Home

Complete Manual

Contents

1. OOOO OOOO Q Q 0 0 0 0 0 O0 0 Q O O O O Q O Q Q OOOO OOO OO O Q O O O O O0 O Q QD De De De Que DDD TO 270 7000 0010 0010 20 0 00010 2010 QD DDD OOO e e Q O O Q Q O O Q O o O O O O O 50BF CB Fail circuit breaker failure A Trip Alarm es SN 7 M 2 hy a Counter Alarm FOC Alarm XI Alarm y e ae eC 0 0 OO O O OOO OOO O OO OOOO esc O Lockout Alarm Ed ga dd rd Close Pulse E xr ue Ue Ro dr up ede sa De 0 0 0 0 0 0 0 0 0 0 0 ARC Active Reclaimed SA Blocked SA Alarm SA Trip OOO OO OOO Alarm 1 A AS qe ENE TENA EA q RENE CNN EUREN EON nes ED EIER Reset Flag amp Outputs output relay control O O O O Min O P Energise Time E i i AO D 10 dO GO ST O OR OO OD errrrrrre Argus Elements vsd AG4 amp 6 2 R2 O0 O O R3 O O O0 R1 00 O O Figure 2 1 Status Input and Output Relay Programming Matrix 2010 Siemens Protection Devices Limited P20011 Page 13 of 22 7SG11 Argus 6 Diagrams and Parameters Section 3 IEC 60870 5 103 Definitions The followi
2. o O O O SEF Starter SEF Delay 1 SEF Delay 2 SEF Lowset SEF Delay 1 Inhib 90N 87G SEF REF gt sensitive earth fault SEF Delay 2 Inhib restricted earth fault SEF Lowset Inhib BESRERERE Trip Circuit Fai 74TC Trip Circuit Fail OOO Omo Omo 0 0 trip circuit supervision PEA enero tas Fault Trigger Bd uq e O O O 0 O O O Q O waveform recorder fault recorder gg O 0 0 0 Q O O O Q Q O Ca R Ta eps p ECO Cloc SYNC eal time clock circuit breaker failure CB Fail 1 CB Fail 2 Le a oe a oe ae ee GR rasas CT Failure CT Failure Alarm XI Update O O O O O Counter Alarm Counter Reset circuit breaker operation counter XI Alarm CO O d Q T O e ji L O O L O O gt p 5 E O C508 e dq E M O Status 1 Status 2 Status 3 Status 4 Status 5 Status 6 Status 7 Status 8 Status 9 OOOO 2 B gt OOO OQ AO E OOO OOO OOOO OD OO OOOO O O O O EN d EO Alarm 1 Alarm 2 Alarm 3 Alarm 4 Alarm 5 d TT Me o QDO R output relay control O O O O e O O C QDO Q O O O OOOO Reset Flag 4 Outputs 10 dos QO a 11 Min O P Energise Time i i QO
3. OONn D C WC DW C C WC C C R2 06 O e R3 O O R1 O Ga Argus Elements vsd AG1 Figure 2 1 Status Input and Output Relay Programming Matrix 2010 Siemens Protection Devices Limited P20008 Page 15 of 33 7SG11 Argus 1 Diagrams and Parameters Section 3 IEC 60870 5 103 amp Modbus RTU Definitions 3 1 IEC 60870 5 103 Definitions The following tables give information on the IEC 60870 5 103 protocol A detailed description of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www siemens com energy in publications section under technical reports communications interface manual Table Showing Function Type Numbers Used Reyrolle Overcurrent Protection Cause of Transmission The cause of transmission COT column of the Information Number and Function table lists possible causes of transmission for these frames The following abbreviations are used Table Showing Permitted Cause of Transmission Numbers nen SOSO a Fre reno SSS T SSS Information Number and Function The following tables list information number and function definitions together with a description of the message and function type and cause of transmission that can result in that message Not all definitions are available on all relay types this is dependent on functionality KEY FUN Function Type defined in IEC60870 5 103 section 7 2 5 1 INF Information Number defined in IEC6
4. 1 wam N HG nm e ja NJ IN 1000 A 30403 IB PRIMARY Demand 2 100 A L 1000 30407 IA PRIMARY Max Demand 2 1000 A 30407 30409 30411 30413 30415 30417 3Phase Watt Demand 1000 IB PRIMARY Max Demand 2 1000 A x IC PRIMARY Max Demand 2 1000 A 1000 N IN IN IN IN 3Phase VarDemand 2 1 var 3Phase Watt Max Demand 2 1 wf LU eee Table Showing Holding Registers Description 2010 Siemens Protection Devices Limited Ml FORMAT SIZE WORDS mes dt P20008 Page 28 of 33 7SG11 Argus 1 Diagrams and Parameters Section 4 Application Diagrams The following pages contain example application diagrams for a variety of connections showing various hardware options Notes 1 CT circuits are shown propane AG1 101 102 connected to 1A inputs use 5A A B C d inputs for 5A rated CTs E 2 CT and earth connections are 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 Rear RS485 comms port ar 98 Oo y 2 0 SE YS O D See note 4 P300001 Argus 1 Connection Diagrams AG1 101 102 Figure 4 1 Typical Connection for Earth fault Protection 2010 Sieme
5. 2 pe Argus 1 NM MM NM NM K MB MB NM ND 2010 Siemens Protection Devices Limited P20008 Page 19 of 33 7SG11 Argus 1 Diagrams and Parameters re m wmmam x 5 x ww 71 comamenancenem x a 5 pa 104 esan x to me enepar x 9 ro LL LC LLLI Cw masa O x 9 8 Tl vivermos azar aol x 04 or remos connor ro x Cw ee mento H mm ao l laenn mm ao nape wmm rol 04 w omuwwese x o ro laenn mm ao 04 w memws x a fro Dw wmm H 9 fro Dw wfe x 9 8 04 meer x 2 9 fro Dw w meesr x 2 rel L LIC LLLI L LI LLLI ww mo camp x mmm ro Dm wem E 6 we wemewe ro Dw wemema x 9 8 paeas EC IE wwe H E Raa f x 9 f L LI LLLI js x wmm ro Dw w wmew f x se EC IE RIRE x iaa we refera x tmm e RIRE x wmm ro we ms remar x mz e we ve ferns HT m e e or erns x o asia ro Argus 1 02010 Siemens Protection Devices Limited P20008 Page 20 of 33 7SG11 Argus 1 Diagrams and Parameters we sem ra ro ii mo Hotinewoning x i notam Ro i io sacon x no 8 LLL LLLI Dw wmwwswe x 2 59 io Cw 132 vent aer x 2 39 8 Cw 199 veamos e 2 39 8 Dw we vm
6. 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 02010 Siemens Protection Devices Limited P20010 Page 19 of 22 7SG11 Argus 4 Diagrams and Parameters Description 164 119 Hot line working ON OFF 20 2 o 164 129 Reset Energy Meters ON OFF 20 2 Note Events listed as responding to a General Interrogation Gl will be raised and cleared RC other events are raised only RO and do not respond to a Gl 2010 Siemens Protection Devices Limited P20010 Page 20 of 22 7SG11 Argus 4 Diagrams and Parameters Section 4 Application Diagrams The following pages contain example application diagrams for a variety of connections showing various hardware options Notes BUSBARS ES 1 CT circuits are shown ABC q connected to 1A tap use d 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 comms ports P300004 Argus 4 Connection Diagrams ArG1 401 402 Figure 4 1 Typical Connection for 3 Phase fault and Earth fault Protection 2010 Siemens Protection Devices Limited P20010 Page 21 of 22 7SG11 Argus 4 Diagrams and Parameters Notes BUSBARS pa 1 CT circuits are shown ABC q connected to 1A tap use
7. 2010 Siemens Protection Devices Limited P20007 Page 49 of 71 7SG11 Argus Technical Reference Demand Window 5 10 15 60 90 300 360 1440 Maximum Demand Reset NO YES Self resetting Yes No confirmation required Sub menu CB Maintenance Setngname aeb mS Energy Meter Reset V applies only to Argus 2 type ll E NO YES Self resetting E id J ae Yes No confirmation required 2 14 Maintenance This section covers features to assist in the maintenance of circuit breakers the protection scheme and the Argus relay itself 2 14 1 S Breaker SIUS section 2 13 2 2 14 1 1 Trip Counter A trip counter is provided which increments on each trip command issued A suitable MAINENANCA limit value can be chosen from the circuit breaker manufacturer s data and entered into 2 14 12 Sum of I Circuit breaker contact wear increases with energy broken therefore summation provides a good estimation for maintenance purposes A suitable maine hanes limit value can be chosen from the circuit breaker manufacturer s 2 14 1 3 Delta Trip Counter Argus 4 and Argus 6 only This provides an additional counter which can be reset independently of the Trip Counter described above This can then be used for example for recording trip operations between visits to a substation 2 14 1 4 Frequent Operations Counter Argus 4 and Argus 6 only Argus 4 and 6 relays incorporate a Frequent Operations Counter FOC which logs the
8. 02010 Siemens Protection Devices Limited P20008 Page 14 of 33 7SG11 Argus 1 Diagrams and Parameters 81 2 S3 S4 S5 S6 7 S8 S9 Relay Identifier o o o o O o o o o Inverted Inputs Relay Address Settings Group Pick up Delay ms Drop off Delay ms Settings Group self supervision tse Select ij P F Charact Inhib 51 P F Charact P F Starter time delayed overcurrent P F Charact R1 O R2 ORS y RA RO R6 com cO rem ARG O R10 CO RTT O O Q OQ O OQ O OQ O OO OQ P F Lowset Inhib 50 P F Lowset P F Lowset PELI PO S instantaneous overcurrent d RO e ee ee RIE Highset 1 Inhib 50 P F Highset 1 P F Highset 1 URSS P F Highset 2 Inhib 90 P F Highset 2 P F Hiahset 2 UA wm wm instantaneous overcurrent 9 KLO O O O 0O O O O O O Ede 8 b E om E F Charact Inhib 51N E F Charact zaneta K O O O O Q Q Q Q Rss time delayed overcurrent E F Charact hm A i L E F Lowset Inhib 50N E F Lowset BE Tarsai E A E instantaneous overcurrent O O O r3 E F Highset 1 Inhib SON E F Highset 1 E F Highset 1 LI RS qq a E F Highset 2 Inhib 90N E F Highset 2 E F Highset 2 St 2a eee a T instantaneous overcurrent 480000 OOO O O O O O O O O O O O O O Q O O O Z o O e e O O
9. 1 5 4 Mechanical 1 5 4 1 Vibration Sinusoidal IEC 60255 21 1 Class Vibration response a lt 5 Vibration endurance 1 5 4 2 Shock and Bump IEC 60255 21 2 Class Shock response 5 gn 11 ms Shock withstand 15 gn 11 ms lt 5 Bump test 10 gn 16 ms 1 5 4 3 Seismic IEC 60255 21 3 Class 1 5 4 4 Mechanical Classification Type eve Dwabily 5 3 3 3 3 f opraons Level Durability gt 10 operations 02010 Siemens Protection Devices Limited P20007 Page 15 of 71 7SG11 Argus Technical Reference 10000 1000 100 C E 10 S SS i 0 1 0 01 1 10 100 Current multiple of setting I Is Figure 1 5 1 IDMTL Curves Time Multiplier 1 2010 Siemens Protection Devices Limited P20007 Page 16 of 71 7SG11 Argus Technical Reference BA e oO Time ms 10 19 Current multiple of setting I Is 20 Figure 1 5 2 Overcurrent Starter Operate Time to Contact 40 30 o E 20 10 0 0 5 10 15 20 25 Current multiple of setting I Is Figure 1 5 3 Instantaneous Highset Operate Time to Contact 40 230 o E E 20 10 0 0 9 10 15 20 25 Current multiple of setting
10. E time delayed overcurrent P F Starter rev O OQ P F Charact Inhib O O_O AN SC Ne Cy EN FV VY M y P F Charact non dir fwd As SA O O C M Dir n Off Fwd P F Charact rev OOO DO O Om O O O O QQ 50 P F Lowset P F Lowset non dir fwd L P F Highset 1 Inhib instantaneous overcurrent P F Lowset Inhib instantaneous overcurrent P F Lowset rev E ee ee E 30 Pir neat P F Highset 1 non dir fwd P F Highset 2 Inhib instantaneous overcurrent P F Highset 1 rev OQO O CS LCS KS KS CS SN NIST NU NU CN RD Di n Off Fwd me SUE Highsere PIF Highset 2 non dir fwd i O O a OQ O O P F Highset 2 rev ES cle ala We Ro dE o uh B os 4 Dir n Off Fwd 51N E F Charact E F Starter non dir fwd gt time delayed overcurrent E F Starter rev es OQ E F Charact Inhib O O O O E F Charact non dirffwd 2 1 4 42444 Dir n Off Fwd E F Charact rev 50N E F Lowset E F Lowset non dir fwd E F Highset 1 Inhiblinstantaneous overcurrent E F Lowset Inhib instantaneous overcurrent E F Lowset rev Dir n Off Fwd on neers E F Highset 1 non dir fwd E F Highset 1 rev O gt
11. 30121 30123 30125 30127 30129 30131 30139 30147 30155 30163 30171 30179 30187 30189 30191 30193 30195 30197 30199 30201 30209 30217 30257 30265 30273 30281 ARC Inhibits 02010 Siemens Protection Devices Limited P20008 Page 27 of 33 30289 Circuit Breaker EE UD 30297 Shot Number 30299 30301 30303 30305 30307 30309 30311 30313 30315 30317 VA PRIMARY VB PRIMARY VC PRIMARY VN PRIMARY VAB PRIMARY VBC PRIMARY VCA PRIMARY Va SECONDARY Vb SECONDARY 7SG11 Argus 1 Diagrams and Parameters I N lt ie ee ar RE RC G UC VA PRIMARY Da oe NEN Da A o 2 oe ee E P xem owed o 2 100 V 2 owes wo 8 Jose ow p o 2 100 V Da lim ow lo N lt NJ JN IN IN N IN N S ISS S po S S N lt 30319 ve SEconDaRY 2 100 v Vn SECONDARY 30321 30323 Vn SECONDARY Vab SECONDARY 30325 Vbc SECONDARY EE 30327 Vea SECONDARY asi 30329 3Phase Power ee AS EN ee oe ee E A o 100 V NEC A NC NJ lt lt lt NJ IN IN IN lt 3PhasePower 30331 3Phase Apparent Power 2 1 KA 30333 30335 30343 Voltage Element 30393 WHr Foward 2 1 30395 30397 30399 30401 WHr Reverse VArHr Forward VArHr Reverse IA PRIMARY Demand 30403 30405 IC PRIMARY Demand NJ IN 3PhaseReacivePower 2 1 Kr 3PhasePowerFactr 8
12. Figure 4 7 Typical Connection for 3 Directional P F and Directional E F Protection 2010 Siemens Protection Devices Limited P20009 Page 33 of 37 7SG11 Argus 2 Diagrams and Parameters Notes 1 CT circuits are shown connected to BUSBARS AG2 4x3 4x4 1A tap use alternative tap for 5A rated CTs A Br Ms 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG2 413 and AG2 414 5 Optional expansion card fitted only on models AG2 423 and AG2 424 6 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit e Cc Z S uc L SE oJ av os C of Do gs e Rear RS485 comms port Rear F Q comms ports Phase rotation see note 4 see note 5 P300002 Argus 2 Connection Diagrams AG2 4x3 4x4 Figure 4 8 Typical Connection for 3 Directional Phase fault and Sensitive Earth fault Protection Notes 1 CT circuits are shown connected to BUSBARS AG2 4x5 4x6 a use alternative tap for 5A rated ABC q 2 CT and earth connections are typical E only 3 Application shows use of Holmgreen connection for E F circuit Use of separate ring core CT is also possible 4 Optional expansion card f
13. YES NO confirmation required Hot Line Working Set to ON for live line working OFF ON When set On detection of a fault causes an instantaneous trip and lockout Trip amp Lockout Trip amp Reslose __ Trip amp Reclose NO YES and confirm Y to carry out EL amp Reclaim command ono 00 nstlowet ORON marga Reset NO YES mr ma IT 02010 Siemens Protection Devices Limited P20007 Page 53 of 1 7SG11 Argus Technical Reference Section 3 Application Notes 3 1 Selection of Characteristics In most applications especially where the relay must grade with other IDMTL relays on the system the characteristic curve is selected to be the same type as the others e g most relays have normal inverse curves type A to IEC 60255 3 and this would be the usual choice on the Argus relay Extremely inverse curves type C to IEC 60255 3 are often used to grade with fuses or moulded case circuit breakers Operating times become slower higher up the system due to the required grading margins between characteristics and VI and NI characteristics are needed Long Time Inverse can be used for thermal protection The Argus relay measures true RMS values of current and for this reason can be used to protect capacitor banks or other circuits where harmonics are significant Each pole has four independent overcurrent stages and each stage may be instantaneous or time lagged When grading with fuses these characteristics may b
14. amp nuaw vueu yueN go MIA 0 nueul ebeJoIs ejeq M8IA 0 NUS 998 19 U SUILUOS MAIA 0 amp nueul Byuoo snes MIA o lt a Nuou Byuos elay d O M9IA 0 amp NUSW M9IA 0 amp NUSW M9IA 0 amp NUSW UO IS OJA MIA 0 nueul Huon WIS S S po sues iz pue snbiy Sas So Re ara ien ei p 2 G T 1 1 1 1 1 1 1 e das j9sou Jejunos du LY Jasmo sul TIY Odv Ulle 293J Y SSO D asoj99y Y du jnox201 9 du BUMJOM SUIT JOH JONjUOS epeos SAS CO epo N uUeussum 9 pue y snfuy Jeynuep Aejoy ejdninuu UIA sBunes Jo 151 susaJos ad nui UO SUSY JO 1SI eje uo usas se Ae dsip uses hoy Ajuo sjoepoui 9 pue p snbiy P20006 Page 13 of 37 Menu Structure for Argus 1 2 4 and 6 Relays 2010 Siemens Protection Devices Limited Figure 2 1 7SG11 Argus User Manual Eight settings groups are stored within the Argus Only one of these is active at a time and only one can be displayed at a time Some settings have a common value across all groups If a setting has different values across the groups this is indicated by Gn in the top left of the display while the setting is being displayed where n is the number of the current display group The active group can be switched from one to another using the Active Group setting in the System Config sub menu Similarly the current di
15. optional 12 VDC power supply TX Rx lt q P300007 Communications vsd Sigma 3 Figure 4 2 3 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 3 and Fibre optic Ring Network 2010 Siemens Protection Devices Limited P20007 Page 67 of 71 7SG11 Argus Technical Reference Control system master link Auxiliary supply up to 29 slaves relays Laptop computer P300007 Communications vsd Sigma 1 Figure 4 2 4 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 1 and Fibre optic Star Network 4 3 Introduction Modbus RTU This section describes how to use the Modbus Interface with a compliant control system For further information regarding the interface reference should be made to the Argus Modbus implementation report 434 TIR 14 available on website www siemens com energy The same communications interface is used to provide control system connections The Argus complies with the physical requirements of Modbus using 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 um glass fibre optics or RS485 electrical connection 4 3 1 1 Sigma Fibre optic to RS232 Converters See previous secti
16. 9 1 4 2 Earthstault Overcurrent ProfecllOU oreet le e o 11 1 4 3 Sensitive Restricted Earth fault Protection 11 1 4 4 Directional Characteristics rara 11 1 4 5 Creu Breaker ole beh eet Lo caga detect Lo ce e t Renn eg ee 12 1 4 6 ATO do A a a O pa o A Oey 13 1 4 7 NSTUMEenta ON da EE e ee ea PO A M s c eed DE e 13 1 4 8 Gommunicaton Interfaces beds 13 1 4 9 Realtime Go RERO TREE 13 1 5 Environmental PEro man Co x22 iv ee ios 13 1 5 1 CSOT a Tee TC CRT 13 o2 MPMI ads da Sel aid DD ba io da ra a Laio A 14 1 5 3 P M aC sce ac a AU US GD SR fu nae esse ne a q au E aM 15 1 5 4 Mai sei piadas EE E A Sa TM 15 Section 2 Functional Description aa sa eee eee ca nite pean te eae een a Fou A cite buda EDU nb so EGO Ra a DU banda En 20 2 JRO CUI CHOU A os cae is era eee e Ren a RE cabe e aces AS das Dina arab ipo no E Sed s PERSAS f arius MEX eS 20 2 1 1 ae Ss citi TTL 21 22 DOCUMENT OLAMISAUO s f siete tatiana eai Ea os deiode e boe Alea A AUS aie dass Dad pi 21 A ULL LIN CL iL eda ecl Ll 22 2 2 1 SeMS OIoupS oum toten dae ta ecc a Dec Museu dU a f Lus LAE ia Cad 22 2 2 2 OVS Pr QUEEN nata ari ln il dont 22 22 3 Currentand Voltage Inputs tice hn e a A A ass 23 2 2 4 Ko Cea Aho REPE ERE A A URN PORE 24 2 2 5 General ANS accro uetus Sut tci tesis titt Pl Ls IE El a MP UL LR IE ELE ELTE 24 2210 DIS CUON TAGS ao 24 2 2 7 SATI a Ea Rau Dor LU DM M MAU a M ML M Na 25 2 2 8 DAA RET o O ed 25 2 2 9 e A a E a
17. Dir n Off Fwd 50N E F Highset 2 R l E F Highset 2 non dir fwd E F Highset 2 Inhib instantaneous overcurrent 3 l E F Highset 2 rev O O Toro OO sens O OQ O O O Dir n On Fwd 50N 87G SEF REF SEF Starter non dir fwd oO L aaa sensitive earth fault SEF Delay 1 non dir fwd i restricted earth fault SEF Delay 1 Inhib 0 0 0 0 0 0 0 0 0 0 0 SEF Delay 2 non dirfwd 1 4 4 4 2245 SEF Delay 2 Inhib SEF Lowset non dir fwd L SEF Lowset Inhib SEF Starter rev SEF Delay 1 rev SEF Delay 2 rev SEF Lowset rev Om Qu De Que OO OOOO 67 67N P F FWD Block directional overcurrent P F REV Block E F SEF FWD Block V Inhib E F SEF REV Block OO Do e e J Oe OO 0 0 0 0 0 0 V Starter V Trip V Inhib undervoltage overvoltage O OO OQO JOO V Block Alarm sci f uy d T ES Ne 74TC Trip Circuit Fail Trip Circuit Fail trip circuit supervision O de O O C O Q Q Argus Elements vsd AG2 1 continued on following page 2010 Siemens Protection Devices Limited P20009 Page 15 of 37 7SG11 Argus 2 Diagrams and Parameters continued from previous page use i SRO HRS RA R5 RO sus RT R8
18. ero LLL C T a efem x 9 ro e meam tino AO H HH e foume x HTH e o omms x HTHH Cw o foum f x mm Dw or fous iaa e Dw eme ee a ref Dw e wen x re Dw w mes x fre 04 e wmems 5 rel x Dw e mec HT tro x Dw mee HT re 04 e wmec 5 re x Argus 4 NM MM NM NM NO MB MB NM KM 2010 Siemens Protection Devices Limited P20010 Page 16 of 22 7SG11 Argus 4 Diagrams and Parameters re m wmnam x a 5 re ww 71 comamenancesem a o gt CO IO IES II IS IO II Cw mas H 9 8 O eanne amar ol x 04 or remos connor ro Cw w weoxa H 1 m aol x l laenn ir aol 04 or Tranan mm aol x 04 aata x a ro x laaa ra mop Dw wea x tro x i meer ef rep LLL E a ef Er COS INES 5 re L LI LLLI Dw w owwmee eof x Dw w wemem rap paeas d CHE wwe f re L LIC T a Argus 4 2010 Siemens Protection Devices Limited P20010 Page 17 of 22 7SG11 Argus 4 Diagrams and Parameters LLL LLLI Dw wmwwswe x 2 39 io Cw 192 vent aer x 2 39 8 Pw 199 veamos e 2 39 8 Dw we vmme x 2 no pre Dw w we 2 fr Cw 190 vatogememoya x 3 59 8 RO x 3 no 8 ros 192 votagemenove x 1 ne ro _ _ TL LI e zo eranc e Ja xo
19. 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 Setting name Ref Applied value System Config Menu Setting name Ref Applied value Set Alarm 4 Active Settings Group Clock Sync From Status Default Screen Timer Change Password Protection Menu Setting name Ref Applied value Gn P F Charact Setting Current Display Set Identifier Set Alarm 1 Set Alarm 2 225 Gn P F Highset1 Delay 02010 Siemens Protection Devices Limited P20008 Page 11 of 33 Setting name Ref Applied value Gn P F Highset2 Setting Gn E F Charact Delay Gn E F Lowset Setting de E SE AAA o NS Gn E F Highset1 Setting Gn E F Highset1 Delay Gn E F Highset2 Setting Gn E F Highset2 Delay Gn SEF REF Current Setting 2 4 Gn SEF REF 2nd Time Delay 24 Gn SEF REF Lowset Delay 2 4 sec Gn CB Fail Time Delay1 o sec d sec 2 Gn CB Fail Time Delay2 12 Gn P F CB Fail Setting E 2 9 xIn Gn E F CB Fail Setting 2 5 xin E 2 5 xIn Gn SEF CB Fail Setting Gn CT Failure Setting 2 5 3 xIn Output Relay Configuration Menu See also Figure 2 1 on page 15 for the programming matrix 7SG11 Argus 1 Diagrams and Parameters Gn E F Starter 2 3 1 Setting name Ref Applied va
20. 100 101 300s xTm 5 absolute or 30 ms TEES EF a char NI VI El LTI where applied current lop Operate time for char NI K 0 14 a 0 02 IEC type A VI K 13 5 a 1 0 IEC type B El K 80 0 a 2 0 IEC type C LTI K 120 0 a 1 0 char DTL ta 1 96 or 10 ms Repeatabiliy pon Disengaging time eases ng 47 Hz to 52 Hz Variation 57 Hz to 62 Hz lt 5 harmonics to 550 Hz Figure 1 5 1 shows the operate times for the four IDMTL curves with a time multiplier of 1 Figure 1 5 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 Is Setting range 0 05 0 1 2 5 3 0 52 5 xIn Operate level 100 xls 5 or 1 In Reset level 95 96 lop 5 or 1 9o In Transient overreach lt 5 9 _ X R lt 100 ee 10 C to 55 C Variation 47 Hz to 52 Hz 57 Hz to 62 Hz harmonics to 550 Hz Operate Time Starter operate time see Figure 1 5 3 and Figure 1 5 4 5 ms Delay setting 0 00 0 01 20 00 20 5 100 101 300 s ta top Operate time ta tstart 1 or 10 ms Repeatability 1 or 10 ms Overshoot time lt 40 ms 47 Hz to 52 Hz Variation 57 Hz to 62 Hz lt 5 har
21. IA 79 Voltage Block Circuit breaker closed IA Reclose Delay K KR BR Reclaim E Lockout Forward SEF 164 91 Reverse SEF 16 92 Power On Counter Alarm 164 97 CT Failure 100 Cold load pickup 11127 03 ARC start A 11130 164 106 External trip block 11134 EF off All ARC off 11135 16 11136 16 Rh e a i BIBI KR A A me ee e KA me ee K NO amp m U a TI gt JJ O O 11137 16 F ARC off 11138 16 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 21 General alarm 1 164 122 General alarm 2 11147 23 General alarm 3 OY 00 SEF inst off Hot line working E I KR BR KA KA e Scada Control I 11148 General alarm 4 md me e ee i KR KR Aa KA KA NIN aN 11149 6 General alarm 5 11155 164 11156 164 5 31 132 E Va Vab starter Vb Vbc starter 2010 Siemens Protection Devices Limited P20009 Page 27 of 37 7SG11 Argus 2 Diagrams and Parameters MODBUS Description Address E sima 64 190 vonage memos ao usi nm vonage memory pais 164 192 vonage memoye H Table Showing Input Registers Address Description Words S PA E T 30002 Latest Event Recora 8 xfx 30101 IA PRIMR 2 100 A x x X X X X 2 A X X x 30105 IC PRIMARY 1000 A X 30107 IE PRI
22. Minor change Minor change Additional features Additional features Minor change Additional features Additional features Minor change Minor change Minor change ASDU4 measurands return value O correctly Minimum setting for P F E F elements now 0 05 xin Modbus added CT Failure function added IEC60870 Class 2 measurands CBF Level detectors added DTL timers extended to 5 minutes Time synch via IEC870 communications with Reydisp power on alarm added CB fail all models external trip via status input SEF 2 stage can be disabled general alarms status input inversion resettable instruments output relay pulse length setting 10 second delay on trip test CB fail trip circuit supervision single pole models current meter averaging status group select default instruments new expansion board 8Sl clock synchronisation using status input settings displayed in ReyDisp status input pick up and drop off delays added CB fail trip circuit supervision all expanded I O models separate settings for P F E F and SEF current ratings sum of I setting range CB fail trip circuit supervision some models reset of latched output relays by status input event numbers new status input functions setting group select all algorithms can be inhibited first version with I O expansion card 4SI 4OR current meter averaging real time clock settings group changes delayed
23. o cn lod ea LO 5 SCCHON 2 SENNO eter EMT 10 Section 3 IEC 60870 5 103 amp Modbus RTU Definitions sese esse ssssss sss ssesss cerne 17 3 1 IEG 60870 5 103 DEMONS DE 17 3 2 Modbus RTU R 2 Tae eene iden 24 Section 4 Application Diagrams eee ceereccrereca n enean a ana a ansa rasa a assa meras anra 30 List of Figures Figure 2 1 Status Input and Output Relay Programming Marix sees eee eee eee eee 16 Figure 4 1 Typical Connection for Directional Earth fault Protection seseeeeessssssssss 30 Figure 4 2 Typical Connection for Directional Sensitive Earth fault Protection 31 Figure 4 3 Typical Connection for 3 Directional Phase fault Protection sse eee eee eee 31 Figure 4 4 Typical Connection for 2 Directional Phase fault and Sensitive Earth fault Protection irea A 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 misi p RT E PES 34 Figure 4 9 Typical Connection for 3 Phase fault and Directional Earth fault Protection 34 Figure 4 10 Typical Connection of Type AG2 5xx Dir P F and
24. 164 sojonsem Y def t RO x Dw m emw ro 164 21 SEFIREF stater x af 19 RO x ESOS AO O NNI a ee 164 23 SEFIREF lowsettip 2 t RO x 164 24 sermersiagetato 2 t RO xo 164 25 sermersiagezato 2 1 RO 4 26 amstatater 2 1 feje ef afers re 160 asjotisistarer J de 1 fejs Argus 6 elle NM MM M NM MB NM Current Measurand Scaling can be User set to either 1 2 x In or 2 4 x In 2010 Siemens Protection Devices Limited P20011 Page 16 of 22 7SG11 Argus 6 Diagrams and Parameters e eem H HE ICO E IE Cw epemme H HT Dw w smme o re 4 afers H re IRES E i si eraoro x 9 rol x Cw m omwwwewz T Dw e meem x ero LLL C T a efem x 9 ro e meam tino AO H HH e foume x HTH e o omms x HTHH Cw o foum f x mm Dw or fous iaa e Dw eme ee a ref Dw e wen x re Dw w mes x fre 04 e wmems 5 rel x Dw e mec HT tro x Dw w mee HT tro w e wmec 5 re x Argus 6 NM MM NM NM NO MB MB NM KM 2010 Siemens Protection Devices Limited P20011 Page 17 of 22 7SG11 Argus 6 Diagrams and Parameters re m wmnam x a 5 re ww 71 comamenancesem a o gt CO IO IES II IS IO II Cw mas H 9 8 O eanne amar ol x 04 or remos connor ro Cw
25. 80 100 80 100 Figure 4 1 Directional Earth Fault Boundary System Angles With balanced 3 phase system quantities 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 80 100 80 100 Figure 4 2 Directional Phase Fault Boundary System Angles Table 4 3 Limits of Operate Pick up Relay Angle Boundaries Operate PU Operate PU A B C forward lag E F forward lag 127 5 137 5 f T 47 02010 Siemens Protection Devices Limited P20006 Page 23 of 37 7SG11 Argus User Manual Ms General Tests Voltage sensitivity can be tested if required by injecting current of twice setting at the Characteristic Angle The voltage should then be increased from zero until operation of the directional element is indicated Operation should occur at less than 2V for phase fault and less than 3 3V for earth fault In Argus relays where the two out of three gate function is available and is enabled then this feature can be checked Provide a reference voltage Vac and inject current at the characteristic angle into the A pole and check that no FWD operation occurs Repeat injecting FWD operate currents into two poles simultaneously and the Argus should operate This test can be carried out as shown in Figure 4 5 A single phas
26. Argus 1 up to and including this document issue is Nov 2005 July 2005 Mar 2005 Aug 2004 April 2004 Jan 2004 Sep 2003 Mar 2003 Nov 2002 Jun 2002 Feb 2002 Oct 2001 Feb 2001 Jan 2000 Jul 1999 May 1999 Mar 1998 Sep 1997 Jul 1997 Apr 1997 2434H80023 R10 2434H80023 R9 2434h80023 R8 2434H80023 R7 2434H80023 R6 2434H80023 R5 2434H80023 R4 2434H80023 R3 2434H80023 R2 2434H80023 R1 2434H80022 R3 2434H80022 R2 2434H80022 R1 2434H80021 R5 2434H80021 R4 2434H80021 R3 2434H80020 R1 2434H80019 R4 2434H80019 R3 2434H80018 R2 2434H80024 7 R2 2434H80024 7 R1 2434H80002 2434H80002 2434H80002 7SG11 Argus 1 Diagrams and Parameters Highset and Lowset setting steps revised between 2 5xIn and 3 0xIn ACD bit in IEC 60870 library corrected CBF logic modified timer will run while trip is being issued and gt ICBF Modification to checking settings screen at switch on Corrected CT Failure setting display when configured to show PRIMARY SECONDARY Amps Additional features Additional features Minor change Additional features Minor change Minor change Minor change Minor change Additional features Additional features Minor change Additional features Additional features Minor change Minor change Additional features Additional features Additional features Minor change Additional features Additional features
27. CA 180 87 52 52 Variation in 10 C to 55 C characteristic 47 Hz to 52 Hz 2 5 per 5 Hz variation angle 57 Hz to 62 Hz 25 Note Some models are available in which the 65 setting is replaced by a 90 setting Operate Threshold Minimum levels for operation Operate Time Operate time type a typically 20 ms at characteristic angle type Il typically 40 ms at characteristic angle type typically 20 ms at characteristic angle type Il typically 40 ms at characteristic angle Reset time See Figure 1 5 7 1 4 5 Circuit Breaker Fail Operate Level AWbue Qi Phase Fault setting Off 0 05 0 1 1 0 xIn Earth Fault Setting Off 0 05 0 1 1 0 xin SEF Setting Off 0 05 0 1 1 0 xin Operate Level 100 96 Is 5 or 1 In Reset Level 95 lop 5 or 1 In Repeatability E 47 Hz to 52 Hz Variation 57 Hz to 62 Hz harmonics to 550 Hz pa Timo tcBF2 Delay setting retrip backtrip 0 00 0 01 20 00 20 5 100 101 300 s 2010 Siemens Protection Devices Limited P20007 Page 12 of 71 7SG11 Argus Technical Reference retrip tcgr1 1 or 10ms Operating time backtrip tcpe1 terra 1 or 10ms Repeatability 1 10ms 1 4 6 Auto reclose Integrated with the Overcurrent Low Set Delay and High Set 1 and High Set 2 elements BEEN Number of reclose shots up to 4 separate for phase fault earth fault SEF and external Timers Reclose DTL 1 2 3 4
28. Dirn Off Fwd 50N E F Highset 2 E F Highset 2 Inhib instantaneous overcurrent O p gt e a O e i E F Highset 2 non a E F Highset 2 rev Dirn off Fwd SEF Delay 1 Inhib 50N 87G SEF REF gt sensitive earth fault SEF Delay 2 Inhib restricted earth fault SEF Lowset Inhib 6 nap OOO 67 67N directional overcurrent 74TC Trip Circuit Fail Trip Circuit Fail trip circuit supervision L c SEF Starter O SEF Delay 1 SEF Delay 2 E B L A Cy OOO E E Sao E E OO O M A Su er A M es SEF Lowset P F FWD Block O P F REV Block E F SEF FWD Block Cs yo SO E D AAA ERA OOO O SS O QO E F SEF REV Block E O O 0 0 0 0 Q 0 O I Argus Elements vsd AG6 1 continued on following page 2010 Siemens Protection Devices Limited P20011 Page 12 of 22 7SG11 Argus 6 Diagrams and Parameters continued from previous page ee c MEER cy stg I penso 88 9 cds RO SERS RA RB R6 scd RT a B R9 R10 O 0O 0 0 0 0 0 O sut R1 Status 1 Status 2 Status 3 Status 4 Status 5 Status 6 Status 7 Status 8 Status 9 waveform Hl waveform recorder fault recorder Fault Trigger Clock Sync real time clock Ap
29. Phase fault and earth fault poles each have a delayed characteristic plus three instantaneous definite time delay elements In the directionally controlled Argus 2 and Argus 6 relays each phase fault and earth fault delay characteristic lowset and highset 1 amp 2 elements can be independently programmed via their directional control settings to non directional forward directional reverse directional or bi directional tri state operation via the 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 47 Hz and 550 Hz higher harmonics are also included in the r m s calculation This makes Argus ideal for applications where true RMS accuracy of measurement and timing must be maintained in the presence of high harmonic content in the current waveform e g protection of lines carrying variable speed motor loads or for capacitor bank protection 2 3 1 Delay Characteristic element characteristic type Normal Inverse NI IEC type A Very Inverse VI IEC type B Extremely Inverse El IEC type C and Long Time Inverse LTI or alternatively a Definite Time Lag DTL can be chosen The time 02010 Siemens Protection Devices Limited P20007 Page 26 of 71 7SG11 Argus Technical Reference A This diagram shows the logic for overcurrent P F Charact Dir Control elements in the forward di
30. Q tput Relay Test Se ups aaa m 51 Internal Supervision Seting IT o o m 52 Linesman Mode SC Ui NN RE mm T 53 Linesman Mode Settings and COMMAnNdS occcoocccncccncnnccnncnncnnnnnnnnnnnnnnnncnnnnnnnnnnnnrnnnnnnrnnnnnnrnnnnnrnnnnnnoos 53 Communications SCTINAS A cce A A LO Ta BIS e ab dsc sede abe LU a EAE SCA io aa 66 COMMUNICATIONS SETAS ess cesar ito 69 P20007 Page 5 of 71 7SG11 Argus Technical Reference Section 1 Performance Specification 1 1 General 1 1 1 C Conformity This product is C compliant to the following applicable EU directives Electromagnetic Compatibility Directive CE 89 336 EEC Compliance to the European Commission Directive on EMC is claimed via testing to the Harmonised Product Standard EN 50263 2000 Low voltage Directive CE 73 23 EEC Compliance to the European Commission Directive on LVD is claimed via testing to the Harmonised 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 Current settings 100 In IDMTL 2 to 30 xls Current input 1 1 3 Dimensions and Weights Dimensions Wat Depth behind panel 7 237 mm including clearance for wiring 2010 Siemens Protection Devices Limited P20007 Page
31. SA Trip 2 14 3 Internal Supervision The Argus relay applies comprehensive supervision of its internal operation both hardware and software In the event of any failure all outputs are de energised and the relay is shut down in a controlled manner Supervision includes a power supply watchdog code execution watchdog memory checks by checksum memory addressing checks and processor and ADC health checks this output to a normally closed contact i e any output relays 1 to 3 an alarm can be generated by relay de energisation or Protection Healthy failure Note relay withdrawal will also generate an alarm as all normally closed contacts have CT shorting contacts which close when the relay is withdrawn from its case If an internal failure is detected a relevant identifying message will be displayed if possible and the Argus will reset and restart in an attempt to restore normal operation this will result in de energisation of the protection healthy contact and flashing of the protection healthy LED Reset takes about 2 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 The count can be reset either from the Instrument display by pressing TEST RESET use up down keys to confirm Y press TEST RESET again or from the CB Maintenance menu using the ENTER and up do
32. The two applications are not possible simultaneously the user must select which is required The restricted earth fault scheme is described in section 2 4 1 below The element includes a software filter for rejection of second third and higher harmonics of the power system delayed reset function section 2 3 3 is applied on each of the two DTL timers Each of the three timing elements has an output mapped by a setting Each timing element can be inhibited from a status input mapped by a setting see Figure 2 4 1 In multi pole directional Argus models the SEF element is non directional In single pole directional SEF models the directional control setting applies to all the SEF Protection elements A In most models the SEF element is non directional in which case ES e directienat se 7 SEF Current Setting A single pole directional SEF model is available for which the diagram shows the logic for elements in the forward direction CX J reverse is identical Ise ED SEF REF starter ap gt SEF REF Starter a Y 7 SEFIREF Lowset Del Dir n SEF Fwd owset Delay SEF REF lowset trip SEF Lowset SEF Lowset Inhib i Y SEF REF 1st Time Delay SEF REF stage 1 trip SEF REF Delay 1 SEF Delay 1 Inhib 1 VSEF REF 2nd Time Delay SEF REF stage 2 trip SEF REF Delay 2 P300008 Protection Functions SEF REF SEF Delay 2 Inhib 1 Figure 2 4 1 Functional Diagram Sensitive Earth fault Restricted
33. on Hus dau a A Eme C Nee INST DELAYED appropriate SEF protection have Gn P F E F SEF Protection O AAA E duplicate sets Trip 1 INST DELAYED e g Gn P F ARC becomes Gn Gn PIF EIFJ SEF Reclose DTL 020 021 20 EF ARC or Gn SEF ARC 1 2 14 9 0 20 2 1 sec 300 360 3600 3900 14400 Gn P F E F SEF Protection ot DELAYED 02010 Siemens Protection Devices Limited P20007 Page 40 of 71 7SG11 Argus Technical Reference Gn P F LL Reclose DTL 2 Gn P F E F SEF Protection Trip 3 Gn P F E F SEF Protection Trip 4 Gn P F E F SEF Reclose DTL 4 Gn P F E F SEF Shots To Lockout Gn P F E F HS1 Trips to Lockout Gn P F E F HS2 Trips to Lockout Reclaim Time Close Pulse Manual Close Delay LO Recovery Gn P F E F SEF Reclose DTL 3 prece Reclose DTL 1 1 2 3 4 5 0 20 0 21 2 0 2 1 20 21 300 360 3600 3900 14400 1 0 1 1 2 0 10 0 as Reclaim Time 2010 Siemens Protection Devices Limited For 4 reclose shots 5 trips are issued the fifth trip is always delayed Not applicable to SEF sequence Common setting across all Groups applies to all Sequences Common setting across all Groups Common setting across all Groups Common setting across all Groups P20007 Page 41 of 71 7SG11 Argus Technical Reference Sub menu O P Relay Config Gn Lockout Alarm _ or 1
34. the need to negotiate the relay s HMI menu structure Table 2 9 Default Instrument Setting Sub menu System Config Default Screen Time 10 sec 60 sec 5 min 1 hour a 2 2 9 Password All settings on Argus relays can be password protected The default password is NONE making the password protection not active therefore all settings can be edited without the relay requesting a password If a password is set by the user then before a setting can be changed the set password must be entered This allows access for further settings changes to be made without the need to re enter the password each time If the user then leaves 2010 Siemens Protection Devices Limited P20007 Page 25 of 71 7SG11 Argus Technical Reference the relay keypad untouched for an hour the password protection is re enabled The Password setting is changed changes or commands performed via the communications link Note if the password is lost forgotten it can be recovered if the code number shown in the password screen is communicated to Siemens Protection Devices Limited Table 2 10 Password Setting Sub menu System Config Change Password ABCDEFGHIJKLMNOPQRSTUV 4 characters WXYZ1234567890 NOT ACTIVE 2 3 Phase fault and Earth fault Overcurrent Argus relays can have up to three phase fault poles and an earth fault pole Each pole has four overcurrent elements which can be used with the starters in blocking and protection schemes
