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Siemens 7SG11 Argus, Manual

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7SG11 Argus User Manual 

The copyright and other intellectual property rights in this document, and in any model or article produced from it 
(and including any registered or unregistered design rights) are the property of Siemens Protection Devices 
Limited. No part of this document shall be reproduced or modified or stored in another form, in any data retrieval 
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 result of 
negligence or any other cause. Any and all such liability is disclaimed. 
 
©2013 Siemens Protection Devices Limited 

 
7SG11 Argus 

Overcurrent Protection Relays 

 
 

Document Release History 

This document is issue 2013/04. The list of revisions up to and including this issue is: 

 

2013/04 

Typographical revisions and added data 

2010/02 

Document reformat due to rebrand 

2006/08 

Fourth issue: VA Tech references replaced by Siemens Protection Devices Ltd 

2006/03 

Third issue: Additional modifications, software revision histories updates 

2004/05 

Second issue:- Improved CBF function, additional metering , Modbus protocol (not available in 
Argus 4 and Argus 6), extended timers added 

2002/12  

First issue 

 

Software Revision History 

 
Since introduction in 1995, Argus overcurrent relays have undergone a number of modifications to improve 
functionality and features provided. The content of this manual is directly applicable to the software versions listed 
below. When used with other versions minor variations may be noticed. A detailed release history for each type is 
given in the appropriate Diagrams and Parameters document. 
 

Argus 1 and Argus 2 

2434H80023 R13a 

release date July 2009 

Argus 1 and Argus 2 

2434H80023 R13 

release date November 2006 

Argus 1 and Argus 2 

2434H80023 R10 

release date November 2005 

Argus 2-500 

2434H80040 R8 

release date November 2005 

Argus 4 and Argus 6 

2716H80005 R5 

release date March 2005 

 

Hardware Release History 

 
Since introduction in 1995, Argus overcurrent relays have undergone a number of minor changes to hardware. 
The content of this manual is directly applicable to Argus hardware in Epsilon cases produced since March 2002. 
When used with earlier versions, minor variations may be noticed. A detailed release history for each type is given 
in the appropriate Diagrams and Parameters document. 
 

Summary of Contents for 7SG11 Argus

Page 1: ...Answers for energy 7SG11 Argus 1 6 Overcurrent Relay Reyrolle Protection Devices ...

Page 2: ...l 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 2011 Siemens Pr...

Page 3: ...rotection Devices Ltd 2006 03 Third issue Additional modifications software revision histories updates 2004 05 Second issue Improved CBF function additional metering Modbus protocol not available in Argus 4 Argus 6 extended timers added 2002 12 First issue Software Revision History Since introduction in 1995 Argus overcurrent relays have undergone a number of modifications to improve functionality...

Page 4: ... form AGn nnn and a Type of the form DCDnnnX or GAFnnnX where n is a digit and X is a letter Standard Models All of the types and ordering codes below refer to Epsilon case and ST fibre optic connectors optimised for 62 5 125 m glass fibre On request it may be possible to supply equivalent models fitted with SMA fibre optic connectors optimised for 62 5 125 m glass fibre or SMA fibre optic connect...

Page 5: ...burden binary input 5 Type of elements Single pole phase fault or single pole earth fault A Single pole sensitive restricted earth fault SEF REF B Nominal current 1 5 A A I O range 1 Binary Inputs 7 Binary Outputs incl 3 changeover 0 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E4 4U high C 1...

Page 6: ...geover 0 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E6 4U high D 1 High burden 110V 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V bi...

Page 7: ...t 7 Binary Outputs incl 3 changeover 0 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E6 4U high D 1 High burden 110V 220V binary inputs compliant with ESI48 4 ESI 1 available via external...

Page 8: ...ut 4 110 220 V DC auxiliary 220 V low burden binary input 5 Type of elements 3 pole phase fault and earth fault E Nominal current 1A B 5A C I O range 3 Binary Input 5 Binary Outputs incl 2 changeover 3 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E4 4U high C 1 High burden 110V 220V binary in...

Page 9: ...t directional G 3 Single pole sensitive restricted directional earth fault SEF REF H 2 Single pole sensitive restricted directional earth fault SEF REF H 3 Nominal current 1 5 A A I O range 1 Binary Input 7 Binary Outputs incl 3 changeover 0 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement chara...

Page 10: ...ctional M 2 D 2 pole phase fault and earth fault directional M 3 D Nominal current 1 5 A A I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 30º 45º for pha...

Page 11: ...e phase fault and earth fault directional Q 3 D Nominal current 1 5 A A I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 30º 45º for phase faults 1 0º 15º ...

Page 12: ...ase fault directional and earth fault directional and sensitive restricted earth fault SEF REF S Nominal current 1 5 A and 63 110 V AC D I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measu...

Page 13: ...ents 3 pole phase fault and earth fault E 3 pole phase fault and sensitive restricted earth fault SEF REF or 2 pole phase fault and earth fault and sensitive restricted earth fault SEF REF F Nominal current 1 5 A A I O range 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 1 RS485 interface IEC 60870 5 103 2 Housing size Case siz...

Page 14: ...ional and earth fault P 5 E 3 pole phase fault and earth fault directional Q 2 D 3 pole phase fault and earth fault directional Q 3 D Nominal current 1 5 A A I O range 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 1 RS485 interface IEC 60870 5 103 2 Directional measurement characteristic angle CA 30º 45º for phase faults 1 0º ...

Page 15: ...ional and earth fault P 5 E 3 pole phase fault and earth fault directional Q 2 D 3 pole phase fault and earth fault directional Q 3 D Nominal current 1 5 A A I O range 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 1 RS485 interface IEC 60870 5 103 2 Directional measurement characteristic angle CA 30º 45º for phase faults 1 0º ...

Page 16: ... SI 7 OR DCD321A AG1 303 DCD323A AG1 304 DCD324A DCD325A 5 SI 11 OR DCD321B AG1 313 DCD323B AG1 314 DCD324B 2 phase fault and SEF 9 S I 7 OR DCD321C AG1 323 DCD323C AG1 324 DCD324C 1 SI 7 OR DCD411A AG1 401 DCD413A AG1 402 DCD414A DCD415A DCD416A 5 SI 11 OR DCD411B AG1 411 DCD413B AG1 412 DCD414B DCD415B DCD416B 3 phase fault and earth fault 9 S I 7 OR DCD411C AG1 421 DCD413C AG1 422 DCD414C DCD41...

Page 17: ...2 422 DCD814C DCD815C DCD816C 5 SI 11 OR DCD821B AG2 413 DCD823B AG2 414 DCD824B DCD825B DCD826B 3 directional phase fault and SEF 9 S I 7 OR DCD821C AG2 423 DCD823C AG2 424 DCD824C DCD825C DCD826C 5 SI 11 OR DCD831B AG2 415 DCD833B AG2 416 DCD834B DCD835B DCD836B 3 phase fault and directional earth fault 9 S I 7 OR DCD831C AG2 425 DCD833C AG2 426 DCD834C DCD835C DCD836C 5 SI 11 OR DCD911B AG2 511...

Page 18: ...intenance Technical Reference Performance Specification Functional Description Application Notes Communication Interface Diagrams and Parameters Variants Settings IEC 60870 5 103 Definitions Application Diagrams P20006 P20007 P20008 Argus 1 P20009 Argus 2 P20010 Argus 4 P20011 Argus 6 Product Documentation Set Argus Overcurrent Protection Relays P1001 P300013 Argus Overcurrent Doc Structure ...

Page 19: ...ection Devices Ltd 2006 03 Third issue Additional modifications software revision histories updates 2004 05 Second issue Improved CBF function additional metering Modbus protocol not available in Argus 4 and Argus 6 extended timers added 2002 12 First issue Software Revision History Since introduction in 1995 Argus overcurrent relays have undergone a number of modifications to improve functionalit...

Page 20: ...60870 5 103 comms only 15 Section 3 Installation 16 3 1 Unpacking Storage and Handling 16 3 2 Recommended Mounting Position 16 3 3 Relay Dimensions 16 3 4 Wiring 16 3 5 Fixings 17 3 6 Ancillary Equipment 17 Section 4 Commissioning 18 4 1 Before Testing 18 4 2 Tests 19 4 3 Putting into Service 27 4 4 Commissioning Record Tables 28 Section 5 Testing and Maintenance 35 5 1 Periodic Tests 35 5 2 Maint...

Page 21: ...List of Tables Table 3 1 Wire crimp sizes 17 Table 4 1 IDMTL Timing Characteristic Time in Seconds 20 Table 4 2 Connections for Directional Polarity 22 Table 4 3 Limits of Operate Pick up Relay Angle Boundaries 23 Table 4 4 Pick up Drop off Results 28 Table 4 5 Timing Characteristic Results 28 Table 4 6 Lowset setting results 28 Table 4 7 Highset 1 setting results 29 Table 4 8 Highset 2 setting re...

Page 22: ...1 2 1 Case The Argus relay is housed in a drawout case designed for either panel mounting or modular 19 racking systems The case is 4U 177 mm high and will be of size 4 size 6 or size 8 width The chassis of the Argus can be withdrawn from the case by pulling on the handles provided Shorting contacts ensure that CT circuits and normally closed contacts remain short circuited All output contacts wil...

Page 23: ...breaker is closed Keypad Five keys are provided to control the functions of the Argus by moving around the menu display They are labelled ENTER CANCEL and The key is also labelled TEST RESET Only two push buttons are accessible when the front cover is in place These are the and buttons which allow the user to view all displays including settings but not to change setting values 1 2 4 Current and V...

Page 24: ...trip counter alarm the status inputs and the self monitoring feature watchdog In their normal mode of operation output contacts remain energised for the duration of fault current but with a user programmable minimum time Alternatively outputs can be programmed to operate as latching contacts if required Latched output relays can be reset either by pressing the TEST RESET button by sending an appro...

Page 25: ...delay setting ILS lowset current setting tLS lowset time delay setting Figure 1 1 Overcurrent Characteristics 1 3 1 2 Sensitive Earth fault Restricted Earth fault Sensitive earth fault and restricted earth fault protection schemes are achieved with identical internal functionality They incorporate filtering for rejection of second third and higher harmonics of the power system frequency Two DTL ti...

Page 26: ...d by an internal or external signal For each type of protection trip phase fault earth fault SEF or external a separate sequence of instantaneous and delayed trips is available Programmable dead times and reclaim times with a wide setting range and integrated sequence co ordination enable virtually all distribution auto reclose schemes to be achieved 1 3 3 Plant Monitoring 1 3 3 1 Trip Circuit Sup...

Page 27: ...isation of that input the associated alarm message is automatically displayed Where more than one General Alarm is raised then the display will scroll right to left to show all energised screens sequentially with screens separated by a sign If required more than one alarm may be mapped to a single status input allowing long messages to be displayed Default Instrumentation Screens The menu presenta...

Page 28: ...s picked up and the current measured at the time of trip The information scrolls along the bottom line of the display External alarms are also shown in the fault record e g 12 05 04 15 32 47 2525 G1 PHASE A LS IDMTL HS1 HS2 IA 12 32xIn The fault record is viewed in the Fault Data Display Mode of the menu display system and can be viewed again at a later date Fault records are stored for the previo...

Page 29: ...The selected group is then made active if the status input is energised and remains active for as long as the input remains energised If multiple status inputs are energised the lower or lowest number status input takes precedence For instance if status input 1 activates settings group 5 and status input 3 activates settings group 2 and both status inputs are energised the Argus would operate in s...

Page 30: ... setting is being edited this key will cancel the edit without changing the setting At all other positions CANCEL will move back up the menu system in the direction of the main menu TEST RESET key when the main menu is visible TEST RESET will briefly light all LEDs in order to test their operation After a trip occurs and the summary fault record is being displayed TEST RESET will reset the trip LE...

Page 31: ...hibits CB Status Power On Count ENTER Fault 1 Fault 2 Fault 3 Fault 4 Fault 5 dd mm yy hh mm Trip X X X Trip Relay Identifier TEST RESET overcurrent protection settings system configuration settings directional elements settings auto reclose settings output relay mappings status input mappings IEC 60870 5 103 comm settings waveform event and fault storage settings CB maintenance settings Argus 2 a...

Page 32: ...nfirmation screen appears the edit field will be flashing N for No Use the up or down key to change the field to Y for Yes and then press ENTER to confirm the change Pressing CANCEL or pressing ENTER without changing the field to Y will abort the change 2 1 2 Instruments While an instrument is being displayed it will be updated regularly 2 1 2 1 Default Instruments When an instrument is being disp...

Page 33: ...se buttons are recessed to prevent inadvertent operation of the keys Referring to Figure 2 1 it can be seen that all areas of the menu can be accessed using the and keys but that settings cannot be changed since the ENTER key is not accessible Counter instruments can be reset while viewing them by pressing RESET then using and RESET to confirm 2 2 Operation using Reydisp Evolution IEC 60870 5 103 ...

