each stage of the circuit breaker fail function is 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 F...

Page 412: ...relay model different methods are used to determine the condition depending upon the measured quantities available Current Transformer Supervision 60CTS 7SR18 without VTs Following a CT Failure if one or two of the three phases falls below the CT supervision setting the element will operate Operation is subject to a time delay to prevent operation for transitory effects A 3 phase CT failure is con...

Page 413: ...G INPUT MATRIX menu To avoid giving spurious alarm messages while the circuit breaker is operating the input is given a 0 4 s 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 9 3 1 Trip Circuit Supervision Connections The following circuits are derived from UK ENA S15 standard schemes H5 H6 and H7 F...

Page 414: ... of trip coil with the circuit breaker Open or Closed It does 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 Scheme 3 Comprehensive Figure 9 3 1 3 Trip Circuit Supervision Scheme 3 H7 Scheme H7 provides full Trip supervision with the circuit br...

Page 415: ...over current elements can be blocked Calculation of the magnetising inrush current level is complex However a ratio of 20 2 nd Harmonic to Fundamental current will meet most applications without compromising the integrity of the Over current protection There are 3 methods of detection and blocking during the passage of magnetising inrush current Phase Blocking only occurs in those phases where Inr...

Page 416: ...and it is therefore recommended to apply a setting as sensitive as possible In practice this minimum setting is governed by the levels of standing NPS current present on the system This can be determined from a system study or measured during commissioning making sure it is measured during maximum system load conditions to ensure all single phase loads are included Operation is subject to a time d...

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