35. the relay checks the reason for that Trip and determines its next state If the relay determines that it is not to go to Lockout but is to proceed to perform the next set step in the Auto raised until the sequence has successfully reclaimed or a lockout occurs at which time the Arc Active event and alarm output is cleared After the Reclose Delay the relay enters the Reclose routine and checks that Reclose Block is not raised before If any ARC INHIBIT is raised before or at any time during a Reclose Delay or during the Reclose Block time the relay will go to Lockout conditions do not allow an immediate close of the circuit breaker e g if a motor wound circuit breaker close spring needs additional time to recharge or if the system is out of synchronism etc External blocking contacts can be wired in parallel If all the reclose block inputs are not cleared within the 5 second reclose block time delay the relay will go to Lockout If all the reclose block inputs are cleared at any time within the 5 secs reclose block time delay then the close pulse will be issued thus the autoreclose close pulse may be held back by up to 5 secs after the end of the reclose delay closes onto a fault and any protection starter picks up Thus the close pulse may be left set to the default of 2 seconds without racing conflicts being created The relay will not issue a Close pulse to a closed CB 02010 Siemens Protection Devices Limited P20007 Page 39 of 71
36. 0 00 OOO OO 0 OO 0Q OOOO A e La Mee 74TC Trip Circuit Fail Trip Circuit Fail trip circuit supervision Argus Elements vsd AG4 1 continued on following page 2010 Siemens Protection Devices Limited P20010 Page 11 of 22 7SG11 Argus 4 Diagrams and Parameters continued from previous page ee c MEER cy stg I penso 88 9 cds RO SERS RA RB R6 scd RT a B R9 R10 O 0O 0 0 0 0 0 O sut R1 Status 1 Status 2 Status 3 Status 4 Status 5 Status 6 Status 7 Status 8 Status 9 waveform Hl waveform recorder fault recorder Fault Trigger Clock Sync real time clock Ap OOOO OOOO Q Q 0 0 0 0 0 O0 0 Q O O O O Q O Q Q OOOO OOO OO O Q O O O O O0 O Q QD De De De Que DDD TO 270 7000 0010 0010 20 0 00010 2010 QD DDD OOO e e Q O O Q Q O O Q O o O O O O O 50BF CB Fail circuit breaker failure A Trip Alarm es SN 7 M 2 hy a Counter Alarm FOC Alarm XI Alarm y e ae eC 0 0 OO O O OOO OOO O OO OOOO esc O Lockout Alarm Ed ga dd rd Close Pulse E xr ue Ue Ro dr up ede sa De 0 0 0 0 0 0 0 0 0 0 0 ARC Active Reclaimed SA Blocked SA Alarm SA Trip O
37. 120W terminating resistor in circuit a Rear RS485 2 Oo res L A SE Y E Q B see note 4 Phase rotation P300002 Argus 2 Connection Diagrams ArG2 101 102 Figure 4 1 Typical Connection for Directional Earth fault Protection 2010 Siemens Protection Devices Limited P20009 Page 30 of 37 7SG11 Argus 2 Diagrams and Parameters Notes 1 CT circuits are shown connected to BUSBARS AG2 103 104 1A tap use alternative tap for 5A rated A B C A CTs D q 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Rear RS485 port is an ordering option On the last relay on the bus connect wire link as shown to include 1200 terminating resistor in circuit Rear RS485 comms port Rear F O comms ports C Phase rotation P300002 Argus 2 Connection Diagrams ArG2 103 104 Figure 4 2 Typical Connection for Directional Sensitive Earth fault Protection Notes 1 CT circuits are shown connected to BUSBARS AG2 3x1 3x2 1A tap use alternative tap for 5A rated A B C A CTs q 2 CT and earth connections are typical only 3 Optional expansion card fitted only on models AG2 311 and AG2 312 4 Optional expansion card fitted only on models AG2 321 and AG2 322 5 Rear RS485 port is an ordering opti
38. 4 alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil C1 O1 JI co A Gn LE oo IO KO 0 Gn DY NI PY NI BY NI PY NI at comms ports P300004 Argus 4 Connection Diagrams ArG4 403 404 1 Figure 4 2 Typical Connection for 2 Phase fault Earth fault and Sensitive Earth fault Protection Notes BUSBAR AA US S 1 CT circuits are shown ABC q connected to 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil comms ports P300004 Argus 4 Connection Diagrams ArG4 403 404 2 Figure 4 3 Typical Connection for 3 Phase fault and Sensitive Earth fault Protection 2010 Siemens Protection Devices Limited P20010 Page 22 of 22 7SG11 Argus 6 Diagrams and Parameters 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 2010 02 Document reformat due to rebrand 2005 06 Third issue Editorial modifications softwar
39. 6 of 71 7SG11 Argus Technical Reference See appropriate case outline and panel drilling drawing as specified in Diagrams and Parameters document for complete dimensional specifications Weights Net weight Argus 2 E8 case 6 6 kg Argus 4 E6 case 4 8 kg Argus 6 E8 case 6 6 kg 1 2 Energising Quantities 1 2 1 Characteristic Energising Quantities Nominal frequency 50 60 Hz 1 2 1 1 AC Current Nominal Current and Measuring Range Measuring Range Note 1 A and 5 A nominal inputs are user selectable on each model Thermal Withstand Overload Period Phase and earth continuous 3 0 x In 3 seconds BT TA 202A gt 37 5A 202 A 2 seconds 70 7A 247A 46A 247 A 1 second 1 cycle Burden Attribute Phase and earth SEF REF AC Burden lt 0 05 VA lt 0 2 VA lt 0 2 VA lt 0 4 VA Impedance 0050 lt 001Q9 lt 02 0 lt 0020 2010 Siemens Protection Devices Limited P20007 Page 7 of 71 7SG11 Argus Technical Reference 1 2 1 2 AC Voltage Argus 2 and Argus 6 relays only Nominal Voltage and Range Operating Range Vn 110 V 250 V continuous Attribute Do AC Burden Value 0 1 VA at 110 V Burden 2 2 Auxiliary Energising Quantity Auxiliary Power Supply 24 30 48 V 18 to 60 VDC Vaux 88 to 280 VDC Md 100 to 130 VAC Burden DC Burden opie Status Digital Inputs Nominal Operating Range S When relays with 48 54V status inputs ar
40. 7SG11 Argus Technical Reference an external relay with a heavy duty break contact connected in series with the close coil of the CB to prevent output contact damage for a stuck circuit breaker condition It can replace the anti pumping timer If at the end of the close pulse the circuit breaker has not closed then the relay will raise a CB FAIL alarm then Lockout section 2 5 2 If at the end of the close pulse the circuit breaker has successfully closed then the relay will start the Reclaim Delay timer Reclaim After the Circuit Breaker has been Le erate reclosed the NS goes into the Reclaim state for the duration of If within the Reclaim Delay a new fault occurs and a protection starter picks up or if an external Arc Start SA input is raised then the relay will continue the existing Protection Auto reclose sequence as programmed If within the final Reclaim Delay a new fault occurs and a protection starter picks up or if an external Arc Start SA input is raised then the relay will apply the programmed last shot Protection characteristic if any protection element operates a trip output will be issued then the relay will go to Lockout If the Reclaim Delay times out without another fault occurring then the relay will Reclaim i e reset the sequence shot counter will be reset to zero and any subsequent fault will start a full new sequence At the start of a Reclaim Delay a Reclaim raised event is generated At the end of a successfu
41. 90 in 1 steps 2010 Siemens Protection Devices Limited P20006 Page 7 of 37 7SG11 Argus User Manual 1 3 1 4 Voltage Protection Certain Argus 2 models only A three phase voltage element with definite time delay is provided which can be used to provide a trip or alarm output or can be set to block any of the overcurrent elements The element can be set to undervoltage or overvoltage with variable hysteresis Overcurrent blocking occurs from each phase independently but a common trip output is provided 1 3 1 5 Cold Load Pickup Argus 4 and Argus 6 only The Argus can apply higher current settings with longer time delays after the circuit breaker has been open for a programmable time On closing of the circuit breaker these higher settings are applied for a programmable time or until the measured current has fallen to normal levels 1 3 1 6 Circuit Breaker Fail The circuit breaker fail function operates by monitoring the current following a trip signal and issues an alarm if the current does not cease within a specified time interval A two stage time delayed output can be used to operate output contacts to retrip the same circuit breaker using a second trip coil or to backtrip an upstream circuit breaker The CBF timer 1 starts to operate following a trip output from any one of the protection algorithms or an external input providing there is current above the circuit breaker fail current setting An output is issued after the C
42. Alarm outputs with programmable settings are available for both features This information is accessed either from the front panel or via the communications interface The values of current used for the I summation are those measured at the time of issuing a trip signal An sum is generated for each phase element and the highest value is used for alarm and display purposes Itis also possible to initiate the I summation algorithm from an external tripping device via the status input if required The trip count and the summation count can be reset by either of two methods e when viewing the appropriate instrument screen and pressing the TEST RESET button e inthe settings menu using appropriate reset setting 1 3 4 Measurements Analogue values can be displayed in primary or secondary quantities on the LCD screen In addition the values can be obtained via the communications port 2010 Siemens Protection Devices Limited P20006 Page 8 of 37 7SG11 Argus User Manual Available Instruments e Primary current RMS values on a phase by phase basis indicated by upper case letters e g A B C E SE sensitive earth e Secondary current RMS values on a phase by phase basis indicated by lower case letters e g a b c e o D Primary phase voltages Primary phase phase voltages Secondary voltages Apparent power and power factor Real and reactive power WHr forward and reverse VarHr forward and reverse Ro
43. Dir E F with Star CONNEC emi rcr Hc HT 35 Figure 4 11 Typical Connection of Type AG2 5xx Dir P F and Dir E F with Open delta VT 35 Figure 4 12 Typical Connection of Type AG2 5xx Dir P F and SEF with Star connected Md sac esate ccs uM IM RUI RR SUPRIR RAROS MEL UM D 36 Figure 4 13 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Star COTM CEs EEE 36 Figure 4 14 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Open 8 2 VA A E 37 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Section 1 Variants This document applies to the Argus relays listed in the following MLFB Structure amp table The MLFB Structure references the complete number for each relay e SGlinn nxxnn nxAO where n is a digit and x is a letter The table uses two references for most relays each of which is valid e an Order code of the form AGn nnn and e a Type of the form DCDnnnX where n is a digit and X is a letter Order code Type 30 48 aux 110 220 aux 30V status 48V status 48V status 110V status 220V status AG2 101 AG2 102 R DCD211A DCD213A DCD214A DCD215A DCD216A AG2 103 AG2 104 R DCD221A DCD223A DCD224A DCD225A DCD226A AG2 311 AG2 312 OR DCD611B DCD613B DCD614B DCD615B DCD616B AG2 321 AG2 322 R DCD611C DCD613C DCD614C DCD615C DCD616C AG2 313 AG2 314 OR DCD621B DCD623B DCD624B DCD625B DCD626B AG2 323 AG2 324 R DCD621C DCD623C DCD624C DCD62
44. E 11 HHHH O HH H H H SG EHH no erne mer Taner aa nal ma Taner m s samenes fonoj m ne prar Taner m m i srar Taner m m 10 mres onore o m 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 02010 Siemens Protection Devices Limited P20008 Page 22 of 33 7SG11 Argus 1 Diagrams and Parameters Description 164 119 Hot line working ON OFF p20 2 o Note Events listing a Gl cause of transmission can be raised and cleared other events are raised only 3 2 Modbus RTU Definitions The following tables give information for MODBUS RTU access to IEC 60870 5 103 protocol data A detailed description of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www reyrolle protection com in publications section under technical reports communications interface manual The tables below detail the MODBUS address map listing data points that are available and the functions 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
45. Earth fault Protection 1A or 5A A r 33 2010 Siemens Protection Devices Limited P20008 Page 5 of 33 7SG11 Argus 1 Diagrams and Parameters Section 1 Variants This document applies to the Argus relays listed in the following MLFB Structure amp table The MLFB Structure references the complete number for each relay e SGlinn nxxnn nxAO where n is a digit and x is a letter The table uses two references for most relays each of which is valid e an Order code of the form AGn nnn and e a Type of the form DCDnnnX where n is a digit and X is a letter Order code Type 30 48 aux Protection s Application l O 110 220 aux Diagram 30V status 48V status 48V status 1 10V status 220V status 1 SI AG1 1041 AG1 102 Single phase fault or earth fault Figure 4 1 or DCDIMA DCD113A DCD114A DCD11SA_ DCD116A 1 SI AG1 103 7OR DCD121A DCD123A AG1 301 DCD313A AG1 311 DCD313B AG1 104 DCD124A AG1 302 DCD314A AG1 312 DCD314B Sensitive earth fault Figure 4 2 DCD125A DCD126A Figure 4 3 7 OR DCD311A DCD315A SUDO 3 phase fault or Figure 4 4 11 OR DCD311B DCD3 6B 2 phase fault and earth fault DCD315B 2 phase fault and SEF 3 phase fault and earth fault 3 phase fault and earth fault 1A 7OR DCD311C 7OR DCD321A Figure 5 44 OR DCD321B 7OR DCD321C 7OR DCD411A Figure 4 6 44 OR DCD411B 7OR DCD411C AG1 321 DCD313C AG1 313 DCD3
46. Enter correct password If correct password has been forgotten note down the Numeric Code which is displayed at the Change Password screen e g Change password 1234567 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 continuously The LCD has many possible error messages which when displayed will flash continuously These indicate various processor card faults General failure Contact Siemens Protection Devices Limited Backlight is on but no text can be seen Adjust the contrast Scrolling text messages are unreadable Adjust the contrast Relay displays one instrument after Default instruments are enabled Remove all instruments from the another with no user intervention default list and only add those which are required 120A B 108A E The LT indicates that the instrument is a default instrument Press ENTER to deselect it See section 2 1 2 1 Default Instruments The LCD is stuck at the General Alarms The trip circuit failure feature is enabled and is expecting a healthy screen and is displaying Trip Circuit status input signal Energise the correct Status Input or disable Failure Sx x 1 5 the trip circuit feature if it is not required 02010 Siemens Protection Devices Limited P20006 Page 35 of 37 7SG11 Argus User Manual Cannot communicate wit
47. IEC 870 5 103 Time Sync optimised Minor change communications with ReyDisp E Minor change Trip amp Reclose action when no CB corrected Feb 2002 2 716H80005R1 Function added trip count alarm display added Function added setting added to hide show linesman mode display Function added close and reclaim command 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 operation counter reset Minor change trip circuit supervision alarm Nov 1998 2716H80001 R3 First release Hardware Release History The Argus hardware is used in many different relays The list of hardware revisions applying to Argus 6 up to and including this document issue is Appearance change modification to grey fascia design logo dark grey band buttons and label First release 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Contents Ten snis sisse iro n MERERI ti ia 2 Hardware Release History eee 2 ITH Monster A A ee ue suse calc er A 3 Bue FIQUIOS NNI e 3 SOCUOD EV A TTS usen ceca erect cee eae oo m
48. INE 4 3 Ctowsetstarter def 1 Jm x 4 4 Esomsetstater 2 t Rx e seme 2 TIEN 164 elBlomam 2j n RO x 164 T Cometo d def t RO x tea elElmam 2j t RO x NI T A E 4 To Bdewdtb j 2 to jm x Ragase 2 1 JR x 4 se Edemar 2j t jm x saj a ansin o 2j t O x 16 aa ensim o 2j t jm x EE NENNEN EUH Es eor T pm 160 sefonsem Y def n O x 164 sojonsem Y def t RO x Dw m emw ro 164 21 SEFIREF stater x af 19 RO x ESOS AO O NNI a ee 164 23 SEFIREF lowsettip 2 t RO x 164 24 sermersiagetato 2 t RO xo 164 25 sermersiagezato 2 1 RO 4 26 amstatater 2 1 feje ef afers re RILE d de to fejs Argus 1 elle NM MM M NM MB NM One of Ia Ib Ie Isef depending on relay type 02010 Siemens Protection Devices Limited P20008 Page 18 of 33 7SG11 Argus 1 Diagrams and Parameters Dw eee o 2 i RII 2 e ROE 2 3 8 Dw w ommme IE 2 3 rea 04 esse o ros w omewmegm x 59 eo 04 m ommewem 2 8 ws afea x EC e e DLL ot tio lts a e wwem x 59 eo e ufea o 2 Tr L LLLI 04 e omus x mmn 8 x Dw 62 romana x 2 no 8 Dw e wmeh x 2 9 8 04 efron x 2 9 8 e rees 2 no pe 04 e mmac x 2 39 8 Dw w weec x 2 nfo Dw efron 2 9 8 me 60
49. 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 for 62 5 125 um glass fibre If the communicating device e g a PC has an RS232C electrical interface a fibre optic to RS232 converter is required 4 2 2 1 Sigma Fibre optic to RS232 Converters Siemens Protection Devices Limited can provide a range of fibre optic to RS232 converter devices e Sigma 1 a panel mounting fibre optic star coupler for up to 29 slaves An RS232 port is available at the front of the device By default communication is to the master fibre connections on the rear however communication is automatically switched to the front RS232 port when a communicating programme is activated on it Each fibre optic port can be individually selected between Light On and Light Off see section 0 e Sigma 3 a panel mounting fibre optic to RS232 converter Two RS232 ports are available one at the rear for connection to a modem and one at the front for connection to a local PC By default the rear port is active however communication is automatically switched to the front port when a communicating programme is activated on it The fibre optic port can be selected between Light On and Light Off see section 0 e Sigma 4 a loose fibre optic to RS232 converter Full details of the above devices can be found by referring to the website www siemens c
50. Pw wemacem pa Dwemwe emaomem x Ja no Cw mwe emacmm x 39 ros mm iorram x Ja o no ii es varaarvotogo x o Teas x a no 06 aar verwy x o RH x ne LL HH E LRL o responses 9 ed dP ass o ewwomewewm w Table Showing Command Information INF Numbers 02010 Siemens Protection Devices Limited P20010 Page 18 of 22 7SG11 Argus 4 Diagrams and Parameters Description CO TYP COT Argus 4 160 160 160 160 X 2 sarge pisa on 2 24 sonnas op 2 on x 2s sonnas crows seee ON m x 2 songs oral o m Po T II IN H EH on o m x o setae Grup oem on m m x sr setae Grup 7er on xo w swmsGmsssma ON Po T IS IE s e ww 5 o m mewsowu o o o x o Cremos ww w mewsomus on o o o w mewsomus o o x m mewsowas o o o x w sewsowar o o x w mewsomus o m m m mewsomus o m m eseou o m o m mewmomun o m m Do T IS IR E to nge on 5 o Coo T H e Tiperaicacn onjo o sa coseanareean on m m o 04 menare o m m x aan fono o m OL ILICE larar owor m 3 id Do T IS II to DE CE o 0L TT TT EXC o E nal erne mer onor a o o m sracmm owrr m 3 ETE ECC xo DIE Ow m 3 E nr spre EXC 3 i name onor 2
51. R9 RO ssi Status 1 Status 2 Status 3 Status 4 Status 5 Status 6 Status 7 Status 8 Status 9 Waveform Trig fault recorder Fault Trigger Clock Sync real time clock 50BF CB Fail circuit breaker failure T T T B TTT B OOOO O OOO OOOO OOO OO Om OOO OOO OO QQ R1 00 Ga A CET R210 O AA O O O AAA CT Failure CT Fail Alarm XI Update Counter Alarm Counter Reset circuit breaker operation counter 21 Alarm Alarm 2 Alarm 3 Alarm 4 Alarm 5 Q 9 9 9 0 0 0 0 9 OO OO OOO DO 0 000 200 2200 O e O Q O O 0 0 0 0 0 0 0 0 Q Q O O O O Q O0 O0 O0 Q Reset Flag amp Outputs output relay control Min O P Energise Time OO Qe Cy Qe Qe Qe Qm 10 AO Q9 Qe o o o o 11 A e O M Qa Qe MD De M O he M Qe Qe Qe Qn DO EA C e O CD Cy C LO O O DC C C WC C Argus Elements vsd AG2 2 RS OS O e O OO Oe R4 R R Figure 2 1 Status Input and Output Relay Programming Matrix 02010 Siemens Protection Devices Limited P20009 Page 16 of 37 7SG11 Argus 2 Diagrams and Parameters Section 3 IEC 60870 5 103 amp Modbus RTU Definitions 3 1 IEC 60870 5 103 Definitions The following tables give information on the IEC 60870 5 103 protocol A detailed descriptio
52. Reclaim time separate for phase fault earth fault SEF and external 0 20 0 21 2 0 2 1 20 21 300 360 3600 3900 14400 s Time accuracy all timers setting 1 or 10 ms 1 4 7 Instrumentation Timer ranges Voltage power and power factor instruments are available on Argus 2 type II models only Instrument Value Typical accuracy Claimed accuracy Curent Iz04xln 1 In 3 In V Voltage V gt 0 8 xVn 1 Vn 3 Vn 9 Power real and apparent V Vn gt 0 1 xin pf gt 0 8 Do cm where Pn pf Power factor V Vn 12 0 1 xin pf gt 0 8 1 4 8 Communication Interface Physical layer Fibre optic option EIA RS 485 Connectors ST BFOC 2 5 RS 485 electrical 4mm terminal Recommended fibre 62 5 125 um glass fibre with ST connector Launch power into recommended fibre 16 dBm Receiver sensitivity 24 dBm Protocol IEC 60870 5 103 or MODBUS RTU ST is the registered trade mark of AT amp T Co 1 4 9 Real Time Clock Attribute Value 1 5 Environmental Performance 1 5 1 General 1 5 1 1 Temperature IEC 60068 2 1 2 02010 Siemens Protection Devices Limited P20007 Page 13 of 71 7SG11 Argus Technical Reference Operating range 10 C to 55 C Storage range 25 C to 70 C 1 5 1 2 Humidity IEC 60068 2 3 Operational test 56 days at 40 C and 95 relative humidity ESAS Insulation IEC 60255 5 Between any terminal and earth l 2 0 kV AC RMS for 1 min
53. T 25 2 3 Phase fault and Earth fault Overcurrent em eene meet n nn teres peres nns 26 2 3 1 Delay Characteristic element eee eee eee ee 26 2 9 2 Instantancous elements doe eoa L ee in A ruin d terti ds 27 2 50 Flashing Pecking Fault Protection uie ean Ete noa sinet as 29 2 4 Sensitive Earth fault and Restricted Earth fault nan 30 2 4 1 High Impedance Restricted Earth fault Scheme eee eee ee 31 2 5 Primary Equipment Fail ProtectiON cooocccocncoccccccncocnconnnnncnnnnnonnnonncnnnnnnonnnnnrnnnnnnnnnnnnrnnnanonnincnaninass 31 2 5 1 Circuit Breaker Trip Fail Protection uei o aber ee E eise Ie ob odes xd etie eae 31 2 5 2 e eau e HM 32 2 9 9 Current Trapstormer FATO dl oia acis 32 2 5 4 Trip Circuit Supervision for details see sections 2 10 and 3 8 ssseeesess 33 AS eile H Kere b Seel eon A A RAD 33 2 7 Directional Control aaa 34 2 1 ROSAS AMI runs e ha a RD M ae th M E EA OD e nthe E i nen 34 2 7 2 Two ouro inree Gale IERI 35 PASE sis 35 20 eio e TOSCO me UR T e 36 VS EN COS a EORR NR MT Ste MeL are Ta OEE A Oe OREN Ot Te ua 37 2 9 1 Auto Teeclose SedgubliCOS iu ca onde wits ee 38 242 ControlinpuiS Cristo r Loc d el S EAR LE De 43 29 3 iFrequenrOperatons Counter succi teeta tetas A ck Le pui Ere tede eu 44 2010 Siemens Pro
54. Tor each output contact Default output relay 7 default ______ 1 Gn Close Pulse or 1 for each output contact default ___1___ Default output relay 4 Gn AUX Close Gn ARC Active Gn Reclaimed m RN each Rz contact etico Nono Sub menu Status Config Gn CB Open _ or 1 for each status input I wee default Default input 6 Gn CB Closed or 1 for each status input default Default input 7 Gn Reclose Block Gn P F ARC Off _ or 1 for each status input Gn E F ARC Off default Gn SEF REF ARC Off Default input None 2 9 1 2 External Protection Reclose Sequence In addition to the relay s internal protection and auto reclose sequences a programmable auto reclose sequence and back up protection functions for an external protection is provided typically be energised from the trip output or starter output of an external protection device e g a distance protection or sensitive earth fault relay The Argus 4 6 will then provide a separate auto reclose sequence with the external protection providing the fault detection and tripping functions Up to four close shots five trips to lockout may be set with independent reclose delays 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 protectio
55. Using a phase sequence indicator first check that the phase sequence of the voltages at the Argus are correct i e A B C and see by inspection that the phasing of the connections to the Argus is correct If system has reverse Phase rotation i e A C B this will affect the Phase Fault directional elements only For correct phasing of Type 1 Directional Relays i e AG2 XXX series reverse Vp i e connect voltage V to terminal 83 and V to terminal 82 For correct phasing of Type 2 Directional Relays i e AG 5XX series connect as shown in figures 4 10 11 12 13 for normal A B C rotation no wiring changes are necessary as the required adjustment is performed internally by the Relay in response to the Phase rotation setting change given below change the rotation setting in S ystemConfig P hase Rotation from AB Cto AC B Setting to AC B automatically changes Forward to Reverse and visa versa Earth Fault connections remain unchanged i e connections as shown Check the magnitudes of the voltage transformer voltages Pass a three phase load current of 2096 or more of the current transformer rating in a known direction From the Instruments Display Mode check that the Argus correctly indicates either FORWARD or REVERSE in line with the direction of flow of the primary current If the flow of current is such that the Argus should operate see that in fact it does operate Note that it may be necessary to r
56. added to hide show linesman mode display close and reclaim command split in two one for local delayed and one for remote no delay fault display shows lockout due to hot line working communications general command blocking trip count non fault trips and alarm action Internal Evaluation code version not released on screen alarm display frequent operation counter reset trip circuit Supervision alarm The Argus hardware is used in many different relays The list of hardware revisions applying to Argus 4 up to and including this document issue is Appearance change modification to grey fascia design logo dark grey band buttons and label First release 2010 Siemens Protection Devices Limited 7SG11 Argus 4 Diagrams and Parameters Contents DOMW abe Release HISTO rossis evi n ia i e as 2 Hardware Release HISLONY Me S 2 Section 1 Varants et E 4 DECOM 2 SO MINGS saias c 6 Section 3 IEC 60870 5 103 Definitions sss s esse sssss sees se eeee cesses eenn eene nennen nnn nnne nnn nnn 13 Section 4 Application Diagrams oia ei Eo aet eerie ao eoa dee c ea ae eva Caere Fea Coda Deo D ve ab su ee 21 List of Figures Figure 2 1 Status Input and Output Relay Programming Marix sees eee eee eee eee 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
57. can be used in order to drive the modem The Reydisp communications package can then be used to interrogate the relay using the IEC 60870 5 103 protocol For remote communications more specialised equipment is required see Section 4 Communications Interface in the Technical Reference section of this manual 2010 Siemens Protection Devices Limited P20006 Page 17 of 37 7SG11 Argus User Manual Section 4 Commissioning 4 1 Before Testing 4 1 1 Test Equipment 500V Insulation resistance test set Secondary injection current source rated 10A or greater Time interval meter Primary injection equipment A d c supply with nominal voltage within the working range of the Argus d c auxiliary supply rating A d c supply with nominal voltage within the working range of the Argus d c status input rating prs ONS Additionally for Argus 2 and 6 relays the following equipment is required Variable voltage source 6 Phase shifting transformer 7 Phase Sequence Indicator Alternatively items 1 2 4 5 6 and 7 can be replaced by a computer programmable V amp source universal test set Additional equipment for general tests and for testing the communications channel Portable PC with an RS232 to fibre optic converter and suitable interface cable or via RS485 input Printer to operate from the above PC Optional Use of PC to Facilitate Testing The functions of Reydisp Evolution see section 2 2 can be used during the commissionin
58. 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 earth fault instantaneous overcurrent highset 1 earth fault instantaneous overcurrent highset 2 and Earth fault Overcurrent sensitive earth fault or Sensitive Earth fault and Protection restricted earth fault Restricted Earth fault Circuit Breaker Fail Protection Cold Load Protection circuit breaker fail Application of different settings group when energising a Directional Voltage Protection Auto reclose Trip Circuit Supervision cold load phase fault directional overcurrent earth fault directional overcurrent undervoltage overvoltage protection auto reclose trip circuit supervision Pick up and drop off timers inversion latching and minimum energise time Status Inputs and Relay Outputs Communications Communication with PC or control system Data Storage Event fault and waveform records Maintenance Assistance for maintenance of circuit breakers protection schemes and the Argus relay Linesman Enables easy enabling disabling of protection and auto reclosing for line work b Within Section 2 Functional Description the following notational and formatting conventions are used 02010 Siemens Protection Devices Limited P2000
59. 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 configuration at the local port i e baud rate and parity so that communication will be at the same rate and format as that set on the relay and the error correction is disabled Auto answer usually requires two parameters to be set The auto answer setting should be switched on and the number of rings after which it will answer selected The Data Terminal Ready DTR settings should be forced on This tells the modem that the device connected to it is ready to receive data The parameters of the modem s RS232C port are set to match those set on the relay set baud rate and parity to be the same as the settings on the relay and number of data bits to be 8 and stop bits 1 Note although the Argus may be able to communicate with the modem at say 19200 bps the modem may only be able to transmit over the telephone lines at 14400 bps Therefore a baud rate setting on which the modem can transmit should be chosen In this example a baud rate of 9600 should be chosen As the modems are required to be transparent simply passing on the data sent from the controlle
60. deactivated and reactivated whereupon another pulsed output will occur 2010 Siemens Protection Devices Limited P20007 Page 45 of 71 7SG11 Argus Technical Reference Output Relay Minimum Energise Time Status Input Inversion and Delays Each status input can be set to inverted action i e the internal signal is raised when the input is de energised and 2 2 Input Matrix Or gates p Status n P U Delay 7 x Status n D O Delay Status n inverted Status n latched Status n Event Logic signals Reset Flags amp Output eset Flags amp Outputs e g P F Charact Inhibit P300008 Protection Functions Input Figure 2 11 1 Status Input Logic Logic signals e g P F Charact Reset Flags amp Outputs A Pulsed Relays Relay 1 pulsed A Hand Reset Relay 1 hand reset Output Matrix Or gates Relay n Relay n hand reset P300008 Protection Functions Input Figure 2 11 2 Output Relay Logic Table 2 24 General Output Relay and Status Input Settings Sub menu O P Relay Config Gn Status 1 Gn Status 2 _ 1 for each output contact n is the number of status inputs default present Gn Status n 02010 Siemens Protection Devices Limited P20007 Page 46 of 71 7SG11 Argus Technical Reference Gn Hand Reset Gn Pulsed Relays PRE 4 and Argus 6 only Min O P Enegerise Time 100 150 500 Sub menu Status Config Inverted ees _ 1 for ea
61. dor IEC Class Il Update period iss us eas ieee sed beta eite tbt lei Ahh eli dd hemes 65 42 5 IEC Glass ll Scala peo dee Deus oec tui ced eiectus etae as eee e te 65 4 29 Baud ALC ccs r cas tpa a o ee M AN EM uL M a e SL ED 65 A 19 Comm PAY NECEM ER QE A A OPI 65 Aa Relay AOUIBSS sides taa ced sechs acm mos Iac dos di nd suu M ERU E 65 AN Um UR EO E RR SR RE SR POD DRE OR NTE OD ET UE RD RSRS RR RR 65 42 e Data ECHO iis a o RU lin tada 66 2 244 IMod mS 2 astutus iusti ct act aay coe eed aes oat IEEE ISP UM SEO MA LIS 66 4 2 15 Connecting a Modem to the Relay S occccooccccccoccncccoconononcncononononnncnnnononnnnnnnrnnnnnnnnnonannnns 66 42 16 setting he Remote Modem iiec qun oa LEE 66 4 2 17 Connecting to the Remote Modem sss eee eee eee eee 67 43 Introductioh ModDUS RTU eet pls A o ac de s 68 4 3 1 IOI A 68 4 3 2 Recommended cable sese 68 43 9 WNeDWOIK LODOIOUM lo ea eed lus 68 2010 Siemens Protection Devices Limited P20007 Page 3 of 71 7SG11 Argus Technical Reference Lr AS 5 clo precisao en ee LT TT 69 A39 COMMS POLO CO zie rn tii 69 A30 Baud AUC aie UTERE 69 AS COMMS PANY ara tota sues ol iu ata adia doi 69 AJO Relay AU OS indi URS RU 69 ZA MEMINI Pe Irc 69 x RS A I 2 cielo o Mob Pen A NRO GR ART DRT MR EE NE 69 Foda TOSSA Sc tei uoo o No dl vid dn LU EU nae 70 List of Figures Figure 1 5 1 IDMTL Curves Time Multiplier 1 essere 16 Figure 1 5 2 Overcurrent Starte
62. in excess of the longest CB operate time relay reset time a safety margin Typically 80 ms 42 ms 50 ms 175ms approximately 3 7 Auto reclose Applications Argus 4 and Argus 6 only Automatic circuit reclosing is extensively applied to overhead line 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 e Reduce to a minimum the loss of supply to the customer e Allows greater automation of the network with relevant cost savings e Instantaneous fault clearance is possible thereby minimising fault damage 3 7 1 Reclose Time Setting The reclose time is defined as the time between the auto reclose scheme being energised and the operation of the output contacts that energise the circuit breaker closing circuit Selection of the optimum time setting is influenced by the recloser characteristics the type of load supplied and the nature of the fault The recloser mechanism reset time and closing time interval between energisation of the mechanism and the making of the contacts or the recloser duty cycle make up the minimum reclose time imposed by the recloser Where the connected plant consists of a motor circuit the motor type must be taken into consideration as regards the requirements of the auto reclose scheme Synchronous machines require a reclose time sufficiently long enough to ensure operation of their undervo
63. inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20008 Page 10 of 33 7SG11 Argus 1 Diagrams and Parameters Section 2 Settings Relay Type Serial Number Substation Feeder Identity Notes on Tables All settings found in the Argus 1 relay types are listed below Within the list some settings indicated with greyed cells are not always visible for the following reasons e Depending on the version of the relay a particular function and hence its related settings may not be present e g on a 2 phase fault and SEF relay any settings related to earth fault will not be present e Depending on the value of some settings other settings will be hidden e g if the main characteristic is set to DTL rather than an IDMT characteristic the time multiplier setting will be hidden and replaced by a time delay setting Some settings in the tables show text in square brackets e g SEF REF Current Setting This indicates different text 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
64. mI TEE Scada Control Hot Line Working Trip amp Lockout Trip amp Reclose Close amp Reclaim oo mI NN Inst Lowset Trip Counter Reset P20010 Page 10 of 22 7SG11 Argus 4 Diagrams and Parameters Relay Identifier Inverted Inputs Relay Address Pick up Delay ms Drop off Delay ms Latched Inputs V Trip a Prot Healthy Settings Group self supervision Select P F Charact Inhib 51 P F Charact piv Starter time delayed overcurrent P F Charact P F Lowset Inhib 50 P F Lowset P F Lowset instantaneous overcurrent P F Highset 1 Inhib 50 P F Highset 1 P F Highset 1 instantaneous overcurrent P F Highset 2 Inhib 90 P F Highset 2 P F Highset 2 instantaneous overcurrent E F Charact Inhib 51N E F Charact SE time delayed overcurrent E F Charact E F Lowset Inhib SON E F Lowset E F Lowset instantaneous overcurrent E F Highset 1 Inhib SON E F Highset 1 E F Highset 1 instantaneous overcurrent E F Highset 2 Inhib SON E F Highset 2 E F Highset 2 instantaneous overcurrent O O O O O O HIBHIR SEF Delay 1 Inhib 50N 87G SEF REF SEF Starter sensitive earth fault SEF Delay 1 SEF Delay 2 Inhib i restricted earth fault SEF Delay 2 SEF Lowset Inhib SEF Lowset
65. may be mapped to multiple alarms in which case a longer message will result All general alarms raised when a Fault Trigger is generated will be logged into the Fault Data record transient general alarms will thus be latched and displayed at the end of the scrolling Fault Data screen see section 2 13 2 Table 2 6 General Alarm Settings Sub menu System Config zal cpa ABCDEFGHIJKLMNOPQRSTU Up to 13 characters per name arm VWXYZ 1234567890 SET Alarm 5 ALARM Sub menu Status Config Gn Alarm 1 Gn Alarm 2 mappable to any status input default Default not mapped to any status Gn Alarm 5 2 2 6 Direction Tags Argus 2 and Argus 6 only User defined text names for the Forward and Reverse directions can be applied to assist in identification of fault direction For example FWD could be renamed FEEDER X and REV renamed BUSBAR Y Note Directional Relay convention is such that current flowing away from a busbar flows in the Forward direction These identifiers are used in the fault records to identify the direction of the fault 2010 Siemens Protection Devices Limited P20007 Page 24 of 71 7SG11 Argus Technical Reference Table 2 7 Direction Settings Sub menu System Config FWD Name Tag ABCDEFGHIJKLMNOPQRSTUV WXYZ1234567890 FWD Argus 2 and Argus 6 only REV Name Tag ABCDEFGHIJKLMNOPQRSTUV Up to 13 characters per name WXYZ1234567890 2 REV 2 2 1 Real Tim
66. number of trip operations in each minute window in a rolling window of one hour ven the total number of trip operations in one hour auto reclose settings are replaced by a Delay HS1 HS2 if applicable characteristic and one trip to lockout operation The normally active protection and sequence settings are suspended until the total number of operations decrements to below the counter setting as the rolling one hour window drops off the high trip count minute windows 2010 Siemens Protection Devices Limited P20007 Page 50 of 71 7SG11 Argus Technical Reference Table 2 27 Circuit Breaker Maintenance Settings Sub menu CB Maintenance A p Counter Reset NO YES pu A Trip Counter Alarm OFF 1 2 999 Trip Counter Reset NO YES Trip Counter Alarm us 4 and Argus 6 only OFF 1 2 999 Freq Op Counter Reset NO YES A rg US 4 an d A rg us 6 on ly Freq Op Counter Alarm i OFF 1 2 999 20000 21000 100000 Sub menu O P Relay Config Gn ATrip Alarm Argus 4 and Argus 6 only Gn Counter Alarm _ 1 for each output contact Gn XP Alarm default Gn FOC Alarm Argus 4 and Argus 6 only Sub menu Status Config Gn ATrip Counter Reset Argus 4 and Argus 6 only Gn Counter Reset 1 for each status input Gn FOC Reset default Argus 4 and Argus 6 only Gn I Update 2 14 2 Output Relay Test The output relay test allows the Argus to simulate a particular eleme
67. of the operate current note however that the summated CT magnetising current Vs must be subtracted to obtain the required relay operate current setting Since the relay operate current setting and stability operating voltage are now known a value for the series resistance can now be calculated A check is made as to whether a Non Linear Resistor is required to limit scheme voltage during internal fault conditions typically where the calculated voltage is in excess of 2kV The required thermal ratings for external circuit components are calculated Figure 3 5 2 shows the secondary wiring circuit including the non linear resistor if required 2010 Siemens Protection Devices Limited P20007 Page 58 of 71 7SG11 Argus Technical Reference Balanced Earth fault Restricted Earth fault P300012 REF Primary Figure 3 5 1 Balanced and Restricted Earth fault protection of Transformers series stabilising resistor Argus REF element 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 overcurrent elements series stabilising resistor j element non linear resistor P300012 REF Primary Figure 3 5 3 Composite Overcurrent and Restricted Earth fault Protection 2010 Siemens Protection Devices Limited P20007 Page 59 of 71 7SG11 Argus Technical Reference 3 6 Circuit Br