Page 34: ...to remove any modules from the chassis If any modules have been removed or tampered with then the guarantee will be invalidated Siemens Protection Devices Limited reserves the right to charge for any subsequent repairs 3 2 Recommended Mounting Position The Argus uses a liquid crystal display LCD which is used in programming and for operation The LCD has a viewing angle of 70 and is back lit Howeve...

Page 35: ... Kit ZA0005 062 comprising of Screw Pan Head M4x10mm Black ZB5364 101 2off Nut M4 2103F11040 2off Lock washer 2104F70040 2off Two kits are required for the R4 R6 and R8 case sizes 3 6 Ancillary Equipment The Argus can be interrogated locally or remotely by making connection to the fibre optic terminals on the rear of the case For local interrogation a portable PC with a fibre to RS232 modem is req...

Page 36: ...vent and waveform records should be cleared and the settings file checked to ensure that the required in service settings are being applied 4 1 2 Precautions Before electrical testing commences the equipment should be isolated from the current transformers and the CTs should be short circuited in line with the local site procedures The tripping and alarm circuits should also be isolated where prac...

Page 37: ...nals of the output relay circuits and measure the insulation resistance between these terminals and all other terminals connected together and to earth Argus 2 and Argus 6 only Connect together all of the V T terminals and measure the insulation resistance between these terminals and all other terminals connected together and to earth Satisfactory values for the various readings depend upon the am...

Page 38: ...nal protection then all Directional Control settings should be set to OFF during the following tests Pick up and Drop off Programme the current setting for the low high set characteristic to the required level and set its time delay to 0 00 sec Inject a level of current below the setting and increase the current until the output contact operates Record the Pick up level for each pole in Table 4 6 ...

Page 39: ...erate separate output contacts other than the main trip output They should also be programmed with their appropriate delays and current level setting CBF delay 1 is initiated by the main trip output and current above the setting after timing out it generates a trip output of its own and also initiates the CBF delay 2 which subsequently generates a final trip output Connect the main trip output to ...

Page 40: ... operation Boundary of Operation The purpose of this test is to ensure that the operating angles are correct for the forward and reverse zones of each pole Note that if a pole is programmed to operate in one direction only then only the angles for that operating zone need be checked Check that the required directional settings have been correctly applied including the characteristic angles Each di...

Page 41: ...es Adjust the phase angle of the currents relative to the voltages Verify directional pick up and drop off at points A B C and D Alternatively Verify correct directional indication at points a b c and d C A 800 1000 800 1000 A B D C a d b c FWD REV 300 600 900 1800 900 1200 1500 00 Figure 4 2 Directional Phase Fault Boundary System Angles Table 4 3 Limits of Operate Pick up Relay Angle Boundaries ...

Page 42: ...ts of the scheme 4 2 4 Auto Reclose Sequences These tests apply to Argus 4 and Argus 6 relays only The Auto Reclose sequences to be applied in service should be set up and proved for each of the fault types As detailed in section 4 1 1 it is suggested that a portable Personal Computer PC with Reydisp Evolution installed be connected to the Argus via an RS232 to Fibre Optic Modem and Fibre optic ca...

Page 43: ...e tested individually by the trip test feature which causes each output relay to be pulsed for the user programmable minimum dwell time or they can be checked during commissioning by testing the feature to which they are assigned Note A quick method of energising an output relay permanently so that wiring can be checked is to temporarily map the output relay being tested to the Protection Healthy ...

Page 44: ...low the available three phase load current Reverse the connections to the current coils and see that the Argus restrains If the flow of current is such that the Argus should restrain see that in fact it does restrain then reverse the connections to the current coils and see that it operates This test is based on the assumption that the load current has a normal power factor If however the power fa...

Page 45: ...all test connections Where possible the Argus settings should be down loaded to a computer and a printout of the settings produced This should then be compared against the required settings It is important that the correct settings group is active if more than one group has been programmed Reset all event waveform and fault records and reset all counters Replace all secondary circuit fuses and lin...

Page 46: ...1 1 Overcurrent IDMTL DTL Characteristic Table 4 4 Pick up Drop off Results Pole Pick up setting Measured pick up Pick up error 4 of 105 Measured drop off Drop off error 95 of pick up Phase A Phase B Phase C E F Table 4 5 Timing Characteristic Results 2x Is 5x Is Pole Characteristic NI VI EI LTI DTL Delay Error 5 or 30 ms Delay Error 5 or 30 ms Phase A Phase B Phase C E F Lowset and Highsets Table...

Page 47: ...g Measured pick up Error 5 of setting Phase A Phase B Phase C E F Table 4 9 Lowset timing results Pole Lowset delay setting Measured delay Error 5 or 30 ms of setting Phase A Phase B Phase C E F Table 4 10 Highset 1 timing results Pole Highset 1 delay setting Measured delay Error 5 or 30 ms of setting Phase A Phase B Phase C E F Table 4 11 Highset 2 timing results Pole Highset 2 delay setting Meas...

Page 48: ...EF REF Timing Results Delay Delay setting Measured delay Error 5 or 30 ms of setting Timer 1 Timer 1 2 Timer 2 Lowset 4 4 1 2 Circuit Breaker Fail Table 4 14 Pick up Drop off Results for CBF Level Detector Pole Pick up setting Measured pick up Error 5 of setting Measured drop off Error 95 of Pick up Phase A Phase B Phase C E F Table 4 15 Circuit Breaker Fail Timing Results CBF delay Delay setting ...

Page 49: ...p off Pick up Drop off Pick up Drop off A B C E F 4 4 2 Autoreclose Sequences These tests apply to Argus 4 and Argus 6 relays only Table 4 17 Auto reclose Sequences and settings Sequence setting Phase fault Earth fault SEF Status ARC IN OUT Line Check trip Protection Trip 1 Reclose delay 1 Protection Trip 2 Reclose delay 2 Protection Trip 3 Reclose delay 3 Protection Trip 4 Reclose delay 4 Protect...

Page 50: ...us User Manual 2013 Siemens Protection Devices Limited P20006 Page 32 of 37 4 4 3 Primary Injection Tests Table 4 18 Primary Injection Results Secondary current Phase injected Primary current A B C E A B B C B E ...

Page 51: ...81 79 83 81 82 80 53 49 45 25 54 50 46 26 A Figure 4 3 Secondary Injection Test Circuit Figure 4 4 Directional Test Circuit 240V a c supply V A VA VB VC IA IB IC phase shifting transformer E F or SEF REF A A B C primary injection test source Figure 4 5 Two out of three Directional Test Circuit Figure 4 6 Phase to Earth Primary Injection Test Circuit E F or SEF REF A A B C primary injection test so...

Page 52: ...wer flow 3 pole directional phase fault and directional earth fault forward reverse Ia Vref phase fault element forward reverse Ia Vpol earth fault element Vpol Vbn Vcn ve ve 53 54 49 50 45 46 25 26 A phase I P B phase I P C phase I P Earth fault I P P1 P2 S1 S2 M L Ia Ia test S C A phase fuse removed test S C test S C test S C A phase fuse removed test S C test S C LOAD Note that the terminal num...

Page 53: ...cept the password The Password being entered is wrong Enter correct password If correct password has been forgotten note down the Numeric Code which is displayed at the Change Password screen e g To retrieve the password communicate this code to a Siemens Protection Devices Limited Protection Healthy LED flashes General failure Contact Siemens Protection Devices Limited LCD screen flashes continuo...

Page 54: ...t Contact a Siemens Protective Devices Ltd representative WARNING DO NOT LOOK AT THE FIBRE OPTIC TRANSMITTER FOR A PROLONGED TIME Relays will not communicate in a ring network Check that the Data Echo setting on all relays is set to ON Check that all relays are powered up Check that all relays have unique addresses Status inputs do not work Check that the correct DC voltage is applied and that the...

Page 55: ...s in PMD Type of failure Device or module does not start up Mechanical problem Overload Sporadic failure Knock sensitive Transport damage Permanent failure Temperature caused failure Failure after ca hrs in use Repeated breakdown Failure after firmware update Error description Display message use separated sheet for more info Active LED messages Faulty Interface s which Wrong measured value s whic...

Page 56: ...whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2013 Siemens Protection Devices Limited 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2013 04 The list of revisions up to and including this issue is 2013 04 Typographical modifications 2010 02 Document reformat due to rebrand 2008 11 Six...

Page 57: ... 20 2 1 1 Models 21 2 1 2 Document Organisation 21 2 2 Configuration 22 2 2 1 Settings Groups 22 2 2 2 System Frequency 22 2 2 3 Current and Voltage Inputs 23 2 2 4 Identifier 24 2 2 5 General Alarms 24 2 2 6 Direction Tags 24 2 2 7 Real Time Clock 25 2 2 8 Default Instruments 25 2 2 9 Password 25 2 3 Phase fault and Earth fault Overcurrent 26 2 3 1 Delay Characteristic element 26 2 3 2 Instantane...

Page 58: ...n 60 3 7 Auto reclose Applications 60 3 7 1 Reclose Time Setting 60 3 7 2 Reclaim Time Setting 60 3 7 3 Shots to Lockout Setting 61 3 7 4 Sequence Auto reclosing 61 3 8 Trip Circuit Supervision 61 3 9 Output Relays 62 3 10 Post fault Analysis 62 3 10 1 Events Fault and Waveform Records 62 3 10 2 Fault triggers 62 3 10 3 Waveform triggers 63 3 10 4 ReyDisp IEC 60870 5 103 63 Section 4 Communication...

Page 59: ...igure 2 11 2 Output Relay Logic 46 Figure 3 2 1 Parallel Feeder Protection 55 Figure 3 4 1 Blocking scheme giving fast fault clearance 56 Figure 3 4 2 Busbar Zone Protection with Circuit Breaker Fail using Non directional Relays For use on Single source Feed Networks 57 Figure 3 4 3 Busbar Zone Protection with Circuit Breaker Fail Employing Bi Directional relays For use on fully Interconnected Net...

Page 60: ...mer Fail Settings 33 Table 2 16 Cold Load Pickup Settings 34 Table 2 17 Directional Settings 35 Table 2 18 Voltage Protection Settings 37 Table 2 19 Auto reclose from Internal Elements Settings 40 Table 2 20 Auto reclose from External Trip Settings 42 Table 2 21 Auto reclose Commands Settings 44 Table 2 22 Live Line Working Setting 45 Table 2 23 Trip Circuit Supervision Settings 45 Table 2 24 Gene...

Page 61: ...d Product Standard EN 60255 5 2000 1 1 2 Reference These products comply with the requirements of the IEC 60255 xx series and IEC 60068 standards and specifically with IEC 60255 3 and IEC 60255 12 1 1 2 1 Accuracy Reference Conditions This product has been tested under the following conditions unless specifically stated otherwise Parameter Value Current settings 100 In Time multiplier 1 0 IDMTL 2 ...

Page 62: ...meter Value Nominal frequency 50 60 Hz 1 2 1 1 AC Current Nominal Current and Measuring Range Nominal Measuring Range Phase and earth 80 x In In 1 5 A SEF REF 2 x In Note 1 A and 5 A nominal inputs are user selectable on each model Thermal Withstand Overload Current Phase and earth SEF REF Overload Period 1A 5A 1A 5A continuous 3 0 x In 2 0 x In 10 minutes 3 5 x In 5 minutes 4 0 x In 3 minutes 5 0...

Page 63: ... This will enable the status input performance specified below for the 48 54V status inputs to be achieved on 110 125 V or 220 250 V Nominal Operating Voltage Resistor Value Rating 110 125 V 2K7 5 2 5 W 220 250 V 8K2 5 6 0 W Performance Attribute Value VST 30 54 V 10 mA Minimum DC current for operation VST 110 250 V 5 mA Reset Operate voltage ratio 90 Typical response time 5 ms 10ms for ARGUS 2 ty...

Page 64: ...t rating to IEC 60255 0 20 Attribute Value Carry continuously 5 A AC or DC for 0 5 s 20 A AC or DC Make and carry L R 40 ms and V 300 V for 0 2 s 30 A AC or DC AC resistive 1250 VA AC inductive 250 VA at p f 0 4 DC resistive 75 W Break 5 A and 300 V DC inductive 30 W at L R 40ms 50 W at L R 10ms Minimum number of operations 1000 at maximum load Minimum recommended load 0 5 W at minimum of 10mA or ...

Page 65: ...2 shows the instantaneous operate times for the principal overcurrent starter These operate times apply to non directional characteristics Where directional control is applied then the directional element operate time section 1 4 4 should be added to give total maximum operating time 1 4 1 2 Lowset Highset 1 Highset 2 Operate Level Attribute Value Is Setting range 0 05 0 1 2 5 3 0 52 5 xIn Iop Ope...

Page 66: ...y 1 10 C to 55 C 5 Variation 47 Hz to 52 Hz 57 Hz to 62 Hz 5 Note SEF relays are required to suppress 2nd 3rd and higher harmonics and have a frequency response at minimum setting as shown in Figure 1 5 5 Operate Time Attribute Value tlowset tDTL1 tDTL2 Delay setting lowset DTL1 DTL2 0 00 0 01 20 00 20 5 100 101 300 s lowset tlowset 1 or 10 ms DTL1 tDTL1 1 or 10 ms Operating time DTL2 tDTL1 tDTL2 ...