68. on an overhead line or new equipment is being added it can be inconvenient or impractical to make the line dead Live line working can be performed using special tools and equipment When live line working is being performed all auto reclose sequences should be inhibited and any fault must force an instantaneous Trip to Lockout 2010 Siemens Protection Devices Limited P20007 Page 44 of 71 7SG11 Argus Technical Reference disabled none of these inputs can be on In the hot line working mode if fault current above any starter setting is seen the relay will give a single instantaneous trip and lockout overriding all protection auto reclose settings and inhibits Table 2 22 Live Line Working Setting Sub menu Status Config Gn Hot Line Working _ 1 for each status input default 2 10 Trip Circuit Supervision One or more trip circuits can be monitored by connecting a status input in each trip circuit to be supervised e g as shown in the application diagram If all mapped status inputs are energised raised then the trip circuits are considered healthy If any trip circuit loses auxiliary supply or becomes high resistance or open circuit then the wired status input will be de energised cleared and a trip circuit fail alarm and indication raised Local indication will be in the form of a message on the LCD e g Trip Circuit FAIL S1 3 if the trip circuits associated with status inputs 1 and 3 have failed By mapping
69. pole phase fault or C 2 pole phase fault and earth fault 2 pole phase fault and sensitive restricted earth fault SEF REF D Nominal current 1 5 A A I O range 1 Binary Input 7 Binary Outputs incl 3 changeover 0 5 Binary Inputs 11 Binary Outputs incl 3 changeover 9 Binary Inputs 7 Binary Outputs incl 3 changeover 2 IE 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 amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 1 binary input and 110 V application order resistor box VCE 2512H10066 in addition for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 9 binary inputs and 110 V application order resistor box VCE 2512H10064 in addition for 1 binary input and 220 V application order resistor box VCE 2512H10068 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition for 9 binary inputs and 220 V application order two resistor boxes VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20008 Page 8 of 33 Product description Nondire tional O C relay Over current and earth fault protection for radial feeders capacitor banks and
70. tripping In such cases it would be undesirable for the Argus to light its TRIP LED and give fault indication Therefore a Fault Trigger setting is included to allow the fault condition to be defined by selecting any combination of output relays as tripping outputs The TRIP LED and the fault record storage will be triggered when any of the selected output relays are energised Note that a trip output can still be generated even if the fault trigger setting is not used but no trip indication is given Fault records are stored in non volatile memory 1 3 5 3 Disturbance Recorder The waveform record feature stores analogue and digital information for all current inputs status inputs and output relays On some relays voltage signals are also stored The Waveform Trigger setting is used to enable the waveform record feature Waveform storage is triggered by operation of any function selected in the waveform trigger setting In addition a record can be triggered remotely via a status input or via the serial communications interface Waveforms are stored in a 1 second rolling time window The 1 second data window has a settable pre fault triggering capability There is capacity to store five waveform records with any new record over writing the oldest All records are time and date stamped Waveform records are stored in RAM with a capacitor providing back up during breaks in auxiliary supply The waveform record store can be erased when
71. until no 2010 Siemens Protection Devices Limited protection elements are operating 2434H80002 2434H80002 2434H80002 2434H80002 2434H80002 2434H80002 Minor change Minor change Minor change Minor change Minor change Minor change Minor change Minor change Minor change Minor change Minor change First release 2010 Siemens Protection Devices Limited 7SG11 Argus 1 Diagrams and Parameters communications parity setting added user must press enter after factory defaults applied sum of setting range output relay minimum energise time reduced from 200 to 100 ms factory defaults display fault record text for characteristic element copy group setting default fault record text for characteristic element relay information provided in communications communication baud rates IDMTL starter drop off and relay reset timer 7SG11 Argus 1 Diagrams and Parameters Hardware Release History The Argus hardware is used in many different relays The list of hardware revisions applying to Argus 1 up to and including this document issue is Additional model 4 pole variant with 3 status inputs and 5 output relays First release 2010 Siemens Protection Devices Limited 7SG11 Argus 1 Diagrams and Parameters Contents doriware Release HIStory E 2 Hardware Release HIStory sz sss syazesasgsyassyasexaze sss kagsgassya2 eS eincielenceuswxwodadeeliseseusi
72. viewing the waveforms instrument screen and pressing the TEST RESET button 1 3 5 4 Sequence of Event Records The Argus event recorder feature allows the time tagging of any change of state Each event is logged with the full date and time and actual event condition every 2 5msec The following events are logged 2010 Siemens Protection Devices Limited P20006 Page 10 of 37 7SG11 Argus User Manual Change of setting though not the actual setting changes Also indication of which group of settings is active Change of state of output relays Change of state of status inputs Change of state of any protection characteristic Trip indication reset Trip test Trip supply failure Circuit Breaker maintenance alarms Circuit breaker failure The event storage buffer holds 500 records When the event buffer is full then any new record overwrites the oldest Event records are stored in RAM with a capacitor providing back up during breaks in auxiliary supply The event record store can be erased when viewing the events stored instrument screen and pressing the TEST RESET button 1 3 6 General Multiple Settings Groups Argus relays provide eight alternative settings groups making it possible to edit one group while the protection algorithms operate using another active group The Argus can then be switched from one group of settings to another to suit alterations in the power system configuration A change of group can b
73. w weoxa H 1 m aol x l laenn ir aol 04 or Tranan mm aol x 04 aata x a ro x laaa ra mop Dw wea x tro x i meer ef rep LLL E a ef Er COS INES 5 re L LI LLLI Dw w owwmee eof x Dw w wemem rap paeas d CHE wwe f re L LIC T a Argus 6 2010 Siemens Protection Devices Limited P20011 Page 18 of 22 7SG11 Argus 6 Diagrams and Parameters LLL LLLI Dw wmwwswe x 2 39 io Cw 192 vent aer x 2 39 8 Pw 199 veamos e 2 39 8 Dw we vmme x 2 no pre Dw w we 2 fr Cw 190 vatogememoya x 3 59 8 RO x 3 no 8 ros 192 votagemenove x 1 ne ro _ _ TL LI e zo eranc e Ja xo Pw wemacem pa Dwemwe emaomem x Ja no Cw mwe emacmm x 39 ros mm iorram x Ja o no ii es varaarvotogo x o Teas x a no 06 aar verwy x o RH x ne LL HH E LRL o responses 9 ed dP ass o ewwomewewm w Table Showing Command Information INF Numbers 02010 Siemens Protection Devices Limited P20011 Page 19 of 22 7SG11 Argus 6 Diagrams and Parameters Description CO TYP COT Argus 6 160 160 160 160 X 2 sarge pisa on 2 24 sonnas op 2 on x 2s sonnas crows seee ON m x 2 songs oral o m Po T II IN H EH on o m x o setae Gr
74. xin Gn P F Lowset Delay 2 3 2 sec Gn P F Highset1 Dir Control ar Gnl l P F Highset1 Setting Gn P F Highset1 Delay Gn P F Highset1 Setting Gn P F Highset1 Delay Gn P F Highset2 Dir Control Gnl l P F Highset2 Setting Gnl l P F Highset2 Delay Gn P F Highset2 Setting Gni P F Highset2 Delay Gn E F Charact Dir Control Gn A E F Charact Setting Gn i E F Charact Gn i E F Charact Time Mult Gnl l E F Charact Delay Gn E F Charact Setting Gn E F Charact BRI 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Setting name Applied value Gn E F Charact Time Mult Gn E F Charact Delay S Gn E F Lowset Dir Control Gn E F Lowset Setting X Gn i E F Lowset Delay se Gn E F Lowset Setting x D n n se O Gn E F Lowset Delay Gn E F Highset1 Dir Control Gn E F Highset1 Setting X 5 Gn E F Highset1 Delay sec Gni E F Highset1 Setting Gni E F Highset1 Delay sec Gn E F Highset2 Dir Control eal Gn i E F Highset2 Setting ec Gn E F Highset2 Setting Gn SEF REF Current Setting X n Gni SEF REF 2nd Time Gn SEF REF Lowset Delay Gn SEF REF 1st Time Delay S ec Gn SEF REF 2nd Time Delay Gn SEF REF Lowset Delay sec P20009 Page 11 of 37 Setting name Gn Relay Reset Delay Directional Menu Setting name Gn 2 Out Of 3 Gate Logic Gn P F Charact Angle Gn E F Charact Angle Gn SEF Charact Angle V
75. 010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters 110 220 aux 30V status 48V status 48V status 110V status 220V status AG6 401 AG6 402 GAF911C GAF913C GAF914C GAF915C P20011 Page 4 of 22 7SG11 Argus 6 Diagrams and Parameters Product description Variants Order No Dire tional O C relay ith auto re lose 7561160 202000 OOA0 A A A A A A AA Bi directional version of ARGUS 4 Number of elements Four pole relay 4 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input uh WN FE Type of elements 3 pole phase fault directional and sensitive restricted N 1 E earth fault SEF REF 3 pole phase fault directional and earth fault directional or P 4 E 3 pole phase fault directional and earth fault 3 pole phase fault directional and earth fault directional or P 5 E 3 pole phase fault directional and earth fault 3 pole phase fault and earth fault directional 2D 3 pole phase fault and earth fault directional 3D 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 or Modbus RTU 1 RS485 interface IEC 60870 5 1
76. 03 or Modbus RTU 2 Directional measurement characteristic angle CA 30 45 for phase faults 0 15 45 65 for earth faults 0 15 45 90 for earth faults 30 45 for phase faults and 0 15 45 65 for earth faults 30 45 for phase faults and 0 15 45 90 for earth faults ur WN ra Housing size Case size E6 4U high D Case size E8 4U high E 2010 Siemens Protection Devices Limited P20011 Page 5 of 22 7SG11 Argus 6 Diagrams and Parameters Section 2 Settings Relay Type Serial Number Substation Feeder Identity Notes on Tables All settings found in the Argus 6 relay types are listed below Within the list some settings indicated with greyed cells are not always visible for the following reasons e Depending on the version of the relay a particular function and hence its related settings may not be present e g on a 2 phase fault and SEF relay any settings related to earth fault will not be present e Depending on the value of some settings other settings will be hidden e g if the main characteristic is set to DTL rather than an IDMT characteristic the time multiplier setting will be hidden and replaced by a time delay setting Some settings in the tables show text in square brackets e g SEF REF Current Setting This indicates different text that may be displayed depending on the value of other settings i e SEF Current Setting or REF Cur
77. 06 Page 9 of 37 7SG11 Argus User Manual 1 3 5 4 Time Stamping All records are stamped with time and date using the Argus real time clock feature If the Argus is de energised then a capacitor provides a back up supply to the real time clock for a limited period Time and date can be set either via the fascia using appropriate commands in the System Configuration Menu or via the communications interface In the latter case Argus relays connected in a communications network can be synchronised by a global command Synchronising pulses can be received via a status input To use this feature one of the status inputs must be assigned to the Clock Sync feature in the Status Configuration Menu Additionally the Clock Sync Period setting in the System Configuration Menu should be set either to Seconds or to Minutes as appropriate depending on the period of the synchronising signals expected from the controlling device If Seconds are selected then energisation of the selected status input will result in the clock being synchronised to the nearest second with milliseconds set to zero If Minutes are selected then the clock is synchronised to the nearest minute with seconds and milliseconds set to zero 1 3 5 2 Fault Records The last 5 fault records are available from the Argus fascia with time and date of trip measured quantities and type of fault When issuing a trip output under fault conditions the Argus illuminates its T
78. 0870 5 103 section 7 2 5 2 TYP ASDU Type defined in IEC60870 5 103 sections 7 3 1 and 7 3 2 Gl Event supports General Interrogation x supported defined in IEC60870 5 103 section 7 2 5 2 COM Type of command single ON only or double ON OFF defined in IEC60870 5 103 section 7 2 5 2 COT Cause of Transmission defined in IEC60870 5 103 section 7 2 3 table 5 DIR Direction of event Raised Only RO Raised Cleared RC or Double Point Travelling Cleared Raised or Unknown DBI X Supported Not supported 2010 Siemens Protection Devices Limited P20008 Page 16 of 33 7SG11 Argus 1 Diagrams and Parameters Table Showing Command Information INF Numbers 0 2 Rese ce TRA ico a Rese Eos ep mol s mew e ro Dw wmm x 9 ro Cw efes 2 e fej 00 omm x 2 no pe re w eme O TEN 9 ref x 00 oe Gene ARA Te o eo Aer w ARA Te 00 vo Senet ARA Te 00 7i cenas ARA Te Argus 1 al NINININI N NIN N 2010 Siemens Protection Devices Limited P20008 Page 17 of 33 7SG11 Argus 1 Diagrams and Parameters wo 93 EF generains wio 2 t RO x Eoo po o LLL LLL 160 128 cBonbyautoredose 1f 1 Jef Eo opo o FEO IESO S 100 130 Recosebiocted x faif 19 fref PAN PS OOOO A ee 60 144 Mesurandi 34 a px Meesurand haga Vaza PQ feoj a x Eoo po oo po LLL LL saj of datos o Ja fo t RO x 164 t Atowsetstarter def t1 Rx MI T A
79. 103 MODBUS RTU IEC Class 2 Measurand ASDU 3 ASDU 9 Class 2 Update Period INST 1 2 60 IEC Class 2 Scaling 1 2x 2 4x Comms Baud Rate 75 110 150 300 600 1200 2400 4800 9600 19200 Comms Parity NONE EVEN Relay Address 0 1 254 Line Idle LIGHT ON LIGHT OFF Data Echo OFF ON 4 2 14 Modems The communications interface has been designed to allow data transfer via modems However IEC 60870 5 103 defines the data transfer protocol as an 11 bit format of 1 start 1 stop 8 data and even parity which is a mode most commercial modems do not support High performance modems will support this mode 4 2 15 Connecting a Modem to the Relay s RS232C defines devices as being either Data Terminal Equipment DTE e g computers or data Communications Equipment DCE e g modems where one is designed to be connected to the other In this case two DCE devices the modem and the fibre optic converter are being connected together so a null terminal connector is required which switches various control lines The fibre optic converter is then connected to the relay network Tx to Relay Rx and Rx to Relay Tx 4 2 16 Setting the Remote Modem The exact settings of the modem are dependent on the type of modem Although most modems support the basic Hayes AT command format different manufacturers use different commands for the same functions In addition some modems use DIP switches to set parameters others are entirely software
80. 12H10064 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition for 9 binary inputs and 220 V application order two resistor boxes VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20009 Page 9 of 37 7SG11 Argus 2 Diagrams and Parameters Section 2 Settings Relay Type Serial Number Substation Feeder Identity Notes on Tables All settings found in the Argus 2 relay types are listed below Within the list some settings indicated with greyed cells are not always visible for the following reasons e Depending on the version of the relay a particular function and hence its related settings may not be present e g on a 2 phase fault and SEF relay any settings related to earth fault will not be present e Depending on the value of some settings other settings will be hidden e g if the main characteristic is set to DTL rather than an IDMT characteristic the time multiplier setting will be hidden and replaced by a time delay setting Some settings in the tables show text in square brackets e g SEF REF Current Setting This indicates different text 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
81. 1610 1G 010 oe rU 46 Figure 2 11 2 Output Relay LOGIC sagas potentes inae elas 46 Figure 3 2 1 Parallel Feeder Protector pira papa oy e Dank Fa EAR a 99 Figure 3 4 1 Blocking scheme giving fast fault clearance eee eee 56 Figure 3 4 2 Busbar Zone Protection with Circuit Breaker Fail using Non directional Relays For use on Single source Feed Networks occccccocccccooccncococcnnonoocononnanonononcnnnnnos 57 Figure 3 4 3 Busbar Zone Protection with Circuit Breaker Fail Employing Bi Directional relays For use on fully Interconnected Networks with Remote Supply ELL KE a do ao li aces 58 Figure 3 5 1 Balanced and Restricted Earth fault protection of Transformers 59 Figure 3 5 2 Restricted Earth fault Secondary CirCulb ooooccccconcccncccnocccnncnonanccnnnnnnanccnnonnnnrnnnnnnnncrnnonnnnns 59 Figure 3 5 3 Composite Overcurrent and Restricted Earth fault Protection sss eee eee 59 Figure 3 8 1 Engineering Recommendations S 15 H6 Trip Circuit Supervision scheme 61 Figure 3 8 2 Engineering Recommendations S 15 H5 Trip Circuit Supervision scheme 62 Figure 4 2 1 Communication to Argus Relay using Sigma 4 Local Connection 67 Figure 4 2 2 Communication to Argus Relay using Sigma 4 and Modem sss sees eee eee 67 Figure 4 2 3 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 3 and Fibre optic Ring Ne
82. 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 will be disconnected before any input contacts in order to prevent maloperation The rear terminals are designed to take two wires terminated using ring crimps and are secured using M4 screws 1 2 2 Front Cover After the Argus has been commissioned it is sealed by fixing a clear plastic cover over the front This allows the user to see the entire front of the relay but only allows access to the and buttons allowing all of the menus to be viewed but not changed The only action which is permitted is to reset the Fault Data Display latched output relays and the trip LED by using the TEST RESET function of the button 1 2 3 User Interface Fascia The user interface is designed to provide a user friendly method of entering settings and retrieving data from the Argus relay Relay Information The Reyrolle logo appears in the top left corner of the Argus At the top right an information label is provided which contains the range name Argus 1 Argus 2 Argus 4 or Argus 6 model number serial number and nominal ratings of energising quantities 2010 Siemens Protection Devices Limited P20006 Page 4 of 37 7SG11 Argus User Manual Liquid Crystal Display A 2 line 16
83. 2 in all relays both Feeder and Incomer are set to the same setting and Forward with no delay instantaneous and are connected to the block Inhibit control line of the HS1 elements on all relays Thus for faults outside the zone busbar protection all HS1 instantaneous elements will be inhibited The forward IDMTL function is set to trip a faulted feeder in accordance with the system grading requirement With Argus relays a busbar fault trip initiation needs to be delayed by only 50ms this is sufficient to enable a feeder circuit relay fast start output contact to block the incomer circuit relay should the fault be on a feeder Adoption of this philosophy will result in fast clearances of busbar faults coupled with through fault stability If Circuit Breaker fail is required then this must be mapped out from each relay into all other relays on the busbar each relay must accept an external Trip input energised from any other relay or the CBF outputs must be connected in parallel to a separate common Trip circuit for all Circuit Breakers 2010 Siemens Protection Devices Limited P20007 Page 57 of 71 7SG11 Argus Technical Reference Incomer Incomer Incomer HS2 Fwd HS2 Fwd HS2 Fwd E HS1 HS1 HS1 IDMT Inhibits a Inhibits HS1 Hs1 HS2 Fwd Inhibits HS2 Fwd HS1 Inhibits Inhibits P300005 Application Diagrams Busbar Dbl Src Figure 3 4 3 Busbar Zone Protection with Circuit Breaker Fail Employing Bi Directi
84. 2 1 Circuit breakers at E and G would have Argus 2 6 relays installed set to bi directional The E amp G reverse IDMTL elements must be set to grade with the forward settings on the load circuit breaker relays and the C amp D forward element settings the E amp G forward IDMTL elements are set more sensitive i e with lower current and time multiplier settings to detect feeder faults 02010 Siemens Protection Devices Limited P20007 Page 54 of 71 7SG11 Argus Technical Reference For a fault as shown close to the load substation the currents at breakers C and D will have similar levels and their associated Argus relays will have prospective operate times of the same order For the anti clockwise fault current flow through C G FWD must be set to be faster than E REV which in turn must be faster than C FWD Relay G will thus Trip first on FWD settings to stop the back feed of the fault leaving D FWD to operate to clear the fault and the un faulted Feeder C maintains power to the load If the fault occurred on feeder C then clockwise fault current will flow through D E FWD must be set to be faster than G REV which in turn must be faster than D Relay E will thus Trip first on FWD settings to stop the back feed of the fault leaving C FWD to operate to clear the fault and the un faulted Feeder D FWD maintains power to the load Relays at C and D at the main substation could be set to non directional but by setting them to be direct
85. 20008 Page 33 of 33 7SG11 Argus 2 Diagrams and Parameters 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 2010 02 Document reformat due to rebrand 2006 03 Third issue Editorial modifications software revision histories updated 2004 05 Second issue Addition of CBF Demand metering settings and Modbus RTUprotocol 2002 12 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 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Software Release History The software listed below is used in one of more types of Argus relay The list
86. 23B AG1 401 DCD413A AG1 411 DCD413B AG1 431 AG1 322 DCD314C AG1 304 DCD324A AG1 314 DCD324B AG1 324 DCD324C AG1 402 DCD414A AG1 412 DCD414B AG1 422 DCD414C AG1 433 AG1 303 DCD323A AG1 323 DCD323C AG1 421 DCD413C DCD415A DCD415C cose DCD325A DCD416A DCD416C 3 phase fault and earth fault 5A OR AG1 432 AG1 434 3 phase fault and SEF or 2 phase fault earth fault and SEF Figure 4 7 1 SI TOR DCD421A 5 SI 11 OR DCD421B 9 SI 7OR DCD421C Figure 4 8 2010 Siemens Protection Devices Limited AG1 403 DCD423A AG1 413 DCD423B AG1 423 DCD423C AG1 404 DCD424A AG1 414 DCD424B AG1 424 DCD424C PEDRA DCD425B DCD425C P20008 Page 6 of 33 DORA DCD4268 DCD426C 7SG11 Argus 1 Diagrams and Parameters Product description Variants Order No Nondire tional O C relay 71561110 20000 on0DAO A A A A A A Over current and earth fault protection for radial feeders capacitor banks and industrial and commercial plant Number of elements Single pole relay 1 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 0 110 220 V DC auxiliary 30 V binary input 1 24 30 48 V DC auxiliary 48 V binary input 2 110 220 V DC auxiliary 48 V binary input 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 Single pole phase fault
87. 4 Sequence Auto reclosing In Argus 4 amp 6 auto reclose Relays the low set overcurrent stage functions as the Instantaneous trip Complex sequences may be user programmed to give the best fault clearance strategy The Argus 4 and 6 relays provide auto reclosing with sequence co ordination of the Instantaneous low set characteristics and Shot Counters The source low set is time delayed i e time delayed instantaneous and grading and Sequence Co ordination with a downstream instantaneous recloser is ensured Typically an auto reclose sequence set to 2 Instantaneous Trips plus one Delayed Trip will restore supplies for 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 circuit develops a fault and monitoring current flow ceases the normally energised status input drops off and if it To avoid giving spurious alarm messages while the circuit breaker is operating the status input should be programmed to have a 400 ms drop off delay Schemes based on the Electricity Association H6 H5 schemes are shown below Argus relay Circuit breaker Trip contacts Trip coil For 110 125 VDC use extern
88. 5C DCD626C AG2 315 AG2 316 OR DCD631B DCD633B DCD634B DCD635B DCD636B AG2 325 AG2 326 R DCD631C DCD633C DCD634C DCD635C DCD636C AG2 317 AG2 318 OR DCD641B DCD643B DCD644B DCD645B DCD646B AG2 327 AG2 328 R DCD641C DCD643C DCD644C DCD645C DCD646C AG2 411 AG2 412 1 OR DCD811B DCD813B DCD814B DCD815B DCD816B AG2 421 AG2 422 R DCD811C DCD813C DCD814C DCD815C DCD816C AG2 413 AG2 414 1 OR DCD821B DCD823B DCD824B DCD825B DCD826B AG2 423 AG2 424 R DCD821C DCD823C DCD824C DCD825C DCD826C SI AG2 415 AG2 416 1 OR DCD831B DCD833B DCD834B DCD835B DCD836B SI AG2 425 AG2 426 7 OR DCD831C DCD833C DCD834C DCD835C DCD836C 3 directional phase fault and 5 SI AG2 511 AG2 512 directional earth fault ig 4 11 OR DCD911B DCD913B DCD914B DCD915B DCD916B under overvoltage ig 4 9 SI AG2 521 AG2 522 Voltage and power measurements 7OR DCD911C DCD913C DCD914C DCD915C DCD916C Fal AG2 513 AG2 514 3 dir n phase fault and SEF or DCD921B DCD923B DCD924B DCD925B DCD926B 2 dirn P F dirn E F and SEF l 11 OR and under overvoltage e Voltage and power measurements l 9 SI AG2 523 AG2 524 7OR DCD921C DCD923C DCD924C DCD925C DCD926C 2010 Siemens Protection Devices Limited P20009 Page 5 of 37 Application Diagram Directional earth fault Fig 4 1 Directional sensitive earth fault Fig 4 2 O Protection Y a OM gt OM Ol 20 3 directional phase fault O1 N 20090 2 directional phase faul
89. 7 Page 21 of 71 7SG11 Argus Technical Reference e Item in menu structure Item e Setting Sub menu setting name e Setting value value e Alternatives 1st 2nd 3rd 2 The purpose of this document is to describe the capabilities and functionality of the Argus Overcurrent Protection relays The User Manual document describes how to set up and operate the Argus apply configuration settings and passwords view instruments and set default instruments and retrieve fault data 2 2 Configuration overall requirements of the system and the protection scheme e g system frequency CT VT ratios identifiers user alarm text date amp time password etc 2 2 1 Settings Groups Settings groups are used to parameterise the protection and configuration of the Argus relay Eight Groups each containing a completely independent set of setting values can be stored in the relay only the designated Group groups i e summer and winter settings cold load settings alternative settings values to cover special temporary situations test settings embedded generation in out settings etc Some settings are common across all groups e g Relay Identifier etc Settings that can be set to a unique value in each group have a setting description beginning with Gn where n is the number of the Group currently being 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
90. B maintenance alarm Frequent operations exceeded A Delta Trip Counter Alarm Voltage Block 85 Circuit breaker closed 87 88 Reclose Delay Reclaim r ockout Forward SEF E Reverse SEF 92 Power On Counter Alarm CT Failure Cold load pickup ARC start A External trip block IN Raja rA LO N O Ha o AIR SEF off 11135 164 All ARC off H ER E 11136 164 11137 16 11138 16 11139 6 11140 6 ke I N U E me K CJ F ARC off F ARC off 4 SEF ARC off KA KA LA ul gt inst off me e BIBI RY a I I oO P F inst off 11141 164 11142 E ER N E F inst off E I 00 SEF inst off 11143 E E LO Hot line working 11144 6 Scada Control 11145 16 11146 164 22 11147 164 23 11148 164 24 General alarm 4 20 21 General alarm 1 General alarm 2 General alarm 3 KA l Kk l KA C Gn AJAJAJA E 11149 164 125 General alarm 5 16 133 Vc Vca starter Va Vab starter Vb Vbc starter IA 170 V starter 2010 Siemens Protection Devices Limited P20008 Page 26 of 33 7SG11 Argus 1 Diagrams and Parameters MODBUS Description Address 11214 164 190 Voltage Memory A 11215 Voltage Memory B 11216 Voltage Memory C Table Showing Input Registers Address Description Words 30001 1 30002 30101 30103 30105 30107 30109 30111 30113 30115 30117 Ie SECONDARY 30119 Isef ref SECONDARY
91. BF timer 1 delay If current is still above the setting CBF timer 2 then begins to operate and will issue a second output after the CBF timer 2 delay 1 3 2 Control 1 3 2 1 Autoreclose Argus 4 and Argus 6 only Integrated auto reclose is available as an ordering option The Argus incorporates a 5 trip 4 close auto reclose sequence that can be initiated 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 Supervision An Argus relay can monitor its associated trip circuit by configuring one of its status inputs using the Trip Circuit Fail setting and connecting the input into the trip circuit refer to the applications guide for details of how this is achieved Indication is then given instantaneously of Trip Circuit Failure should a fault be detected this display also identifies which input has detected the fault Since the status inputs can be programmed to operate output contacts an alarm output can also be generated from the trip circuit supervision feature 1 3 3 2 Circuit Breaker Maintenance The I summation feature and the trip counter provide circuit breaker condition monitoring
92. Between independent circuits Across normally open contacts 1 0 kV AC RMS for 1 min 1 5 1 4 IP Ratings Installed with cover removed 1 5 2 Immunity 1 5 2 1 Auxiliary DC Supply Variation Quantity Value Allowable superimposed ac component lt 12 of DC voltage Allowable breaks dips in supply collapse to zero from nominal voltage lt 20ms 1 5 2 2 High Frequency Disturbance IEC 60255 22 1 Class III Common longitudinal mode 2 5 kV E Series transverse mode nus 1 5 2 3 Electrostatic Discharge IEC 60255 22 2 Class Ill Type Contact discharge Variation 5 9 Level 8 0 kV 1 5 2 4 Radiated Radio Frequency Interference IEC 60255 22 3 Class III 20 MHz to 1000 MHz 10 V m lt 5 10 20 Fast Transients IEC 60255 22 4 Class IV Type 5 50 ns 2 5 kHz repetitive 4kV lt 3 Level Variation 2010 Siemens Protection Devices Limited P20007 Page 14 of 71 7SG11 Argus Technical Reference 1 5 2 6 Surge Immunity IEC 60255 22 5 Between all terminals and earth or between any two independent circuits 4 0 kV 1 2 50 us or 8 20 us 1 5 2 7 Conducted Radio Frequency Interference IEC 60255 22 6 1 5 3 Emissions 1 5 3 1 Radiated Radio Frequency Interference Limits at 10 m Quasi peak 30 to 230 MHz 40 dB uV IEC 60255 25 230 to 10000 MHz 47 dB uV 1 5 3 2 Conducted Radio Frequency Interference IEC 60255 25 Type 0 15 to 0 5 MHz 79 dB uV 66 dB uV 0 5 to 30 MHz 73 dB uV 60 dB uV
93. DIESMOOUNG GUIAS MER TE tt TO 35 2010 Siemens Protection Devices Limited P20006 Page 3 of 37 7SG11 Argus User Manual Section 1 Relay Description 1 1 Overview The Argus range of overcurrent protection combines the power and flexibility of microprocessor technology with decades of experience in the field of overcurrent protection and auto reclose A wide range of protection elements are supplemented by advanced features such as control metering data storage and fibre optic based communications Features IDMTL phase overcurrent stage 50 51 3 DTL phase overcurrent stages 50 IDMTL earth fault stage 50N 51N 3 DTL earth fault stages 50N 2 instantaneous and DTL SEF REF stages with harmonic rejection 50N Trip circuit supervision 74TC Circuit breaker failure protection 50BF Single pole three pole and four pole variants True RMS measurement Status inputs with independent pick up and drop off timers and logic inversion to reduce scheme engineering Flexible supply voltage ranges Low AC DC burden Eight independent settings groups Self hand and electrical reset contacts Extensive fault sequence of event and disturbance recorder IEC60870 5 103 fibre optic communications Modbus RTU communications Continuous self supervision of operation and power supply 1 2 Hardware 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
94. DIR Direction of event Raised Only RO Raised Cleared RC or Double Point Travelling Cleared Raised or Unknown DBI X Supported Not supported 2010 Siemens Protection Devices Limited P20011 Page 14 of 22 7SG11 Argus 6 Diagrams and Parameters Table Showing Command Information INF Numbers 0 2 Rese Eos TRA ico a Rese Eos e mo s mew 5 i Dw wmm e 9 rox Cw efes 2 e fej 00 omm x 2 no pe re w eme O TEN 9 ref x 00 oe Gene ARA Te o eo Aer w ARA Te 00 vo Senet ARA Te 00 7i cenas ARA Te Argus 6 al NINININI N NIN N 2010 Siemens Protection Devices Limited P20011 Page 15 of 22 7SG11 Argus 6 Diagrams and Parameters wo 93 EF generains wio at RO x EO opo oo o IESO LLL wo 128 cBonbyautoredose 1f 1 Toe x PEI O ee PAN PS OOOO OS CO EE ee ee teo 144 Messuramdl fat a o px Measurand haza Ves PA feoj a Eoo po o o po LLL LL 4 of datos o Ja fo t RO x 164 t Atowsetstarter def t1 Rx MI T A INE 4 3 Ctowsetstarter def 1 Jm x 4 4 Esomsetstater 2 t Rx e seme 2 TIEN 164 elBlomam 2j n RO x 164 T Cometo d def t RO x tea elElmam 2j t RO x NI T A E 4 To Bdewdtb j 2 to jm x Ragase 2 1 JR x 4 se Edemar 2j t jm x saj a ansin o 2j t O x 16 aa ensim o 2j t jm x EE NENNEN EUH Es eor T pm 160 sefonsem Y def n O x
95. E F Charact Angle Auto reclose Menu Setting name Gn Line Check Trip Gn Seq Edit View GnP F ARC GnP F Line Check Trip GnP F Protection Trip 1 Ref Applied value xin Ref Applied value EI EI Ref Applied value e BI BI mI BI P20011 Page 7 of 22 Setting name GnP F Reclose DTL 1 GnP F Protection Trip 2 GnP F Reclose DTL 2 GnP F Protection Trip 3 GnP F Reclose DTL 3 GnP F Protection Trip 4 GnP F Reclose DTL 4 GnP F Shots To Lockout GnP F HS1 Trips to Lockout GnP F HS2 Trips to Lockout GnE F ARC GnE F Line Check Trip GnE F Protection Trip 1 GnE F Reclose DTL 1 GnE F Protection Trip 2 GnE F Reclose DTL 2 GnE F Protection Trip 3 GnE F Reclose DTL 3 GnE F Protection Trip 4 GnE F Reclose DTL 4 GnE F Shots To Lockout GnE F HS1 Trips to Lockout GnE F HS2 Trips to Lockout Gn SEF REF ARC Gn SEF REF Line Check Trip Gn SEF REF Protection Trip 1 Gn SEF REF Reclose DTL 1 Gn SEF REF Protection Trip 2 Gn SEF REF Reclose DTL 2 Gn SEF REF Protection Trip 3 Gn SEF REF Reclose DTL 3 Gn SEF REF Protection Trip 4 Gn SEF REF Reclose DTL 4 Ref Applied value sec BI sec BI sec mI sec mI mI mI mI BI mI sec mI mI Sec BI Sec 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Setting name Ref Applied value Gn SEF REF Shots To 2a Lockout id GnSA Line Check Trip 2 GnSA Reclose DTL 1 sec GnSA Reclose DTL 2 s
96. EF REF Lowset SEF REF Delay 1 SEF REF Delay 2 SEF Delay 2 Inhibit E F FWD Block E F REV Block Argus 2 and Argus 6 only P F Lowset Inhibit E F Lowset Inhibit SEF Lowset Inhibit _ Lockout Alarm Close Pulse Reclaimed SA Blocked SA Alarm SA Trip trip circuit supervision Hot Line Working P300008 Protection Functions Overall Figure 2 1 1 Overview of Argus Relay Protection Functions Scaled analogue inputs are derived via input transformers Control inhibit input signals and output relays can be user mapped to be raised from any one or more status inputs similarly protection alarm and control element outputs can be user mapped to output relays The user can thus create an individual Input Output matrix mapping specific to each installation Each status input can be set to be inverted and or latched and have pick up and drop off delay times set Each output relay may be individually set to be latched Hand Reset The flexibility of this input output mapping coupled to the Protection and Control functions and Settings Group selection enables users to integrate scheme functions into the ARGUS Relay to produce a sophisticated protective device Each of the functions shown in Figure 2 1 1 is described in the relevant sections below 2010 Siemens Protection Devices Limited P20007 Page 20 of 71 7SG11 Argus Technical Reference 2 1 1 Models A variety of Argus overcurrent protection models is avai
97. Earth fault Elements Table 2 13 Sensitive Earth fault Restricted Earth fault Settings Sub menu Protection e Gn SEF Dir Control OFF FWD REV TRI ur aa 2 Single pole dir n SEF Gn SEF REF Current Setting 0 005 0 010 0 050 0 960 xin Gn SEF REF 1st Time Delay 0 00 0 01 5 00 20 00 20 5 100 101 300 s Gn SEF REF 2nd Time Delay OFF 0 00 0 01 5 00 20 00 see note 1 below 20 5 100 101 300 s 7 SEC Gn SEF REF Lowset Delay 0 00 0 01 20 00 20 5 100 101 300 s Sub menu O P Relay Config Setting name Range bold default Notes see note 1 below 02010 Siemens Protection Devices Limited P20007 Page 30 of 71 7SG11 Argus Technical Reference Setting name Range bold default Notes see note 1 below Gn SEF REF Starter _ 1 for each output contact default Gn SEF REF Delay 1 Gn SEF REF Delay 2 E E see note 1 below Gn SEF REF Lowset 1 for each output contact default settings all Protection GnF SEF REF Block default _ 1 elements energise the Trip output GnR SEF REF Block relay 2 Sub menu Status Config Gn SEF REF Delay 1 Inhib Gn SEF REF Delay 2 Inhib e T SIRE Gn SEF REF Lowset Inhib l Note 1 On the single pole directional SEF model if the directional control is set to tri state these settings will be duplicated for forward and reverse directions The settings for the forward direction are indicated by an F 2 4 1 Hi
98. F Charact Angle Earth forward Dir n Blk E F FWD Earth reverse Dir n Blk E F REV P300008 Protection Functions Dir n E F Figure 2 7 2 Functional Diagram Earth fault Directional Element Table 2 17 Directional Settings Sub menu Directional 2010 Siemens Protection Devices Limited P20007 Page 35 of 71 7SG11 Argus Technical Reference Setting name Range bold default Units Notes 2 Out Of 3 Gate Logic OFF ON EM P F Charact Angle 30 45 Type element 90 89 45 90 Type Il element E F Charact Angle 0 15 45 65 Type element 90 89 15 90 Type Il element SEF Charact Angle 0 15 45 65 Type 1 only Voltage Memory OFF 0 1 0 5 Sub menu O P Relay Config Gn P F FWD Block Gn P F REV Block _ 1 for each output contact Gn E F FWD Block default Gn E F REV Block Gn SEF FWD Block _ 1 for each output contact Argus 2 single pole directional Gn SEF REV Block default SEF only 2 8 Voltage Protection Argus 2 type Il models only The voltage elements are set in terms of the directly measured voltage If used for phase phase connection the voltage elements will be phase phase if used for phase neutral connection the voltage elements will be phase neutral The voltage elements provide pole by pole outputs that can be used to block the appropriate overcurrent element the Vab element will block the phase A overcurrent element Vbc will block phas