Page 67: ...le in which the 65 setting is replaced by a 90 setting Operate Threshold Attribute Value I 5 In V p f 2 V Minimum levels for operation V e f 3 3 V Operate Time Attribute Value Operate time type I typically 20 ms at characteristic angle type II typically 40 ms at characteristic angle Reset time type I typically 20 ms at characteristic angle type II typically 40 ms at characteristic angle See Figure...

Page 68: ...1 1 4 7 Instrumentation Voltage power and power factor instruments are available on Argus 2 type II models only Instrument Value Reference Typical accuracy Claimed accuracy I Current I 0 1 xIn 1 In 3 In V Voltage V 0 8 xVn 1 Vn 3 Vn 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 1 4 8 Communication Interface Attribute Value Physical l...

Page 69: ...Installed with cover removed IP 30 1 5 2 Immunity 1 5 2 1 Auxiliary DC Supply Variation Quantity Value Allowable superimposed ac component 12 of DC voltage Allowable breaks dips in supply collapse to zero from nominal voltage 20ms 1 5 2 2 High Frequency Disturbance IEC 60255 22 1 Class III Type Level Variation Common longitudinal mode 2 5 kV Series transverse mode 1 0 kV 3 1 5 2 3 Electrostatic Di...

Page 70: ...uasi peak 30 to 230 MHz 40 dB V 230 to 10000 MHz 47 dB V 1 5 3 2 Conducted Radio Frequency Interference IEC 60255 25 Limits Type Quasi peak Average 0 15 to 0 5 MHz 79 dB V 66 dB V 0 5 to 30 MHz 73 dB V 60 dB V 1 5 4 Mechanical 1 5 4 1 Vibration Sinusoidal IEC 60255 21 1 Class I Type Level Variation Vibration response 0 5 gn Vibration endurance 1 0 gn 5 1 5 4 2 Shock and Bump IEC 60255 21 2 Class I...

Page 71: ...iemens Protection Devices Limited P20007 Page 16 of 71 0 01 0 1 1 10 100 1000 10000 1 10 100 Current multiple of setting I Is Time s normal inverse very inverse extremely inverse long time inverse Figure 1 5 1 IDMTL Curves Time Multiplier 1 ...

Page 72: ...to Contact Figure 1 5 3 Instantaneous Highset Operate Time to Contact Figure 1 5 4 Instantaneous Lowset Operate Time to Contact 0 10 20 30 40 0 5 10 15 20 25 Current multiple of setting I Is Time ms 0 10 20 30 40 0 5 10 15 20 25 Current multiple of setting I Is Time ms 0 10 20 30 40 0 5 10 15 20 25 Current multiple of setting I Is Time ms ...

Page 73: ...007 Page 18 of 71 0 20 40 60 80 100 120 50 60 70 80 90 Frequency Hz Pick up Level mA Figure 1 5 5 Sensitive Earth fault Frequency Response Is 5 mA Figure 1 5 6 Sensitive Earth fault Operate Time to Contact 0 10 20 30 40 0 5 10 15 20 25 Current multiple of setting I Is Time ms ...

Page 74: ...s Technical Reference 2013 Siemens Protection Devices Limited P20007 Page 19 of 71 0 20 40 60 80 100 120 90 60 30 0 30 60 90 Angle from Characteristic Angle Time ms Figure 1 5 7 Directional Timing Characteristic ...

Page 75: ... Lowset SEF REF Delay 1 SEF REF Delay 2 E F Charact Inhibit E F Lowset Inhibit E F Highset 1 Inhibit E F Highset 2 Inhibit SEF Lowset Inhibit SEF Delay 1 Inhibit SEF Delay 2 Inhibit E F FWD Block E F REV Block P F FWD Block P F REV Block 50BF circuit breaker fail CB Fail 1 CB Fail 2 IE ISE VN P F Highset 2 Inhibit Trip Circuit Fail Fault Trigger Lockout Alarm Close Pulse AUX Close ARC Active Recla...

Page 76: ...ncy CT VT ratios identifiers password etc 2 3 Phase Fault and Earth fault Overcurrent Protection 51 50 50 50 51N 50N 50N 50N phase fault time delayed overcurrent charact phase fault instantaneous overcurrent lowset phase fault instantaneous overcurrent highset 1 phase fault instantaneous overcurrent highset 2 earth fault time delayed overcurrent charact earth fault instantaneous overcurrent lowset...

Page 77: ... only done in a setting group that it is off line i e not active To assist in the parameterisation of different settings groups where only a few settings differ after entering user settings into one group the completed set of setting values can be copied from that group to another using the System Config Copy Group From Gn to Gx setting note that settings cannot be copied to the currently active g...

Page 78: ... purposes This setting will not affect the Protection Menu setting s display if they are displayed as xIn however see Current Display Bases below CT and VT ratios can be set allowing the relay to calculate primary currents and voltages for display VT settings appear on Argus 2 relays with type II directional elements only In addition to the VT ratio setting a VT connection setting allows a three p...

Page 79: ...output contact for the alarm this can be programmed using the status input to output relay mapping section 2 11 If multiple alarms are active simultaneously the messages are linked in series in a rolling display on the LCD separated by a character If it is necessary to display alarm messages longer than 13 characters then a status input may be mapped to multiple alarms in which case a longer messa...

Page 80: ...ult not mapped to any status 2 2 8 Default Instruments When a user stops accessing the keypad e g on leaving the Sub Station the relay will after a user set delay automatically switch to default metering whereby the user selected default instruments are displayed in turn at 5 seconds intervals without user intervention The time before this occurs is programmable with the System Config Default Scre...

Page 81: ...t of each element can be inhibited from a mapped status input set via the STATUS CONFIG MENU to allow comprehensive blocking schemes to be developed Furthermore on Argus 2 relays with type II directional elements the voltage element output can be set to raise inhibits The current input signals are sampled at a frequency of 1600 Hz 32 times per 50 Hz cycle giving a flat frequency response between 4...

Page 82: ... and settings are omitted Event Event Earth starter Earth delayed trip E F Charact Dir Control E F Charact Setting E F Charact E F Charact Time Mult E F Charact Delay Relay Reset Delay c Figure 2 3 2 Functional Diagram Characteristic Earth fault Overcurrent Element 2 3 2 Instantaneous elements There are three separate instantaneous elements per pole Lowset Highset 1 and Highset 2 The setting range...

Page 83: ...hib E F Lowset This diagram shows the logic for overcurrent elements in the forward direction reverse is similar On relays with no directional elements these inputs and settings are omitted Event Event Earth lowset starter Earth lowset trip E F Lowset Setting E F Lowset Dir Control c c Figure 2 3 4 Functional Diagram Instantaneous Earth fault Overcurrent Elements Table 2 11 Phase fault and Earth f...

Page 84: ...ction Gn E F Charact Dir Control 2 3 3 Flashing Pecking Fault Protection Flashing Faults are characterised by a series of short pulses of fault current which are intermittent if the IDMT DTL element characteristic has an instantaneous reset then it may not operate In order to detect and operate for such faults the relay has a setting that enables the user to set the Protection Relay Reset Delay Th...

Page 85: ...le directional SEF models the directional control setting applies to all the SEF Protection elements Figure 2 4 1 Functional Diagram Sensitive Earth fault Restricted Earth fault Elements Table 2 13 Sensitive Earth fault Restricted Earth fault Settings Sub menu Protection Setting name Range bold default Units Notes Gn SEF Dir Control OFF FWD REV TRI Argus 2 Single pole dir n SEF only Gn SEF REF Cur...

Page 86: ...evel detectors If the Circuit Breaker CB fails to respond to a Trip output and fault current continues to flow then the ARGUS Circuit Breaker Fail CBF function can be set to automatically issue a graded time delayed CBF 1 output Re trip then if that fails a second CBF 2 output Back Trip to an up stream CB Any Protection element or Status input for which a Trip output is required must be mapped to ...

Page 87: ...name Range bold default Units Notes Gn P F CB Fail Setting OFF 0 05 0 1 1 00 xIn Gn E F CB Fail Setting OFF 0 05 0 1 1 00 xIn Gn SEF CB Fail Setting OFF 0 005 0 96 xIn Gn CB Fail Time Delay 1 Gn CB Fail Time Delay 2 OFF 0 00 0 01 20 00 20 5 100 101 300 s sec Sub menu O P Relay Config Setting name Range bold default Units Notes Gn CB Fail 1 Gn CB Fail 2 _ 1 for each output contact default _ _ _ _ _...

Page 88: ...he circuit breaker is closed will apply that group s overcurrent and auto reclose settings until the user set Autoreclose Cold Load Reset time expires then revert to the normally active group The Relay can be set up to revert to the normally active group sooner if the load current falls and remains below the cold load group s Protection P F Highset 2 Setting for longer than the Protection P F High...

Page 89: ... overcurrent settings will be presented and operation will only occur for fault current falling within the forward operate zone Conversely if a protection element is programmed for reverse directional mode then the reverse zone overcurrent settings will be presented and operation will only occur for fault current falling within the reverse operate zone Where the tri state option is selected an ele...

Page 90: ...ere 1 2 1 fault current distribution can occur When the Directional 2 Out Of 3 Gate Logic setting is set to ON the directional elements will only operate for the majority direction e g if phase A and C detect forward current flow and phase B detects reverse current flow phase A and C will operate forwards while phase B will be inhibited 2 7 3 Voltage Memory In the condition of a 3 phase fault wher...

Page 91: ...e level detector Voltage V Ph Ph Setting Voltage V Ph N Setting with a follower definite time delay Voltage V Delay driving the Voltage V Trip output These outputs can be set by the Voltage V O P Phases setting to operate from any phase operation or only when all phase elements operate The Voltage V Hysteresis setting specifies the percentage above or beneath the Voltage V Ph Ph Setting Voltage V ...

Page 92: ...0 5 100 0 101 0 600 0 sec Gn V Hysteresis 1 2 90 Gn V Block Threshold OFF 1 2 5 100 V Gn V O P Phases Any One All Sub menu O P Relay Config Setting name Range bold default Units Notes Gn V Starter Gn V Trip Gn V Block Alarm _ 1 for each output contact default _ _ _ _ _ _ _ _ _ _ _ Sub menu Status Config Setting name Range bold default Units Notes Gn V Inhibit _ 1 for each status input default _ _ ...

Page 93: ...he STATUS CONFIG CB Open and STATUS CONFIG CB Closed settings and Fault current monitoring to determine if the circuit breaker is open or closed If the CB is closed or its state indeterminate due to interlock failure producing conflicting inputs a reclose Close pulse output will be inhibited but a Manual Close Reclaim or Remote Close Reclaim Close pulse output is always allowed The AUTO RECLOSE P ...

Page 94: ...to reclose P F HS1 Trips To Lockout and Auto reclose P F HS2 Trips To Lockout settings may be set to limit the number of high current trips or if set to 1 to truncate a P F sequence to Lockout if the HS1 or HS2 fault level setting is exceeded Reclose Delay Dead time and Close Routine The Reclose delay or line Dead Time is basically the length of time the Circuit Breaker is open before being reclos...

Page 95: ...y using the O P Relay Config Reclaimed setting Lockout Lockout is a state where the relay truncates the current sequence or operation and resets leaving the Circuit Breaker Open and no further action is taken The relay goes to the Lockout state when it reaches the last trip of a sequence without being able to clear a permanent fault or if conditions are such that a sequence or operation is truncat...

Page 96: ...DTL 1 sec Gn P F E F SEF Shots To Lockout 1 2 3 4 For 4 reclose shots 5 trips are issued the fifth trip is always delayed Gn P F E F HS1 Trips to Lockout 1 2 3 4 5 Gn P F E F HS2 Trips to Lockout 1 2 3 4 5 Not applicable to SEF sequence Reclaim Time 0 20 0 21 2 0 2 1 20 21 300 360 3600 3900 14400 sec Common setting across all Groups applies to all Sequences Close Pulse 1 0 1 1 2 0 10 0 sec Common ...

Page 97: ...Config SA Blocked setting This is intended to allow blocking of the external protection For example the Argus can provide the auto reclose sequences and back up IDMT protection to a distance protection The distance relay could be allowed to trip twice it can then be blocked and the IDMT protection of the Argus allowed to grade with other inverse protection relays to clear the fault Back up protect...

Page 98: ...then goes to lockout Local Close and Reclaim It is desirable that an Engineer should not be standing close to a Circuit Breaker when it is being closed it could close onto a fault which could cause it to fail This function inserts a Health and Safety time delay between the initiation by the operator of a Local Close Reclaim command to the relay and the relay sending an output to the CLOSE circuit ...

Page 99: ...ockout This command is typically used for a routine test of the Trip and Close operations of the Circuit Breaker Close and Lock in When this command is raised edge triggered if the CB is open the relay immediately issues a defined close pulse and then inhibits all Protection and Autoreclose functions This allows the circuit breaker to be operated as a switch without protection trip functions Table...

Page 100: ...itable pick up delay should be set on the status input More details about the application of trip circuit supervision are given in the Application Notes Section 3 8 Table 2 23 Trip Circuit Supervision Settings Sub menu Status Config Setting name Range bold default Units Notes Gn Trip Circuit Fail _ 1 for each status input default _ _ _ _ _ _ _ _ _ 2 11 Status inputs and Relay Outputs The status in...

Page 101: ...ming inactive Event Status 1 1 Status 1 1 Inverted Inputs Status 1 inverted Status 1 D O Delay Status 1 P U Delay Latched Inputs Status 1 latched S R Q Event Status n 1 Status n 1 Status n inverted Status n D O Delay Status n P U Delay Status n latched S R Q Input Matrix Or gates Logic signals e g P F Charact Inhibit P300008 Protection Functions Input Reset Flags Outputs Figure 2 11 1 Status Input...

Page 102: ...lear All Events setting All events can be obtained through the communications link and are displayed in the Reydisp Evolution package in chronological order allowing the user to see the sequence of events surrounding a trip They are also made available spontaneously to a compliant control system For a complete listing of events available in each model refer to the appropriate Diagrams and Paramete...

Page 103: ... LOCKOUT Recloser locked out following trip LINE CHECK TRIP Trip due to switch onto fault Auto reclose SA TRIP External trip General Alarms user defined text tag A user defined text tag can be programmed e g BUCHHOLZ TRIP Multiple Alarms are concatenated with symbols Example 12 05 04 17 25 51 2525 G1 PHASE A LS IDMTL HS1 HS2 IA 12 32xIn PHASE B LS IDMTL HS1 HS2 IB 12 23xIn PHASE C LS IC 0 78xIn EA...

Page 104: ...is reset at the start of the window and incremented with new values until the end of the window period Upon reaching the end of the window the average is calculated and a new window started The average and maximum quantities are reported with new instruments one for each quantity i e one screen would show IA MAX 300 0 or IA MAX 300 0 ROLL 176 0 FIXED 176 0 The display depends upon the window type ...

Page 105: ...ing The current flowing at the time of trip is added to individual summations for each phase If any of these exceed the alarm setting the output relays mapped by O P Relay Config I2 Alarm are raised An instrument shows the largest I2 summation of the three phases The summation can be reset using CB Maintenance I2 Reset or when viewing the summation instrument 2 14 1 3 Delta Trip Counter Argus 4 an...

Page 106: ...unter Reset Gn FOC Reset Argus 4 and Argus 6 only Gn I2 Update _ 1 for each status input default _ _ _ _ _ _ _ _ _ 2 14 2 Output Relay Test The output relay test allows the Argus to simulate a particular element operation e g P F Highset 1 and energise all output contacts that would normally be energised from that element output This is useful during commissioning routine tests so that wiring and ...

Page 107: ... 3 seconds Each time power is applied to the relay or the relay resets internal Power On and Reset counters are incremented the total count is shown in Instruments Power On Count An alarm level can be set in the CB Maintenance Power On Count Alarm and an output will be raised if the count is exceeded this can be mapped to an output relay Output Relay Power On Count This can be useful in tracing pr...

Page 108: ...e Setting Sub menu System Config Setting name Range bold default Units Notes Linesman Display VISIBLE HIDDEN If attempts are made to access Linesman mode when it is set to Hidden the Display will show Linesman Display hidden Table 2 31 Linesman Mode Settings and Commands Setting name Range bold default Units Note YES NO confirmation required Scada Control OFF ON Hot Line Working OFF ON Set to ON f...

Page 109: ...s The repeating process of the fault often causes electromechanical disc relays to ratchet up and eventually trip the faulty circuit if the reset time of the relay was longer than the time between successive flashes Early electronic IDMTL relays with instantaneous reset features were not at all effective in dealing with this condition and only tripped after the flashing fault had developed into a ...

Page 110: ...lied for feeder and busbar faults At A and B bi directional relays enable sensitive settings to be applied to the forward direction to detect transformer faults whilst reverse settings can be graded with forward settings at C and D By using a single bi directional Argus relay with different settings for forward and reverse directions complex ring circuits can be set to grade correctly whether faul...

Page 111: ...next upstream HS1 characteristic via a Status input All upstream HS1 elements have same overcurrent setting plus HS1 Delay DTL of 50ms IDMT protection not affected Scheme can be arranged to provide pilot wire supervision trip inhibit Radial System Overcurrent Protection Relay Overcurrent Protection Relay Overcurrent Protection Relay Figure 3 4 1 Blocking scheme giving fast fault clearance This exa...

Page 112: ...Fault HighSet 1 elements HS1 are applied to perform the busbar fault trip function and in all relays both Feeder and Incomer are set to the same current setting above the maximum load current but beneath the minimum fault current and with a minimum typically 100ms grading delay Each HSI output is mapped to trip its associated Circuit Breaker therefore if no block signal is raised then all circuits...

Page 113: ...rgus can be used to provide high impedance balanced or restricted earth fault protection as shown in Figure 3 5 1 The SEF REF starter output is used to provide an instantaneous trip output from the relay A separate Siemens Protection Devices Limited Publication is available covering the calculation procedure for REF protection To summarise the calculation The relay Stability operating Vs voltage i...

Page 114: ... resistor series stabilising resistor Argus REF element relay circuit P300012 REF Secondary Figure 3 5 2 Restricted Earth fault Secondary Circuit Composite overcurrent and REF protection can be provided using a multi element relay as Figure 3 5 3 P300012 REF Primary 25 45 49 53 46 50 54 26 non linear resistor series stabilising resistor overcurrent elements REF element Figure 3 5 3 Composite Overc...

Page 115: ...e circuits where a high percentage of faults that occur are of a transient nature and cause no permanent damage to connected plant The benefits of auto reclosing are Reduce to a minimum the loss of supply to the customer Allows greater automation of the network with relevant cost savings Instantaneous fault clearance is possible thereby minimising fault damage 3 7 1 Reclose Time Setting The reclos...

Page 116: ...90 of fault conditions 3 8 Trip Circuit Supervision The Argus relay can be used to supervise one or more trip circuits via status inputs with the associated circuit breaker open or closed A low value of d c current is passed through the entire trip circuit to monitor the auxiliary supply the trip coil its auxiliary switch the C B secondary isolating contacts and the relevant wiring links If the ci...

Page 117: ...iate isolator operation In due course this output relay can be remotely reset by a status input 3 10 Post fault Analysis Argus overcurrent protection relays provide extensive information for post fault analysis however to use this effectively the Argus must be correctly set when put into service This section describes measures that should be taken to ensure the correct data is captured in the even...

Page 118: ... that the current will continue to be present for one to two hundred milliseconds before the circuit breaker interrupts the current The Data Storage Waveform Pre Trigger setting allows a percentage typically 80 of the 1 second to be allocated to pre trigger recording The user should consider the application the likely fault type and the area of greater interest inception of fault or post trip wave...

Page 119: ...ed by ReyDisp Evolution software 4 2 1 Physical Connection The Argus complies with the physical requirements of IEC 60870 5 103 using fibre optics however it is possible to apply more flexible but non compliant settings for connection to PCs etc 4 2 2 Medium The communicating medium is optical fibre The device communicating with the Argus should have a fibre optic interface preferably optimised fo...

Page 120: ...he range but half the resolution per bit The Communications Interface IEC Class II Scaling setting should be set as appropriate for each system 4 2 9 Baud Rate Rates of 19200 9600 4800 2400 1200 600 300 150 110 and 75 bits per second are provided However only 19200 and 9600 are defined in IEC 60870 5 103 the additional rates are provided for local or modem communications The Communications Interfa...

Page 121: ...re configured Before applying the following settings the modem s factory default settings should be applied to ensure it is in a known state Several factors must be considered to allow remote dialling to the relays The first is that the modem at the remote end must be configured as auto answer This will allow it to initiate communications with the relays Next the user should set the data configura...

Page 122: ...hing settings If it cannot do this the local modem should be set with settings equivalent to those of the remote modem as described above Laptop computer P300007 Communications vsd Sigma 4 remote RS232 Sigma 4 SG4 103 Tx Rx Tx Rx Figure 4 2 1 Communication to Argus Relay using Sigma 4 Local Connection Laptop computer P300007 Communications vsd Sigma 4 remote RS232 Sigma 4 SG4 103 Tx Rx Telephone N...

Page 123: ...fibre optics or an RS485 interface 4 3 1 Medium The communicating medium is optical fibre or electrical RS485 The device communicating with the Argus should have an interface optimised for 62 5 125 µm glass fibre optics or RS485 electrical connection 4 3 1 1 Sigma Fibre optic to RS232 Converters See previous section 4 2 2 1 4 3 2 Recommended cable Selection of fibre optic cable is important Fibres...

Page 124: ...ices on any one RS485 connection 4 3 9 Line Idle If the communication medium is fibre optic the Communications Interface Line Idle setting defines the quiescent state When set as Light On binary 0 is represented by light on binary 1 is represented by light off and vice versa for Light Off mode While in Light On mode and the device is not communicating it maintains the Light On mode to allow breaks...

Page 125: ...with Sigma 1 and Fibre optic Star Network A Laptop computer P300007 Communications vsd RS485 RS232 RS232 RS485 A B B Figure 4 3 3 Communication to Argus Relay using RS485 RS232 converter Local Connection Laptop computer P300007 Communications vsd RS485 Multidrop RS232 RS485 A B A B A B A B A A B B Figure 4 3 4 Communication to Argus Relay using RS485 RS232 converter Multidrop Connection 4 3 11 Glo...

Page 126: ...ce for connecting computer equipment to a telephone line Parity Method of error checking by counting the value of the bits in a sequence and adding a parity bit to make the outcome for example even Parity Bit Bit used for implementing parity checking Sent after the data bits RS232C Serial Communications Standard Electronic Industries Association Recommended Standard Number 232 Revision C Start Bit...

Page 127: ...the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Devices Limited 7SG11Argus Overcurrent Protection Relays Document Release History This docume...

Page 128: ...nput Minor change SEF 2nd stage can be disabled Feb 2001 2434H80022 R1 Additional features general alarms status input inversion resettable instruments output relay pulse length setting 10 second delay on trip test Additional features CB fail trip circuit supervision single pole models Jan 2000 2434H80021 R5 Minor change current meter averaging Jul 1999 2434H80021 R4 Minor change status group sele...

Page 129: ...Minor change output relay minimum energise time reduced from 200 to 100 ms Minor change factory defaults display Minor change fault record text for characteristic element Apr 1996 2434H80002 7 R8 Minor change copy group setting default Minor change fault record text for characteristic element Minor change relay information provided in communications Apr 1996 2434H80002 7 R7 Minor change communicat...

Page 130: ...ge modification to grey fascia design logo dark grey band buttons and label Jan 2002 External change SMA fibre optic connectors replaced by ST TM BFOC 2 5 by default Jul 1999 Appearance change introduction of grey fascia design to replace existing black fascia Jul 1999 External change introduction of Epsilon case and terminal blocks Mar 1998 Additional features introduction of new expansion board ...

Page 131: ...on for Earth fault Protection 29 Figure 4 2 Typical Connection for Sensitive Earth fault Protection 30 Figure 4 3 Typical Connection for 3 Phase fault Protection 30 Figure 4 4 Typical Connection for 2 Phase fault and Earth fault Protection 31 Figure 4 5 Typical Connection for 2 Phase fault and Sensitive Earth fault Protection 31 Figure 4 6 Typical Connection for 3 Phase fault and Earth fault Prote...

Page 132: ...1A AG1 301 DCD313A AG1 302 DCD314A DCD315A DCD316A Figure 4 4 5 SI 11 OR DCD311B AG1 311 DCD313B AG1 312 DCD314B DCD315B DCD316B 3 phase fault or 2 phase fault and earth fault 9 SI 7 OR DCD311C AG1 321 DCD313C AG1 322 DCD314C DCD315C 1 SI 7 OR DCD321A AG1 303 DCD323A AG1 304 DCD324A DCD325A Figure 4 5 5 SI 11 OR DCD321B AG1 313 DCD323B AG1 314 DCD324B 2 phase fault and SEF 9 SI 7 OR DCD321C AG1 32...

Page 133: ...220 V low burden binary input 5 Type of elements Single pole phase fault or single pole earth fault A Single pole sensitive restricted earth fault SEF REF B Nominal current 1 5 A A I O range 1 Binary Inputs 7 Binary Outputs incl 3 changeover 0 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E4 4...

Page 134: ...ncl 3 changeover 0 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E6 4U high D 1 High burden 110V 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors w...

Page 135: ...inary Input 7 Binary Outputs incl 3 changeover 0 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E6 4U high D 1 High burden 110V 220V binary inputs compliant with ESI48 4 ESI 1 available vi...

Page 136: ... binary input 4 110 220 V DC auxiliary 220 V low burden binary input 5 Type of elements 3 pole phase fault and earth fault E Nominal current 1A B 5A C I O range 3 Binary Input 5 Binary Outputs incl 2 changeover 3 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E4 4U high C 1 High burden 110V 220...