99. Gn CB Fail 2 Gn ATrip Alarm Gn Counter Alarm Gn FOC Alarm Gn XI Alarm Gn Power On Count Gn Hand Reset Gn Pulsed Relays 02010 Siemens Protection Devices Limited P20011 Page 9 of 22 See also Figure 2 1 on page 13 for the programming matrix Setting name Ref Applied value Settings Group Select em o Gn Inverted Inputs Gn Latched Inputs Gn P F Charact Inhib Gn P F Lowset Inhib Gn P F Highset 1 Inhib Gn P F Highset 2 Inhib Gn E F Charact Inhib Gn E F Lowset Inhib Gn E F HighSet 1 Inhib Gn E F HighSet 2 Inhib Gn SEF REF Delay 1 Inhib Gn SEF REF Delay 2 Inhib Gn SEF REF Lowset Inhib Gn Trip Circuit Fail Gn Waveform Trig Gn ZI Update Gn Reset Flag amp Output Gn Clock Sync Setting name Ref Applied value Gn Status 1 P U Delay Sec Gn Status 1 D O Delay Sec Gn Status 2 P U Delay Sec Gn Status 2 D O Delay am sec p E Gn Status 8 D O Delay memes ef notices fees cameron femal mmm fe ewm e e pe AE re e meme e porem e mae e aem m mee E www ees ewm ef arar pe 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Setting name Ref Applied value EP E B Gn Alarm 3 ee nete below a25 poes ins fas The text of these setting names reflects the value applied to the Set Alarm n settings in the System Config menu Gn Hot Line Working Gn Alarm 1 x see note below Gn Alarm 2 x see note below Comms Interface Men
100. I Is Figure 1 5 4 Instantaneous Lowset Operate Time to Contact 2010 Siemens Protection Devices Limited P20007 Page 17 of 71 7SG11 Argus Technical Reference Co iN lt E o gt o 7 x A 70 Frequency Hz Figure 1 5 5 Sensitive Earth fault Frequency Response Is 5 mA D gt O O O N Time ms O 0 5 10 15 20 25 Current multiple of setting I Is Figure 1 5 6 Sensitive Earth fault Operate Time to Contact 2010 Siemens Protection Devices Limited P20007 Page 18 of 71 7SG11 Argus Technical Reference Q o E H Angle from Characteristic Angle Figure 1 5 7 Directional Timing Characteristic 2010 Siemens Protection Devices Limited P20007 Page 19 of 71 Section 2 Functional Description 2 1 integrated control Introduction The Argus overcurrent relays incorporate a range of protection elements and functions that together with the automation display and communication functions provide comprehensive protection for 7SG11 Argus Technical Reference application in distribution substations or backup protection on transmission feeders The protective functions that can be provided are shown in Figure 2 1 1 together with the analogue and digital input signals and outputs P F Charact Inhibit P F Lowset Inhibit P F Highset 1 I
101. I directional elements an open delta tertiary winding can be used or alternatively the relay will itself calculate the residual voltage internally from the three applied phase earth voltages With these relays any characteristic angle between 90 and 90 can be selected The characteristic angle setting should be matched to the expected nominal angle of system fault Note that when type directional Argus relays are used on 60Hz systems the nominal characteristic angles will change slightly typically P F by less than 5 and E F by less than 5 2 2 Two out of three Gate This feature is applicable to relays with three directional phase fault poles It provides the means of achieving absolute discrimination between two directional overcurrent protection relays in power system applications where 1 2 1 fault current distribution can occur 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 1 3 Voltage Memory In the condition of a 3 phase fault where the polarising voltage collapses the relay can maintain the Forward or Dir n BIK A FWD 2 out of 3 logic Dir n BIK B FWD fwd Dir n BIk C FWD Dir n BIK A REV 2 out of 3 logic Dir n BIK B REV rev Dir n BIK C REV P300008 Protection Functions Dir n P F Figure 2 7 1 Functional Diagram Phase fault Directional Element E
102. L TRIP Trip generated externally and monitored through status input CB FAIL 1 Circuit breaker fail re trip CB FAIL 1 2 Circuit breaker fail back trip lt XX gt E Element shown e g lt IDMTL gt raised the fault trigger Current lA xxx Current of phase A is xxx IB xxx Current of phase B is xxx IC 2xxx Current of phase C is xxx IE xxx Current of earth fault pole is xxx IS E xxx Current of sensitive or restricted earth fault pole is xxx VA XXX Voltage of phase A is xxx VB xxx Voltage of phase B is xxx VC 2xxx Voltage of phase C is xxx VN xxx Neutral displacement voltage is xxx Auto reclose TRIP amp RECLOSE Autoreclose following trip HOT LINE LOCKOUT Recloser locked out following trip due to hot line working active TRIP amp LOCKOUT Recloser locked out following trip LINE CHECK TRIP Trip due to switch onto fault 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 lt HS1 gt HS2 IA 12 32xIn PHASE B LS IDMTL HS1 HS2 IB 12 23xIn PHASE C LS IC 0 78xIn EARTH FAULT LS IDMTL IEz0 27xln BUCHHOLZ TRIP This specifies the date and time of the trip and that settings group 1 was active at the time of trip On phase A the lowset delayed characteristic and highsets 1 and 2 were picked up Phase A highset 1 iss
103. L1 tor1 1 or 10 ms DTL2 Lnn toro 1 or 10 ms Repeatability 1 or 10ms Overshoot time lt 40 ms Disengaging time lt 42 ms nio 47 Hz to 52 Hz bisons 57 Hz to 62 Hz 5 Figure 1 5 6 shows the sensitive earth fault starter output This instantaneous operate time applies to non directional characteristics Where directional control is applied then the directional element operate time section1 4 4 should be added to give total maximum operating time 1 4 4 Directional Characteristics Applies to Argus 2 and Argus 6 relays only Directional characteristics can be applied to phase fault overcurrent elements earth fault overcurrent elements and single pole sensitive earth fault models Two types of directional element exist referred to below as type and type II On a particular model the type of element in the relay can be identified from the range of the angle setting as listed below 02010 Siemens Protection Devices Limited P20007 Page 11 of 71 7SG11 Argus Technical Reference Operate Angle 430 45 Phase tault 90 89 0 1 90 0 15 45 65 2 see note below coli 90 89 0 1 90 Angle setting type lat 50 Hz g Characteristic type Os t5 CA angle I with respect to V Phase fault 25 5 or 40 5 BES gue Earth fault 0 5 13 5 46 5 or 67 5 forward CA 87 5 5 to CA 87 5 5 Operating angle reverse CA 180 87 52 5 to
104. MARY 1000 A X 1000 A x 1000 A x 30113 Ib SECONDARY 1000 A X 30115 Ic SECONDARY 1000 A X 30117 Ie SECONDARY 1000 A X 1000 A 30121 Ia xIn 30123 Ib xIn 30125 Ic xIn 30127 Ie xIn 30129 Isef ref xIn A Direction B Direction 30147 C Direction E Direction Relay Status 30171 Status Inputs Trip Circuit Fail 30187 Trip Counter 30189 Deltatripcount 2 31 30191 Frequent Operation Counter 2 1 30193 Sumofl2 2 100 MA72 x xo 30195 Number of Waveforms 2 1 x x 30197 NumberofEvents 2 1 x x 30199 NumberofFauts 2 1 x x 3000 Time 8 x x 3009 Dte 8 x x 30217 starters 8 J klx 30257 Generalalarms 8 x x Power On Resets ecce HET A xIn EMEN po ee ee a oor a eee EE ANN Loa Jos FrhEERE FF FF FF FE N IN IN IN IN IN 2010 Siemens Protection Devices Limited P20009 Page 28 of 37 7SG11 Argus 2 Diagrams and Parameters 30273 arcstaus 8 30281 ARC Inhibits 30289 Circuit Breaker 8 30297 ShtNumber 2 a 30299 Power On Counter 2 1 x x 30301 VA PRIMRY 2 100 V x 30303 VB PRIMARY Polis pw Ede 30305 VC PRIMARY 1000 A E 30307 VN PRIMARY 1000 SE WESS 30309 VAB PRIMARY 1000 ie 30311 VBC PRIMARY 1000 a eee 30313 VCA PRIMARY 1000 op lia Too a e
105. N x x oos 160 25 Seungs Group see on x x mos aea 9 energie ouput Jo e mme i9 52 Lanz fon x x moz 1 53 messeowpus ov x x 2010 Siemens Protection Devices Limited P20009 Page 24 of 37 7SG11 Argus 2 Diagrams and Parameters MODBUS Description Address use vee 54 energie Oupe Jon x xo ume use 55 energie Outputs Ov x x mom ice ss energie outputs Ov x x mom is 57 energie Output ON x x mom use ss energie cupra ov x x mom ice 59 energie Output ov x x moe ses 60 energie parao on x x mos use s energie oututis Jon x _ x Loos 166 60 moger waver Storage ON x x eue use amp mpanatocoue om oum fies m Goseand Reciam o oum use a mpananecose o onmo ice as coseangrccin oworr oum rss 100 coa roaa pao ovo fum fiss uo ser Poor mue ie ua pmc ovor mus see us rrmcmwe Jovor oum use arem ovorr ous Jre us instantaneous Jowo om0 use ue Snn ovo eim use 117 arnas Jowo oue ros ue ser instantaneous Jowo me um ns pene were ovn ouse 164 130 Reset Movimum Demand Jon x x Table Showing Inputs MODBUS Description Address 10016 Auto Reclose Active aie 2010 Siemens Protection Devices Limited P20009 Page 25 of 37 7SG11 Argus 2 Diagrams and Paramet
106. O Raised Cleared RC or Double Point Travelling Cleared Raised or Unknown DBI X Supported Not supported 2010 Siemens Protection Devices Limited P20009 Page 17 of 37 7SG11 Argus 2 Diagrams and Parameters Table Showing sommana Information INF Number Reset FCB Reset CU Start Restart ARC in progress Trip Test Settings changed 23 Setting G1 selected Setting G2 selected Setting G3 selected 26 Setting G4 selected Input 1 Trip circuit fail 46 Group Warning Alarm o 54 E ME I F general HS trip E F general trip 5 O c m NO 5 O c m d I zi O c m oO 2010 Siemens Protection Devices Limited P20009 Page 18 of 37 7SG11 Argus 2 Diagrams and Parameters wo s EFgenerainswio fo o aef t pope AAA wo 126 cBonbyautoredose af 1 Jef f Eo opo po oL O O 100 130 Reciose blocked f x Re ee ee ee eee eee 60 144 measurana i Jar aro Messurand lazo Vasa PQ o a x x Lobo a saj of datos Et Tt RO x x 1604 t assinet f o def 1 Re x x 4 2 Bwesmer f Ja 1 frefxf 164 3 cHowsetstater 2j 1 Jm x x 4 4 Esomsetstater 2j tx x to SiAewetb O EA Jm x RIL 2j t jm x to TiCemeto Ja t jm x x 4 8SiEewetb Y 2j t ro x LE lou 4 10 Bxdelwedme Ja t ro x 4 Mice Ja fo t Jm x x 4 se Edemedro Ja t jm x pte faust O EA gm x 4 safensim 2 t jm x E H Eca De memw
107. O LLL wo 128 cBonbyautoredose 1f 1 Toe x PEI O ee PAN PS OOOO OS CO EE ee ee teo 144 Messuramdl fat a o px Measurand haza Ves PA feoj a Eoo po o o po LLL LL 4 of datos o Ja fo t RO x 164 t Atowsetstarter def t1 Rx MI T A INE 4 3 Ctowsetstarter def 1 Jm x 4 4 Esomsetstater 2 t Rx e seme 2 TIEN 164 elBlomam 2j n RO x 164 T Cometo d def t RO x tea elElmam 2j t RO x NI T A E 4 To Bdewdtb j 2 to jm x Ragase 2 1 JR x 4 se Edemar 2j t jm x saj a ansin o 2j t O x 16 aa ensim o 2j t jm x EE NENNEN EUH Es eor T pm 160 sefonsem Y def n O x 164 sojonsem Y def t RO x Dw m emw ro 164 21 SEFIREF stater x af 19 RO x ESOS AO O NNI a ee 164 23 SEFIREF lowsettip 2 t RO x 164 24 sermersiagetato 2 t RO xo 164 25 sermersiagezato 2 1 RO 4 26 amstatater 2 1 feje ef afers re 160 asjotisistarer J de 1 fejs Argus 4 elle NM MM M NM MB NM Current Measurand Scaling can be User set to either 1 2 x In or 2 4 x In 2010 Siemens Protection Devices Limited P20010 Page 15 of 22 7SG11 Argus 4 Diagrams and Parameters e eem H HE ICO E IE Cw epemme H HT Dw w smme o re 4 afers H re IRES E i si eraoro x 9 rol x Cw m omwwwewz T Dw e meem x
108. OO OO OOO Alarm 1 A AS qe ENE TENA EA q RENE CNN EUREN EON nes ED EIER Reset Flag amp Outputs output relay control O O O O Min O P Energise Time E i i AO D 10 dO GO ST O OR OO OD errrrrrre Argus Elements vsd AG4 amp 6 2 R2 O0 O O R3 O O O0 R1 00 O O Figure 2 1 Status Input and Output Relay Programming Matrix 2010 Siemens Protection Devices Limited P20010 Page 12 of 22 7SG11 Argus 4 Diagrams and Parameters Section 3 IEC 60870 5 103 Definitions The following tables give information on the IEC 60870 5 103 protocol A detailed description of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www reyrolle protection com in publications section under technical reports communications interface manual Table Showing Function Type Numbers Used Reyrolle Overcurrent Protection Cause of Transmission The cause of transmission COT column of the Information Number and Function table lists possible causes of transmission for these frames The following abbreviations are used Table Showing Permitted Cause of Transmission Numbers A on OO fine one 0 fertigation SS Information Number and Function The following tables list information number and fu
109. Op 104 jueuinoop sjejeujeJeg pue sbumes ejyeudoudde oj Jajay A uo sj pow pajoajas ui Jeedde peyJeW sjueuunuisu Z JepouJ JEU JO jueuunoop sjejeujejegd pue suwelbelg ejeldoldde ay 01 19J9J lepouJ uoee ui sjuaun sul pue sbunes jo SISI eAniugep JOY SON e JUNOD UC J9MOd snjeis go Silgiuu OHV suue v snjeis OHV suJe e jeJjauao SIGUBIS eu pue ejeq SJUSAI JO UUNN SUJJOJOAEM JO WAN lt l WINS Jajuno9 do bay SJ9JUNOD du Jejunoo du BISA UOIPUOD NID du sjndu snes snes ejey snjejs jJeuonoeJlq IVA M puewep XEN A9Y PM4 JHJVA A9Y PM JUM JOMOd 91119891 pue 9 J0 26j Jamod Jamod 1ueJeddy soDeyoA eseud eseud S soDeyoA eseud Aoeg soDeyoA eseud eseud Aeuwud soeDeyoA eseud Ajeulug sjuauno jeg sjueuino eud S Ney y INCA INCA c Ney Joyo JUNO 18524 ED unesop 2 660 Eu L ney 9polN eyeq 1ne4 cl spol jueuunJjsu Ajuo sjepoui 9 pue p snbiy AJuo sjapou z snbiy uieua2 Ajuo sjoepoui 9 pue z snbiy DO Do LL LI sbumos eouBUSjuIeuw go CO sBunjos eDeJojs jnej pue juaAe UWOJOACM sbumos wulo 04 G 02809 Ol sbuiddeu jndui snjejs sbuiddeu Aejas ndino sbumos es0 981 0 ne sbunjos juaulajo eDejjoA suas sjuauejo euonoaJp sbumos uoij28joud JUALINDIBAO sbumos uongeinbiuos uoajsAs 1891 GAT xx nmuapI aJemyos GO ed Aejoy MBIA 0
110. Optional expansion card fitted only on models AG1 423 and AG1 424 6 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 hom Rear RS485 l comms port comms ports see note 4 see note 5 P300001 Argus 1 Connection Diagrams AG1 4x3 4x4 2 Figure 4 8 Typical Connection for 3 Phase fault and Sensitive Earth fault Protection BUSBARS AG1 43x Notes A BC 1 CT circuits are shown connected to 1A tap 5A rated CTs use the same terminal numbers and are an ordering option 2 CT and earth connections are typical only 3 Application shows use of residual Holmgreen connection for E F circuit Use of separate ring core CT is also possible see note 1 4 Status input 2 and 3 are internally commoned on the negative supply 5 Rear RS485 port is an ordering option On the last relay on the bus connect wire link as shown to include 1200 terminating resistor in circuit Rear RS485 comms port as see note 3 Rear F O comms ports b see note 5 see note 4 A S C B Phase rotation P300001 Argus 1 Connection Diagrams AG1 43x 5A Version Figure 4 9 Typical Connection for 3 Phase fault and Earth fault Protection 1A or 5A Version 2010 Siemens Protection Devices Limited P
111. P F Charact Delay Gn P F Lowset Dir Control Gn il P F Lowset Setting Gn il P F Lowset Delay Gn P F Lowset Setting Gn P F Lowset Delay Gn P F Highset1 Dir Control Gnl l P F Highset1 Setting Gn il P F Highset1 Delay Gn P F Highset1 Setting Gni P F Highset1 Delay Gn P F Highset2 Dir Control Gn il P F Highset2 Setting Gn fil P F Highset2 Delay Gn P F Highset2 Setting Gni P F Highset2 Delay Gn E F Charact Dir Control Gn i E F Charact Setting Gn i E F Charact Gnl l E F Charact Time Mult Gn Bi E F Charact Delay Gn E F Charact Setting Gn E F Charact Gn E F Charact Time Mult Gn E F Charact Delay Gn E F Lowset Dir Control Gn il E F Lowset Setting Gn i E F Lowset Delay Ref Applied value Sec 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Setting name Gni E F Lowset Setting Gn E F Lowset Delay Gn E F Highset1 Dir Control Gn i E F Highset1 Setting Gn i E F Highset1 Delay Gni E F Highset1 Setting Gni E F Highset1 Delay Gn E F Highset2 Dir Control Gn fi E F Highset2 Setting Gn E F Highset2 Delay Gni E F Highset2 Setting Gni E F Highset2 Delay Gn SEF REF Current Setting Gn SEF REF 1st Time Delay Gn SEF REF 2nd Time Delay Gn SEF REF Lowset Delay Gn CB Fail Time Delay1 Gn CB Fail Time Delay2 Gn Relay Reset Delay Gn Backup Alarm SA Gn Backup Trip SA Directional Menu Setting name Gn 2 Out Of 3 Gate Logic Gn P F Charact Angle Gn
112. P F Starter non dir fwd O P F Starter rev P F Charact non HUMO n Off Fwd Rev OO DO OO O O OO OO DO OO O P F Charact rev 90 P F Lowset P F Lowset Inhib instantaneous overcurrent o P F Lowset non dir fwd O P F Lowset rev Dirn Off Fwd 50 P F Highset 1 P F Highset 1 Inhib instantaneous overcurrent O L pe L yt P F Highset 1 non TON P F Highset 1 rev EN pe EN A Dirn Off Fwd 50 P F Highset 2 P F Highset 2 Inhib instantaneous overcurrent Ont O OQ OO OO O OO O OO P F Highset 2 non cn P F Highset 2 rev C1 Q Q Q C O O o t O Dir n Off Fwd 51N E F Charact E F Charact Inhip me delayed overcurrent E E F Starter non dir fwd O E F Starter rev v E F Charact non dif n Offi Fwd E F Charact rev 50N E F Lowset E F Lowset Inhib instantaneous overcurrent e O Q Q O O O O m e O O O E F Lowset non dir fwd E E F Lowset rev Dirn Off Fwd 50N E F Highset 1 E F Highset 1 Inhib instantaneous overcurrent OO OO OO OO O O OO OO O O OO E F Highset 1 non ma E F Highset 1 rev
113. Phase Fault AutoReclose sequence If set to OUT off the relay will perform a one Trip to Lockout sequence applying the first programmed protection trip characteristic unless this is overridden by any applied inhibit controls The first protection trip characteristic in a sequence will typically be set to INST i e Instantaneous Lowset therefore if P F ARC is set to OUT off the relay will not grade with other Protections in the system to isolate a permanent fault However the relay can be re configured to perform one delayed Trip to Lockout by raising P F Protection Trips 1 to 4 The Protection characteristic applied for each of the first four trips in a Sequence can be user set to INST I D I D or 2D 21 etc However the fifth trip in any sequence if allowed by the user will always apply the composite delayed HS1 HS2 characteristic to attempt to retain as much of the system in service as possible The two highset elements can be applied as trip elements with the delayed characteristic to provide a composite 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 reclosed An auto reclose sequence may have more than one Reclose delay After the first and subsequent trips when the Circuit Breaker has opened and all starters and External ARC Start SA are cleared
114. RIP LED stores a fault record and displays the fault indication screen The fault indication screen displays a summary of the fault record giving immediate simple information on what has occurred It displays date DD MM time HH MM SS and the poles which were picked up when the trip signal was issued for example 25 04 17 25 51 TRIPAE This display is held until the TEST RESET button is pressed upon which the LED turns off and any latched output relays are reset The Argus enters Fault Data Display Mode at which point the fault indication screen is replaced with a more detailed scrolling fault data display Fault 1 fault data gt gt gt This shows date and time of fault the active settings group at the point of trip plus for each pole the elements 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 lt IDMTL gt HS1 HS2 IA 12 32xln 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 previous five faults The five displays are numbered from 1 to 5 with fault 1 indicating the most recent record It is necessary to define a fault for these purposes Depending on the application some of the protection outputs may be used for alarm purposes rather than for
115. Ratio E F CT Ratio SEF REF CT Ratio VT Connection VT Primary 0 1 9 for each of 6 digits EE 7 default 11000 Argus 2 type II only VT Secondary 40 0 40 1 70 0 70 5 110 0 150 0 Current Display xin PRIMARY SECONDARY 2010 Siemens Protection Devices Limited P20007 Page 23 of 71 7SG11 Argus Technical Reference Export eng lag VAr Sign 2 2 4 Identifier text is displayed on the title screen of the Argus and is used in communications with ReyDisp to identify the Argus relay Table 2 5 Identifier Setting Sub menu System Config Set Identifier ABCDEFGHIJKLMNOPQRSTUV Up to 16 characters WXYZ1234567890 default ARGUS n e g ARGUS 1 2 2 5 General Alarms General Alarms are user defined text messages displayed on the LCD when mapped status inputs are raised Up to five general alarms can be programmed however this is limited by the number of status inputs on the device Each general alarm can be TENE from one or more status inputs as programmed by the appropriate setting general alarm will also generate an event If it is wished to operate an 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
116. Reyrolle Protection Devices 7SG11 Argus 1 6 Overcurrent Relay Answers for energy SIEMENS 7SG11 Argus 1 6 Contents Contents Technical Manual Chapters 1 User Manual 2 Technical Reference 3 1 Diagrams and Parameters 4 Argus 2 Diagrams and Parameters 5 Argus 4 Diagrams and Parameters 6 Argus 6 Diagrams and Parameters 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 2010 Siemens Protection Devices Limited 7SG11 Argus User Manual 7SG11 Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 2010 02 Document reformat due to rebrand 2006 08 Four
117. SEF REF 2 pole phase fault directional and earth fault directional or 2 pole phase fault directional and earth fault 2 pole phase fault directional and earth fault directional or 2 pole phase fault directional and earth fault 2 pole phase fault and earth fault directional 2 pole phase fault and earth fault directional r A E Hm rmi m n gi rm 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 30 45 for phase faults 0 15 45 65 for earth faults 0 15 45 90 for earth faults 30 45 for phase faults and 0 15 45 65 for earth faults 30 45 for phase faults and 0 15 45 90 for earth faults ur WN E Housing size Case size E6 4U high D Case size E8 4U high E 1 High burden 110V amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 9 binary inputs and 110 V application order resistor box VCE 2512H10064 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition
118. SET will allow the count to be reset see section 2 1 2 2 At all other times the right K function of this key is available for menu navigation 2 1 1 Settings While a setting or other editable value e g in Linesman mode is being displayed on the screen the ENTER key can be pressed to edit the setting value If the Argus is password protected the user will be asked to enter the password as described below If an incorrect password is entered editing will not be permitted While a setting is being edited flashing characters indicate the edit field Pressing the up 4 and down keys will increment and decrement the value of the field within the valid limits of the setting If the up and down keys are held on the rate of scrolling will increase On a multi field setting e g text settings or CT ratios pressing the right gt key will move the edit point to the next field Once editing is complete pressing ENTER stores the new setting value into the non volatile memory The setting change is effective immediately unless any protection element is operating above setting in which case the change becomes effective when no elements are operating If during editing the CANCEL key is pressed the edit mode is exited the setting change is discarded and the original value is redisplayed 2010 Siemens Protection Devices Limited P20006 Page 12 of 37 7SG11 Argus User Manual jueun24eAQ snBuy eunjonas DUSUN 60000 d ES SAINU
119. Sensitive Earth fault mise meu EE 22 Figure 4 3 Typical Connection for 3 Phase fault and Sensitive Earth fault Protection 22 2010 Siemens Protection Devices Limited P20010 Page 3 of 22 7SG11 Argus 4 Diagrams and Parameters Section 1 Variants This document applies to the Argus relays listed in the following MLFB Structure amp table The MLFB Structure references the complete number for each relay e SGlinn nxxnn nxAO where n is a digit and x is a letter The table uses two references for most relays each of which is valid e an Order code of the form AGn nnn and e 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 30V status 48V status 48V status 110V status 220V status Application 1 0 Protection Diagram 9 SI AG4 401 AG1 402 3 phase fault and earth fault Fig 4 1 7 OR GAF431C6 GAF433C GAF434C 3 phase fault and SEF REF or Fig 4 3 9 SI AG4 403 AG4 404 2 phase fault earth fault and SEF REF Fig 4 2 FOR GAF441C GAF443C GAF444C GAF445C 02010 Siemens Protection Devices Limited P20010 Page 4 of 22 7SG11 Argus 4 Diagrams and Parameters Product description Variants Order No Nondire tional O C Relay ith auto re lose 7561140 O 0 DA 0 A A Integrated overcurrent and earth fault relay with multishot autoreclose facilities Number of elements Four pole relay 4 Auxiliary supp
120. agram X X X refer to an Argus AG2 4x5 4x6 The terminals available on other models may be different however the principle remains the same LOAD Figure 4 8 Resultant Applied Voltages and Currents for a Simulated Earth Fault Condition using Load Current 2010 Siemens Protection Devices Limited P20006 Page 34 of 37 7SG11 Argus User Manual Section 5 Testing and Maintenance Argus relays are maintenance free with no user serviceable parts 5 1 Periodic Tests During the life of the Argus it should be checked for operation during the normal maintenance period for the site on which the product is installed It is recommended the following checks tests are carried out 1 Visual inspection of the metering display 2 Operation of output contacts 3 Secondary injection of each element 5 2 Maintenance Failure of the Argus will be indicated by the Protection Healthy LED being off or flashing A message may also be displayed on the LCD In the event of failure Siemens Protection Devices Limited or one of its agents should be contacted see defect report sheet in section O If removal of the Argus from its case is required the procedure described in section 3 1 should be followed 5 3 Troubleshooting Table 5 1 Troubleshooting Guide Relay does not power up Check that the correct auxiliary DC voltage is applied and that the polarity is correct Relay won t accept the password The Password being entered is wrong
121. al 2K7 dropper resistor with 48V status input Auxiliary contacts P300005 Application Diagrams TCS Figure 3 8 1 Engineering Recommendations S 15 H6 Trip Circuit Supervision scheme This scheme provides continuous Trip Circuit Supervision of trip coil with circuit breaker Open or Closed It does not however provide pre closing supervision of the connections and links between the tripping contacts and the circuit breaker 2010 Siemens Protection Devices Limited P20007 Page 61 of 71 7SG11 Argus Technical Reference Circuit breaker Open position nd Trip coil Auxiliary contacts Provides continuous Trip circuit supervision of all wiring and links with Breaker Open or Closed illi Note1 Auxilliary otatus Rs Rd Pazar Rio bome Voltage Voltage CB Open CB Closed CB Closed 110 125 V 48 V 2K7 2K7 20ma 35 ma lt 55ma 110 125 V 110 125 V 4K7 4K7 2 5ma lt 5 ma lt 35 ma 220 250 V 220 250 V 10K 10K lt 2 5ma lt 5ma lt 30 ma Note 1 Worst case current Short circuit applied across Status input with CB Closed and max Auxilliary Voltage Resistors must be at least 18 Watt rated and connected using crimped connections as under worst case they will run hot P300005 Application Diagrams TCS H5 Figure 3 8 2 Engineering Recommendations S 15 H5 Trip Circuit Supervision scheme This scheme provides continuous high security Trip Circuit Supervision of all wiring and links with circuit breaker Open or Closed No
122. all poles i e P F amp E F amp SEF settings Typical settings will be below the protection settings applicable for each pole phase fault setting can normally be above maximum Load current The CBF scheme will then run until all currents fall below the set detector levels If any CBF current setting is set to OFF i e Zero current then once enabled the CBF function will run until all currents are zero Grading time margins and settings will be typically 200ms for CB Fail Time delay 1 and 200ms for CB Fail Time delay 2 If CBF is not required then CBF Time delay 1 and CBF Time delay 2 should be set to OFF i e Infinity 02010 Siemens Protection Devices Limited P20007 Page 31 of 71 7SG11 Argus Technical Reference Any Protection Element 0 VA CB Fail Time Delay 1 Status Input Y E Circuit breaker fail 1 CB Fail 1 O Fault Trigger Output relay e WA gt CB Fail Time Delay 2 P F CBF Current Setting Circuit breaker fail 2 ENABLE E F CBF Current Setting EN SEF CBF Current Setting CB Fail 2 see note 1 Note 1 EN Enable input is edge triggered and level active 21 IF CBF is applied then P F amp E F amp SEF must each have an lcBr current setting IF any CBF Current Setting OFF Zero then output 1 when enabled sef Enable Output is Reset when all currents are OFF Zero or all are below setting P300008 Protection Functions CBF Figure 2 5 1 Functional Diagram Circuit Breaker Fail Table 2 14 Circuit B
123. ance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG2 513 and AG2 514 Rear RS485 comms port Direction of power flow in the forward direction see note 7 Rear F O comms ports 5 Optional expansion card fitted only on models AG2 523 and AG2 524 6 Application shows use of 5 limb star connected VT with neutral voltage derived internally 7 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Phase rotation see note 4 see note 5 Argus 2 Connection Diagrams AG2 5x3to4 2 Figure 4 13 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Star connected VT 2010 Siemens Protection Devices Limited P20009 Page 36 of 37 7SG11 Argus 2 Diagrams and Parameters BUSBARS AG2 5x3 5x4 Notes CT circuits are shown connected to A BC q 1A tap use alternative tap for 5A rated P CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG2 513 and AG2 514 en cn ES Rear RS485 comms port Kn cn n Direction of power flow in the forward direct
124. angeover 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 30 45 for phase faults 0 15 45 65 for earth faults 0 15 45 90 for earth faults 30 45 for phase faults and 0 15 45 65 for earth faults 30 45 for phase faults and 0 15 45 90 for earth faults ur WN kA Housing size Case size E6 4U high D Case size E8 4U high E 1 High burden 110V amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 9 binary inputs and 110 V application order resistor box VCE 2512H10064 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition for 9 binary inputs and 220 V application order two resistor boxes VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20009 Page 8 of 37 7SG11 Argus 2 Diagrams and Parameters Product description Variants Order No Dire tional O C relay 78G112 r gt m gt m Kr Kr Kr Kr Kr gt e Ideal for directional overcurrent and earth fault protection of solid ring systems utilising the fully independent Number of ele
125. angle setting Then for each pole monitor the directional display in the instrument menu and check that indication of forward current FWD is displayed 3 Repeat all of the above with the current connections reversed Indication should now be given of reverse REV current flow 4 To check the direction of the earth fault element on the Argus AG2xx series or the AG2xx 5xx series when connected Ph Ph the 3Vo must then be applied to the residual voltage input To check the direction of the earth fault element on the AG2xx 5xx series of relays when connected Ph N remove the voltage from the phase under test keeping the voltage healthy on the other two phases Where only single phase equipment is available then reverse voltage must be applied to the phase under test For all of the above tests inject residual current at the MTA into the earth fault input to confirm correct directional 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 directional operate zone has two boundaries of operation at leading and lagging boundaries of with respect to V To find the boundaries of operation for a part
126. ble 4 16 Table 4 17 Table 4 18 Table 5 1 Wire nT sa ERE ANCHO oido A O cias 17 IDMTL Timing Characteristic Time in Seconds cccccoccccnccoccnnonoconcnnnconononcnnnnnncnnonrnnnnnnnrnnonanennnnos 20 Connections for Directional Polar A edle perite e dades el assu euet ouais 22 Limits of Operate Pick up Relay Angle Boundaries sse eee 23 PICK UP DIOD O d DT deti ebixvod acit dre to ten tidaidiida 28 Timing Characteristic Result eee ee eee 28 Reu seb SUITS a etree Oa ae at arpa ta Nae osa E 28 Higniset T seting TESTS ceux von prece t tede vented sse Eb ccc epo a Eae EU Heres e Eua ctu Fax en as bra 29 HighseEZ settinigiTeSullS escandalos il 29 POS CUMING SS UN asso uq a ED PCS E EDO period 29 Hignset TUNING FesuliS iaceo Pince eines e tag iat Me qoe E Incun eI a NC Cap dre qoe Fa He Po ER RR I MA KU Cada e Pad LEUR 29 HigriseE2 TIMING TesbllIs pistas etc erns gun tatcua todo PREMO dA poca pev da ois E Etapa vds a dd v lio satu ba 29 Pick up Dropsolr Results Tor EF REE e rci be oett enge dte Lode uos eL 30 SBEETISEF liming RESUS taaan sao teta bate biu Esas ia 30 Pick up Drop off Results for CBF Level Detector see 30 Circuit Breaker Fail Timing Results onte calida 30 Directional Boundaries of Operation ee 31 Auto reclose Sequences and SettingS cccococoncconnococonononcnconononaconononononnnnonononrnnononnncnnanannnnnes 31 Primary IJ SCHONSIRGSUILS sd rra litre Dale e er eas ue Du aa Da Moda E Di 32 TOU
127. ble to be detected These potential breaks would not be detected when the device mode is set to Light Off This must be set to OFF when connected to the RS485 electrical connection 4 3 10 Data Echo Table 4 2 Communications Settings Sub menu Communications Interface Setting name Range bold default Units Notes Comms Protocol IEC 60870 5 103 MODBUS RTU Comms Baud Rate 75 110 150 300 600 1200 2400 4800 9600 19200 Comms Parity NONE EVEN Relay Address 0 1 254 Line Idle LIGHT ON LIGHT OFF Data Echo OFF ON Sigma 4 SG4 103 Rx gt Laptop computer P300007 Communications vsd Sigma 4 remote Figure 4 3 1 Communication to Argus Relay using Sigma 4 Local Connection 2010 Siemens Protection Devices Limited P20007 Page 69 of 71 7SG11 Argus Technical Reference Control System lt Auxiliary supply Laptop computer master link Rx TX up to 29 slaves relays Rx Tx P300007 Communications vsd Sigma 1 Figure 4 3 2 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 1 and Fibre optic Star Network Laptop computer P300007 Communications vsd RS485 RS232 Figure 4 3 3 Communication to Argus Relay using RS485 RS232 convert
128. block All inputs and outputs except for the serial communications interface are made through these connectors 1 3 Functionality 1 3 1 Protection Argus provides comprehensive overcurrent protection with programmable input and output matrix In addition 8 setting groups enable a flexible approach to protection settings Up to four current measuring inputs are available in the Argus relays and these may be phase fault overcurrent earth fault overcurrent or SEF REF depending on the model 2010 Siemens Protection Devices Limited P20006 Page 6 of 37 7SG11 Argus User Manual 1 3 1 1 Phase fault and Earth fault Overcurrent Phase fault and earth fault inputs each have four independent overcurrent elements Each has a current setting and timing characteristic as illustrated in Figure 1 1 The principal overcurrent element is selectable between IDMTL inverse definite minimum time lag and DTL definite time lag characteristics Four IDMTL curves are available namely normal inverse NI very inverse VI extremely inverse El and long time inverse LTI The IDMTL algorithms operate correctly for developing faults where current varies with time Two independent highsets and an independent lowset are included with shaped instantaneous characteristics and DTL The instantaneous outputs are designed for transient free operation where high values of system X R are experienced IDMTL current setting time multiplier highset 1 current s
129. ce IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 0 15 45 65 for earth faults 2 0 15 45 90 for earth faults 3 Housing size Case size E4 4U high C 1 High burden 110V amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 1 binary input and 110 V application order resistor box VCE 2512H10066 in addition for 1 binary input and 220 V application order resistor box VCE 2512H10068 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20009 Page 6 of 37 7SG11 Argus 2 Diagrams and Parameters Product description Variants Order No Dire tional O C relay 78 G112C E A A Kr Kr Kr Kr Kr Kr gt e Ideal for directional overcurrent and earth fault protection of solid ring systems utilising the fully independent Number of elements bi directional feature Three pole relay 3 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input Qn RuJN FO Type of elements 3 pole phase fault directional 1 E 2 pole phase fault directional and sensitive restricted earth fault
130. ch status input Latched inputs default a Argus 4 and Argus 6 only Gn Status 1 P U Delay Gn Status 1 D O Delay Default settings of 0 02 for pick Gn Status 2 P U Delay 0 00 0 01 0 02 2 0 2 1 20 up and 0 01 for drop off are Gn Status 2 D O Delay 21 applied to give AC rejection 300 360 3600 3900 14400d n is the number of status inputs Gn Status n P U Delay present Gn Status n D O Delay Gn Reset Flag amp Outputs 1 for each status input default 2 12 Communications All settings and information relating to communications with the Argus are given in Section 4 Communication Interface 2 13 Data Storage Argus relays store three types of data to assist the user in fault evaluation i e events waveforms and faults 2 13 1 Event Storage When an event occurs a date and time tagged entry is added to the storage buffer Some of the events that can be stored are indicated in the function diagrams throughout this functional description section Up to 500 events 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 Parameters document 2 13 2 Fault Data Record A Fault Data Record is a ti
131. character backlit liquid crystal display LCD is used to present settings instruments and fault data in a textual format The display backlighting is turned off to conserve power if no pushbuttons are pressed for 5 minutes After an hour the whole display is de activated except in the case of the instruments which remain visible permanently Protection Healthy LED This green LED indicates that DC volts have been applied to the Argus and that the relay is operating correctly If a permanent fault is detected by the internal watchdog then this LED will continuously flash Starter LED This self resetting yellow LED indicates that any pole is measuring current above the IDMTL DTL current setting Trip LED This latching red LED indicates that a trip as defined by customer setting has occurred Such a trip may have been issued by any of the protection functions The user will be given more detailed information concerning the trip from the LCD screen After being energised the LED can be reset by pressing the TEST RESET key or by energising a status input which has been programmed to reset latched relays and the trip LED CB Open LED Argus 4 and Argus 6 only This green LED indicates that the circuit breaker is open CB Closed LED Argus 4 and Argus 6 only This red LED indicates that the circuit breaker is closed Keypad Five keys are provided to control the functions of the Argus by moving around th
132. ction Gn CT Failure Setting OFF 0 05 0 1 1 00 Gn CT Failure Delay OFF 0 00 0 01 20 00 20 5 de 100 101 300 s S Sub menu O P Relay Config Gn CT Failure _ 1 for each output contact default 2 5 4 Trip Circuit Supervision for details see sections 2 10 and 3 8 2 6 Cold Load Protection Argus 4 and Argus 6 only A cold load protection function is provided to cater for closing onto the type of load that after being de energised for some time on energisation takes a high level of current for an extended period time This cold load group s overcurrent settings will normally be set higher and the time characteristics will be set slower than the normally active group s settings The relay will switch to the nominated cold load group n and then when the circuit breaker is closed will apply that group s overcurrent and auto reclose settings until the user set highset 2 in the set cold load group operates as an under current element This element s setting should be set 5 or more below the normally active group s phase fault overcurrent element settings This prevents the relay from changing back from the cold load group to the normally active group before the cold load inrush current has fallen below the normally active group s P F starter settings so that when the relay reverts to the normally active group settings the relay does not then operate and give a trip output The cold load group s phase fault highs