Page 137: ...nt on the value of the Earth Fault Mode Select setting The second column in the tables Ref provides a reference to the section in the Technical Reference publication P20007 issue 2004 02 that describes the setting The third column is left blank to allow users to complete the table with applied settings System Config Menu Setting name Ref Applied value Active Settings Group 2 2 1 Settings Group Edi...

Page 138: ...c Gn Relay Reset Delay 2 3 3 sec Output Relay Configuration Menu See also Figure 2 1 on page 15 for the programming matrix Setting name Ref Applied value Gn Prot Healthy 2 14 3 Gn P F Starter 2 3 1 Gn P F Charact 2 3 1 Gn P F Lowset 2 3 2 Gn P F Highset1 2 3 2 Gn P F Highset2 2 3 2 Setting name Ref Applied value Gn E F Starter 2 3 1 Gn E F Charact 2 3 1 Gn E F Lowset 2 3 2 Gn E F Highset1 2 3 2 Gn...

Page 139: ... Gn Status 6 D O Delay 2 11 sec Gn Status 7 P U Delay 2 11 sec Gn Status 7 D O Delay 2 11 sec Gn Status 8 P U Delay 2 11 sec Gn Status 8 D O Delay 2 11 sec Gn Status 9 P U Delay 2 11 sec Gn Status 9 D O Delay 2 11 sec Gn Alarm 1 see note below 2 2 5 Setting name Ref Applied value Gn Alarm 2 see note below 2 2 5 Gn Alarm 3 see note below 2 2 5 Gn Alarm 4 see note below 2 2 5 Gn Alarm 5 see note bel...

Page 140: ...ection Devices Limited P20008 Page 14 of 33 CB Maintenance Menu Setting name Ref Applied value Trip Counter Reset 2 14 1 Trip Counter Alarm 2 14 1 ΣI Reset 2 14 1 ΣI Alarm 2 14 1 Power On Count Reset 2 14 3 Power On Count Alarm 2 14 3 O P Relay Test 2 14 2 ...

Page 141: ...50N 87G SEF REF sensitive earth fault restricted earth fault SEF Starter SEF Lowset SEF Delay 1 SEF Delay 2 Drop off Delay ms Pick up Delay ms Inverted Inputs Settings Group Select self supervision Prot Healthy S1 S2 S3 S4 S5 S6 S7 S8 S9 74TC Trip Circuit Fail trip circuit supervision Trip Circuit Fail Relay Identifier Relay Address Settings Group Argus Elements vsd AG1 R1 R2 R3 R4 R5 R6 R7 R8 R9 ...

Page 142: ... Communication Unit CU 5 Start Restart 6 Power On 7 Test Mode 8 Time Synchronisation 9 General Interrogation 10 Termination of General Interrogation 11 Local Operation 12 Remote Operation 20 Positive Command Acknowledge 21 Negative Command Acknowledge 31 Transmission of Disturbance Data Information Number and Function The following tables list information number and function definitions together w...

Page 143: ...ted x 1 1 9 11 12 20 21 RC x 160 25 Setting G3 selected x 1 1 9 11 12 20 21 RC x 160 26 Setting G4 selected x 1 1 9 11 12 20 21 RC x 160 27 Input 1 x 1 1 9 RC x 160 28 Input 2 x 1 1 9 RC x 160 29 Input 3 x 1 1 9 RC x 160 30 Input 4 x 1 1 9 RC x 160 36 Trip circuit fail x 1 1 9 RC x 160 46 Group Warning x 1 1 9 RC 160 47 Alarm x 1 1 9 RO 160 64 A starter x 2 1 9 RC x 160 65 B starter x 2 1 9 RC x 1...

Page 144: ...x 164 6 B lowset trip 2 1 RO x 164 7 C lowset trip 2 1 RO x 164 8 E lowset trip 2 1 RO x 164 9 A delayed trip 2 1 RO x 164 10 B delayed trip 2 1 RO x 164 11 C delayed trip 2 1 RO x 164 12 E delayed trip 2 1 RO x 164 13 A HS1 trip 2 1 RO x 164 14 B HS1 trip 2 1 RO x 164 15 C HS1 trip 2 1 RO x 164 16 E HS1 trip 2 1 RO x 164 17 A HS2 trip 2 1 RO x 164 18 B HS2 trip 2 1 RO x 164 19 C HS2 trip 2 1 RO x...

Page 145: ...ate x 1 1 9 RO 164 44 External Trip 2 1 RO x 164 45 Input 5 x 1 1 9 RC x 164 46 Input 6 x 1 1 9 RC x 164 47 Input 7 x 1 1 9 RC x 164 48 Input 8 x 1 1 9 RC x 164 49 Input 9 x 1 1 9 RC x 164 51 Output 1 x 1 1 9 12 20 21 RC x 164 52 Output 2 x 1 1 9 12 20 21 RC x 164 53 Output 3 x 1 1 9 12 20 21 RC x 164 54 Output 4 x 1 1 9 12 20 21 RC x 164 55 Output 5 x 1 1 9 12 20 21 RC x 164 56 Output 6 x 1 1 9 1...

Page 146: ...uit breaker closed x 1 1 9 RO 164 86 Close And Lockin 1 1 12 20 21 RO 164 87 Reclose delay x 1 1 9 RC 164 88 Reclaim x 1 1 9 RC 164 89 Lockout x 1 1 9 RC 164 90 Forward SEF x 2 1 9 RC 164 91 Reverse SEF x 2 1 9 RC 164 92 Power On Counter Alarm x 1 1 9 RC x 164 97 CT Failure x 1 1 9 RC x 164 100 Cold load pickup x 1 1 9 12 20 21 RC 164 101 Cold load trip 2 1 RO 164 102 Line check trip 2 1 RO 164 10...

Page 147: ...ca starter x 2 1 9 RC 164 170 V starter x 2 1 9 RC 164 182 V trip 2 1 RO 164 190 Voltage Memory A x 1 1 9 RC 164 191 Voltage Memory B x 1 1 9 RC 164 192 Voltage Memory C x 1 1 9 RC 164 240 Ia Fault Current x 4 1 9 x 164 241 Ib Fault Current x 4 1 9 x 164 242 Ic Fault Current x 4 1 9 x 164 243 Ie Fault Current x 4 1 9 x 164 244 Isef Fault Current x 4 1 9 x 164 245 Va Fault Voltage x 4 1 9 164 246 V...

Page 148: ...4 Energise Output 4 ON 20 20 x 164 55 Energise Output 5 ON 20 20 x 164 56 Energise Output 6 ON 20 20 x 164 57 Energise Output 7 ON 20 20 x 164 58 Energise Output 8 ON 20 20 x 164 59 Energise Output 9 ON 20 20 x 164 60 Energise Output 10 ON 20 20 x 164 61 Energise Output 11 ON 20 20 x 164 80 Trigger Waveform Storage ON 20 20 x 164 82 Trip and Lockout ON 20 20 164 83 Close and Reclaim ON 20 20 164 8...

Page 149: ...ed for access Please note not all addresses will apply to all models To configure MODBUS a new setting has been added to the communications sub menu to select the protocol to use either IEC60870 5 103 or MODBUS RTU After selecting MODBUS set the remaining parameters baud rate parity station slave address line idle and data echo as appropriate When an electrical RS485 module is connected to the Arg...

Page 150: ...F 01124 164 100 Cold Load Pickup ON OFF 01134 164 110 SEF ON OFF 01136 164 112 PF ARC Inhibit ON OFF 01137 164 113 EF ARC Inhibit ON OFF 01138 164 114 SEF ARC Inhibit ON OFF 01139 164 115 Instantaneous ON OFF 01140 164 116 P F Instantaneous ON OFF 01141 164 117 E F Instantaneous ON OFF 01142 164 118 SEF Instantaneous ON OFF 01143 164 119 Hot Line Working ON OFF 01154 164 130 Reset Maximum Demand O...

Page 151: ...n 11059 164 35 Setting G5 selected x 11060 164 36 Setting G6 selected x 11061 164 37 Setting G7 selected x 11062 164 38 Setting G8 selected x 11065 164 41 CB close fail 11067 164 43 CB DBI state 11069 164 45 Input 5 x 11070 164 46 Input 6 x 11071 164 47 Input 7 x 11072 164 48 Input 8 x 11073 164 49 Input 9 x 11075 164 51 Output1 x 11076 164 52 Output2 x 11077 164 53 Output3 x 11078 164 54 Output4 ...

Page 152: ...everse SEF 11116 164 92 Power On Counter Alarm x 11121 164 97 CT Failure x 11124 164 100 Cold load pickup 11127 164 103 ARC start A 11130 164 106 External trip block 11134 164 110 SEF off 11135 164 111 All ARC off 11136 164 112 P F ARC off 11137 164 113 E F ARC off 11138 164 114 SEF ARC off 11139 164 115 All inst off 11140 164 116 P F inst off 11141 164 117 E F inst off 11142 164 118 SEF inst off ...

Page 153: ... x 30113 Ib SECONDARY 2 1000 A x 30115 Ic SECONDARY 2 1000 A x 30117 Ie SECONDARY 2 1000 A x 30119 Isef ref SECONDARY 2 1000 A x 30121 Ia xIn 2 1000 xIn x 30123 Ib xIn 2 1000 xIn x 30125 Ic xIn 2 1000 xIn x 30127 Ie xIn 2 1000 xIn x 30129 Isef ref xIn 2 1000 xIn x 30131 A Direction 8 30139 B Direction 8 30147 C Direction 8 30155 E Direction 8 30163 Relay Status 8 x 30171 Status Inputs 8 x 30179 Tr...

Page 154: ...ONDARY 2 1000 V 30329 3Phase Power 2 1 kW 30331 3Phase Apparent Power 2 1 kVA 30333 3Phase Reactive Power 2 1 kVAr 30335 3Phase Power Factor 8 30343 Voltage Element 8 30393 WHr Forward 2 1 kWHr 30395 WHr Reverse 2 1 kWHr 30397 VArHr Forward 2 1 kVArHr 30399 VArHr Reverse 2 1 kVArHr 30401 IA PRIMARY Demand 2 1000 A x 30403 IB PRIMARY Demand 2 1000 A x 30405 IC PRIMARY Demand 2 1000 A x 30407 IA PRI...

Page 155: ... typical only 3 Diagram shows use of residual Holmgreen connection for E F circuit Alternatively use a ring core CT 4 Rear RS485 port is an ordering option On the last Relay on the bus only connect wire link as shown to include 120 ohm terminating resistor in circuit 25 26 27 28 13 14 15 3 4 5 6 7 8 9 10 16 17 18 11 12 19 20 S1 RL1 RL2 RL3 RL4 RL5 21 22 RL6 23 24 RL7 AG1 101 102 P300001 Argus 1 Co...

Page 156: ... 1 Diagrams and Parameters 2010 Siemens Protection Devices Limited P20008 Page 30 of 33 Figure 4 2 Typical Connection for Sensitive Earth fault Protection Figure 4 3 Typical Connection for 3 Phase fault Protection ...

Page 157: ...arameters 2010 Siemens Protection Devices Limited P20008 Page 31 of 33 Figure 4 4 Typical Connection for 2 Phase fault and Earth fault Protection Figure 4 5 Typical Connection for 2 Phase fault and Sensitive Earth fault Protection ...

Page 158: ...ers 2010 Siemens Protection Devices Limited P20008 Page 32 of 33 Figure 4 6 Typical Connection for 3 Phase fault and Earth fault Protection Figure 4 7 Typical Connection for 2 Phase fault Earth fault and Sensitive Earth fault Protection ...

Page 159: ... 2010 Siemens Protection Devices Limited P20008 Page 33 of 33 Figure 4 8 Typical Connection for 3 Phase fault and Sensitive Earth fault Protection Figure 4 9 Typical Connection for 3 Phase fault and Earth fault Protection 1A or 5A Version ...

Page 160: ...s Limited consent While the information and guidance given in this document is believed to be correct no liability shall be accepted for any loss or damage caused by any error or omission whether such error or omission is the result of negligence or any other cause Any and all such liability is disclaimed 2010 Siemens Protection Devices Limited 7SG11Argus Overcurrent Protection Relays Document Rel...

Page 161: ...inor change DTL timers extended to 5 minutes Mar 2003 2434H80023 R3 Minor change Time synch via IEC870 Nov 2002 2434H80023 R2 Minor change communications with ReyDisp Jun 2002 2434H80023 R1 Minor change power on alarm added Feb 2002 2434H80022 R3 Additional features CB fail all models Oct 2001 2434H80022 R2 Additional features external trip via status input Minor change SEF 2nd stage can be disabl...

Page 162: ...ied Apr 2003 2434H80040 R1 First Release Hardware Release History The Argus hardware is used in many different relays The list of hardware revisions applying to Argus 2 up to and including this document issue is Dec 2002 Additional features introduction of new models with star connected VTs Mar 2002 Appearance change modification to grey fascia design logo dark grey band buttons and label Jan 2002...

Page 163: ...ive Earth fault Protection 32 Figure 4 5 Typical Connection for 2 Directional P F and Directional E F Protection 32 Figure 4 6 Typical Connection for 2 Phase fault and Directional Earth fault Protection 33 Figure 4 7 Typical Connection for 3 Directional P F and Directional E F Protection 33 Figure 4 8 Typical Connection for 3 Directional Phase fault and Sensitive Earth fault Protection 34 Figure 4...