133. cuit Breaker When a Local Close amp Reclaim command input edge triggered is raised the relay executes a LOSE IN XX s setting default OFF to define the delay between the Command initiation being RE re D CLOSE pulse being issued by the relay thus allowing time for the operator to move away from the vicinity of the Circuit Breaker before it operates to close and make the circuit live When the CB is open and a CLOSE amp RECLAIM command is raised the relay jumps to the ARC Status screen in which is displayed the count down timer CLOSE IN xx s where the time xx s is counted down from the User set Manual Close Delay value On reaching the count of zero the CLOSE pulse is issued and the screen then shows the RECLAIM timer counting down after which RECLOSE SUCCESS is displayed Note the Manual Close delay starts when the mapped Status input is raised clearing it and raising it again restarts the timer each time Application Note This function allows the normal panel mounted Circuit Breaker Control switch to initiate via the relay the delayed closing of the Circuit breaker thus removing complexity from the implementation of this Health and Safety feature If the CB is open the relay enables line check then issues a defined close pulse and enters the reclaim delay If 2010 Siemens Protection Devices Limited P20007 Page 43 of 71 7SG11 Argus Technical Reference the CB closes onto a fault or a fault occurs during t
134. d 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 However the best viewing position is at eye level and this is particularly important when using the built in instrumentation features The LCD contrast will normally be correct for all positions and environments however it can be adjusted if required using the adjustment screw mounted through the fascia to the upper right of the LCD The Argus relay should be mounted on the circuit breaker or panel to allow the operator the best access to the functions 3 3 Relay Dimensions The following drawings are available which give panel cut out and mounting details Refer to the appropriate Diagrams and Parameters part of the documentation for a cross reference of case sizes and models e 2995X10004 Overall Dimensions and Panel Drilling for Epsilon E4 Case 2995X10006 Overall Dimensions and Panel Drilling for Epsilon E6 Case 2995X10008 Overall Dimensions and Panel Drilling for Epsilon E8 Case 3 4 Wiring The Argus should be wired according to the scheme requirements with reference to the appropriate wiring diagram Refer to the appropriate Diagrams and Parameters part of the documentation for a cross reference of wiring diagrams and models 3 4 1 Communications Fibre optic ST BFOC 2 5 bayonet connectors 2 per Argus Glass fibre is recommended for all but the shortest dista
135. ded on the event record display enables the user to make time difference comparisons between two events This allows for example accurate measurement of the Reclose delay Dead time or the Reclaim delay without external equipment The following information can be easily measured from a single Sequence event record Instantaneous Protection element operate times Circuit Breaker first Trip time Protection Starter element reset time Reclose Dead Time delay Circuit Breaker Close time Delayed Protection operate times Subsequent Circuit Breaker Trip and Close times Subsequent Reclose delays Reclaim delay Overall sequence time Status Interlock timing Also the Waveform Record display for each trip enables time measurements to be made between the analogue waveforms and the digital binary traces of the Status inputs and output relays Measurement of the relative timing of the a c current waveforms and the Circuit Breaker Status contacts provides valuable data on the condition of the Circuit Breaker operate times In addition the Instruments provided by the Argus can be continuously monitored via Reydisp during a test sequence providing information on the state of the Argus and Circuit Breaker during a test sequence 2010 Siemens Protection Devices Limited P20006 Page 24 of 37 7SG11 Argus User Manual The sequence provided by the Argus in response to a permanent fault should be checked to ensure that the programmed sequence is as g
136. deinseelesescensinwideusencciaie d Content R ee eee 5 ISU OF FIQUIOS ct E ecessserncetend coco vantne odia 5 Section 1 VaFIants 092055 o ea ae RI LIED LI DOLI a 6 DEGCUOINZ SENNO aia 11 Section 3 IEC 60870 5 103 amp Modbus RTU Definitions 1 eeee eere rere 16 3 1 IEG 6087 0 5 103 Defin MOMS sssieaiezcassoieas 16 3 2 Modbus RTU DG TIA ONS isis seis cece ia 23 Section 4 Application Diagrams 1 cesse 29 List of Figures Figure 2 1 Status Input and Output Relay Programming Marix sees eee eee eee eee 15 Figure 4 1 Typical Connection for Earth fault Protection sees eee 29 Figure 4 2 Typical Connection for Sensitive Earth fault Protection sese 30 Figure 4 3 Typical Connection for 3 Phase fault Protection esse eee eee eee 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 Protection 32 Figure 4 7 Typical Connection for 2 Phase fault Earth fault and Sensitive Earth fault misse pP PTT cpm EIE 32 Figure 4 8 Typical Connection for 3 Phase fault and Sensitive Earth fault Protection 33 Figure 4 9 Typical Connection for 3 Phase fault and
137. ditional rates are provided for local or modem communications 4 2 10 Comms Parity IEC 60870 5 103 defines transmission as using Even parity however in some instances an alternative may be match that of the communicating device e g PC 4 2 11 Relay Address 4 2 12 Line Idle The IEC60870 5 103 protocol defines a line idle state of Light On Binary 0 is represented by light on binary 1 is represented by light off and when a device is not communicating it idles with the light on sending 0 This allows detection of a broken fibre condition When the line is idling a binary 0 should be received constantly If binary 1 is received constantly then no light is being received hence the fibre may be broken communicating device connected to the relay 2010 Siemens Protection Devices Limited P20007 Page 65 of 71 7SG11 Argus Technical Reference 4 2 13 Data Echo Argus relays may be connected in a ring e g as shown in Fig 4 3 The optical ring architecture requires data to be passed from one relay to the next therefore when using this method all relays in the ring must have the For Argus with individual connections e g Figure 1 5 1Error Reference source not found or connected in a star topology e g Figure 4 the setting should be set to Off Table 4 1 Communications Settings Sub menu Communications Interface Setting name Range bold default Units Notes Comms Protocol IEC 60870 5
138. e B overcurrent and Vca will block phase C overcurrent 02010 Siemens Protection Devices Limited P20007 Page 36 of 71 7SG11 Argus Technical Reference V Operation V Setting V Hysteresis V Inhibit V starter Event V Starter Va Vab starter Vc Vca starter Vc Vca Block P F A V trip Block P F B Block P F C Voltage Block V Block Alarm P300008 Protection Functions V Figure 2 8 1 Functional Diagram Undervoltage Overvoltage Element Table 2 18 Voltage Protection Settings Sub menu ro Gn V Setting Ph N Setting indicates whether phase Gn V Setting Ph Ph B 0 5 5 80 0 200 0 phase or E is in use Gn V Delay PT 0 01 20 20 5 100 0 101 0 600 0 Gn V Hysteresis Gn V Block Threshold OFF 1 2 5 100 Gn V O P Phases Any One All Sub menu O P Relay Config a y z _ 1 for each output contact nV trip default Gn V Block Alarm Sub menu Status Config Gn V Inhibit _ 1 for each status input default 2 9 Auto Reclose Argus 4 and Argus 6 only Approximately 90 of all overhead line faults are transient non damage arcing Phase s to Earth faults induced by lightning or due to other transient initiation Use of a sequence of Instantaneous Lowset trips followed by Delayed trips e g 21 1D with line Dead Times Reclose Delays ensures that such transient faults are cleared quickly before consequential permanent damage to the plant can occur and hence after the li
139. e Clock The date and time can be programmed and then maintained by the internal real time clock The clock is also maintained for 2 3 week while the relay is de energised Additionally in order to maintain synchronism within a substation all Argus relays can be synchronised to the nearest second or minute using a mapped status input or via the IEC 60870 5 103 protocol Time Synchronising Frame minute or second when the status input is activated Table 2 8 Real Time Clock Settings Sub menu System Config Setting name Range bold default Notes Calendar Set Date DD MM YY 01 01 00 D ID Clock Set Time When user presses ENTER after HH MM SS 00 00 00 editing seconds are zeroed and clock begins counting Clock Sync From Status Minutes Seconds Sub menu Status Config Setting name Range bold default Notes Gn Clock Sync _ 1 for each status input Default not mapped to any default 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 detail in the User Manual document section 1 3 4 This function enables the user to set the relay to automatically return to displaying ammeters and other instruments such as ARC Status or Counters Therefore essential data is presented to visiting engineers without
140. e Drop off level Repeat this test for each pole Check that all measured Pick up current levels are within 105 4 of the applied setting Check that the Drop off levels are 29596 of the measured Pick up value 2010 Siemens Protection Devices Limited P20006 Page 19 of 37 7SG11 Argus User Manual Note Depending upon the applied settings a TRIP could occur if the current is on for longer than the operating time This may be undesirable while measuring Pick up and Drop off levels The Fault Trigger setting in the data storage menu can be used to disable tripping indication temporarily during this test also the Low and High Set elements may need to be temporarily turned OFF in order to prevent unwanted instantaneous operations Timing This test checks the accuracy of the main time delay characteristic IDMTL DTL Select the current setting characteristic type and time multiplier setting as required Then inject current at multiples of the setting The correct output contact must be programmed for the phase fault and earth fault elements A time interval meter must be connected to the correct terminals The timer should be started by the source and stopped by the trip contacts Each pole should be tested A secondary injection timing test circuit is illustrated in Figure 4 3 Table 4 1 shows theoretical values for each characteristic curve with a time multiplier of 1 0 Record the actual results in Table 4 5 and check that the m
141. e achieved either locally at the fascia remotely via a communications interface command or by energisation of a status input On models with a voltage element this can also be used to change settings group For setting group change by status input the Settings Group Select setting is used to configure any one or more of the status inputs to select a settings group 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 settings group 5 Self Monitoring The Argus incorporates a number of self monitoring features listed below each of which initiates a reset sequence that can be used to generate an alarm output In addition the Protection Healthy LED gives visual indication e Power supply watchdog e Microprocessor watchdog e Program memory test using CRC Any failure is detected with sufficient time warning so that the microprocessor can be shut down in a safe and controlled manner Password Feature The programmable password feature enables the user to enter a 4 character alpha numeric code As soon as the user attempts to change a setting the password is requested before any setting a
142. e combined to give a composite curve to correctly co ordinate The use of an instantaneous element is common on transformer protection to give fast clearance of terminal faults In some instances such as a feeder that is cabled from a substation and then becomes an overhead line the highset can be selected to operate only for cable faults and can be utilised to block auto reclosing Argus relays can be supplied with sensitive earth fault or restricted earth fault functions Refer to the VA TECH Reyrolle ACP Application Guide on REF for details 3 1 1 Reset Delay The increasing use of plastic insulated cables both conventionally buried and aerial bundled conductor have given rise to the number of flashing intermittent faults on distribution systems At the fault position the plastic melts and temporarily reseals the faulty cable for a short time after which the insulation fails again The same phenomenon has occurred in compound filled joint boxes where an internal flashover temporarily reseals 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 solid permanent fault To overcome this the Argus rela
143. e giving fast fault clearance This example shows the use of a starter output to block a Highset protection function for a circuit breaker nearer to the source Type tests have shown that with a time delay as low as 40ms on the upstream Highset function that grading is ensured preventing the upstream relay instigating a trip For security reasons a minimum time delay of 50ms is recommended typically 100ms can be used The Blocking Status input used to inhibit the HighSet function should have 10ms Pick up and Zero Drop off delay settings to give fast operation but a c pick up rejection The example shown in Figure 3 4 1 also proposes the use of IDMTL functions grading in the normal manner as back up protection for a down stream circuit e g due to failure of the circuit breaker to clear a fault The combination of blocked lowset or Highset function and IDMTL back up ensures fast operation for a circuit fault and provided the IDMTL grading has been correctly calculated and set will also provide back up protection 2010 Siemens Protection Devices Limited P20007 Page 56 of 71 7SG11 Argus Technical Reference Busbar Zone Protection On a radial substation with a defined incomer a simple logic busbar protection can be applied if each circuit is equipped with an Argus relay Figure 3 4 2 As above the Instantaneous Lowset or Highset elements in all relays can be set to the same setting with the Incomers having 50ms grading delays set For a fa
144. e menu display They are labelled 4 v ENTER CANCEL and gt The K 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 Voltage Inputs Current Inputs Two types of current input are incorporated within the Argus range One type of input is used for phase fault and earth fault protection while the other is used for sensitive earth fault and restricted earth fault protection The current inputs can be configured for operation with either 1A or 5A transformers The appropriate connections are required on the terminal blocks and the CT rating must be set as required Voltage Inputs Argus 2 and Argus 6 only Voltage inputs are used for setting the direction of the overcurrent elements and up to 4 voltage inputs are provided In most models voltage inputs for the phase voltages must be connected phase phase while a separate open delta VT must provide the neutral voltage In some models however the option is given to connect 3 voltage inputs in a star configuration Each voltage input is capable of being connected to VTs with a nominal 63 5V or 110V secondary voltage 1 2 5 Status Inputs and Output Relays Four configurations of digital I O are available e 1 status input 7 output relays 3 changeover 4 normally open e 3 status inputs 5 o
145. e operate time of the output relay 4 2 6 Output Relays A minimum of five output relays is provided Three of these have change over contacts the remainder have normally open contacts Each contact can be 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 signal as this is permanently energised the mapped relay will be held energised and normally open contacts will be closed Remember to deselect the output relays from the Protection Healthy signal following the test 4 2 Primary Injection Tests Primary injection tests are essential to check the ratio and polarity of the transformers as well as the secondary wiring 4 2 7 1 Primary Current Tests Use the circuit shown in Figure 4 6 to check the current transformer ratio and the C T connections for phase to earth fault current Inject a current of sufficient magnitude for the Argus relay ammeters to display These levels should be compared with the ammeters connected in series with the Argus The secondary current is Primary current CT ratio Is Use the circuit shown in Figure 4 7 to check the current transformer ratio a
146. e revision histories updated 2004 07 Second issue Power On alarm added 2002 12 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 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Software Release History The software listed below is used in one of more types Argus relay The list of software revisions applying to Argus 6 up to and including this document issue is Mar 2005 2716H80005 R5 Mods to reclose blocked Mod to Checking Settings screen at switch on Jul 2003 2716H80005 R3 Function added Status input Inversion Minor change Latched input 8 9 display corrected Mar 2003 2716H80005 R2 Function added Power On count alarm Minor change
147. e supplied for 110 125 V or 220 250 V working external dropper resistors will be supplied listed in the table below 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 96 6 0 W Performance operation Var 110 250 V 5 mA Typical response time 5 ms 10ms for ARGUS 2 type Il Typical response time when programmed to Jes is energise an output relay contact Recommended Minimum pulse duration 40 ms with setting of 20ms PU delay for a c rejection Each status input has associated timers which can be programmed to give time delayed pick up and time delayed drop off These timers have default settings of 20ms thus providing rejection and immunity to an AC input signal Status inputs will not respond to the following e 250V RMS 50 60Hz applied for two seconds through a 0 1uF capacitor e Discharge of a 10uF capacitor charged to maximum DC auxiliary supply voltage 2010 Siemens Protection Devices Limited P20007 Page 8 of 71 7SG11 Argus Technical Reference The status inputs with nominal voltage of 30 V to 54 V meet the requirements of ESI 48 4 ESI 1 Low Burden Status Inputs Optionally low burden status inputs are available directly rated for 110 125Vd c or 220 250Vd c without dropper resistors These inputs do not meet the ESI 48 4 ESI 1 req
148. e voltage is applied across two inputs with the third in reverse and a single phase current at characteristic angle is injected through all three poles in series This applies one pole FWD and the other two poles REV reverse the current direction to give two poles FWD and one pole REV Further tests may be required to check that the directional control settings have been correctly applied where these are complex Similarly if different threshold and delay settings have been applied for forward and reverse operation then these should be tested Such additional tests should be specified according to the particular requirements 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 cables This will greatly facilitate the testing and documentation of the results of the various tests applied to the Scheme Reydisp Evolution can display the complete chronological event record generated by a full multi shot Auto Reclose sequence for post test analysis it is often difficult on site to keep track of protection and circuit breaker operations during a sequence test The analysis function provi
149. each trip circuit fail status input to a changeover contact an alarm output can also be generated from the normally closed contact A suitable 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 Gn Trip Circuit Fail _ 1 for each status input default 2 11 Status inputs and Relay Outputs The status inputs and relay outputs are all user programmable The settings related to each function are described in the relevant section of this document The relevant Diagrams and Parameters document for each Argus series provides matrix diagrams that allow user mappings of the status inputs and output relays to be recorded The operation of the status inputs and output relays is described below and shown in Figure 2 11 1 and Figure 2 11 2 respectively Hand Reset Output Relays Relay outputs are self resetting by default however each relay output can be individually set to hand reset In this case the relay latches on operation and can be released by using the TEST RESET key on the relay fascia Pulsed Output Relays Argus 4 and Argus 6 only for the period that any mapped output signal is activated a pulsed output relay will be energised for the minimum energise time see Table 2 24 and will then be de energised It will remain de energised until the output signal is
150. eaker Fail Protection The Argus relay incorporates a two stage circuit breaker fail feature If a designated trip relay operates and the circuit breaker fails to open the protection algorithm continues to run for as long as current above the starter level or CBF level detector setting continues to flow and a continuous trip output is given This combination of conditions is programmed to start a definite time lag feature designated CB Fail 1 This function can be programmed to energise an output relay when the C B fail time delay is completed At the same time operation of this timer starts a second time lag feature designated CB Fail 2 and if the trip outputs already initiated do not stop the current flow through the relay another relay can be programmed through the output matrix to trip a further breaker e g a bus section circuit breaker Schemes These timers support schemes as follows e Single stage CB fail where all adjacent upstream infeeds are tripped after DTL1 on detection of a CB fail occurrence e Two stage CB fail where stage 1 DTL outputs attempt to re trip the faulted CB in stage 1 time delay and when this fails the stage 2 time delayed output trips the relevant adjacent infeeds The circuit breaker fail feature can also be used to implement a multi stage tripping scheme A typical example of this is illustrated in Figure 3 4 2 Setting Calculation The time delay setting applied to the CB fail protection must be
151. easured times lie within 5 or 30ms of nominal time Table 4 1 IDMTL Timing Characteristic Time in Seconds Curve 2x5 xs 4 2 3 2 Lowset and Highsets Phase Fault poles can have up to two highsets and one lowset also the Earth fault can have up to two highsets and one lowset The following tests should be applied to each element in the scheme The low high set under test should be programmed to operate an output contact which can then be monitored to detect operation of the element Argus 2 and Argus 6 only If the Argus is to be employed for directional 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 Table 4 7 or Table 4 8 and confirm that in each case it occurs within 5 of the applied setting For high levels of current the thermal limit of the Argus must not be exceeded Refer to the performance specification for the Argus which defines the thermal limits Manual testing runs the risk of exceeding the thermal limit When manually testing a high setting it is not considered necessary to establish the exact pick up level and the following procedure is recommended to ensure
152. ec GnSA Reclose DTL 3 sec sec A EA GnSA Reclose DTL 4 GnSA Shots To Lockout GnSA Trips To Block Gn Reclaim Time Gn Close Pulse Manual Close Delay Gn LO Recovery Cold Load Enable Cold Load Reset Output Relay Configuration Menu See also Figure 2 1 on page 13 for the programming matrix For non directional settings use the Gnif settings ignoring the forward jg notation Setting name Ref Applied value Gn Prot Healthy ar Gn fi P F Starter aa Gn P F Starter as o Gn il P F Charact paro Gnl P F Charact aarp Gn il P F Lowset Rag Gn P F Lowset acl Gn fil P F Highset1 COEM Gni P F Highset1 Sa Gn fil P F Highset2 ael o Gn P F Highset2 RSS Gn i E F Starter EI Gn E F Starter ea Gn fi E F Charact as P20011 Page 8 of 22 7SG11 Argus 6 Diagrams and Parameters Setting name Ref Applied value Gn Lockout Alarm Sanl Gn Close Pulse a9 5 Gn AUX Close zsif Gn ARC Active zsa Setting name Ref Applied value Gn E F Charact S Gnl l E F Lowset Gn E F Lowset Gnl l E F Highset1 Gni E F Highset1 Gn i E F Highset2 Gni E F Highset2 Gn SA Blocked zs Gn SA Alarm zsa Min O P Energise Time Status Configuration Menu Gn SEF REF Delay1 Gn SEF REF Delay2 Gn SEF REF Lowset Gn P F FWD Block Gn P F REV Block Gn E F FWD Block Gn E F REV Block Gn Status 1 Gn Status 2 anf Gn Status 3 oe Gn Status 4 Gn Status 5 Gn Status 6 Gn Status 7 Gn Status 8 Gn Status 9 Gn CB Fail 1
153. ection 5 Testing and Maintenance see eee eee sii A 35 Dil Penodi TCS cte 35 5 2 nara e t bi wars 35 5 3 A OLDICSMOOUIO eee m 35 5 4 DETER he esee octo rep tibt ted atem le n ease E 37 02010 Siemens Protection Devices Limited P20006 Page 2 of 37 7SG11 Argus User Manual List of Figures Figure 1 1 Figure 2 1 Figure 4 1 Figure 4 2 Figure 4 3 Figure 4 4 Figure 4 5 Figure 4 6 Figure 4 7 Figure 4 8 Overcurrent Gharacterisll6S oo boda c bk Ui ld lo RU 7 Menu Structure for Argus 1 2 4 and 6 RelayS coooccccccnccccnnccccnccnnnncnnnnnnncnonnnnnnnnnnconnnonnnnonanonnnons 13 Directional Earth Fault Boundary System Angles sese 23 Directional Phase Fault Boundary System Angles ee 23 Secondary Injection Test Circuit eee eee 33 Direcional Test Circula a cas 33 Two out of three Directional Test CirCult coooccooncconnconncconnconnconcnconnnoncnoncnonnnnonrnnnrnconnnonenononcnnnnnnns 33 Phase to Earth Primary Injection Test Circuit eee eee eee 33 Phase to Phase Primary Injection Test Circuit see eee eee eee 33 Resultant Applied Voltages and Currents for a Simulated Earth Fault Condition using Load i em EET 34 List of Tables Table 3 1 Table 4 1 Table 4 2 Table 4 3 Table 4 4 Table 4 5 Table 4 6 Table 4 7 Table 4 8 Table 4 9 Table 4 10 Table 4 11 Table 4 12 Table 4 13 Table 4 14 Table 4 15 Ta
154. ection Diagrams AG1 3x1 3x2 1 Figure 4 3 Typical Connection for 3 Phase fault Protection 2010 Siemens Protection Devices Limited P20008 Page 30 of 33 7SG11 Argus 1 Diagrams and Parameters BUSBARS AG1 3x1 3x2 Notes 1 CT circuits are shown ABC S connected to 1A inputs use 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Diagram shows use of residual Holmgreen connection for E F circuit Alternatively use a ring core CT 4 Optional expansion card fitted only on models AG1 311 and AG1 312 5 Optional expansion card fitted only on models AG1 321 and AG1 322 6 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 Rear RS485 comms port Rear F O comms ports see note 4 see note 5 P300001 Argus 1 Connection Diagrams AG1 3x1 3x2 2 Figure 4 4 Typical Connection for 2 Phase fault and Earth fault Protection BUSBARS AG1 3x3 3x4 Notes CT circuits are shown ABC S connected to 1A inputs use d 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Diagram shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG1 313 and AG1 314 5 Opti
155. ection for 2 Directional Phase fault and Sensitive Earth fault Protection BUSBARS AG2 3x5 3x6 ABC Direction of power flow in the forward direction Phase rotation Rear C O comms ports see note 4 i S2 2rt q ss Curt 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 separate ring core CT is also possible 4 Optional expansion card fitted only on models AG2 315 and AG2 316 5 Optional expansion card fitted only on models AG2 325 and AG2 326 6 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Rear R5485 comms port D see note 6 7233 437 S4 CER 432 bo t sort 443 S8 S i sr Def BR Cv see note 5 P300002 Argus 2 Connection Diagrams AG2 3x5 3x6 Figure 4 5 Typical Connection for 2 Directional P F and Directional E F Protection 2010 Siemens Protection Devices Limited P20009 Page 32 of 37 7SG11 Argus 2 Diagrams and Parameters Notes CT circuits are shown connected to BUSBARS AG2 3x7 3x8 ER use alternative tap for 5A rated A BC q 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
156. ed milliseconds or over 1 second before a trip occurs Following the trip output it is likely that the current will continue to be present for one to two hundred milliseconds before the circuit breaker interrupts the current 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 waveform when applying this setting 3 10 4 ReyDisp IEC 60870 5 103 The Reydisp Evolution software allows the recorded data events fault records waveform records to be uploaded from the Argus to a PC for analysis When saving data it is important to save the applied settings at the time of trip in order to correctly interpret the data Get All Data The ReyDisp Get All Data command allows all data to be easily uploaded from the Argus If this command is selected ReyDisp will ask the user to specify a directory name which will be created if it does not exist and will then upload all events all 5 fault records all 5 waveform records and all settings from all 8 settings groups This ensures that all necessary data is available for post fault analysis 2010 Siemens Protection Devices Limited P20007 Page 63 of 71 7SG11 Argus Technical Reference Section 4 Communication Interface 4 1 Introduction Argus relays can communicate with controlling systems using either 1EC60870 5 103 or MODBUS communications protocols The protocol is selectable in the
157. educe the current setting to a level below 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 factor is very low leading or lagging difficulties may be encountered For example a very low leading power factor with power in the forward direction may cause a quadrature connected protection to restrain When the test is complete all connections must be restored to normal If any settings have been changed in proving the direction restore them to the original settings and repeat secondary injection testing as considered necessary Earth Directional Element If the application includes a directional earth element polarised in the normal fashion from the open delta winding of a voltage transformer then the following procedure should be followed Disconnect the A phase primary input to the voltage transformer Where primary fuses exist this can be done by removing the A phase fuse Short circuit the A phase main secondary winding This should be done on the load side of the V T secondary circuit protection eg fuse or miniature circuit breaker MCB Short circuit and disconnect the current transform
158. eference current Based on the above considerations the minimum setting of a relay in a resistance earthed power system is 6 to 9 times the charging current per phase 3 4 Blocking Schemes Where substations in a radial network are physically close such as on the MV system in a power station and pilot cables can be economically run between switchboards the times set on a particular relay and an upstream relay can be made identical This reduces the fault clearance time by eliminating the grading margin delay To achieve this the Overcurrent starter contact of the downstream relay is connected via pilot wires to Block inhibit the upstream relay Grading is ensured by this blocking feature provided that the upstream tripping time is set to be longer with margin than the time taken for the downstream blocking signal input to be raised Figure 3 4 1 illustrates the scheme Radial System Power Flow Overcurrent Overcurrent HS1 Protection HS1 Protection Overcurrent 50ms Relay 50ms Relay Protection DTL Block DTL Block Relay Starter Starter Metallic connection required between relaying points Starter output of downstream relay arranged to block Inhibit the 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 oe aoe IA d Figure 3 4 1 Blocking schem
159. en e g if the main characteristic is set to DTL rather than an IDMT characteristic the time multiplier setting will be hidden and replaced by a time delay setting Some settings in the tables show text in square brackets e g SEF REF Current Setting This indicates different text 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 table with applied settings Setting name Ref Applied value SET Alarm 3 a25 SET Alarm 4 a25 l SET Alarm 5 pos o Calendar Set Date 227 System Config Menu Setting name Ref Applied value Active Settings Group R o Settings Group Edit View Cold Load Pickup Group Copy Group Power System Frequency Set Pole B Type Earth Fault Mode Select P F Rating In E F Rating In SEF REF Rating In P F CT Ratio E F CT Ratio SEF REF CT Ratio Current Display Set Identifier SET Alarm 1 SET Alarm 2 2010 Siemens Protection Devices Limited P20010 Page 6 of 22 Clock Set Time 22 MEME Clock Sync From Status E ooo Default Screen Time a289 Change Password a29 Linesman Display pis o Protection Menu Setting name Gn P F H
160. energisation of the input Output Relays Outputs are user programmable to operate from any or all of the protection characteristics In addition they can be programmed to generate outputs from the 1 summation alarm the 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 appropriate communications command or electrically via a status input A trip test feature is provided to operate the output contacts 1 2 6 Auxiliary Supply A d c voltage of the appropriate level must be supplied onto the correct terminals on the rear of the case 1 2 7 Communications A pair of fibre optic ST BFOC 2 5 bayonet connectors optimised for glass fibre are fitted to the rear of the case one transmit and one receive These are used as the standard interface for all communications with the Argus An alternative RS485 option is available The Argus is supplied using IEC 60870 5 103 as its default communications Modbus is available via a setting in the communications menu 1 2 8 Terminals These are of a modular design Depending on the model either 1 2 or 3 terminal blocks will be fitted with 28 terminals per
161. er Local Connection Laptop computer P300007 Communications vsd RS485 Multidrop Figure 4 3 4 Communication to Argus Relay using RS485 RS232 converter Multidrop Connection 4 3 11 Glossary Baud Rate See bits per second Bit The smallest measure of computer data Bits Per Second BPS Measurement of data transmission speed Data Bits 2010 Siemens Protection Devices Limited P20007 Page 70 of 71 7SG11 Argus Technical Reference A number of bits containing the data Sent after the start bit Half Duplex Asynchronous Communications Communications in two directions but only one at a time Hayes AT Modem command set developed by Hayes Microcomputer products Inc Modem MOdulator DEModulator device 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 Bit logical 0 sent to signify the start of a byte during data transmission Stop Bit Bit logical 1 sent to signify the end of a byte during data transmission 2010 Siemens Protection Devices Limited P20007 Page 71 of 71 7SG11 Argus 1 Diagrams a
162. er secondary winding connections on the B and C phases Energise the circuit with primary load current eg 2209 of In If the load power is flowing away from the busbars then the directional earth fault element should indicate operation in the forward zone Check that this is the case Reverse the connections either to the current or voltage input and check for operation in the reverse zone If the load power is flowing toward the busbars then the opposite results should be expected Finally de energise the circuit restore normal connections replace the A phase primary fuse and remove the shorting connections from the A phase V T and from the B and C phase C T connections Figure 4 8 shows the test set up and the resultant applied voltages and currents for a simulated earth fault condition using load current 2010 Siemens Protection Devices Limited P20006 Page 26 of 37 7SG11 Argus User Manual 4 3 Putting into Service After tests have been performed satisfactorily the Argus should be put back into service as follows Remove 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
163. ers MODBUS Address Description 29 30 36 X 10046 6 46 Group Warning 10066 E 160 84 General starter 160 128 CB on by auto recluse 10130 130 Reclose blocked 11045 164 Input 3 Input 4 Trip circuit fail ER Alarm A starter 65 B starter X C starter X Oo 67 E starter ER mn Oo m oO O N 1 SEF REF starter 11058 16 11059 164 35 11060 164 36 11061 164 37 11062 164 38 Setting G8 selected E 11067 16 43 CB DBI state 11075 1 11079 55 E 11084 E E E A 34 Circuit breaker open Setting G5 selected Setting G6 selected Setting G7 selected 41 CB close fail BH nput 5 Input 6 Input 7 48 Input 8 49 Input 9 I A utput1 Output2 Output3 E R O Output4 Oo Output5 56 Output6 57 D Output7 Output8 I D Output9 Output10 61 62 63 64 Output11 Forward A A Reverse A Forward B I Oo BI KR A 2010 Siemens Protection Devices Limited P20009 Page 26 of 37 7SG11 Argus 2 Diagrams and Parameters MODBUS Address Description 65 Reverse B X 11089 164 11090 16 11091 11092 11093 164 11094 164 70 11095 164 1 11096 11097 6 E E A Forward C m OY 67 Reverse C m A A OY TI orward E Reverse E rip count alarm N O B maintenance alarm X o 72 Frequent operations exceeded 73 Delta Trip Counter Alarm
164. escription o lt x 164 118 SEF Instantaneous ON OFF p20 2 164 129 Reset Energy Meters ON OFF 20 2 164 130 Reset Maximum Demand ON OFF 20 2 x Note Events listing a Gl cause of transmission can be raised and cleared other events are raised only 3 2 Modbus RTU Definitions The following tables give information on the IEC 60870 5 103 protocol A detailed description of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www reyrolle protection com in publications section under technical reports communications interface manual The tables below detail the MODBUS address map listing data points that are available and the functions 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 connected to the Argus relay the Line Idle and Data Echo settings must both be set to OFF Table showing Coil Addresses MODBUS Description Address 16 Autoredose ON OFF Cm CRRI oT NUUS ANC CN 00023 160 23 Sewings Group 1 seea fon x x 0002 160 24 Sewings Group zseea fon x x oos 160 25 sengs Group sse O
165. et 1 and Highset 2 The setting range of each element allows it to be set and used either as a lowset or highset protection or for overcurrent monitoring For each element common settings are used by each of the three phase fault poles of the relay each element has an OFF setting Each element has a shaped instantaneous characteristic plus follower time delay which can be used to provide time grading margins sequence co ordination grading or for scheme logic The instantaneous elements have transient free low overreach operation under conditions of high values of system X R Figure 2 3 2 and the following text describe the operation of the Lowset element Highset 1 and Highset 2 Each of these elements is identical in operation 2010 Siemens Protection Devices Limited P20007 Page 27 of 71 7SG11 Argus Technical Reference A d This diagram shows the logic for P F Lowset Dir Control overcurrent elements in the forward BIE Lowset Setting direction reverse is similar On relays with no directional elements these P F Lowset Inhib O inputs and settings are omitted d P F Lowset Delay Phase A Phase A a lowset starter lowset trip Dirn A Fwd V Phase B lowset trip P F Lowset Ib Phase B lowset starter Event Dir n B Fwd Ic Phase B Phase B lowset starter lowset trip Event Event Dirn C Fwd P300008 Protection Functions Instantaneous P F Figure 2 3 3 Functional Diagram Instantaneous Phase fault O
166. et 2 element will be picked up during cold load inrush conditions and should not be user mapped to the trip relay Selecting the cold load group s Phase Fault highset 2 to OFF will de select this fast revert mode reversion will then only occur at the end of the cold load reset delay At the end of the cold load reset delay if the current is still above the HS2 setting or any starter is picked up the relay will issue a trip and lockout It will then revert to the normally active group settings allows Cold Load Group n to be selected via a mapped Status Input 02010 Siemens Protection Devices Limited P20007 Page 33 of 71 7SG11 Argus Technical Reference Table 2 16 Cold Load Pickup Settings Sub menu System Config Sub menu Auto reclose Cold Load Enable OFF 0 20 2 0 2 1 20 21 300 360 3600 3900 14400 Cold Load Reset 0 20 2 0 2 1 20 21 300 360 600 3600 3900 14400 2 Directional Control Argus 2 and Argus 6 only Each phase fault and earth fault delay characteristic lowset and highset elements can be independently programmed to non directional forward directional reverse directional or bi directional tri state operation The SEF REF element on most Argus 2 and Argus 6 models is not normally directional however a single pole directional SEF model is available Figure 1 5 7 illustrates the directional operating characteristic relative to the characteristic angle CA historically know
167. et elements 1 amp 2 can be used together to provide a composite characteristic with IDMTL DTL operation at low fault levels and higher speed operation at higher fault levels to grade with fuses etc Sequence Co ordination of the Instantaneous Lowset and Delayed protection operation of two relays in series on a feeder is automatically provided if the upstream Lowset Instantaneous has a grading delay set Grading between both relays Lowsets will be maintained and both upstream and downstream protections will keep their shot counters in step throughout a sequence the upstream protection will apply the same sequence of INST DELAY protection grading with the downstream CB on each shot and not tripping thus the downstream CB performs all the necessary trips to clear the fault settings enable auto reclose to be independently selected ON or OFF for each fault type When ARC is set to IN On i e switched into service each setting can be overridden to OUT Off via a raised mapped status input communications link AutoReclose OFF command At significant stage points during an auto reclose sequence the relay logs and sends named events via the communications link with raised or cleared status as applicable These named events greatly assist the user in the process of determining the timing and exact sequence of events and the relay s response to system fault conditions The relay also indicates the status and progress of the auto reclose sequence via i
168. etting highset 1 time delay setting highset 2 current setting highset 2 time delay setting s lowset current setting s lowset time delay setting S M HS HS HS HS L L t t t t Current 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 timers and a lowset characteristic are provided The lowset does not have an independent current setting in this case The delayed reset function operates on the two DTL timers 1 3 1 3 Directional Control Argus 2 and Argus 6 only Directional elements are available for phase fault and earth fault as an ordering option Bi directional elements provide independent characteristic current and time settings for each direction of each overcurrent stage In models with three phase fault directional elements single phase or two out of three directional decisions are available In most models the phase fault characteristic angles are selectable from 30 and 45 the earth fault characteristic angle is selectable from 0 15 45 and 65 In Argus 2 models with voltage and power measurement the phase fault and earth fault characteristic angles are selectable to any angle between 90 and
169. for 9 binary inputs and 220 V application order two resistor boxes VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20009 Page 7 of 37 7SG11 Argus 2 Diagrams and Parameters Product description Variants Order No Dire tional O C relay 78 G112C CEELL ECAO A AAA A A A Ideal for directional overcurrent and earth fault protection of solid ring systems utilising the fully independent Number of elements bi directional feature Four pole relay 4 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input Qn RuJN FO Type of elements 3 pole phase fault directional and sensitive restricted N 1 E earth fault SEF REF 3 pole phase fault directional and earth fault directional or P 4E 3 pole phase fault directional and earth fault 3 pole phase fault directional and earth fault directional or P 5 E 3 pole phase fault directional and earth fault 3 pole phase fault and earth fault directional 2 D 3 pole phase fault and earth fault directional 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 ch
170. g tests to assist with test procedures or to provide documentation recording the test and test parameters One method is to clear both the waveform and event records before each test is started then after the tests upload from the Argus the settings events and waveform files generated as a result of application of the tests These can then be saved off to retain a comprehensive record of all tests This method is particularly useful when auto reclose sequences are being checked When testing is completed then the event 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 practical The provision and use of secondary injection test sockets on the panel simplifies the test procedure Ensure that the correct d c auxiliary supply voltage and polarity is applied See the relevant scheme diagrams for the relay connections Check that the nominal secondary current rating of the current transformers has been correctly set on the P F Rating E F Rating and SEF Rating settings in the System Config menu of the relay 4 1 3 Applying Settings The settings for the particular application should be applied before any sec
171. gh Impedance Restricted Earth fault Scheme Externally mounted power resistors connected in series with the relay are required to set the stability voltage Vs See Section 3 Application Notes for the theory and formulae required to calculated the ls and Vs settings and resistor values A non linear resistor may also be required to protect the scheme wiring and current transformers against transient over voltages at high fault levels 2 5 Primary Equipment Fail Protection 2 5 1 Circuit Breaker Trip Fail Protection Provides 50CBF Trip Fail two stage time delay with Phase Earth and SEF current level 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 an output relay which in turn is mapped to Fault Trigger When Fault Trigger is raised this enables the CBF current level detectors that check for cessation of current flow in each pole If and while any current exceeds setting specified setting On time out CB Fail 2 output is raised this can be mapped to a different output relay to provide a Back trip output NB If CBF is to be applied then a current setting should be entered for
172. h the relay Check that all of the communications settings match those used by Reydisp Evolution E g Protocol set to IEC 60870 5 103 Check that the Tx and Rx fibre optic cables are connected correctly Tx gt Rx and Rx Tx Check that all cables modems and fibre optic cables work correctly Set the line idle setting to Light On Examine the Tx port on the back of the relay with the fibre removed and check that it is glowing red If it is not then the communications board on the case may not be aligned correctly with the processor card socket Contact a VA TECH representative WARNING DO NOT LOOK AT THE FIBRE OPTIC TRANSMITTER FOR A PROLONGED TIME Relays will not communicate in a ring Check that the Data Echo setting on all relays is set to ON network 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 polarity is correct Check that the status input settings such as the Pick up and Drop off timers and the status inversion function are correctly set Relay instrument displays show small This is normal The relay is displaying calculation noise This will currents or voltages even though the not affect any accuracy claims for the relay system is dead If the above checklist does not help in correcting the problem please contact Siemens Protection Devices Limited 02010 Siemens Protection Dev
173. he 2 stage circuit breaker failure feature should be tested if required by the application If only one of the stages is to be used then only CBF delay 1 need be tested In order to test both stages of the CBF feature then the two CBF delays should be programmed to operate 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 start a time interval meter Connect the output from CBF delay 1 to stop both the timer and the current source Inject current of 2x setting into any pole and record the first CBF time delay in Table 4 15 Connect the CBF delay 1 output to start the time interval meter Connect the output from CBF delay 2 to stop both the timer and the current source Inject current of 2x setting into any pole and record the second CBF time delay Check that the measured delays are within 5 of the set values 4 2 3 5 Directional Tests This applies to Argus 2 and Argus 6 relays only The following tests deal specifically with directional functionality Note that there are a number of variants of directional Argus relays with various combinations of directional and non directional poles These tests shou
174. he reclaim delay time then the relay performs the programmed one trip to lockout The relay will not issue a close pulse to a circuit breaker that is indicating that it is closed i e the double command status inputs CB Open is cleared and CB Closed is raised If a Don t Believe It DBI condition exists e g CB Open and CB Closed are both raised then the relay will issue the close pulse Remote Close and Reclaim When this command is raised edge triggered if the CB is open the relay enables line check then immediately issues a defined close pulse and enters the reclaim delay There is no delay as for Local Close amp Reclaim since there are tight Time allowed to live limits on SCADA commands If the CB closes onto a fault or a fault occurs during the reclaim delay time then the relay performs the programmed one trip to lockout The relay will not issue a close pulse to a circuit breaker that is indicating that it is closed i e the double command status inputs CB Open is cleared and CB Closed is raised If a Don t Believe It DBI condition exists e g CB Open and CB Closed are both raised the relay will issue the close pulse Trip and Auto reclose When this command is raised edge triggered the relay immediately issues a trip pulse then after the first phase fault reclose delay it enables line check then issues a close pulse to reclose the circuit breaker and enters reclaim If the CB closes onto a fault or a fault devel
175. i 9 ro IO A IO E O A O H H mpwmeae a e ros eo wams ts ra rol x ros npma 1 a x ros e weeueka up mm rol ros Rap 3 ma rol 06 oe omare wmm rol inl sommes x 1 te prof i e oseaan 3 wmm rol 04 or reses x 3 te feof Dw eo resem HHH te 8 Dw um x 3 8 i oo ronas x prep e w weesr x 2 3 prep gt LLL LLLI LL ot tt CIL Rare x 3 mm feo Dw m oeem imo Dw we wemem 2 we o farsen e ft 59 8 ros ros atecupime up fre saes fre Sanr x 3 ae 8 L LL ot tto ti to Dw we sew s amp ma feo Dw w wmes x if ds EC IO RET x 3 amp mm feo sf mo erac HHH nam RE rama eo e ns ans ra feo we ne ferns HHH mm feo Dw aw emem it x ft rama m AG 2 500 2010 Siemens Protection Devices Limited P20009 Page 21 of 37 7SG11 Argus 2 Diagrams and Parameters Cw we srmw x ICI oan ro Cw we muweewe x mmn e i i sacon x a fro CO ISO IO O R T Ito RIRE x HTHH RIRE x HHT i is vevas H Pa Tre REE x HTHH Dw w we 1 timo Cw we weewee k x e rc x www x e rc x TR nere x e rc x LL O 3 E A Dm eforme pep oss opa fo LL LLL LLLI o wesmwwwm 5 LIC LLLI EM EEE a w Table Showing Command Informatio
176. ices Limited P20006 Page 31 of 37 7SG11 Argus User Manual 4 4 3 Primary Injection Tests Table 4 18 Primary Injection Results Phase Primary Secondary current injected current 2010 Siemens Protection Devices Limited P20006 Page 32 of 37 7SG11 Argus User Manual phase shifting transformer 240V a c e 240V a c supply supply auxiliary d c supply Figure 4 3 Secondary Injection Test Circuit Figure 4 4 Directional Test Circuit phase shifting transformer 240V a c supply primary injection test source Figure 4 5 Two out of three Directional Figure 4 6 Phase to Earth Primary Injection Test Circuit Test Circuit primary injection test source Figure 4 7 Phase to Phase Primary Injection Test Circuit 2010 Siemens Protection Devices Limited P20006 Page 33 of 37 7SG11 Argus User Manual 3 pole directional phase fault and directional earth fault End 1 Direction of load power flow MP reverse 1 C L phase fault element Y C L P S reverse forward V A phase fuse T A pol removed test SiC Ve a e N AE T earth fault element A e Q 36 e E O ve 3 pole directional phase fault dn 790 and directional earth fault A phase fuse da removed forward phase fault element reverse L P B v O Y C Earth fault I P i p M E Y forward earth fault element End 2 Direction power flow 193 A phase I P A Note that the terminal numbers in this di
177. ices Limited P20006 Page 36 of 37 7SG11 Argus User Manual DEFECT REPORT Please copy this sheet and use it to report any defect that may occur Customers Name amp Address Site Circuit Software Version Article No Report Required Y N Date Found During During From a System Other please state Commissioning Maintenance Fault Product Name Serial No Copy any message displayed by the relay Describe Defect Describe any other action taken m For Siemens Protection Devices Limited use only Date Received Contact Name Reference No Date Date of Reply Date Cleared Acknowledged To report a problem please return this completed form to Siemens Protection Devices Limited PO Box 8 Hebburn Tyne amp Wear NE31 1TZ England Telephone 44 0 191 401 7901 Fax 44 0 191 401 5575 2010 Siemens Protection Devices Limited P20006 Page 37 of 37 7SG11 Argus Technical Reference 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 2006 03 Third issue Editorial modifications software revision histories updated Second issue Modification of CBF feature DTL timers extended CT Failure added Auto 2004 05 Reclose sequence settings modified Modbus protocol included and additional metering included 2002 12 Software Revision History The copyright and other
178. icular pole inject current and volts at the characteristic angle and check that FWD is indicated Then adjust the phase angle to find the lagging drop off boundary ie lags V giving a negative angle the FWD indicator disappears at the drop off angle Set the angle back until the FWD indicator reappears and adjust the phase angle to find the leading drop off angle positive angle To measure pick up angles set the applied phase angle to be in the reverse zone and reduce the phase angle until FWD is displayed Do for both leading and lagging boundaries The reverse zone boundaries can be found in a similar fashion Initially inject at the characteristic angle plus 180 and check that REV is indicated Then find the pick up and drop off angles at the leading and lagging boundaries Find the boundaries of the operate zones for each pole and record them in Table 4 16 If the test equipment is not accurate enough to measure the boundary then an all or nothing test could be applied to verify the correct direction indication 2010 Siemens Protection Devices Limited P20006 Page 22 of 37 7SG11 Argus User Manual Apply residual voltage either directly to input or by reducing voltage of faulted phase Adjust the phase angle of the residual current relative to the voltage 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
179. ighset 1Delay Cee 00 0 01 20 00 20 5 100 101 300 Gn P F E F Highset 2 Dir Control rarr pine arp fore E 3 5 4 0 52 5 Gn PIF E F Highset 2 Delay 0 00 0 01 20 00 20 5 300 OFF FWD REV TRI Argus 2 and Argus 6 only see note 1 below Sub menu O P Relay Config Gn P F E F Starter _ 1 for each output contact default see note 1 below Gn P F E F Charact Gn P F E F Lowset _ 1 for each output relay R1 R11 default settings all protections Gn P F E F Highset 1 default 1 energise output relay 2 Gn P F E F Highset 2 Sub menu Status Config Gn P F E F Charact Inhib 1 for each status input S1 S811 and Argus 2 type Il relays only each Gn P F E F Lowset Inhib Vstart a hone Gn P F E F Highset 1 Inhib element can be set to be inhibited Gn P F E F Highset 2 Inhib default from the voltage element starter Note 1 If the directional control is set to tri state these settings will be duplicated for forward and reverse 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 n order to detect and setting modifies the reset mode of the IDMT DTL protection algorithm such that after the fault current has disappeared the current time totals are held For faults that
180. ighset1 Setting Gn P F Highset1 Delay Gn P F Highset2 Setting Gn P F Highset2 Delay Gn E F Charact Setting Gn E F Charact Gn E F Charact Time Mult Gn E F Charact Delay Gn E F Lowset Setting Gn E F Lowset Delay Gn E F Highset1 Setting Gn E F Highset1 Delay Gn E F Highset2 Setting Gn E F Highset2 Delay Gn SEF REF Current Setting Gn SEF REF 1st Time Delay Gn SEF REF 2nd Time Delay Gn SEF REF Lowset Delay Gn CB Fail Time Delay1 Gn CB Fail Time Delay2 Gn Relay Reset Delay Gn Backup Alarm SA Gn Backup Trip SA Ref Applied value xin mI mI sec xin 2010 Siemens Protection Devices Limited 7SG11 Argus 4 Diagrams and Parameters Auto reclose Menu Setting name Gn Line Check Trip Gn Seq Edit View Gn P F ARC Gn P F Line Check Trip Gn P F Protection Trip 1 Gn P F Reclose DTL 1 Gn P F Protection Trip 2 Gn P F Reclose DTL 2 Gn P F Protection Trip 3 Gn P F Reclose DTL 3 Gn P F Protection Trip 4 Gn P F Reclose DTL 4 Gn P F Shots To Lockout Gn P F HS1 Trips to Lockout Gn P F HS2 Trips to Lockout Gn E F ARC Gn E F Line Check Trip Gn E F Protection Trip 1 Gn E F Reclose DTL 1 Gn E F Protection Trip 2 Gn E F Reclose DTL 2 Gn E F Protection Trip 3 Gn E F Reclose DTL 3 Gn E F Protection Trip 4 Gn E F Reclose DTL 4 Gn E F Shots To Lockout Gn E F HS1 Trips to Lockout Gn E F HS2 Trips to Lockout Gn SEF REF ARC Gn SEF REF Line Check Trip Gn SEF REF Protection Trip 1 Ref Ap
181. industrial and commercial plant 7SG11 Argus 1 Diagrams and Parameters Variants Order No 7 G1110 0OA0 A au Number of elements Four pole relay 4 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input uh WN FE Type of elements 3 pole phase fault and earth fault 3 pole phase fault and sensitive restricted earth fault SEF REF or F 2 pole phase fault and earth fault and sensitive restricted earth fault SEF REF Nominal current 1 5 A A I O range 1 Binary 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 amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 1 binary input and 110 V application order resistor box VCE 2512H10066 in addition for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 9 binary input
182. 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 2010 Siemens Protection Devices Limited 7SG11 Argus Technical Reference Contents Section 1 Performance SHECHIC AVION ioo eed ssssssssesssssee senses nenen neeaae mavens Do eu Da A Ceu M CE ue E 6 Ulea a ad dd o 6 1 1 1 Ce COM ONT 226206 sos cencetn sea H ce Dum usa DORA RS Rea TR DO epu AS Dana ERAS e eR a fauna 6 1 1 2 PREFS CS ER RTT o as ENA TE 6 iS DIMENSIONS and We Sii A A M oco 6 12 Energin QUARTOS xD 7 1 2 1 Characteristic Energising Quantities e eee eee eee eee eee 7 1 2 2 Auxiliary Energising Quantity eee e ee ee 8 1 32 O ido UNE CONCISA Sere eee 9 14 oEunclional Pe nor mande ads A EE pates oa RE 9 1 4 1 Phase fault Overcurrent Protection
183. ion a see note 7 Rear F O comms ports 5 Optional expansion card fitted only on models AG2 523 and AG2 524 6 Application shows use of 5 limb star VT with separate open delta winding providing the neutral voltage 7T Rear RS485 port is an ordering option Connect wire link as shown to B include 120W terminating resistor in circuit Phase rotation see note 4 see note 5 Argus 2 Connection Diagrams AG2 5x3to4 3 Figure 4 14 Typical Connection of Type AG2 5xx Dir P F Dir E F and SEF with Open delta VT 2010 Siemens Protection Devices Limited P20009 Page 37 of 37 7SG11 Argus 4 Diagrams and Parameters 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 2010 02 Document reformat due to rebrand 2005 06 Third issue Editorial modifications software revision histories updated 2004 07 Second issue Power On alarm added 2002 12 First issue 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
184. ional the bi directional function enables different settings to be applied 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 fault current flows in a clockwise or counter clockwise direction i e only one relay must be used where normally two relays are required The same applies to Generator circuits Argus Application Diagrams Parallel Fdr Protn Figure 3 2 1 Parallel Feeder Protection 3 3 Sensitive Earth fault Protection Where sensitive earth fault settings are required the setting must be above any line charging current levels that can be detected by the relay On occurrence of an out of zone earth fault the elevation of sound phase voltage to earth in a non effectively earthed system can result in a zero sequence current of up 3 times phase charging current flowing through the relay location The step change from balanced 3 phase charging currents to this level of zero sequence current includes transients It is recommended to allow for a transient factor of 2 to 3 when determining the limit of charging 02010 Siemens Protection Devices Limited P20007 Page 55 of 71 7SG11 Argus Technical R
185. is connected to the Argus relay the Line Idle and Data Echo settings must both be set to OFF Table showing Coil Addresses MODBUS Description Address 16 Autoredose 0 ON OFF Cm EE 00 3 iso 25 Setings Group select Jon x ooo 160 24 Sewings Group 2sele ON x oos 10 25 setos Group 3 Select Jon x gt oos 160 26 serios Group Seect Jon gt mos 1 9 energie Ouputt ON P moe aea 52 Energise ouput ON P ur ie 53 enerose outputs on x mom i9 s Energise pura ON gt 2010 Siemens Protection Devices Limited P20008 Page 23 of 33 7SG11 Argus 1 Diagrams and Parameters MODBUS Description Address mo im 5 reroee ouuts fon x mom res 56 treweoumto on x mom res 57 aeae gn Jon x mom ic ss treweoumes ON x 0103 ase 50 Taare ouput on x moe res 60 Enerose gnn ON x mos use m Ererose ompun fon x Fons 164 so Twager waver Storage ow x oue fres m ema o oum fres 65 Tae an o oum fres 06 eme on omo fres as coseand ocun owo ou ase 100 cadis eno Tovor rouse fies aso ser omo ou ase ma rarcinnpe Jovo ms ase mo erancinnioe omor oux ase ana aeaa ous res ais instantaneous Towo anas res s instantaneous ovo oie 1e ur einsantaneous Tovor ma 1e amp ua seF instantaneous Towo oues fres us Hot Une w
186. itted only on models AG2 415 and AG2 416 5 Optional expansion card fitted only on models AG2 425 and AG2 426 6 Rear R5485 port is an ordering option Connect wire link as shown to include 120W terminating resistar in circuit Rear RS485 comms port Direction of power flow in the forward direction see note 3 see note 6 Rear F O comms ports Phase rotation see note 4 see note 5 P300002 Argus 2 Connection Diagrams AG2 4x5 4x6 Figure 4 9 Typical Connection for 3 Phase fault and Directional Earth fault Protection 2010 Siemens Protection Devices Limited P20009 Page 34 of 37 7SG11 Argus 2 Diagrams and Parameters Notes T CT circuits are shown connected to BUSBARS AG2 5x1 5x2 1A tap use alternative tap for 5A rated CTs ABC 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 4 Optional expansion card fitted only on models AG2 511 and AG2 512 en C Rear RS485 comms port C 2 o tb o D a E 2 o LD Sl q ES 55h dais BG 343 agl Tou oy sop 42 51k G 52 gt 5A3 45 2 NY IX NY e CO Cn DO VV VI V NT a Rear F O comms ports E 2 uc L Oo O a UH O t o e e D see note 6 5 Optional expansion card f
187. itted only on models AG2 521 and AG2 522 6 Application shows use of 5 limb star connected VT with neutral voltage derived j internally m 6 Rear R5485 port is an ordering see note 6 es option Connect wire link as shown to C B include 120W terminating resistor in circuit Phase rotation see note 4 see note 5 Argus 2 Connection Diagrams AG2 5x1to2 1 Figure 4 10 Typical Connection of Type AG2 5xx Dir P F and Dir E F with Star connected VT Notes 1 CT circuits are shown connected to BUSBARS AG2 5x1 5x Es tap use alternative tap for 5A rated S A BC q 2 CT and earth connections are typical 3 only 3 Application shows use of Holmgreen connection for E F circuit Use of separate ring core CT is also possible 4 Optional expansion card fitted only on models AG2 511 and AG2 512 5 Optional expansion card fitted only on models AG2 521 and AG2 522 Rear RS485 comms port Direction of power flow in the forward direction p see note 7 Gg Loa SE Y o 6 Application shows use of 5 limb star VT with separate open delta winding providing the neutral voltage Y Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Phase rotation see note 4 see note 5 Argus 2 Connection Diagrams AG2 5x1to2 2 Figure 4 11 Typical Connection of Type AG2 5xx Di
188. iven for a Phase Fault and is also applicable to Earth Fault and or Sensitive Earth Fault If the scheme requires the Argus to provide Auto Reclose initiated by a Status input then the SA Sequence should be checked The response to a Transient fault should be checked Record the results of the sequence test in Table 4 17 4 2 5 Status Inputs The operation of the status input s can be monitored on the Status Input display shown in Instruments Mode Inject the required supply voltage into each status input and check for correct operation Depending on the application each status input may be programmed to perform a specific function each status should be checked to prove that its mapping and functionality is as set Where the pick up and or drop off timers associated with a status input are set to user scheme required delays these delays should be checked either as part of the scheme logic or individually To check a status pick up time delay temporarily map the status to an output relay that has a normally open contact Use an external timer and time the interval between status energisation and closure of the output contacts To measure the drop off delay map to an output relay that has a normally closed contact time the interval between status de energisation and closure of the output contacts Note The time measured will include an additional delay typically less than 20ms due to the response time of the status input and th
189. ks or close m c b s 2010 Siemens Protection Devices Limited P20006 Page 27 of 37 7SG11 Argus User Manual 4 4 Commissioning Record Tables These tables should be completed during commissioning as a record of the commissioning tests Relay Type Serial Number Substation Feeder Identity Tester Date 4 4 1 Secondary Injection Tests 4 4 1 1 Overcurrent IDMTL DTL Characteristic Table 4 4 Pick up Drop off Results Pick up error Measured rae Pick up setting Measured pick up 44 A drop off EN NEN Table 4 5 Timing Characteristic Results Characteristic NI VI El Error Error LTI DTL 5 or 5 or Lowset and Highsets EJ 4 6 Lowset setting results Drop off error 295 of pick up Error Lowset setting Measured pick up 5 of setting AE 0 2010 Siemens Protection Devices Limited P20006 Page 28 of 37 7SG11 Argus User Manual Table 4 7 Highset 1 setting results migiiset Measured pick u Error setting P P 5 of setting Table 4 8 Highset 2 setting results B die Measured pick u eli setting P P 5 of setting Table 4 9 Lowset timing results Lowset delay Mesa dla Error setting y 2596 or 30 ms of setting Table 4 10 Highset 1 timing results Highset 1 Measured dela Error delay setting y 5 or 30 ms of setting Table 4 11 Highset 2 timing results Highset 2 Messired dela Error delay setting y 15 or 30 ms of setting 2010 Siemens Protection Device
190. l Reclaim Delay a Reclaimed cleared exen IS issued and an output is raised this may be mapped by the user to any output relay 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 truncated without completion lt is not necessary to reset the relay s Lockout state to be able to close the circuit breaker mana for c a set time delay after lockout The delay can be user selected to OFF or to a set time delay If set the delay prevents an operator from repeatedly quickly closing onto a permanent fault allowing the Plant to cool between closes preventing overheating overstressing Table 2 19 Auto reclose from Internal Elements Settings A menu Auto reclose EOM Line Check Trip ON OFF Common setting applies to all Sequences in that group Gn Seq Edit View The settings below relating to P F are repeated for E F and SEF This setting allows the user to display a subset of them only Default depends on relay type ALE P F Sequence E F Sequence SEF REF Sequence SANS Equence ALL shows all settings Gn P F E F SEF ARC IN OUT These settings are for phase fault JH a elements earth fault and where
191. lable Different combinations of the functions shown in Figure 2 1 1 are provided in each model to achieve different protective requirements Four series of relays are provided within the range Argus 1 overcurrent protection Argus 2 directional overcurrent protection Argus 4 overcurrent protection and integrated autoreclose Argus 6 directional overcurrent protection and integrated autoreclose Two types of current input circuits are used in the Argus range One is used for phase fault P F and earth fault E F protection The second type provides harmonic filtering and is used for sensitive earth fault SEF and restricted earth fault REF protection Two types of directional voltage inputs are used in the Argus 2 series Type provides a fixed set of characteristic angles type Il allows any angle to be set and provides a voltage protection element and voltage and power measurands Argus 6 series relays all have a type voltage input The Diagrams and Parameters document for each series lists explicitly the functions that are provided within each model 2 1 2 Document Organisation The remainder of Section 2 Functional Description is organised as follows Table 2 1 Overview of Functional Description Sections Principal Configuration 2 9 Phase Fault Protection Configuration of Argus for system requirements system frequency CT VT ratios identifiers password etc phase fault time delayed overcurrent
192. ld only be applied to those poles that are directionalised Note also that the directional response for each characteristic eg IDMTL highset etc is programmable and may be selected as either Non directional Forward Reverse or TRI state depending on the requirements of the scheme For the following tests the Directional Control settings should be set to the required settings Directional Polarity Check This test checks for correct polarity of the directional circuits In the Instruments menu display indication is provided on the output states of the directional elements i e whether they see forward current reverse current or neither for each pole This display is an aid to commissioning testing If the Argus is allowed to trip during testing then this display will be interrupted and replaced by the fault data display screen If this normal operation interferes with testing then temporarily change the Fault Trigger setting so that no fault indication will be given if the Argus trips 2010 Siemens Protection Devices Limited P20006 Page 21 of 37 7SG11 Argus User Manual 1 Check the direction of each pole in turn by connecting to the appropriate terminals Table 4 2 shows the polarising quantity for each pole Figure 4 4 shows a directional test circuit for one type of Argus 2 Table 4 2 Connections for Directional Polarity Overcurrent pole Polarising voltage 2 Inject rated current and apply rated voltage at the CA MTA phase
193. lling and Max demand la Ib Ic Rolling and Max demand W Rolling and Max demand Var Direction Autoreclose status Output contacts Status inputs Trip circuit healthy failure Trip counters summation Number of waveform and event records stored Time and date Starters Power on counter Instruments marked are not available in all models consult ordering information and the appropriate Diagrams and Parameters document Note The rolling demand measurements can be configured to measure over a rolling window with the following ranges OFF 0 25 0 5 1 0 1 5 5 0 6 0 12 0 16 00 24 0 hours General Alarm Screens The Argus has an independent display function that provides up to five General Alarm screens each of which may be programmed by the user to display a message associated with an external alarm Within the System Configuration Menu each General Alarm message can be text edited by the user to display up to 13 characters Also each General Alarm can be user mapped to any status input via the Status Configuration Menu so that on energisation 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 Defau
194. ls with an SEF REF input the user can set the pole B current input to be the menu system not the functionality of the element Phase Rotation Ratings and CT VT Ratios The current input for each pole can be user selected for operation from a 1A or 5A CT secondary The display purposes This setting will not affect the Protection Menu setting s display if they are displayed as xln 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 phase earth VT to be used with the relay calculating the neutral voltage internally Current Display Bases secondary amps or xln i e multiple of relay nominal current The user can thus enter settings in the most convenient units The Argus will perform the necessary conversion if the display units are changed Note For the Argus to correctly calculate these values the nominal CT Secondary Ratings and CT Ratios must be correctly entered see above Table 2 4 Current and Voltage Input Settings Sub menu System Config Set Pole B Type P F E F m Some Argus 1 and 2 models only Earth Fault Mode Select SEF REF Models with SEF only Phase Rotation A B C A C B Argus 2 type II only P F Rating In E F Rating In SEF REF Rating In P F CT
195. lt Instrumentation Screens The menu presentation of the various instruments allows the user to view a single screen at a time However for in service use it is desirable that a small number of high interest user selectable screens are presented automatically by default without user intervention e g Ammeter display of the Primary Load Currents and in addition the TRIP Count The screens of interest to the user e g those required to be presented to a visiting engineer for record purposes can be selected by the user by pressing ENTER when viewing the required screen A Screen Set As Default message will be flashed up and will appear at top right of that screen To cancel a screen default scroll to that screen and press ENTER Screen Cleared As Default will be flashed up and the symbol will be cleared If no button is pressed for the duration of the user set Default Time Delay then each Default Screen is displayed in turn for five seconds each If any General Alarm is raised then the General Alarm screen is presented in the Default Screen sequence The General Alarm screen which has a scrolling display will present one pass of its display Any key press while in default screens will result in a return to the Relay Identifier screen at the top of the menu structure 1 3 5 System Data Data records are available in three forms fault records waveform records and event records 2010 Siemens Protection Devices Limited P200
196. ltage protection i e should not be reconnected Whilst for induction motors the interruption period needs to be short to enable them to coast until reconnection of the supply For overhead lines applications the reclose time must be long enough to allow the ionised air to disperse Factors that affect the de ionisation time are the system voltage cause of the fault and weather conditions 3 2 Reclaim Time Setting The reclaim time is defined as the time window following a successful closing operation within which if a fault occurs the current reclose sequence will continue After the Reclaim time if a fault occurs a new sequence will start Under repetitive fault conditions a long reclaim time in excess of the interval between successive faults may cause unnecessary lockout and interruption of supply 2010 Siemens Protection Devices Limited P20007 Page 60 of 71 7SG11 Argus Technical Reference 3 3 Shots to Lockout Setting There are no strict guidelines for setting this parameter but a few factors need to be taken into consideration The recloser design should be taken into account and the system conditions should be examined as to the nature of typical faults If there is a sufficient percentage of semi permanent faults which could be burnt away e g fallen branches a multi shot scheme would be appropriate Alternatively if there is a likelihood of permanent faults a single shot scheme would provide a higher quality of supply 3
197. lterations are allowed Once the password has been validated the user is said to be logged on and any further changes can be made without re entering the password If no more changes are made within hour then the user will automatically be logged out re enabling the password feature Note that the password validation screen also displays a numerical code If the password is lost or forgotten authorised personnel can communicate this code to Siemens Protection Devices Limited and the password can be retrieved The Argus is supplied with the password set to NONE which means the feature is de activated 2010 Siemens Protection Devices Limited P20006 Page 11 of 37 7SG11 Argus User Manual Section 2 Operation Guide 2 1 User Interface Operation The basic settings displays flow diagram is shown in Figure 2 1 This diagram shows the main modes of display Linesman Mode Argus 4 and 6 only Settings Mode Instrument Mode and Fault Data Mode When the Argus leaves the factory all data storage areas are cleared and the settings set to default values as specified in the Argus Overcurrent Technical Reference document When the Argus is first powered on the screen will display the default relay identifier and Factory Settings The identifier can be changed to a user definable identifier or code if the user prefers Once any setting changes have been made the Factory Settings text will be replaced by Relay Settings O