Page 164: ...AG2 316 DCD634B DCD635B DCD636B 2 directional phase fault and directional earth fault Fig 4 5 9 SI 7 OR DCD631C AG2 325 DCD633C AG2 326 DCD634C DCD635C DCD636C 5 SI 11 OR DCD641B AG2 317 DCD643B AG2 318 DCD644B DCD645B DCD646B 2 phase fault and dir n earth fault Fig 4 6 9 SI 7 OR DCD641C AG2 327 DCD643C AG2 328 DCD644C DCD645C DCD646C 5 SI 11 OR DCD811B AG2 411 DCD813B AG2 412 DCD814B DCD815B DCD8...

Page 165: ... earth fault directional G 3 Single pole sensitive restricted directional earth fault SEF REF H 2 Single pole sensitive restricted directional earth fault SEF REF H 3 Nominal current 1 5 A A I O range 1 Binary Input 7 Binary Outputs incl 3 changeover 0 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measur...

Page 166: ...fault directional M 2 D 2 pole phase fault and earth fault directional M 3 D Nominal current 1 5 A A I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 30º 4...

Page 167: ... 2 D 3 pole phase fault and earth fault directional Q 3 D Nominal current 1 5 A A I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 30º 45º for phase faults...

Page 168: ... 2 pole phase fault directional and earth fault directional and sensitive restricted earth fault SEF REF S Nominal current 1 5 A and 63 110 V AC D I O range 5 Binary Inputs 11 Binary Outputs incl 3 changeover 1 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 Communication interface Fibre optic ST connector IEC 60870 5 103 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directi...

Page 169: ... of other settings i e SEF Current Setting or REF Current Setting dependent on the value of the Earth Fault Mode Select setting The second column in the tables Ref provides a reference to the section in the Technical Reference publication P20007 issue 2004 02 that describes the setting The third column is left blank to allow users to complete the table with applied settings System Config Menu Sett...

Page 170: ...in Gn F E F Charact 2 3 1 Gn F E F Charact Time Mult 2 3 1 Gn F E F Charact Delay 2 3 1 sec GnR E F Charact Setting 2 3 1 xin GnR E F Charact 2 3 1 Setting name Ref Applied value GnR E F Charact Time Mult 2 3 1 GnR E F Charact Delay 2 3 1 sec Gn E F Lowset Dir Control 2 3 2 Gn F E F Lowset Setting 2 3 2 xIn Gn F E F Lowset Delay 2 3 2 sec GnR E F Lowset Setting 2 3 2 xIn GnR E F Lowset Delay 2 3 2...

Page 171: ...P F Starter 2 3 1 GnR P F Starter 2 3 1 Gn F P F Charact 2 3 1 GnR P F Charact 2 3 1 Gn F P F Lowset 2 3 2 GnR P F Lowset 2 3 2 Gn F P F Highset1 2 3 2 GnR P F Highset1 2 3 2 Gn F P F Highset2 2 3 2 GnR P F Highset2 2 3 2 Setting name Ref Applied value Gn F E F Starter 2 3 1 GnR E F Starter 2 3 1 Gn F E F Charact 2 3 1 GnR E F Charact 2 3 1 Gn F E F Lowset 2 3 2 GnR E F Lowset 2 3 2 Gn F E F Highs...

Page 172: ...eset Flag Outputs 2 11 Gn Clock Sync 2 2 7 Setting name Ref Applied value Gn Status 1 P U Delay 2 11 sec Gn Status 1 D O Delay 2 11 sec Gn Status 2 P U Delay 2 11 sec Gn Status 2 D O Delay 2 11 sec Gn Status 3 P U Delay 2 11 sec Gn Status 3 D O Delay 2 11 sec Gn Status 4 P U Delay 2 11 sec Gn Status 4 D O Delay 2 11 sec Gn Status 5 P U Delay 2 11 sec Gn Status 5 D O Delay 2 11 sec Gn Status 6 P U ...

Page 173: ...form Trig 2 13 3 Gn Waveform Pre trigger 2 13 3 Clear All Waveforms 2 13 3 Clear All Events 2 13 1 Clear All Faults 2 13 2 Demand Window Type 2 13 4 Demand Window 2 13 4 Setting name Ref Applied value Maximum Demand Reset 2 13 4 CB Maintenance Menu Setting name Ref Applied value Trip Counter Reset 2 14 1 Trip Counter Alarm 2 14 1 ΣI Reset 2 14 1 ΣI Alarm 2 14 1 Power On Count Reset 2 14 3 Power On...

Page 174: ...er non dir fwd E F Highset 2 Inhib E F Starter rev E F Charact non dir fwd E F Charact rev E F Lowset non dir fwd E F Lowset rev E F Highset 1 non dir fwd E F Highset 1 rev E F Highset 2 non dir fwd E F Highset 2 rev E F SEF FWD Block E F SEF REV Block SEF Delay 1 Inhib SEF Delay 2 Inhib SEF Lowset Inhib 50N 87G SEF REF sensitive earth fault restricted earth fault SEF Starter non dir fwd SEF Start...

Page 175: ...uit breaker operation counter Counter Alarm ΣI2 Alarm waveform recorder Waveform Trig ΣI2 Update Counter Reset Alarm 1 Alarm 2 Alarm 3 Alarm 4 Alarm 5 Reset Flag Outputs output relay control Hand Reset Min O P Energise Time S1 S2 S3 S4 S5 S6 S7 S8 S9 R1 R2 R3 R4 R5 R6 R7 R8 R9 R10 R11 Argus Elements vsd AG2 2 R1 R2 R3 R4 R5 R6 R7 R8 R9 R10 R11 real time clock Clock Sync fault recorder Fault Trigge...

Page 176: ...et Communication Unit CU 5 Start Restart 6 Power On 7 Test Mode 8 Time Synchronisation 9 General Interrogation 10 Termination of General Interrogation 11 Local Operation 12 Remote Operation 20 Positive Command Acknowledge 21 Negative Command Acknowledge 31 Transmission of Disturbance Data Information Number and Function The following tables list information number and function definitions together...

Page 177: ... 9 11 12 20 21 RC x x 160 25 Setting G3 selected x 1 1 9 11 12 20 21 RC x x 160 26 Setting G4 selected x 1 1 9 11 12 20 21 RC x x 160 27 Input 1 x 1 1 9 RC x x 160 28 Input 2 x 1 1 9 RC x x 160 29 Input 3 x 1 1 9 RC x x 160 30 Input 4 x 1 1 9 RC x x 160 36 Trip circuit fail x 1 1 9 RC x x 160 46 Group Warning x 1 1 9 RC 160 47 Alarm x 1 1 9 RO 160 64 A starter x 2 1 9 RC x x 160 65 B starter x 2 1...

Page 178: ...lowset trip 2 1 RO x x 164 7 C lowset trip 2 1 RO x x 164 8 E lowset trip 2 1 RO x x 164 9 A delayed trip 2 1 RO x x 164 10 B delayed trip 2 1 RO x x 164 11 C delayed trip 2 1 RO x x 164 12 E delayed trip 2 1 RO x x 164 13 A HS1 trip 2 1 RO x x 164 14 B HS1 trip 2 1 RO x x 164 15 C HS1 trip 2 1 RO x x 164 16 E HS1 trip 2 1 RO x x 164 17 A HS2 trip 2 1 RO x x 164 18 B HS2 trip 2 1 RO x x 164 19 C H...

Page 179: ...4 External Trip 2 1 RO x x 164 45 Input 5 x 1 1 9 RC x x 164 46 Input 6 x 1 1 9 RC x x 164 47 Input 7 x 1 1 9 RC x x 164 48 Input 8 x 1 1 9 RC x x 164 49 Input 9 x 1 1 9 RC x x 164 51 Output 1 x 1 1 9 12 20 21 RC x x 164 52 Output 2 x 1 1 9 12 20 21 RC x x 164 53 Output 3 x 1 1 9 12 20 21 RC x x 164 54 Output 4 x 1 1 9 12 20 21 RC x x 164 55 Output 5 x 1 1 9 12 20 21 RC x x 164 56 Output 6 x 1 1 9...

Page 180: ...5 Circuit breaker closed x 1 1 9 RO 164 86 Close And Lockin 1 1 12 20 21 RO 164 87 Reclose delay x 1 1 9 RC 164 88 Reclaim x 1 1 9 RC 164 89 Lockout x 1 1 9 RC 164 90 Forward SEF x 2 1 9 RC x 164 91 Reverse SEF x 2 1 9 RC x 164 92 Power On Counter Alarm x 1 1 9 RC x x 164 97 CT Failure x 1 1 9 RC x x 164 100 Cold load pickup x 1 1 9 12 20 21 RC 164 101 Cold load trip 2 1 RO 164 102 Line check trip...

Page 181: ...x 2 1 9 RC x 164 170 V starter x 2 1 9 RC x 164 182 V trip 2 1 RO x 164 190 Voltage Memory A x 1 1 9 RC x 164 191 Voltage Memory B x 1 1 9 RC x 164 192 Voltage Memory C x 1 1 9 RC x 164 240 Ia Fault Current x 4 1 9 x x 164 241 Ib Fault Current x 4 1 9 x x 164 242 Ic Fault Current x 4 1 9 x x 164 243 Ie Fault Current x 4 1 9 x x 164 244 Isef Fault Current x 4 1 9 x x 164 245 Va Fault Voltage x 4 1 ...

Page 182: ...put 3 ON 20 20 x x 164 54 Energise Output 4 ON 20 20 x x 164 55 Energise Output 5 ON 20 20 x x 164 56 Energise Output 6 ON 20 20 x x 164 57 Energise Output 7 ON 20 20 x x 164 58 Energise Output 8 ON 20 20 x x 164 59 Energise Output 9 ON 20 20 x x 164 60 Energise Output 10 ON 20 20 x x 164 61 Energise Output 11 ON 20 20 x x 164 80 Trigger Waveform Storage ON 20 20 x x 164 82 Trip and Lockout ON 20 ...

Page 183: ...unctions supported for access Please note not all addresses will apply to all models To configure MODBUS a new setting has been added to the communications sub menu to select the protocol to use either IEC60870 5 103 or MODBUS RTU After selecting MODBUS set the remaining parameters baud rate parity station slave address line idle and data echo as appropriate When an electrical RS485 module is conn...

Page 184: ... ON 01110 164 86 Close and Lockin ON OFF 01124 164 100 Cold Load Pickup ON OFF 01134 164 110 SEF ON OFF 01136 164 112 PF ARC Inhibit ON OFF 01137 164 113 EF ARC Inhibit ON OFF 01138 164 114 SEF ARC Inhibit ON OFF 01139 164 115 Instantaneous ON OFF 01140 164 116 P F Instantaneous ON OFF 01141 164 117 E F Instantaneous ON OFF 01142 164 118 SEF Instantaneous ON OFF 01143 164 119 Hot Line Working ON O...

Page 185: ... x 11058 164 34 Circuit breaker open 11059 164 35 Setting G5 selected x x 11060 164 36 Setting G6 selected x x 11061 164 37 Setting G7 selected x x 11062 164 38 Setting G8 selected x x 11065 164 41 CB close fail 11067 164 43 CB DBI state 11069 164 45 Input 5 x x 11070 164 46 Input 6 x x 11071 164 47 Input 7 x x 11072 164 48 Input 8 x x 11073 164 49 Input 9 x x 11075 164 51 Output1 x x 11076 164 52...

Page 186: ...13 164 89 Lockout 11114 164 90 Forward SEF x 11115 164 91 Reverse SEF x 11116 164 92 Power On Counter Alarm x x 11121 164 97 CT Failure x x 11124 164 100 Cold load pickup 11127 164 103 ARC start A 11130 164 106 External trip block 11134 164 110 SEF off 11135 164 111 All ARC off 11136 164 112 P F ARC off 11137 164 113 E F ARC off 11138 164 114 SEF ARC off 11139 164 115 All inst off 11140 164 116 P ...

Page 187: ...1000 A x x 30111 Ia SECONDARY 2 1000 A x x 30113 Ib SECONDARY 2 1000 A x x 30115 Ic SECONDARY 2 1000 A x x 30117 Ie SECONDARY 2 1000 A x x 30119 Isef ref SECONDARY 2 1000 A x x 30121 Ia xIn 2 1000 xIn x x 30123 Ib xIn 2 1000 xIn x x 30125 Ic xIn 2 1000 xIn x x 30127 Ie xIn 2 1000 xIn x x 30129 Isef ref xIn 2 1000 xIn x x 30131 A Direction 8 x x 30139 B Direction 8 x x 30147 C Direction 8 x x 30155...

Page 188: ... Vca SECONDARY 2 1000 V x 30329 3Phase Power 2 1 kW x 30331 3Phase Apparent Power 2 1 kVA x 30333 3Phase Reactive Power 2 1 kVAr x 30335 3Phase Power Factor 8 x 30343 Voltage Element 8 x 30393 WHr Forward 2 1 kWHr x 30395 WHr Reverse 2 1 kWHr x 30397 VArHr Forward 2 1 kVArHr x 30399 VArHr Reverse 2 1 kVArHr x 30401 IA PRIMARY Demand 2 1000 A x x 30403 IB PRIMARY Demand 2 1000 A x x 30405 IC PRIMAR...