198. lue Gn E F Charact 2 3 1 Gn E F Lowset 2 3 2 Gn E F Highset 2 04 Gn E F Highset2 2 3 2 Gn SEF REF Starter 2 4 24 Gn SEF REF Delay1 Gn SEF REF Delay2 12 A Gn SEF REF Lowset 4 M 2 2 Gn Status 1 Gn Status 2 2 11 Gn Status 3 2 11 244 Gn Status 4 Gn Status 5 2 11 Gn Status 6 2 11 ES 241 Gn Status 7 Gn Status 8 2 11 244 Gn Status 9 Gn CB Fail 1 25 Gn CB Fail 2 2 5 1253 Gn CT Failure Gn Counter Alarm E 2 14 1 Gn XI Alarm Gn Power On Count 2 14 3 Gn Hand Reset 2 ELE Min O P Energise Time PAN ms Status Configuration Menu Setting name Ref Applied value See also Figure 2 1 on page 15 for the programming matrix Setting name Ref Applied value Gn Prot Healthy Gn P F Starter Gn P F Charact Gn P F Lowset Gn P F Highset1 Gn P F Highset2 2010 Siemens Protection Devices Limited Settings Group Select 2 2 1 Inverted Inputs Gn P F Lowset Inhibit 3 Gn P F Charact Inhibit 3 o o P20008 Page 12 of 33 Setting name Ref Applied value Gn P F Highset1 Inhibit E ooo Gn P F Highset2 Inhibit ae Gn E F Charact Inhibit SS Gn E F Lowset Inhibit ao Gn E F HighSet 1 Inhibit ro Gn E F HighSet 2 Inhibit S Gn SEF REF Delay1 Inhibit AS Gn SEF REF Delay2 Inhibit A Gn SEF REF Lowset Inhibit A Gn Trip Circuit Fail am f Gn Waveform Trig Sal o Gn El Update zaaf Gn Reset Flag amp Outputs al Gn Clock S
199. ly binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input uP WN FE Type of elements 3 pole phase fault and earth fault 3 pole phase fault and sensitive restricted earth fault SEF REF or F 2 pole phase fault and earth fault and sensitive restricted earth fault SEF REF 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 or Modbus RTU 1 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Housing size Case size E6 4U high D 2010 Siemens Protection Devices Limited P20010 Page 5 of 22 7SG11 Argus 4 Diagrams and Parameters Section 2 Settings Relay Type Serial Number Substation Feeder Identity Notes on Tables All settings found in the Argus 4 relay types are listed below Within the list some settings indicated with greyed cells are not always visible for the following reasons e Depending on the version of the relay a particular function and hence its related settings may not be present e g on a 2 phase fault and SEF relay any settings related to earth fault will not be present e Depending on the value of some settings other settings will be hidd
200. me x 2 nero Dw w we e 2 rop Cw 190 voregen x 3 59 8 RO x 3 no 8 tos 192 votogememoy o x fs no ro Lp TL LI ROI x xo o RH x 9 H Dwemwe emaomm x no H Dw w emacmm x 9 H ros 2a istratcurem x ro o x ros es varaarvotoso x Ja no ii 20 vores x o ii ar verwy x o RH x 9 LL HH E LRL o Tine Sewonsaton pa dP ass o ensot mera nenes w o x Table Showing Command Information INF Numbers 2010 Siemens Protection Devices Limited P20008 Page 21 of 33 7SG11 Argus 1 Diagrams and Parameters Description CO TYP COT Argus 1 160 160 160 160 X B swwGmpises oN m a w swmwomises o m m swmwGmeise o m mswmwompass ON 3 Do Tito ir s Sets pasea on m a e w swmwompssma ov 3 w swmsomp sem o w swmsompsse o m IESO IS O IO E W mewsowar onfa a e e ewe on m a a ewes on m 3 w mewwmomas ON m os cree outs o m a o cree outs on m w weweomar ww 5 se ewes o m a e o creando o m a Terese ouput ww m w or eessen on m a a O HH H H H mh ss Ov 3 3 Po OO O II E amwa owna a m Gwemsmeam on m 3 s remar on m 5 anaa ET o 2 OO H H H larer an a Do HH H H H C
201. me tagged textual record of the conditions at the instant of a Fault Trigger e g Trip Table 2 25 shows all possible entries in a fault record Details are included of all operated or operating protection elements aaa and directions of currents in each pole at the time of trip operates in combination with any protection element or a status input mapped to a Fault Trigger output relay is raised To trigger a Fault Data ET from an external ced device connect its trip output to a status input when a protection function E ned to that output lay operates Up to 5 oe are stored in a le buffer with oldest faults overwritten All Fault Data records can be cleared if Table 2 25 List of Entries for Fault Data Records Fault Record Entry Date amp Time dd mm yy Time stamp hh mm ss ssss 02010 Siemens Protection Devices Limited P20007 Page 47 of 71 7SG11 Argus Technical Reference Fault Record Entry Active setting group at time of trip where n is the group number PHASE A PHASE B PHASE C EARTH FAULT SEF REF Direction FWD or user tag Forward and reverse direction User defined text tags can be programmed for each direction e g LINE BUS FEEDER REV orusertag TRANSFORMER etc Elements LS Lowset E DTL Time delayed characteristic set to DTL IDMTL Time delayed characteristic set to IDMTL HS1 Highset 1 HS2 Highset 2 TIMER 1 SEF REF 1 time delay TIMER 2 SEF REF 2 time delay EXTERNA
202. ments bi directional feature includes additional Four pole relay numeric VT 5 voltage protection and energy metering Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input Qn RuJN FO Type of elements 3 pole phase fault directional and earth fault directional 3 pole phase fault directional and sensitive restricted earth fault SEF REF or 2 pole phase fault directional and earth fault directional and sensitive restricted earth fault SEF REF o2 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 RS485 interface IEC 60870 5 103 or Modbus RTU 2 Directional measurement characteristic angle CA 90 to 90 in steps of 1 6 Housing size Case size E8 4U high E 1 High burden 110V amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 5 binary inputs and 110 V application order resistor box VCE 2512H10065 in addition for 9 binary inputs and 110 V application order resistor box VCE 25
203. monics to 550 Hz 02010 Siemens Protection Devices Limited P20007 Page 10 of 71 7SG11 Argus Technical Reference Figure 1 5 3 and Figure 1 5 4 show the instantaneous highset and lowset outputs These instantaneous operate times i e delay setting td 0 005 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 2 Earth fault Overcurrent Protection A main characteristic IDMTL DTL and 3 DTL characteristics Lowset Highset 1 and Highset 2 are provided 1 4 2 1 Time Delayed Characteristic Specification as for phase fault overcurrent section 1 4 1 1 1 4 2 2 Lowset Highset 1 Highset 2 Specification as for phase fault overcurrent section 1 4 1 2 1 4 3 Sensitive Restricted Earth fault Protection A single element with three timing characteristics lowset DTL1 and DTL2 is provided Operate Level Current setting 0 005 0 010 0 960 x n Operate level 100 Is 5 or 1 In _ Reset level 95 lop 5 or 1 96 In 10 C to 55 C Variation 47 Hz to 52 Hz 57 Hz to 62 Hz Note SEF relays are required to suppress 2 3 and higher harmonics and have a frequency response at minimum setting as shown in Figure 1 5 5 Operate Time Delay setting lowset DTL1 DTL2 0 00 0 01 20 00 20 5 100 101 300s lowset tiowset 1 or 10 ms Operating time DT
204. n INF Numbers AG 2 500 K NM ND KR 2010 Siemens Protection Devices Limited P20009 Page 22 of 37 7SG11 Argus 2 Diagrams and Parameters o lt CES Y T a HHH o msmmeGmeise ow a 0 ene seza on m a x x mo ame ena on m a x 100 ene sen a on m a x x H H IS O IO ea Ow a m x tos ene sera on m x x l ene sea on m x x ros ene seta on m x H T a COLI Emei o a a tee s weweowu o m m it x i m weweowus o m m x x tos sw meweowus H m x x tos s meweowus o m m x x i s meweowus o fm m ia w weweowar H m 2 x x ii sm meweowus ow m x x tos m weweowus o m x x io e seweowws o m m Cw e meweowun H m m x x LL T T trio ies eWwawwesenseme on a L E rt COLI a elw ona Raeann on m e ew wememem ow m i Ranar oor m m LL LLLI ies o coarae oner m LL O e E O Dw w se Jawa a CE H H H HHH ROI 1 i 1 erac oer gt Dw we sewcome fono o m mars fono o m i ne Pr msnen orm m i or ermanno onor o m AG 2 500 2010 Siemens Protection Devices Limited P20009 Page 23 of 37 7SG11 Argus 2 Diagrams and Parameters D
205. n Local Close amp Reclaim Gn Remote Close Reclaim Gn CB Open Gn CB Closed Gn Reclose Block Gn P F ARC Off Gn E F ARC Off Gn SEF REF ARC Off Gn Hot Line Working Gn Alarm 4 see note below Gn Alarm 2 see note below Gn Alarm 3 x see note below Gn Alarm 4 ee nete below Gn Alarm 5 x see note below Ref Applied value sec sec sec sec sec sec sec sec mI ea em ee mI mI BD mI mI mI mI mI mI BI mI E E E E E The text of these setting names reflects the value applied to the Set Alarm n settings in the System Config menu P20010 Page 9 of 22 Comms Interface Menu Setting name Comms Baud Rate Comms Parity Relay Address Line Idle Data Echo Data Storage Menu Setting name Gn Fault Trigger Gn Waveform Trig Gn Waveform Pre Trigger Clear All Waveforms Clear All Events Clear All Faults CB Maintenance Menu Setting name A Trip Counter Reset A Trip Counter Alarm Trip Counter Reset Ref Applied value mI mI CON EI Ref Applied value e p os E Eno Ref Applied value 2010 Siemens Protection Devices Limited 7SG11 Argus 4 Diagrams and Parameters Setting name Ref Applied value E o NN pal e NN pol e po E Trip Counter Alarm Freq Op Counter Reset Freq Op Counter Alarm Xl Reset 21 Alarm Power On Count Reset Power On Count Alarm O P Relay Test Linesman Menu Setting name Ref Applied value MD
206. n Power On Count Gn Hand Reset Gn Pulsed Relays Gn Lockout Alarm Gn Close Pulse Gn AUX Close Gn ARC Active Gn Reclaimed Gn SA Blocked Gn SA Alarm Gn SA Trip Setting name Min O P Energise Time Status Configuration Menu Ref Applied value See also Figure 2 1 on page 12 for the programming matrix Setting name Settings Group Select Gn Inverted Inputs Gn Latched Inputs Gn P F Charact Inhib Gn P F Lowset Inhib Gn P F Highset 1 Inhib Gn P F Highset 2 Inhib Gn E F Charact Inhib Gn E F Lowset Inhib Gn E F HighSet 1 Inhib Gn E F HighSet 2 Inhib Gn SEF REF Delay 1 Inhib Gn SEF REF Delay 2 Inhib Gn SEF REF Lowset Inhib Gn Trip Circuit Fail Gn Waveform Trig Gn ZI Update Gn Reset Flag amp Output Gn Clock Sync Gn Status 1 P U Delay Gn Status 1 D O Delay Gn Status 2 P U Delay Gn Status 2 D O Delay Gn Status 3 P U Delay Gn Status 3 D O Delay Gn Status 4 P U Delay Gn Status 4 D O Delay Gn Status 5 P U Delay Gn Status 5 D O Delay Ref Applied value E 2010 Siemens Protection Devices Limited 7SG11 Argus 4 Diagrams and Parameters Setting name Gn Status 6 P U Delay Gn Status 6 D O Delay Gn Status 7 P U Delay Gn Status 7 D O Delay Gn Status 8 P U Delay Gn Status 8 D O Delay Gn Status 9 P U Delay Gn Status 9 D O Delay Gn ARC Status A Gn ATrip Counter Reset Gn Counter Reset Gn FOC Reset Gn Trip amp ARC Gn Close amp Lockin Gn Trip amp Lockout G
207. n as the maximum torque angle This is the phase angle of the fault current relative to the polarising voltage reference for which the directional detector gives maximum sensitivity in the forward operate zone The reverse operate zone is an exact mirror image of the forward zone The directional element is referred to as tri state because conditions will occur for which neither the forward nor the reverse element should operate If a protection element is programmed by the user to be non directional then only non directional overcurrent settings will be presented The element will operate independently of the output of the directional detector and operation will occur for current above setting regardless of phase angle If a protection element is programmed for forward directional mode then the forward zone 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 element will operate for fault current above its setting in either direction Different overcurrent settings can be programmed for forward and reverse operation In addition the forward and reverse trip output signals can be issued to different output contact
208. n each subsequent power on the screen that was showing before the last power off will be displayed The menu system is navigated as shown in Figure 2 1 Note however that some sub menus and screens are relevant to certain models only and will not always appear This is indicated in the diagram The exact list of settings and instruments available in each model is given in the appropriate Diagrams and Parameters document The five keys have the following functions Up down and right E keys used to navigate the menu system ENTER key when a setting is being displayed this key will enter edit mode for the setting see section 2 1 1 When in edit mode pressing ENTER will accept the setting change When an instrument is being displayed pressing ENTER will toggle the instruments default screen status on and off see section 2 1 2 1 CANCEL key when a 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 LED and any hand reset contacts before displaying the scrolling fault display When an instrument which records a count is being displayed e g number of CB operations pressing TEST RE
209. n of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www reyrolle protection com in publications section under technical reports communications interface manual Table Showing Function Type Numbers Used Reyrolle Overcurrent Protection Cause of Transmission The cause of transmission COT column of the Information Number and Function table lists possible causes of transmission for these frames The following abbreviations are used Table Showing Permitted Cause of Transmission Numbers Cause of Transmission COT Description CAT one SSS Fre reno SSS DO SiS SSS Information Number and Function The following tables list information number and function definitions together with a description of the message and function type and cause of transmission that can result in that message Not all definitions are available on all relay types this is dependent on functionality KEY FUN Function Type defined in IEC60870 5 103 section 7 2 5 1 INF Information Number defined in IEC60870 5 103 section 7 2 5 2 TYP ASDU Type defined in IEC60870 5 103 sections 7 3 1 and 7 3 2 GI Event supports General Interrogation x supported defined in IEC60870 5 103 section 7 2 5 2 COM Type of command single ON only or double ON OFF defined in IEC60870 5 103 section 7 2 5 2 COT Cause of Transmission defined in IEC60870 5 103 section 7 2 3 table 5 DIR Direction of event Raised Only R
210. n relays to clear the fault starts running on time out a SA Alarm is given and the Backup Trip timer then starts running on its time out the relay gives a SA Trip output Both timers stop amp reset when ARC Status A is cleared This two stage back up protection therefore has the external protection settings e g Impedance or SEF levels The timers provide a protection trip when the SA sequence has progressed to the point at which the external protection is blocked and the fault level falls below the overcurrent protection settings For example a five pole protection scheme can be engineered with a 3P E Argus 4 relay and a separate SEF relay where the P F E F and SEF protection each have independent auto reclose sequences two stage back up alarm and back up trip times Table 2 20 Auto reclose from External Trip Settings Sub menu Protection Gn Backup Alarm SA 0 00 0 01 10 00 20 00 sc Gn Backup Trip SA 0 00 0 01 10 00 20 00 sec 02010 Siemens Protection Devices Limited P20007 Page 42 of 71 7SG11 Argus Technical Reference ae 1 menu Auto reclose o SA ARC If set to OUT and an SA input IN OUT occurs then the relay will go to LOCKOUT Gn SA Line Check Trip INST DELAYED Gn SA Reclose DTL 1 0 20 0 21 2 00 2 1 Gn SA Reclose DTL 2 2 2 3 0 20 0 Gn SA Reclose DTL 3 21 22 300 360 420 3600 Gn SA Reclose DTL 4 3900 4200 14400 Gn SA Shots To Lockout 1 2 3 4 Gn SA Trips To Bl
211. nces When installing fibre ensure that the fibre s bend radii comply with the recommended minimum for the fibre used typically 50mm is acceptable for single fibres 2010 Siemens Protection Devices Limited P20006 Page 16 of 37 7SG11 Argus User Manual An option for RS485 electrical interface is available A maximum of 256 devices can be connected using 120 ohm screened twisted pair wire ie Belden 3105A or similar terminated with a suitable flat blade or pin connector The last device in the circuit must be terminated with the termination link as show in section P20008 Diagrams amp Parameters this connects the internal 120 ohm terminating resistor 3 5 Fixings 3 5 1 Crimps Davico ring tongue with 90 deg bend Table 3 1 Wire crimp sizes WreSze Daio 0 25 to 1 6 mm DVR1 4 90deg 1 0 to 2 6mm DVR2 4 90deg 3 5 2 Panel Fixing Screws Kit ZA0005 062 comprising of e Screw Pan Head M4x10mm Black ZB5364 101 2off e Nut MA 2103F11040 2off e 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 required The PC must be capable of running Microsoft Windows 98 or greater and it must have a standard RS232 port a USB RS232 adaptor or a suitable PCMC1A RS232 adaptor
212. nction definitions together with a description of the message and function type and cause of transmission that can result in that message Not all definitions are available on all relay types this is dependent on functionality KEY FUN Function Type defined in IEC60870 5 103 section 7 2 5 1 INF Information Number defined in IEC60870 5 103 section 7 2 5 2 TYP ASDU Type defined in IEC60870 5 103 sections 7 3 1 and 7 3 2 Gl Event supports General Interrogation x supported defined in IEC60870 5 103 section 7 2 5 2 COM Type of command single ON only or double ON OFF defined in IEC60870 5 103 section 7 2 5 2 COT Cause of Transmission defined in IEC60870 5 103 section 7 2 3 table 5 DIR Direction of event Raised Only RO Raised Cleared RC or Double Point Travelling Cleared Raised or Unknown DBI X Supported Not supported 2010 Siemens Protection Devices Limited P20010 Page 13 of 22 7SG11 Argus 4 Diagrams and Parameters Table Showing Command Information INF Numbers KINH Eos TRA ieo a Resare Eos o o sfm ro Dw wmm HHH HT TH 11 H e e fej o eese x 2 no pe re w eme O TEN 9 ref x 00 oe Gene ARA Te o eo Aer w ARA Te 00 vo Senet ARA Te 00 7i cenas ARA Te Argus 4 al NINININI N NIN N 2010 Siemens Protection Devices Limited P20010 Page 14 of 22 7SG11 Argus 4 Diagrams and Parameters wo 93 EF generains wio at RO x EO opo oo o IES
213. nd Parameters 7SG11Argus Overcurrent Protection Relays Document Release History This document is issue 2010 02 The list of revisions up to and including this issue is Pre release 3 Document reformat due to rebrand 200808 Third issue Editorial modifications software revision histories updated 2004 05 Second issue Modification of CBF feature software release updated Modbus porre en included connection a EE for new models 200042 ac issue 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 2010 Siemens Protection Devices Limited Software Release History The software listed below is used in one of more types Argus relay The list of software revisions applying to
214. nd the C T connections for phase to phase fault Record the results in Table 4 18 4 2 7 2 Primary Directional Tests This applies to Argus 2 and Argus 6 relays only General If the Argus being commissioned is directional then the voltage circuits should be tested to ensure correct polarity It is recommended that the Argus be connected to the C T s and V T s with the polarity as shown in the Diagrams and Parameters section of this manual With the polarity connections shown Argus relays will indicate FORWARD direction of current when power is flowing away from the switchboard busbar and REVERSE when flowing into the busbar For an outgoing feeder FORWARD is the normal direction of power flow and for an incoming circuit FORWARD is opposite to the normal direction of power However normal application of directional protection is 2010 Siemens Protection Devices Limited P20006 Page 25 of 37 7SG11 Argus User Manual to initiate a trip when fault current flows away from the busbar For an incomer this requires a parallel supply source In both cases therefore the FORWARD direction is the trip direction for normal applications Argus 2 and 6 protection elements can be programmed to trip either NON directional FORWARD REVERSE or both TRI STATE operation The FWD and REV TRI STATE operation settings can be user programmed independently to different sets of setting values Phase Directional Element
215. ne has been dead for a short time 1 5 s to allow arc by products and ionised air to disperse the healthy line can be reclosed and 2010 Siemens Protection Devices Limited P20007 Page 37 of 71 7SG11 Argus Technical Reference the system restored The Delay trips ensure that if the instantaneous trips do not clear the fault i e it is permanent grading of the protections in series on the system occurs and the protection closest to the fault will trip and isolate the fault 2 9 1 Auto Reclose Sequences settings i e each trip can be selected to be either INSTantaneous or DELAYed with different Dead Times before Reclosure for each shot The User can set the required Sequence and number of Instantaneous trips and Delayed trips to LockOut the number of shots Recloses to LockOut the number of High Set 1 Instantaneous trips to LockOut and the number of High Set 2 trips to LockOut allowed to achieve maximum retention availability of the power system After each trip the relay determines its next course of action using the User settings The correct Auto Reclose delay and Protection Characteristic response is applied after each trip in response to the type of fault cleared thus the correct sequence is applied at each stage of a developing fault instantaneous HighSet Also all protection elements operate in parallel therefore the first non inhibited element that is mapped to trip to time out will generate a trip output The Delay and HighS
216. ng tables give information on the IEC 60870 5 103 protocol A detailed description of all protocol information is available in report no 434 TM 5 13 which can be accessed on the www reyrolle protection com in publications section under technical reports communications interface manual Table Showing Function Type Numbers Used Reyrolle Overcurrent Protection Cause of Transmission The cause of transmission COT column of the Information Number and Function table lists possible causes of transmission for these frames The following abbreviations are used Table Showing Permitted Cause of Transmission Numbers A on OO fine one 0 fertigation SS Information Number and Function The following tables list information number and function definitions together with a description of the message and function type and cause of transmission that can result in that message Not all definitions are available on all relay types this is dependent on functionality KEY FUN Function Type defined in IEC60870 5 103 section 7 2 5 1 INF Information Number defined in IEC60870 5 103 section 7 2 5 2 TYP ASDU Type defined in IEC60870 5 103 sections 7 3 1 and 7 3 2 Gl Event supports General Interrogation x supported defined in IEC60870 5 103 section 7 2 5 2 COM Type of command single ON only or double ON OFF defined in IEC60870 5 103 section 7 2 5 2 COT Cause of Transmission defined in IEC60870 5 103 section 7 2 3 table 5
217. ngs file to the Argus Change individual settings Get the active group number Set the active group number Monitor for events and display them spontaneously Upload the complete events file from the Argus Clear the events file Upload waveform records from the Argus Trigger waveform recording Clear waveform records Continuously display instruments i e meters counters relay status ARC status etc Get system data hardware and software details from the relay Reset all flags e Send commands to the relay Allows user to access the command set of the Argus which includes synchronise the clock change settings group trip and close circuit breakers enable and disable auto reclose functions and protection elements The Reydisp Evolution software can be used with all Argus and Modular ll protection relays supplied by Siemens Protection Devices Limited Use of the Reydisp Evolution software is menu driven with the settings events waveforms instruments and commands all being available in separate menus The settings are displayed in the same order as on the relay fascia 2010 Siemens Protection Devices Limited P20006 Page 15 of 37 7SG11 Argus User Manual Section 3 Installation 3 1 Unpacking Storage and Handling On receipt remove the Argus from the container in which it was received and inspect it for obvious damage It is recommended that the Argus relay not be removed from the case To prevent the possible ingress of dir
218. nhibit i IO e dnhibiic VBC VCA VAB Argus 2 and Argus 6 only 51 T phase fault time delayed 44 p p p overcurrent charact Bn hase fault instantaneous e lowset A phase fault instantaneous overcurrent highset p zu hase fault instantaneous overcurrent highset 2 A phase fault directional overcurrent 27 59 E undervoltage overvoltage aa VCA VC a8 A Fault Trigger Trip Circuit Fail 50BF circuit breaker fail 74TC 50 CTF current transformer failure P F Starter P F Charact P F Lowset P F Highset 1 P F Highset 2 P F REV Block V Starter V Trip V Block Alarm CB Fail 1 CB Fail 2 CT Failure IE E F Charact Inhibit E F Lowset Inhibit E F Highset 1 Inhibit E F Highset 2 Inhibit ISE SEF Lowset Inhibit SEF Delay 1 Inhibit IE ISE CB Open CB Closed Reclose Block SEFIREF ARC Off ARC Status A Trip amp ARC Close amp Lockin Trip amp Lockout Close amp Reclaim 1N earth fault time delayed overcurrent charact 50N earth fault instantaneous overcurrent lowset H 50N earth fault instantaneous overcurrent highset 1 50N earth fault instantaneous overcurrent highset 2 50N 87G sensitive earth fault restricted earth fault SE RE earth fault directional overcurrent autoreclose E F Starter E F Charact E F Lowset E F Highset 1 E F Highset 2 SEF REF Starter S
219. 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 2010 Siemens Protection Devices Limited Software Release History 7SG11 Argus 4 Diagrams and Parameters The software listed below is used in one of more types Argus relay The list of software revisions applying to Argus 4 up to and including this document issue is Mar 2005 2716H80005 R5 Jul2003 2716H80005 R3 Function added Minor change Function added Mar2003 2716H80005 R2 Minor change Minor change E Minor change Feb 2002 2716H80005R1 Function added Function added Function added Minor change Minor change Minor change Nov 2000 2716H80004 R1 2 Sep 1999 2716H80003 R2 Minor change Minor change Minor change Nov 1998 2716H80001 R3 First release Hardware Release History Mods to reclose blocked Mod to Checking Settings screen at switch on Status input Inversion Latched input 8 9 display corrected Power On count alarm IEC 870 5 103 Time Sync optimised communications with ReyDisp Trip amp Reclose action when no CB corrected trip count alarm display added setting
220. ns Protection Devices Limited P20008 Page 29 of 33 7SG11 Argus 1 Diagrams and Parameters Notes BUSBARS AG1 103 104 1 CT circuits are shown ABC A connected ta 1A inputs use 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Diagram shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 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 P Rear RS485 comms port Rear F O comms ports P300001 Argus 1 Connection Diagrams AG1 103 104 Figure 4 2 Typical Connection for Sensitive Earth fault Protection BUSBARS AG1 3x1 3x2 Notes 1 CT circuits are shown A BC connected to 1A inputs use 4 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Optional expansion card fitted only on models AG1 311 and AG1 312 4 Optional expansion card fitted only on models AG1 321 and AG1 322 5 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 Rear RS485 comms port Se Jr mr 241 sr asa sg ei E see note 3 see note 4 comms ports P300001 Argus 1 Conn
221. nt 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 operational checks can be performed without the need for Sana injection setting press ENTER select the required element name using the up or down keys press ENTER to select a confirmation screen O P Test Are You Sure N will be shown confirm by using the up or down key to change to Y and press ENTER An active countdown timer will then be shown in a TRIP TEST IN xx SECONDS screen The counter decrements from 10 seconds to zero then all output relays mapped to that element are energised for 100ms then a message TRIP TEST FINISHED is briefly displayed The time delay before output relay energisation allows personnel to leave the vicinity of the circuit breaker before a live system trip test is performed Table 2 28 Output Relay Test Setting Sub menu CB Maintenance Setting name Range bold default Units Notes 000 2010 Siemens Protection Devices Limited P20007 Page 51 of 71 7SG11 Argus Technical Reference O P Relay Test OFF Protection Healthy all P F E F SEF overcurrent element outputs all voltage elements YES NO confirmation is all mapped status Alarms counters required hand amp pulsed relays Lockout alarm Close pulse Aux Close ARC active Reclaimed SA Blocked SA Alarm
222. ock Sub menu O P Relay Config Gn SA Blocked _ or 1 for each output contact Default output None SI SAT TOA A A O Gn SA Trip or 1 foreach output contact a default 1 Default output relay 2 Sub menu Status aoa o mim ARC Status A or 1 for each status input Default input None default 2 9 2 Control Inputs The user enters the protection settings and auto reclose sequence settings into the relay to set up the required sequence for the different fault types however the operation of these functions may be modified or controlled by the programming inputs These inputs may be via status inputs from external scheme logic and include blocking and CB Status inputs or SCADA Control commands from the remote operator via the Communications link or local commands via the Linesman Mode menu The Argus 2 and Argus 6 provide the following command set Trip and Lockout When this command is raised edge triggered any existing auto reclose sequence is aborted a defined trip pulse is issued and the relay 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 amp Reclaim command to the relay and the relay sending an output to the CLOSE circuit of the Cir
223. of software revisions applying to Argus 2 up to and including this document issue is Nov 2005 2434H80040 R Highset and Lowset setting steps revised between 2 5xIn and 3 0xlIn July 2005 2434H80040 R7 ACD bit in IEC 60870 library corrected Mar 2005 2434H80040 R6 CBF logic modified timer will run while trip is being issued and gt l ICBF Level Aug 2004 2434H80040 R5 Modification to checking settings screen at switch on Corrected CT Failure setting display when configured to show PRIMARY SECONDARY Amps ASDU4 measurands return value O correctly April 2004 2434H80023 R6 Minor change Min P F E F settings now 0 05 x In Jan 2004 2434H80023 R5 Additional features Modbus added Additional features CT Failure function added E Minor change EC60870 Class 2 measurands Sep 2003 2434H80023 R4 Additional features CBF Level detectors added E Minor 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 2 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 tri
224. oltage Memory Voltage Menu Argus 2 type 2 only Setting name Gn V Operation Gn V ph n ph ph Setting Gn V Delay Gn V Hysteresis V Block Threshold V O P Phases Ref Applied value Ref Applied value EI EI EI m Ref Applied value MI BI RI BI Output Relay Configuration Menu See also Figure 2 1 on page 16 for the programming matrix For non directional settings use the ng settings ignoring the forward notation Setting name Gn Prot Healthy Gnl l P F Starter Gn P F Starter Gn il P F Charact Gnl P F Charact Gnl l P F Lowset Gn P F Lowset Gnl l P F Highset1 Gni P F Highset1 Gnl l P F Highset2 Gn P F Highset2 Ref Applied value p BI BI BI BI BD BD BI BD BD BI 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Setting name Gn fi E F Starter Gn E F Starter Gn i E F Charact Gn E F Charact Gn E F Lowset Gn E F Lowset Gn fi E F Highset1 Gni E F Highset1 Gn fi E F Highset2 Gni E F Highset2 Gn i SEF REF Starter Gn SEF REF Delay 1 Gn SEF REF Delay 2 Gn fil SEF REF Lowset Gn SEF REF Starter Gn SEF REF Delay 1 Gn SEF REF Delay 2 Gn SEF REF Lowset Gn P F FWD Block Gn P F REV Block Gn E F SEF FWD Block Gn E F SEF REV Block Gn V Starter Gn V Trip Gn V Block Alarm Gn Status 1 Gn Status 2 Gn Status 3 Gn Status 4 Gn Status 5 Gn Status 6 Gn Status 7 Gn Statu
225. om energy 4 2 3 Recommended cable Selection of fibre optic cable is important Fibres must be terminated with ST BFOC 2 5 connectors The recommended type is 62 5 125um glass fibre Communication distances over 1 km are achievable using this type of fibre 2010 Siemens Protection Devices Limited P20007 Page 64 of 71 7SG11 Argus Technical Reference 4 2 4 Network Topology Communication networks can be connected either in star or ring format Sigma 4 SG4 103 Laptop computer P300007 Communications vsd Sigma 4 remote 4 2 5 Figure 4 2 1Settings 4 2 6 IEC Class Il Measurands Class Il measurands can be sent as either ASDU 3 reports 1 current channel or ASDU 9 reports 9 channels la 4 2 7 EC Class Il Update period 4 2 8 IEC Class Il scaling The measurands returned are fractions of nominal system quantities The maximum range of the measurand can be set either 1 2 or 2 4 times the nominal Values that exceed this range will be returned as the maximum value and flagged overflow Note using 2 4 times scaling will double the 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 ad
226. on Connect wire link as shown to include 120W terminating resistor in circuit Rear RS485 comms port Direction of power flow in the forward direction og L SE c 5 O Ex 344 241 f Sy 39 0 Phase rotation see note 3 see note 4 P300002 Argus 2 Connection Diagrams AG2 3x1 3x2 Figure 4 3 Typical Connection for 3 Directional Phase fault Protection 2010 Siemens Protection Devices Limited P20009 Page 31 of 37 BUSBARS AG2 3x3 3x4 A BC Direction of power flow in the forward direction Phase rotation Rear F Q comms ports see note 4 7SG11 Argus 2 Diagrams and Parameters 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 SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG2 313 and AG2 314 5 Optional expansion card fitted only on models AG2 323 and AG2 324 6 Rear RS485 por is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Rear RS485 comms port D see note 6 see note 5 P300002 Argus 2 Connection Diagrams AG2 3x3 3x4 Figure 4 4 Typical Conn
227. on 4 2 2 1 4 3 2 Recommended cable Selection of fibre optic cable is important Fibres must be terminated with ST BFOC 2 5 connectors The recommended type is 62 5 125um glass fibre Communication distances over 1 km are achievable using this type of fibre The RS485 electrical interface can be connected using 120 ohm screened twisted pair wire i e Belden 9841 or equivalent 4 3 3 Network Topology Fibre optical communication networks can be connected singularly or in a star configuration Modbus does not support a fibre optic ring configuration RS485 electrical connection can be used in a single or multi drop configuration The last device must be terminated correctly Figure 4 2 1 amp Figure 4 2 4 illustrate typical network arrangements 2010 Siemens Protection Devices Limited P20007 Page 68 of 71 7SG11 Argus Technical Reference 4 3 4 Settings 4 3 5 Comms Protocol See previous section 4 1 1 4 3 6 Baud Rate Rates of 19200 9600 4800 2400 1200 600 300 150 110 and 75 bits per second are provided match that of the communicating device 4 3 8 Relay Address number of devices will be limited to 32 devices on any one RS485 connection 4 3 9 Line Idle 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 in the ca
228. onal expansion card fitted only on models AG1 323 and AG1 324 6 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 Rear RS485 comms port comms ports see note 4 see note 5 P300001 Argus 1 Connection Diagrams AG1 3x3 3x4 Figure 4 5 Typical Connection for 2 Phase fault and Sensitive Earth fault Protection 2010 Siemens Protection Devices Limited P20008 Page 31 of 33 7SG11 Argus 1 Diagrams and Parameters BUSBARS AG1 4x1 4x2 Notes o 1 CT circuits are shown A B C connected to 1A inputs use 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Diagram shows use of residual Holmgreen connection for E F circuit Alternatively use a ring core CT 4 Optional expansion card fitted only on models AG1 411 and AG1 412 5 Optional expansion card fitted only on models AG1 421 and AG1 422 6 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 Rear RS485 comms port Rear F O comms ports see note 4 see note 5 P300001 Argus 1 Connection Diagrams AG1 4x1 4x2 Figure 4 6 Typical Connection for 3 Phase fault and Earth fault Protection BUSBARS AG1 4x3 4x4 N
229. onal relays For use on fully Interconnected Networks with Remote Supply Sources If bus coupler and bus section circuit breakers are equipped with CTs and suitable VTs are available then bi directional Argus relays can be fitted to those circuits Suitable steering of blocking and tripping signals can ensure that in the event of a busbar fault only the minimum plant is disconnected from the system Figure 3 4 3 shows a typical example of this If there are no CTs on the bus sections couplers a staged tripping logic can still be established to achieve the same result although in a little longer time 3 5 High Impedance Restricted Earth fault Protection The SEF REF element of the Argus 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 is calculated using worst case lead burden to avoid relay operation for through fault conditions where one of the CTs may be fully saturated The required fault setting primary operate current of the protection is chosen typically this is between 10 and 25 of the protected winding rated current The relay setting current is calculated based on the secondary value
230. ondary testing occurs If they are not available then the Argus has default settings that can be used for pre commissioning tests Refer to the appropriate Diagrams and Parameters document for the default settings Note that the tripping and alarm contacts must be programmed correctly before any scheme tests are carried out Argus relays feature eight alternative settings groups In applications where more than one settings group is to be used then it may be necessary to test the Argus in more than one configuration Note One group may be used as a Test group to hold test only settings that can be used for regular maintenance testing eliminating the need for the Test Engineer to interfere with the actual in service settings in the normally active group This Test group may also be used for functional testing where it is necessary to disable or change settings to facilitate testing 2010 Siemens Protection Devices Limited P20006 Page 18 of 37 7SG11 Argus User Manual When using settings groups it is important to remember that the Argus need not necessarily be operating according to the settings that are currently being displayed There is an Active Settings Group on which the Argus operates and an Edit View Group which is visible on the display and which can be altered This allows the settings in one group to be altered while the protection continues to operate on a different unaffected group The Active Settings Group and
231. onnrnnnnnnnnnnnnnnnnnnnrnnnonanens 23 UST eS STU NG Rr 24 General Alarm Settings i iret eae vecta adve e ete aet E Casadas e eae audae tice o dote id 24 Direction SOWING M 25 Real Time Lee nae EX ti ti pida 25 Default Instrument Setting sss eee eee eee e eee 25 STs SEIO cU a 26 Phase fault and Earth fault Overcurrent Settings see eee eee 28 Rasmning Faul SSN se octet E T 29 Sensitive Earth fault Restricted Earth fault Settings eee eee ee eee 30 Circuit Breaker Rall Settings ya pei aser tr Potens lee az T 32 Current Transformer Fall Settings esito cete wees Pie to ve sbestes A 39 Gold Load Pickup SCS dato Science actores ee Abele e Lora cea MU Mee 34 DIPECHO Mall 5 GLUING cR RR mU ER 35 Voltage Protection Sells ts ri ri oa cde ceed ass aec seu vitaes RS 37 Auto reclose from Internal Elements Settings eee eee e eee eee eee 40 Auto reclose from External Trip SettingS ooncccococoncconnonoconononcnconoconcnnononnnnonnnrnnononcnnnnananononos 42 AUtO reclose command SM lado 44 Live Line Working SEUA A ibas 45 TUP Creu SUDervISIOP CUM co 45 General Output Relay and Status Input SettingS ccoooccnccocncncccncnnononcnnnonanonononcnnononcnonnnnononnnons 46 List or Entries Tor Fault Data eee eios i t ie icone ceo ee o Uoc a bb aa asa ud EL des 47 Data Storage SCHINOS ce 49 Circuit Breaker Maintenance Settings eee eee eee eee 51