Page 189: ...ion Devices Limited P20009 Page 30 of 37 Section 4 Application Diagrams The following pages contain example application diagrams for a variety of connections showing various hardware options Figure 4 1 Typical Connection for Directional Earth fault Protection ...

Page 190: ...nal expansion card fitted only on models AG2 321 and AG2 322 5 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit 48 47 46 45 52 51 50 49 56 55 54 53 13 14 15 3 4 5 6 7 8 9 10 16 17 18 11 12 19 20 S1 RL1 RL2 RL3 RL4 RL5 21 22 RL6 23 24 RL7 35 36 33 34 31 32 29 30 S2 S3 S4 S5 Direction of power flow in the forward direction 43 44 41 42 3...

Page 191: ...2010 Siemens Protection Devices Limited P20009 Page 32 of 37 Figure 4 4 Typical Connection for 2 Directional Phase fault and Sensitive Earth fault Protection Figure 4 5 Typical Connection for 2 Directional P F and Directional E F Protection ...

Page 192: ...ters 2010 Siemens Protection Devices Limited P20009 Page 33 of 37 Figure 4 6 Typical Connection for 2 Phase fault and Directional Earth fault Protection Figure 4 7 Typical Connection for 3 Directional P F and Directional E F Protection ...

Page 193: ...10 Siemens Protection Devices Limited P20009 Page 34 of 37 Figure 4 8 Typical Connection for 3 Directional Phase fault and Sensitive Earth fault Protection Figure 4 9 Typical Connection for 3 Phase fault and Directional Earth fault Protection ...

Page 194: ...s 2010 Siemens Protection Devices Limited P20009 Page 35 of 37 Figure 4 10 Typical Connection of Type AG2 5xx Dir P F and Dir E F with Star connected VT Figure 4 11 Typical Connection of Type AG2 5xx Dir P F and Dir E F with Open delta VT ...

Page 195: ...2010 Siemens Protection Devices Limited P20009 Page 36 of 37 Figure 4 12 Typical Connection of Type AG2 5xx Dir P F and SEF with Star connected VT Figure 4 13 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Star connected VT ...

Page 196: ...7SG11 Argus 2 Diagrams and Parameters 2010 Siemens Protection Devices Limited P20009 Page 37 of 37 Figure 4 14 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Open delta VT ...

Page 197: ...ction 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 2013 Siemens Protection Devices Limited 7SG11Argus Overcurrent Protection Relays ...

Page 198: ...it in two one for local delayed and one for remote no delay Minor change fault display shows lockout due to hot line working Minor change communications general command blocking Minor change trip count non fault trips and alarm action Nov 2000 2716H80004 R1 2 Internal Evaluation code version not released Sep 1999 2716H80003 R2 Minor change on screen alarm display Minor change frequent operation co...

Page 199: ... 3 IEC 60870 5 103 Definitions 13 Section 4 Application Diagrams 21 List of Figures Figure 2 1 Status Input and Output Relay Programming Matrix 12 Figure 4 1 Typical Connection for 3 Phase fault and Earth fault Protection 21 Figure 4 2 Typical Connection for 2 Phase fault Earth fault and Sensitive Earth fault Protection 22 Figure 4 3 Typical Connection for 3 Phase fault and Sensitive Earth fault P...

Page 200: ...he table uses two references for most relays each of which is valid an Order code of the form AGn nnn and a Type of the form GAFnnnX where n is a digit and X is a letter Order code Type 30 48 aux 110 220 aux Protection Application Diagram I O 30V status 48V status 48V status 110V status 220V status 3 phase fault and earth fault Fig 4 1 9 SI 7 OR GAF431C AG4 401 GAF433C AG1 402 GAF434C 3 phase faul...

Page 201: ...V DC auxiliary 48 V binary input 2 110 220 V DC auxiliary 48 V binary input 1 3 110 220 V DC auxiliary 110 V low burden binary input 4 110 220 V DC auxiliary 220 V low burden binary input 5 Type of elements 3 pole phase fault and earth fault E 3 pole phase fault and sensitive restricted earth fault SEF REF or 2 pole phase fault and earth fault and sensitive restricted earth fault SEF REF F Nominal...

Page 202: ...ext that may be displayed depending on the value of other settings i e SEF Current Setting or REF Current Setting dependent on the value of the Earth Fault Mode Select setting The second column in the tables Ref provides a reference to the section in the Technical Reference publication P20007 issue 2002 12 that describes the setting The third column is left blank to allow users to complete the tab...

Page 203: ... Time Delay1 2 5 sec Gn CB Fail Time Delay2 2 5 sec Gn Relay Reset Delay 2 3 3 sec Gn Backup Alarm SA 2 9 1 sec Gn Backup Trip SA 2 9 1 Sec Auto reclose Menu Setting name Ref Applied value Gn Line Check Trip 2 9 1 Gn Seq Edit View 2 9 Gn P F ARC 2 9 1 Gn P F Line Check Trip 2 9 1 Gn P F Protection Trip 1 2 9 1 Gn P F Reclose DTL 1 2 9 1 sec Gn P F Protection Trip 2 2 9 1 Gn P F Reclose DTL 2 2 9 1...

Page 204: ...6 sec Output Relay Configuration Menu See also Figure 2 1 on page 12 for the programming matrix Setting name Ref Applied value Gn Prot Healthy 2 14 3 Gn P F Starter 2 3 1 Gn P F Charact 2 3 1 Gn P F Lowset 2 3 2 Gn P F Highset1 2 3 2 Gn P F Highset2 2 3 2 Gn E F Starter 2 3 1 Gn E F Charact 2 3 1 Setting name Ref Applied value Gn E F Lowset 2 3 2 Gn E F Highset1 2 3 2 Gn E F Highset2 2 3 2 Gn SEF ...

Page 205: ...Status 3 P U Delay 2 11 sec Gn Status 3 D O Delay 2 11 sec Gn Status 4 P U Delay 2 11 sec Gn Status 4 D O Delay 2 11 sec Gn Status 5 P U Delay 2 11 sec Gn Status 5 D O Delay 2 11 sec Setting name Ref Applied value Gn Status 6 P U Delay 2 11 sec Gn Status 6 D O Delay 2 11 sec Gn Status 7 P U Delay 2 11 sec Gn Status 7 D O Delay 2 11 sec Gn Status 8 P U Delay 2 11 sec Gn Status 8 D O Delay 2 11 sec ...

Page 206: ... 3 Clear All Events 2 13 1 Clear All Faults 2 13 2 CB Maintenance Menu Setting name Ref Applied value Trip Counter Reset 2 14 1 Trip Counter Alarm 2 14 1 Trip Counter Reset 2 14 1 Setting name Ref Applied value Trip Counter Alarm 2 14 1 Freq Op Counter Reset 2 14 1 Freq Op Counter Alarm 2 14 1 I Reset 2 14 1 I Alarm 2 14 1 Power On Count Reset 2 14 3 Power On Count Alarm 2 14 3 O P Relay Test 2 14...

Page 207: ...0 P F Highset 1 instantaneous overcurrent 50 P F Highset 2 instantaneous overcurrent P F Charact Inhib P F Lowset Inhib P F Highset 1 Inhib P F Starter P F Highset 2 Inhib P F Charact P F Lowset P F Highset 1 P F Highset 2 51N E F Charact time delayed overcurrent 50N E F Lowset instantaneous overcurrent 50N E F Highset 1 instantaneous overcurrent 50N E F Highset 2 instantaneous overcurrent E F Cha...

Page 208: ... Reset Counter Reset FOC Reset Trip ARC Close Lockin Trip Lockout Loc Close Reclaim Rem Close Reclaim CB Open CB Closed Reclose Block P F ARC Off E F ARC Off SEF REF ARC Off Hot Line Working Lockout Alarm Close Pulse AUX Close ARC Active Reclaimed SA Blocked SA Alarm SA Trip Alarm 1 Alarm 2 Alarm 3 Alarm 4 Alarm 5 Reset Flag Outputs output relay control Hand Reset Pulsed Relays Min O P Energise Ti...

Page 209: ... 5 Start Restart 6 Power On 7 Test Mode 8 Time Synchronisation 9 General Interrogation 10 Termination of General Interrogation 11 Local Operation 12 Remote Operation 20 Positive Command Acknowledge 21 Negative Command Acknowledge 31 Transmission of Disturbance Data Information Number and Function The following tables list information number and function definitions together with a description of t...

Page 210: ...ed x 1 1 9 11 12 20 21 RC x 160 25 Setting G3 selected x 1 1 9 11 12 20 21 RC x 160 26 Setting G4 selected x 1 1 9 11 12 20 21 RC x 160 27 Input 1 x 1 1 9 RC x 160 28 Input 2 x 1 1 9 RC x 160 29 Input 3 x 1 1 9 RC x 160 30 Input 4 x 1 1 9 RC x 160 36 Trip circuit fail x 1 1 9 RC x 160 46 Group Warning x 1 1 9 RC x 160 47 Alarm x 1 1 9 RO x 160 64 A starter x 2 1 9 RC x 160 65 B starter x 2 1 9 RC ...

Page 211: ...owset trip 2 1 RO x 164 7 C lowset trip 2 1 RO x 164 8 E lowset trip 2 1 RO x 164 9 A delayed trip 2 1 RO x 164 10 B delayed trip 2 1 RO x 164 11 C delayed trip 2 1 RO x 164 12 E delayed trip 2 1 RO x 164 13 A HS1 trip 2 1 RO x 164 14 B HS1 trip 2 1 RO x 164 15 C HS1 trip 2 1 RO x 164 16 E HS1 trip 2 1 RO x 164 17 A HS2 trip 2 1 RO x 164 18 B HS2 trip 2 1 RO x 164 19 C HS2 trip 2 1 RO x 164 20 E H...

Page 212: ... x 1 1 9 RO x 164 44 External Trip 2 1 RO x 164 45 Input 5 x 1 1 9 RC x 164 46 Input 6 x 1 1 9 RC x 164 47 Input 7 x 1 1 9 RC x 164 48 Input 8 x 1 1 9 RC x 164 49 Input 9 x 1 1 9 RC x 164 51 Output 1 x 1 1 9 12 20 21 RC x 164 52 Output 2 x 1 1 9 12 20 21 RC x 164 53 Output 3 x 1 1 9 12 20 21 RC x 164 54 Output 4 x 1 1 9 12 20 21 RC x 164 55 Output 5 x 1 1 9 12 20 21 RC x 164 56 Output 6 x 1 1 9 12...

Page 213: ...ed x 1 1 9 RO x 164 86 Close And Lockin 1 1 12 20 21 RO x 164 87 Reclose delay x 1 1 9 RC x 164 88 Reclaim x 1 1 9 RC x 164 89 Lockout x 1 1 9 RC x 164 90 Forward SEF x 2 1 9 RC x 164 91 Reverse SEF x 2 1 9 RC x 164 92 Power On Counter Alarm x 1 1 9 RC x 164 97 CT Failure x 1 1 9 RC 164 100 Cold load pickup x 1 1 9 12 20 21 RC x 164 101 Cold load trip 2 1 RO x 164 102 Line check trip 2 1 RO x 164 ...

Page 214: ...33 Vc Vca starter x 2 1 9 RC 164 170 V starter x 2 1 9 RC 164 182 V trip 2 1 RO 164 190 Voltage Memory A x 1 1 9 RC 164 191 Voltage Memory B x 1 1 9 RC 164 192 Voltage Memory C x 1 1 9 RC 164 240 Ia Fault Current x 4 1 9 164 241 Ib Fault Current x 4 1 9 164 242 Ic Fault Current x 4 1 9 164 243 Ie Fault Current x 4 1 9 164 244 Isef Fault Current x 4 1 9 164 245 Va Fault Voltage x 4 1 9 164 246 Vb F...

Page 215: ...e Output 4 ON 20 20 x 164 55 Energise Output 5 ON 20 20 x 164 56 Energise Output 6 ON 20 20 x 164 57 Energise Output 7 ON 20 20 x 164 58 Energise Output 8 ON 20 20 164 59 Energise Output 9 ON 20 20 164 60 Energise Output 10 ON 20 20 164 61 Energise Output 11 ON 20 20 164 80 Trigger Waveform Storage ON 20 20 x 164 82 Trip and Lockout ON 20 20 x 164 83 Close and Reclaim ON 20 20 x 164 84 Trip And Re...

Page 216: ...9 Hot line working ON OFF 20 20 x 164 129 Reset Energy Meters ON OFF 20 20 164 130 Reset Maximum Demand ON OFF 20 20 x 255 0 Initiate General Interrogation 7 9 x 255 0 Time Synchronisation 6 8 x Note Events listed as responding to a General Interrogation GI will be raised and cleared RC other events are raised only RO and do not respond to a GI ...

Page 217: ...s are shown connected to 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of Holmgreen connection for E F circuit Use of separate ring core CT is also possible 48 47 46 45 52 51 50 49 56 55 54 53 25 26 27 28 13 14 15 3 4 5 6 7 8 9 10 16 17 18 11 12 19 20 S1 RL1 RL2 RL3 RL4 RL5 21 22 RL6 23 24 RL7 43 44 41 42 39 40 37 38 S6 35 36 33 34 ...

Page 218: ... 24 RL7 43 44 41 42 39 40 37 38 S6 35 36 33 34 31 32 29 30 S2 S3 S4 S5 S7 S8 S9 P2 P1 S2 S1 AG4 403 404 P300004 Argus 4 Connection Diagrams ArG4 403 404 2 A B C BUSBARS Rx Tx Rear F O comms ports see note 3 A B C SEF 1A 5A 1A 5A 1A 5A 1A 5A P2 P1 S2 S1 P2 P1 S2 S1 P2 P1 S2 S1 Notes 1 CT circuits are shown connected to 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typic...

Page 219: ...ction 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 2013 Siemens Protection Devices Limited 7SG11Argus Overcurrent Protection Relays ...

Page 220: ...ommand split in two one for local delayed and one for remote no delay Minor change fault display shows lockout due to hot line working Minor change communications general command blocking Minor change trip count non fault trips and alarm action Nov 2000 2716H80004 R1 2 Internal Evaluation code version not released Sep 1999 2716H80003 R2 Minor change on screen alarm display Minor change frequent op...

Page 221: ...gs 6 Section 3 IEC 60870 5 103 Definitions 14 Section 4 Application Diagrams 21 List of Figures Figure 2 1 Status Input and Output Relay Programming Matrix 13 Figure 4 1 Typical Connection for 3 Directional Phase fault and Directional Earth fault 21 Figure 4 2 Typical Connection for 3 Directional Phase fault and Sensitive Earth fault 22 Figure 4 3 Typical Connection for 3 Phase fault and Direction...

Page 222: ...f which is valid an Order code of the form AGn nnn and a Type of the form GAFnnnX where n is a digit and X is a letter Order code Type 30 48 aux 110 220 aux Protection Application Diagram I O 30V status 48V status 48V status 110V status 220V status 3 directional phase fault and directional earth fault Fig 4 1 9 SI 7 OR GAF911C AG6 401 GAF913C AG6 402 GAF914C GAF915C 3 directional phase fault and S...

Page 223: ...3 pole phase fault directional and earth fault directional or 3 pole phase fault directional and earth fault P 4 E 3 pole phase fault directional and earth fault directional or 3 pole phase fault directional and earth fault P 5 E 3 pole phase fault and earth fault directional Q 2 D 3 pole phase fault and earth fault directional Q 3 D Nominal current 1 5 A A I O range 9 Binary Inputs 7 Binary Outpu...

Page 224: ...rth Fault Mode Select setting The second column in the tables Ref provides a reference to the section in the Technical Reference publication P20007 issue 2002 12 that describes the setting The third column is left blank to allow users to complete the table with applied settings System Config Menu Setting name Ref Applied value Active Settings Group 2 2 1 Settings Group Edit View 2 2 1 Cold Load Pi...

Page 225: ...haract 2 3 1 GnR E F Charact Time Mult 2 3 1 GnR E F Charact Delay 2 3 1 sec Gn E F Lowset Dir Control 2 3 2 Gn F E F Lowset Setting 2 3 2 xIn Gn F E F Lowset Delay 2 3 2 sec Setting name Ref Applied value GnR E F Lowset Setting 2 3 2 xIn GnR E F Lowset Delay 2 3 2 sec Gn E F Highset1 Dir Control 2 3 2 Gn F E F Highset1 Setting 2 3 2 xIn Gn F E F Highset1 Delay 2 3 2 sec GnR E F Highset1 Setting 2...

Page 226: ... Protection Trip 2 2 9 1 Gn SEF REF Reclose DTL 2 2 9 1 sec Gn SEF REF Protection Trip 3 2 9 1 Gn SEF REF Reclose DTL 3 2 9 1 sec Gn SEF REF Protection Trip 4 2 9 1 Gn SEF REF Reclose DTL 4 2 9 1 sec Setting name Ref Applied value Gn SEF REF Shots To Lockout 2 9 1 GnSA ARC 2 9 1 GnSA Line Check Trip 2 9 1 GnSA Reclose DTL 1 2 9 1 sec GnSA Reclose DTL 2 2 9 1 sec GnSA Reclose DTL 3 2 9 1 sec GnSA R...

Page 227: ...n I Alarm 2 14 1 Gn Power On Count 2 14 3 Gn Hand Reset 2 11 Gn Pulsed Relays 2 11 Setting name Ref Applied value Gn Lockout Alarm 2 9 1 Gn Close Pulse 2 9 1 Gn AUX Close 2 9 1 Gn ARC Active 2 9 1 Gn Reclaimed 2 9 1 Gn SA Blocked 2 9 1 Gn SA Alarm 2 9 1 Gn SA Trip 2 9 1 Min O P Energise Time 2 11 ms Status Configuration Menu See also Figure 2 1 on page 13 for the programming matrix Setting name Re...

Page 228: ...eclaim 2 9 2 Gn CB Open 2 9 1 Gn CB Closed 2 9 1 Gn Reclose Block 2 8 1 Gn P F ARC Off 2 9 1 Gn E F ARC Off 2 9 1 Gn SEF REF ARC Off 2 9 1 Setting name Ref Applied value Gn Hot Line Working 2 9 4 Gn Alarm 1 see note below 2 2 5 Gn Alarm 2 see note below 2 2 5 Gn Alarm 3 see note below 2 2 5 Gn Alarm 4 see note below 2 2 5 Gn Alarm 5 see note below 2 2 5 The text of these setting names reflects the...

Page 229: ...ng name Ref Applied value Power On Count Alarm 2 14 3 O P Relay Test 2 14 2 Linesman Menu Setting name Ref Applied value Scada Control 2 15 Hot Line Working 2 15 Trip Lockout 2 15 Setting name Ref Applied value Trip Reclose 2 15 Close Reclaim 2 15 ARC 2 15 Inst Lowset 2 15 Trip Counter Reset 2 15 SEF 2 15 ...

Page 230: ...rent E F Charact Inhib E F Lowset Inhib E F Highset 1 Inhib E F Starter non dir fwd E F Highset 2 Inhib E F Starter rev E F Charact non dir fwd E F Charact rev E F Lowset non dir fwd E F Lowset rev E F Highset 1 non dir fwd E F Highset 1 rev E F Highset 2 non dir fwd E F Highset 2 rev E F SEF FWD Block E F SEF REV Block SEF Delay 1 Inhib SEF Delay 2 Inhib SEF Lowset Inhib 50N 87G SEF REF sensitive...

Page 231: ... Reset Counter Reset FOC Reset Trip ARC Close Lockin Trip Lockout Loc Close Reclaim Rem Close Reclaim CB Open CB Closed Reclose Block P F ARC Off E F ARC Off SEF REF ARC Off Hot Line Working Lockout Alarm Close Pulse AUX Close ARC Active Reclaimed SA Blocked SA Alarm SA Trip Alarm 1 Alarm 2 Alarm 3 Alarm 4 Alarm 5 Reset Flag Outputs output relay control Hand Reset Pulsed Relays Min O P Energise Ti...

Page 232: ... 5 Start Restart 6 Power On 7 Test Mode 8 Time Synchronisation 9 General Interrogation 10 Termination of General Interrogation 11 Local Operation 12 Remote Operation 20 Positive Command Acknowledge 21 Negative Command Acknowledge 31 Transmission of Disturbance Data Information Number and Function The following tables list information number and function definitions together with a description of t...

Page 233: ...ed x 1 1 9 11 12 20 21 RC x 160 25 Setting G3 selected x 1 1 9 11 12 20 21 RC x 160 26 Setting G4 selected x 1 1 9 11 12 20 21 RC x 160 27 Input 1 x 1 1 9 RC x 160 28 Input 2 x 1 1 9 RC x 160 29 Input 3 x 1 1 9 RC x 160 30 Input 4 x 1 1 9 RC x 160 36 Trip circuit fail x 1 1 9 RC x 160 46 Group Warning x 1 1 9 RC x 160 47 Alarm x 1 1 9 RO x 160 64 A starter x 2 1 9 RC x 160 65 B starter x 2 1 9 RC ...

Page 234: ...owset trip 2 1 RO x 164 7 C lowset trip 2 1 RO x 164 8 E lowset trip 2 1 RO x 164 9 A delayed trip 2 1 RO x 164 10 B delayed trip 2 1 RO x 164 11 C delayed trip 2 1 RO x 164 12 E delayed trip 2 1 RO x 164 13 A HS1 trip 2 1 RO x 164 14 B HS1 trip 2 1 RO x 164 15 C HS1 trip 2 1 RO x 164 16 E HS1 trip 2 1 RO x 164 17 A HS2 trip 2 1 RO x 164 18 B HS2 trip 2 1 RO x 164 19 C HS2 trip 2 1 RO x 164 20 E H...

Page 235: ... x 1 1 9 RO x 164 44 External Trip 2 1 RO x 164 45 Input 5 x 1 1 9 RC x 164 46 Input 6 x 1 1 9 RC x 164 47 Input 7 x 1 1 9 RC x 164 48 Input 8 x 1 1 9 RC x 164 49 Input 9 x 1 1 9 RC x 164 51 Output 1 x 1 1 9 12 20 21 RC x 164 52 Output 2 x 1 1 9 12 20 21 RC x 164 53 Output 3 x 1 1 9 12 20 21 RC x 164 54 Output 4 x 1 1 9 12 20 21 RC x 164 55 Output 5 x 1 1 9 12 20 21 RC x 164 56 Output 6 x 1 1 9 12...

Page 236: ...ed x 1 1 9 RO x 164 86 Close And Lockin 1 1 12 20 21 RO x 164 87 Reclose delay x 1 1 9 RC x 164 88 Reclaim x 1 1 9 RC x 164 89 Lockout x 1 1 9 RC x 164 90 Forward SEF x 2 1 9 RC x 164 91 Reverse SEF x 2 1 9 RC x 164 92 Power On Counter Alarm x 1 1 9 RC x 164 97 CT Failure x 1 1 9 RC 164 100 Cold load pickup x 1 1 9 12 20 21 RC x 164 101 Cold load trip 2 1 RO x 164 102 Line check trip 2 1 RO x 164 ...

Page 237: ...33 Vc Vca starter x 2 1 9 RC 164 170 V starter x 2 1 9 RC 164 182 V trip 2 1 RO 164 190 Voltage Memory A x 1 1 9 RC 164 191 Voltage Memory B x 1 1 9 RC 164 192 Voltage Memory C x 1 1 9 RC 164 240 Ia Fault Current x 4 1 9 164 241 Ib Fault Current x 4 1 9 164 242 Ic Fault Current x 4 1 9 164 243 Ie Fault Current x 4 1 9 164 244 Isef Fault Current x 4 1 9 164 245 Va Fault Voltage x 4 1 9 164 246 Vb F...

Page 238: ...e Output 4 ON 20 20 x 164 55 Energise Output 5 ON 20 20 x 164 56 Energise Output 6 ON 20 20 x 164 57 Energise Output 7 ON 20 20 x 164 58 Energise Output 8 ON 20 20 164 59 Energise Output 9 ON 20 20 164 60 Energise Output 10 ON 20 20 164 61 Energise Output 11 ON 20 20 164 80 Trigger Waveform Storage ON 20 20 x 164 82 Trip and Lockout ON 20 20 x 164 83 Close and Reclaim ON 20 20 x 164 84 Trip And Re...

Page 239: ...are options Figure 4 1 Typical Connection for 3 Directional Phase fault and Directional Earth fault A B C 83 82 81 79 80 Rx Tx Rear F O comms ports P2 P1 S2 S1 P2 P1 S2 S1 P2 P1 S2 S1 see note 3 Notes 1 CT circuits are shown connected to 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of Holmgreen connection for E F circuit Use of sep...

Page 240: ...3 24 RL7 Direction of power flow in the forward direction 43 44 41 42 39 40 37 38 S6 35 36 33 34 31 32 29 30 S2 S3 S4 S5 S7 S8 S9 Va Vb Vc P2 P1 S2 S1 A B C Phase rotation AG6 403 404 P300004 Argus 6 Connection Diagrams AG6 403 404 BUSBARS A B C SEF 1A 5A 1A 5A 1A 5A 1A 5A A B C 1 2 Rx Tx Rear F O comms ports P2 P1 S2 S1 P2 P1 S2 S1 P2 P1 S2 S1 see note 3 Notes 1 CT circuits are shown connected to...

Page 241: ...49 180 524 70 00 Fax 49 180 524 24 71 Charges depending on provider E mail support energy siemens com Power Distribution Division Order No C53000 G7076 C52 2 Printed in Fürth Printed on elementary chlorine free bleached paper All rights reserved Trademarks mentioned in this document are the property of Siemens AG its affili ates or their respective owners Subject to change without prior notice The...

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