232. operty 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 2010 Siemens Protection Devices Limited 7SG11 Argus User Manual Contents Secuon 1 Relay DSS COU Mi e 4 UE ES IS M HT X Y 4 O 4 Re N T Taise T il a E EE NURSE 6 Section 2 Ole ieoaRele 12 21 User Interiace Operatoria DD E EET 12 2 2 Operation using Reydisp Evolution IEC 60870 5 103 COMMS only ee eee e eee 15 section 3 Instala A sens deis Pee eens 16 3 1 Unpacking Storage and Handing 2 ld e ds ee 16 3 2 Recommended Mounting POSITION soii A A A a AAA dis 16 do Relay DIMENSIONS a A AA A AAA 16 O 16 SO rae o e T 17 AE A 17 Secuon A COMMISSION O ss TO E EET 18 a S HT lt T DES UNO sora T 18 PEG ES SUS NEN ERU Nc t Mr PE ee RAP rM CRT MID ON 19 zo EM o CG aa rat RII O ad A E dA aceite 27 4 4 Commissioning Record Tables sees 28 S
233. oping and flashing faults using the event records If a waveform record is available the current waveforms and voltage waveforms in some models allow the type of fault to be easily identified However the waveform record lasts only 1 second whereas the event records will cover many seconds or minutes If a fault is of a flashing nature this will be apparent from the event records while the waveform record may show only the final overcurrent leading to trip 3 10 2 Fault triggers In order to generate a fault record it is important that the fault trigger is correctly set A fault will be recorded if any element trips and it is mapped to an output relay that is defined as a fault trigger relay Therefore any output relay addition if it is required to record a fault for any other element an output relay driven by that element should also be defined as a fault trigger relay 2010 Siemens Protection Devices Limited P20007 Page 62 of 71 7SG11 Argus Technical Reference 3 10 3 Waveform triggers In order to generate a waveform record on occurrence of a fault it is important that the waveform trigger is correctly set Each type of fault phase fault earth fault or SEF for which it is required to record a waveform must When the source of waveform triggers has been selected consideration should be given to the pre trigger recording Each waveform is 1 second long therefore for a delayed element the current could be present for a few hundr
234. ops during reclaim then the relay will perform the line check one trip to lockout 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 2 21 Auto reclose Commands Settings Sub menu Auto reclose Manual Close Delay OFF 1 2 10 Er Sub menu Status Config Gn Trip amp ARC 1 for each status aa ra Gn Close amp Lockin default Gn Trip amp Lockout Gn Local Close amp Reclaim Gn Remote Close Reclaim _ 1foreachstatusinput d efault 2 9 3 Frequent Operations Counter Argus 4 amp 6 relays incorporate a Frequent Operations Counter FOC which operates to prevent cyclical operations caused by multiple fault re occurrences or by setting interactions between AutoReclosers at different points in the system in response to a permanent fault While the FOC is exceeded it will act to truncate and modify a sequence to break the cyclical operation The FOC also acts to limit the number of Circuit Breaker operations per hour to the value set by the User For further details see section 2 14 1 4 2 9 4 Hot Live Line Working When maintenance is being performed
235. or single pole earth fault 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 High burden 110V amp 220V binary inputs compliant with ESI48 4 ESI 1 available via external dropper resistors with 48V binary input version for 1 binary input and 110 V application order resistor box VCE 2512H10066 in addition for 1 binary input and 220 V application order resistor box VCE 2512H10068 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20008 Page 7 of 33 7SG11 Argus 1 Diagrams and Parameters Product description Variants Order No Nondire tional O C relay 1SG111 C C OT AO Over current and earth fault protection for radial feeders capacitor banks and industrial and commercial plant Number of elements Three pole relay 3 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 110 220 V DC auxiliary 30 V binary input 24 30 48 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 48 V binary input 110 220 V DC auxiliary 110 V low burden binary input 110 220 V DC auxiliary 220 V low burden binary input uP WN FE Type of elements 3
236. or this feature The first is a rolling window which measures the average quantities over a rolling window of n minutes i e as new values are added old values are removed from the sum the average is calculated constantly The second method is a fixed window where the sum 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 ROLL 176 0 and will report the maximum quantities since the last user reset of this function Resetting the quantities can be done either from the setting Maximum Demand Reset the instruments screen or via an IEC60870 comms command Table 2 26 Data Storage Settings Sub menu Status Config Gn Waveform Trig The trigger must also be set to STAtus in the Data Storage menu _ 1 for each status input default Sub menu Data Storage Gn Fault Trigger _ 1 for each output contact default _ 1 Gn Waveform Trig _ 1 for each of P F E F SEF STAtus V default V applies only to Argus 2 type II Off Gn Waveform Pre Trigger OFF 10 20 100 Suggested setting 80 Clear All Waveforms Clear All Events NO YES Self resetting Yes No confirmation required Clear All Faults OFF ROLLING FIXED
237. orking ovo Table Showing Inputs MODBUS Address Description 10016 160 10021 10022 6 10023 16 E mito Recoge Active a gt s ER ER I oO O O O ED 2010 Siemens Protection Devices Limited P20008 Page 24 of 33 2 2 160 29 160 30 7 8 9 0 7SG11 Argus 1 Diagrams and Parameters MODBUS Address Description 36 X 160 64 A starter E 10084 16 84 160 28 CB on by auto recluse 160 130 Reclose blocked 16 21 SEF REF starter 11060 6 36 Setting G6 selected E 11077 16 53 Output3 11080 164 56 Output6 11081 16 E 11085 164 1 E Trip circuit fail 46 Group Warning 47 Alarm B starter eo C starter 67 E starter General starter X Circuit breaker open E Setting G5 selected ER 37 Setting G7 selected Setting G8 selected IA CB close fail CB DBI state I nput 5 BH Input 6 I nput 7 I nput 8 Input 9 51 Output1 52 Output2 Output4 Output5 57 Output7 58 Output8 59 Output9 Output10 Output11 Forward A Reverse A Forward B A 65 Reverse B Forward C 2010 Siemens Protection Devices Limited P20008 Page 25 of 33 7SG11 Argus 1 Diagrams and Parameters MODBUS Address Description 67 Reverse C 11091 164 11092 16 11093 11094 6 70 11103 16 79 E E E E 11134 A Forward E m OY Reverse E H rip count alarm O
238. orte oe ead ace enn aac cup ie cies eee Ep be oben pep ie Ru ER t D eDUd 4 SOCLIOD 2 SEUNG S scene quiescit CURE co RD Ds S Mec P II be ced tse boc aoc Ae oL HEN bleed MES baec 6 Section 9 IEC 60970 5 109 Deninitl ONS a Gor pene E Ee onde toe E Ud Roe apo Da LHA OER dR EE SS 14 Section 4 Application Diagrams eee eee 21 List of Figures Figure 2 1 Status Input and Output Relay Programming Marix sees eee eee eee eee 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 Directional Earth fault Protection 22 2010 Siemens Protection Devices Limited P20011 Page 3 of 22 Section 1 Variants This document applies to the Argus relays listed in the following table The MLFB Structure references the complete number for each relay e SGlinn nxxnn nxAO where n is a digit and x is a letter The table uses two references for most relays each of which is valid e an Order code of the form AGn nnn and e a Type of the form GAFnnnX where n is a digit and X is a letter Order code Type EODEM 30 48 aux Diagram 3 directional phase fault and AG6 403 AG6 404 i GAF921C GAF923C GAF924C 3 phase fault and directional earth Fia 4 AG6 405 AG6 406 9 GAF931C GAF933C GAF934C 2
239. otes 1 CT circuits are shown ABC connected to 1A inputs use 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG1 413 and AG1 414 5 Optional expansion card fitted only on models AG1 423 and AG1 424 6 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 Cn cn P L Cn I Ca Ln DIO Co On Rear RS485 comms port comms ports see note 4 see note 5 P300001 Argus 1 Connection Diagrams AG1 4x3 4x4 1 Figure 4 7 Typical Connection for 2 Phase fault Earth fault and Sensitive Earth fault Protection 2010 Siemens Protection Devices Limited P20008 Page 32 of 33 7SG11 Argus 1 Diagrams and Parameters BUSBARS AG1 4x3 4x4 Notes CT circuits are shown ABC q connected to 1A inputs use 4 5A inputs for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG1 413 and AG1 414 5
240. p test Additional features CB fail trip circuit supervision single pole models Apr2000 2434H80021 R6 Additional features New model variants Jan 2000 2434H80021 R5 Minor change current meter averaging Jul 1999 2434H80021 R4 Minor change status group select May 1999 2434H80021 R3 Additional features default instruments Mar 1998 2434H80020 R1 Additional features new expansion board 8Sl Additional features clock synchronisation using status input Additional features new directional SEF model and 90 characteristic angle available for E F and SEF Sep 1997 2434H80019 R4 Minor change settings displayed in ReyDisp Jul 1997 2434H80019 R3 Additional features status input pick up and drop off delays added Additional features CB fail trip circuit supervision all expanded I O models Minor change separate settings for P F E F and SEF current ratings Minor change sum of I setting range Apr 1997 2434H80018 R2 First release Argus 2 5xx software release history April 2434H80040 R4 2004 Jan 2004 2434H80040 R3 Minor change Min P F E F settings now 0 05 x In Additional Features Added CT Failure functionality Maximum Demand Added for la Ib Ic W Vars General Alarms added to scrolling fault screen 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Settings added to configure the IEC60870 class2 measurands Added WHr and VArHr meters Add setting to configure sign con
241. plied value E P20010 Page 7 of 22 Setting name Gn SEF REF Reclose DTL 1 Gn SEF REF Protection Trip 2 Gn SEF REF Reclose DTL 2 Gn SEF REF Protection Trip 3 Gn SEF REF Reclose DTL 3 Gn SEF REF Protection Trip 4 Gn SEF REF Reclose DTL 4 Gn SEF REF Shots To Lockout Gn SA ARC Gn SA Line Check Trip Gn SA Reclose DTL 1 Gn SA Reclose DTL 2 Gn SA Reclose DTL 3 Gn SA Reclose DTL 4 Gn SA Shots To Lockout Gn SA Trips To Block Gn Reclaim Time Gn Close Pulse Manual Close Delay Gn LO Recovery Cold Load Enable Cold Load Reset Output Relay Configuration Ref Applied value Menu See also Figure 2 1 on page 12 for the programming matrix Setting name Gn Prot Healthy Gn P F Starter Gn P F Charact Gn P F Lowset Gn P F Highset1 Gn P F Highset2 Gn E F Starter Gn E F Charact Ref Applied value e BI BI BID EI BD BI BI 2010 Siemens Protection Devices Limited 7SG11 Argus 4 Diagrams and Parameters Setting name Ref Applied value af mI BI ee RI RI RI mI ET ME INN E EE INN E Gn E F Lowset Gn E F Highset1 Gn E F Highset2 Gn SEF REF Starter Gn SEF REF Delay1 Gn SEF REF Delay2 Gn SEF REF Lowset Gn Status 1 Gn Status 2 BI BI P20010 Page 8 of 22 Gn Status 3 Gn Status 4 Gn Status 5 Gn Status 6 Gn Status 7 Gn Status 8 Gn Status 9 Gn CB Fail 1 Gn CB Fail 2 Gn ATrip Alarm Gn Counter Alarm Gn FOC Alarm Gn XI Alarm G
242. pm o 160 Rnz ne 2 t jm x 4 sojonsem O EA RO x Dw m emw E 3 1 E 164 21 SEFIREF stater x 2 19 RO x OTT S o LLL LL LL 164 23 SEFIREF lowsettip 2 1 RO x x 164 24 SEFIREF stage ip f 2 t JR x x 164 25 SEFIREF stazii 2 t JR x x 4 2 AHSisater o de t1 RO xx Lm afers HHHH Lr wj oHssme del te x AG 2 500 deese tll NM MM M NM NM NM One of Ia Ib Ie Isef depending on relay type 2010 Siemens Protection Devices Limited P20009 Page 19 of 37 7SG11 Argus 2 Diagrams and Parameters e eme dt sdf 7 aee od E Dm wpemew H ae of H Cw w emme H 2 fp e emmw E HE x Cw si eraoro x e rol 04 w owmwewz rol x e e meem HT se LLLI LOL Ito e mwesm x se Dw mmm 1 de Tr LLL OLLI ILILIL Cw lant x mm ro x x Dw eme HT 2 a Tre Dw e men HT 9 Tre 04 w mes O x Tr e e mes 5 re x x tes e mec x 9 re x Dw w mee HT 5 re x Dw e wmec 2 5 re x x AG 2 500 NN 313 313 NM NM K NM MBM PM NM I ND 2010 Siemens Protection Devices Limited P20009 Page 20 of 37 7SG11 Argus 2 Diagrams and Parameters e o waman 3 ae Rx x re me wenam x fe 9 e x ww n omwmewesm x Ja H x 168 aana x 3 ro del ros vo beta Tin Couneraem x
243. possible 4 Optional expansion card fitted only on models AG2 317 and AG2 318 5 Optional expansion card fitted only on models AG2 327 and AG2 328 6 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Rear RS485 comms port E E EG 5 g E 6 ag os Cc og Go ge C see note 3 Rear F O comms ports C B Phase rotation see note 4 see note 5 P300002 Argus 2 Connection Diagrams AG2 3x7 3x8 Figure 4 6 Typical Connection for 2 Phase fault and Directional Earth fault Protection Notes 1 CT circuits are shown connected to BUSBARS AG2 4x1 4x be tap use alternative tap for 5A rated S A BC L q 2 CT and earth connections are typical d only 3 Application shows use of Holmgreen connection for E F circuit Use of separate ring core CT is also possible 4 Optional expansion card fitted only on models AG2 411 and AG2 412 5 Optional expansion card fitted only on models AG2 421 and AG2 422 6 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Rear RS485 comms port Direction of power flow in the forward direction D see note amp Ea Phase rotation C see note 4 see note 5 P300002 Argus 2 Connection Diagrams AG2 4x1 4x2
244. r Operate Time to Contact sse eee 17 Figure 1 5 3 Instantaneous Highset Operate Time to Contact eee 17 Figure 1 5 4 Instantaneous Lowset Operate Time to Contact eee 17 Figure 1 5 5 Sensitive Earth fault Frequency Response ls 5 mA eee 18 Figure 1 5 6 Sensitive Earth fault Operate Time to COonacCt eee 18 Figure 1 5 7 Directional Timing Characteristic C sceri innin a r a i 19 Figure 2 1 1 Overview of Argus Relay Protection Functions eee eee eee ee 20 Figure 2 3 1 Functional Diagram Characteristic Phase fault Overcurrent Element 2f Figure 2 3 2 Functional Diagram Characteristic Earth fault Overcurrent Element 2f Figure 2 3 3 Functional Diagram Instantaneous Phase fault Overcurrent Elements 28 Figure 2 3 4 Functional Diagram Instantaneous Earth fault Overcurrent Elements 28 Figure 2 4 1 Functional Diagram Sensitive Earth fault Restricted Earth fault Elements 30 Figure 2 5 1 Functional Diagram Circuit Breaker Eai eee eee 32 Figure 2 5 2 Functional Diagram Current Transformer Eai sees eee eee 33 Figure 2 7 1 Functional Diagram Phase fault Directional Element sees eee ee eee ee 35 Figure 2 7 2 Functional Diagram Earth fault Directional Element see eee eee eee 35 Figure 2 8 1 Functional Diagram Undervoltage Overvoltage Element 3 Figure 2 11 1 Status 7
245. r P F and Dir E F with Open delta VT 2010 Siemens Protection Devices Limited P20009 Page 35 of 37 7SG11 Argus 2 Diagrams and Parameters BUSBARS AG2 5x3 5x4 Notes CT circuits are shown connected to ABC q 1A tap use alternative tap for 5A rated dq CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil 4 Optional expansion card fitted only on models AG2 513 and AG2 514 Rear RS485 comms port Direction of power flow in the forward direction Y see note 7 Rear E O comms ports 5 Optional expansion card fitted only on models AG2 523 and AG2 524 6 Application shows use of 5 limb star connected VT with neutral voltage derived internally 7 Rear RS485 port is an ordering option Connect wire link as shown to include 120W terminating resistor in circuit Phase rotation see note 4 see note 5 Argus 2 Connection Diagrams AG2 5x3to4 1 Figure 4 12 Typical Connection of Type AG2 5xx Dir P F and SEF with Star connected VT Notes 1 CT circuits are shown connected to BUSBARS AG2 5x3 5x4 1A tap use alternative tap for 5A rated ABC G CTs l 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high imped
246. r to the device and vice versa error correction and buffering should be turned off 2010 Siemens Protection Devices Limited P20007 Page 66 of 71 7SG11 Argus Technical Reference If possible Data Carrier Detect DCD should be forced on as this control line will be used by the Fibre optic converter Finally these settings should be stored in the modem s memory for power on defaults 4 2 17 Connecting to the Remote Modem Once the remote modem has been configured correctly it should be possible to dial up the modem and make connection to the relay As the settings on the remote modem are fixed the local modem should negotiate with it on connection choosing suitable matching settings If it cannot do this the local modem should be set with settings equivalent to those of the remote modem as described above ME SG4 103 Laptop computer P300007 Communications vsd Sigma 4 remote Figure 4 2 1 Communication to Argus Relay using Sigma 4 Local Connection Telephone Sigma 4 Tx Network SG4 103 Rx Laptop computer P300007 Communications vsd Sigma 4 remote Figure 4 2 2 Communication to Argus Relay using Sigma 4 and Modem Control System serial optical ring Laptop computer Sigma 3 SG4 103
247. re appear within the Relay Reset Delay time the current time integration continues from the last value reached Where the fault current does not reappear within the Relay Reset Delay time then the integrator will reset to zero and any subsequent fault will start a new integration of current time Thus for flashing faults where the fault current pulses reappear within the set reset time up to 60 seconds after the end of the last pulse the delayed characteristic will operate on the summation of the fault current time Where auto reclose is not required after a delay protection trip i e sequence 2 1D then the Relay Reset Delay time setting should be set to 60sec Where a delay protection trip is to be followed by auto reclose delay protection then this setting may be left at the default value of instantaneous or set to a time which is less than the reclose delay between consecutive delay protection operations Setting times as above will provide flashing fault coverage and still allow grading between relays in series on the system If this function is not required the Relay Reset Delay time can be set to INST Table 2 12 Flashing Fault Setting Sub menu Protection 2010 Siemens Protection Devices Limited P20007 Page 29 of 71 7SG11 Argus Technical Reference 2 4 Sensitive Earth fault and Restricted Earth fault This element can be used for either sensitive earth fault or high impedance restricted earth fault protection schemes
248. reaker Fail Settings Sub menu Protection Setting name Range bold default Gn P F CB Fail Setting OFF 0 05 0 1 1 00 xl 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 OFF 0 00 0 01 20 00 20 5 Gn CB Fail Time Delay 2 100 101 300 s Sub menu O P Relay Config Gn CB Fail 1 _ 1 for each output contact Gn CB Fail 2 default 2 5 2 Close Fail Argus 4 and Argus 6 only Circuit breaker close operation is also monitored The relay checks the status of the CB at the end of each close pulse If the CB has not closed then the relay locks out due to CB close fail and any sequence is terminated 2 5 3 Current Transformer Failure The current flowing from each of the Phase Current Transformers is monitored If one or two of the three input currents falls below the CT Supervision current setting for more than the CT Failure time delay then CT Failure is raised If all three input currents fall below the setting CT Failure is not raised 02010 Siemens Protection Devices Limited P20007 Page 32 of 71 7SG11 Argus Technical Reference CT Failure Current Setting 7 d CT Failure Time Delay 1 out of 3 lt le CT Failure CT Fail 2 out of 3 lt lere 3 out of 3 no op P300008 Protection Functions CTF Figure 2 5 2 Functional Diagram Current Transformer Fail Table 2 15 Current Transformer Fail Settings Sub menu Prote
249. rection reverse is P F Charact Setting similar On relays with no directional elements Z these inputs and settings are omitted I N P F Charact P F Charact Time Mult P F Charact Delay N N Relay Reset Delay P F Charact Inhib O Phase A starter sant m 21 la p Dir n A Fwd Phase B starter Phase B delayed trip EL trip P F Charact Phase C starter Phase C delayed trip Ib Fa Dir n B Fwd C Ic Dirn C Fwd o S amp o 1 P300008 Protection Functions Time Delayed P F Figure 2 3 1 Functional Diagram Characteristic Phase fault Overcurrent Element The earth fault pole similarly has its own delayed overcurrent element with its own starter setting and selectable IDMT DTL characteristic 7 This diagram shows the logic for overcurrent E F Charact Dir Control elements in the forward direction reverse is i similar On relays with no directional elements these inputs and settings are omitted i E F Charact Setting N E F Charact E F Charact Time Mult E F Charact Delay Relay Reset Delay E F Charact Inhib Earth starter E F Starter Earth delayed trip E F Charact P300008 Protection Functions Time Delayed E F le F Dir n E F Fwd 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 Highs
250. relay settings menu 4 1 1 Comms Protocol Setting The relay protocol can be selected from a default setting of IEC60870 5 103 to Modbus RTU whichever is 4 2 IEC 60870 5 103 Argus relays can communicate with control and automation systems or with PCs running ReyDisp software to provide operational information post fault analysis and settings interrogation and editing This section describes how to use the IEC 60870 5 103 compliant Informative Communication Interface with a control system or interrogating computer Appropriate software within the control system or on the interrogating computer e g ReyDisp Evolution is required to access the interface This section specifies connection details provided in the Argus relays For further information regarding the interface reference should be made to the separate Informative Communications Interface manual reference 434 TM 5 which covers all Reyrolle products See website www siemens com energy The same communications interface is used to provide control system connections and for dialogue communications by the protection engineer An appropriate IEC 60870 5 103 control system interface will be required for the former application while the latter is provided 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
251. rent 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 table with applied settings Setting name Applied value SET Alarm 3 System Config Menu Setting name Ref Applied value Active Settings Group R o Settings Group Edit View Cold Load Pickup Group Copy Group Power System Frequency Set Pole B Type Earth Fault Mode Select P F Rating In C SET Alarm 4 EE SET Alarm 5 Po FWD Name Tag NEN REV Name Tag 2 MEE Calendar Set Date 2 Clock Set Time 2 EE Clock Sync From Status MEN Default Screen Time LO NEN S Change Password E F Rating In SEF REF Rating In P F CT Rati 2 2 F CT Ratio Protection Menu E F CT Ratio For non directional settings use the Gn g settings ignoring the forward ig notation SEF REF CT Ratio 2 2 3 Setting name Ref pplied value Linesman Display Current Display Set Identifier SET Alarm 1 SET Alarm 2 A Gn i P F Charact Setting xin Gn P F Charact Dir Control Z Gni P F Charact EA Gn i P F Charact Time Mult a 2010 Siemens Protection Devices Limited P20011 Page 6 of 22 Setting name Gnl l P F Charact Delay Gn P F Charact Setting Gn gl P F Charact Gn P F Charact Time Mult Gn sl
252. rm this using a Yes No confirmation as described in section 2 1 1 2 but TEST RESET can also be used to confirm rather than pressing ENTER 2 1 3 Fault Displays As shown in Figure 2 1 the occurrence of a fault as defined by the Fault Trigger setting will cause the red trip LED to be lit and the trip display will be shown This gives the date DD MM and time HH MM SS of fault and the poles that were active at the time of trip 12 05 17 25 51 TRIPAE Pressing the TEST RESET key will extinguish the trip LED reset latched output relays and change the display to the scrolling fault display giving a more detailed fault record On the top line of this display the fault number 1 to 5 is displayed The bottom line gives the date and time of trip DD MM YY HH MM SS ssss the active group and then for each pole of the Argus relay Example 2010 Siemens Protection Devices Limited P20006 Page 14 of 37 7SG11 Argus User Manual Current at time of trip The voltage at time of trip certain Argus 2 models only Forward or reverse direction of current flow directional relays only Elements which were active above setting at time of trip Elements that operated for the trip to occur are indicated by lt gt around the element Fault 1 lt lt lt fault data gt gt gt where fault data is 25 02 01 17 25 51 2525 G1 PHASE A LS IDMTL lt HS1 gt HS2 IA 12 32xln Example This information scrolls along the bo
253. rminals and all other terminals connected together and to earth Satisfactory values for the various readings depend upon the amount of wiring concerned Where considerable multi core wiring is involved a reading of 2 5 to 3 0 megohms can be considered satisfactory For short lengths of wiring higher values can be expected A value of 1 0 megohm should not be considered satisfactory and should be investigated Remove temporary connections 4 2 3 Secondary Injection Tests Select the required configuration and settings for the application Note that the Argus may be connected as either a 1A or a 5A rated device The user should check this before commencing secondary testing For all high current tests it must be ensured that the test equipment has the required rating and stability and that the Argus is not stressed beyond its thermal limit 4 2 3 1 IDMTL DTL Characteristics Argus 2 and Argus 6 only If the Argus is to be employed for directional protection then all Directional Control settings should be set to OFF during the following tests Pick up and Drop off This test checks the accuracy of the current setting for the main overcurrent characteristic Note that SEF REF poles are considered later Inject single phase current into one of the current inputs Slowly increase the current until the gt Ils LED yellow operates and record the pick up current in Table 4 4 Reduce the current until the LED goes out and record this as th
254. s Directional relays can be applied to directional blocking schemes Both Ir and or earth fault blocking outputs operate for a phase fault in the forward direction Blocking inputs can be received via the status inputs each of which can be programmed to inhibit operation of any overcurrent protection element see section 2 2 2 1 Polarisation Phase fault Voltage polarisation is achieved for the phase fault elements using the quadrature voltage whereby each phase current is compared to the voltage between the other two phases i e la Vesec Ip VGA Ic Vas Two types of directional element exist referred to here as type and type Il On a relay with type directional ESI the phase fault characteristic angles can be user programmed to either 30 or 45 using the can be selected The characteristic angle setting should be matched to the approximate expected nominal angle of system fault i e the source impedance angle Earth fault Voltage polarisation is also used for earth fault elements comparing the earth fault current le 3lo against the system residual voltage Vn 3Vo 2010 Siemens Protection Devices Limited P20007 Page 34 of 71 7SG11 Argus Technical Reference In relays with type directional elements the residual voltage is obtained from the open delta connection of the tertiary windings of the line N voltage transformers The earth fault characteristic angles can be user programmed In relays with type I
255. s 30317 1000 oo ES 30319 Vc SECONDARY 1000 COS 30321 Vn SECONDARY 1000 vj 30323 Vab SECONDARY 1000 Sis 1000 ao T 30327 Tooni H ES 30329 3Phase Power 1 kW Slime 30331 3Phase Apparent Power 2 1 kva x 30333 3Phase ReactivePower 2 1 wae x Tuc pop e E AA 30343 Voltage Element Wesce iens secs pim t 30393 WHr Fowrd 2 1 kWHr xo 30395 WHr Reverse 2 1 wr xo 30397 VArHr Forward 1 kvarHr x 30399 VArHr Reverse 1 kVArdr x 30401 30403 IB PRIMARY Demand 1000 30407 30409 IB PRIMARY Max Demand 2 1000 30411 IC PRIMARY Max Demand 2 1000 30413 3Phase Watt Demand w a w x 30415 rese Var Demand 0 1 1 fva 30417 xs ee 1 a ee a Table Showing Holding Registers Description EM FORMAT SIZE WORDS MEA Time Times 2010 Siemens Protection Devices Limited P20009 Page 29 of 37 7SG11 Argus 2 Diagrams and Parameters Section 4 Application Diagrams The following pages contain example application diagrams for a variety of connections showing various hardware options BUSBARS AG2 101 102 Notes CT circuits are shown A BC d 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 4 Rear RS485 port is an ordering option Connect wire link as shown to include
256. s 8 Ref Applied value mI mI BI BI mI mI mI mI mI mI RI RI RI RI RI RI RI P20009 Page 12 of 37 Setting name Gn Status 9 Gn CB Fail 1 Gn CB Fail 2 Gn CT Failure Gn Counter Alarm Gn XI Alarm Gn PowerOn Count Gn Hand Reset Min O P Energise Time Ref Applied value elo BI BI es ew ew ews RI Status Configuration Menu See also Figure 2 1 on page 16 for the programming matrix Setting name Settings Group Select Inverted Inputs Gn P F Charact Inhibit Gn P F Lowset Inhibit Gn P F Highset1 Inhibit Gn P F Highset2 Inhibit Gn E F Charact Inhibit Gn E F Lowset Inhibit Gn E F HighSet 1 Inhibit Gn E F HighSet 2 Inhibit Gn SEF REF Delay 1 Inhibit Ref Applied value mI o 7SG11 Argus 2 Diagrams and Parameters Setting name Gn Status 1 P U Delay Gn Status 1 D O Delay Gn Status 2 P U Delay Gn Status 2 D O Delay Gn Status 3 P U Delay Gn Status 3 D O Delay Gn Status 4 P U Delay Gn Status 4 D O Delay Gn Status 5 P U Delay Gn Status 5 D O Delay Gn Status 6 P U Delay Gn Status 6 D O Delay Gn Status 7 P U Delay Gn Status 7 D O Delay Gn Status 8 P U Delay Ref Applied value The text of these setting names reflects the value applied to the Set Alarm n settings in the System Config menu Gn SEF REF Delay 2 Inhibit Gn SEF REF Lowset Inhibit Gn V Inhibit Gn Trip Circuit Fail Gn Waveform Trig Gn El Update Gn Reset Flag amp Outp
257. s Limited P20006 Page 29 of 37 7SG11 Argus User Manual SEF REF Table 4 12 Pick up Drop off Results for SEF REF Pick up settin Measured Error Measured Error p g pick up 5 of setting drop off gt 95 of Pick up SEF REF Error 5 or 30 ms of setting 4 4 1 2 Circuit Breaker Fail Table 4 14 Pick up Drop off Results for CBF Level Detector Pick up settin Measured Error Measured Error p g pick up 5 of setting drop off 29596 of Pick up seh o o o LL Phase C Table 4 15 Circuit Breaker Fail Timing Results Error 2596 or 30 ms of setting 02010 Siemens Protection Devices Limited P20006 Page 30 of 37 7SG11 Argus User Manual 4 4 1 3 Directional Tests These tests apply to Argus 2 and Argus 6 relays only Table 4 16 Directional Boundaries of Operation Reverse ao anma Reeme 00 M T A Lag point C Lead point A Lag pointB Lead point D Pickup Drop off Pick up Drop off Pick up Drop off Pick up Drop off ee eee eee eee 4 4 2 Autoreclose Sequences These tests apply to Argus 4 and Argus 6 relays only Table 4 17 Auto reclose Sequences and settings AL E ICI mt 1 Lo lol CL MEMNME 4 ll pese EN Redeedii EP pese A pese meesms 1 1 IES pese OOO MEN memi ll es MEE A 5 1 ll Hiohset 1 Tepe to Lockout MILL Hiohset2 Trips te Lockout 8 MEME pue 7 1 1 1 2010 Siemens Protection Dev
258. s and 110 V application order resistor box VCE 2512H10064 in addition for 1 binary input and 220 V application order resistor box VCE 2512H10068 in addition for 5 binary inputs and 220 V application order resistor box VCE 2512H10067 in addition for 9 binary inputs and 220 V application order two resistor boxes VCE 2512H10067 in addition Refer to website for application note about ESI48 4 compliance 2010 Siemens Protection Devices Limited P20008 Page 9 of 33 7SG11 Argus 1 Diagrams and Parameters Product description Variants Order No Nondire tional O C relay 71561110 20000 on0DAO A A A A A A Over current and earth fault protection for radial feeders capacitor banks and industrial and commercial plant Number of elements Four pole relay fixed 1 0 5 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 0 110 220 V DC auxiliary 30 V binary input 1 24 30 48 V DC auxiliary 48 V binary input 2 110 220 V DC auxiliary 48 V binary input 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 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 amp 220V binary
259. s the IDMTL DTL Characteristic Pick up Drop off tests Record the results in Table 4 12 Confirm that the measured Pick up level is within 5 of the set value and that Drop off occurs at 29596 of the measured Pick up value Timing The timers used in the SEF REF mode are operated sequentially Separate contacts must be configured for timer 1 and timer 2 in order that operation of each timer is checked Set the operating time on timer 1 to the required time and connect a time interval meter to the contact configured for timer 1 Inject a current at least three times the setting and record the time Set the operating time on timer 2 to the required time and connect a time interval meter to the contact configured for timer 2 Inject a current at least three times the setting and record the time The operating time is the addition of time 1 and time 2 Subtract time 1 from time 1 2 to get the operating time for timer 2 Note that the SEF REF pole has an additional available timer that is referred to as the lowset delay this should be tested if required by the application Record the results in Table 4 13 and confirm that the measured delays are within 5 of the set values 4 2 3 4 Circuit Breaker Fail To measure the pick up level temporarily set a status input to operate the external CBF function then invert the input this enables the element The delay time should be set to zero Inject current and record the pick up level in Table 4 14 T
260. 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 input is raised at the same time the group associated with the lowest number status input takes precedence e g Status 2 Group 8 takes precedence over Status 3 Group 2 Change of group takes typically 15 ms but less than 17 5 ms Argus 2 500 series relays with a type Il voltage input can also be programmed to change settings group on the operation of the voltage element forcing a group change regardless of any starters which may be raised This function can be used to set up the Argus 2 to implement Voltage Controlled Overcurrent operation Change of group takes typically 40 ms but less than 50 ms Table 2 2 Settings Group Settings Sub menu System Config Active Settings Group 42 8 Settings Group EditView 1 Copy Group From 1 2 8 to 1 2 8 Sub menu Status Config Settings Group Select _ 1 2 8 for each status input Argus 2 type Il relays can change and Vop default settings group from operation of the voltage element 2 2 2 System Frequency 2010 Siemens Protection Devices Limited P20007 Page 22 of 71 7SG11 Argus Technical Reference Table 2 3 System Frequency Setting Sub menu System Config Setting name Range bold default Units 2 2 3 Current and Voltage Inputs Input Type Selection On 3 pole models and 4 pole mode
261. splay group is controlled by the Display Group setting 2 1 1 1 Password Entry If at any point a password is required the screen will display Enter password and a four character field The password is entered as described for settings changes above On pressing ENTER if the password is correct the user is logged in and editing will be allowed The user will remain logged in for an hour after the last key press after which he she will be logged out and the password must be re entered for further changes To change the password the Change Password setting in the System Config sub menu should be edited If an attempt is made to change the password the user will first be logged out and will have to log in again to prove authenticity After changing the setting the user will be asked to confirm the password by re entering it If no password has been set the text NOT ACTIVE will be shown as the setting value of the Change Password setting If a password has been set the setting value will be shown as either a 7 or 8 digit number If the password is forgotten this 7 or 8 digit number can be communicated to Siemens Protection Devices Limited by an authorised person and the password can be decoded If a password has been set it can be removed by entering the text NONE into the Change Password setting 2 1 1 2 Yes No Confirmation Some settings require further confirmation of change using Yes No confirmation When
262. t the sealed polythene bag should not be opened until the Argus is to be used If damage has been sustained a claim should immediately be made against the carrier also inform Siemens Protection Devices Limited When not required for immediate use the Argus should be returned to its original carton and stored in a clean dry place The Argus relay contains static sensitive devices These devices are susceptible to damage due to static discharge and for this reason it is essential that the correct handling procedure is followed The Argus relay s electronic circuits are protected from damage by static discharge when it is housed in its case When the relay has been withdrawn from the case static handling procedures should be observed as follows e Before removing the Argus from its case the operator must first physically touch the case to ensure that he she is at the same potential e The Argus relay must not be handled by any of the terminals on the rear of the chassis e Argus relays must be packed for transport in an anti static container e Ensure that anyone else handling the Argus is at the same potential As there are no user serviceable parts in the Argus relay then there should be no requirement 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 Recommende
263. t and SEF O1 4 20090 2 directional phase fault and directional earth fault 2 phase fault and dir n earth fault O1 4 20090 o o noou 3 directional phase fault and directional earth fault X T l O noou 3 directional phase fault and SEF SO OL O0 3 phase fault and directional earth fault co 7SG11 Argus 2 Diagrams and Parameters Product description Variants Order No Dire tional O C relay 78G112 r E Kr Kr Kr Kr Kr Kr gt e Ideal for directional overcurrent and earth fault protection of solid ring systems utilising the fully independent Number of elements bi directional feature Single pole relay 1 Auxiliary supply binary input voltage 24 30 48 V DC auxiliary 30 V binary input 0 110 220 V DC auxiliary 30 V binary input 1 24 30 48 V DC auxiliary 48 V binary input 2 110 220 V DC auxiliary 48 V binary input 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 Single pole earth fault directional G 2 Single pole 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 interfa
264. te a TCS Alarm will be generated if the trip contact is latched 3 9 Output Relays The output relays in the Argus range can be programmed to be self or hand reset In the hand reset mode a status input can be programmed to electrically reset the hand reset output relays In Figure 3 2 1 if the transformers at A and B are for example 132 33kV or 132 11kV and on the 132kV side there are no local circuit breakers but motor operated isolators then the reverse characteristic elements can be programmed to operate a hand reset output relay This relay can be wired to give an intertrip signal and initiate 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 event of a fault 3 10 1 Events Fault and Waveform Records Fault records provide textual information on the source of the trip within the Argus i e the element that tripped and any elements that were picked up at the time of trip This gives the first indication of the type of fault However the fault record should be examined in coordination with the event records to see the full sequence of events leading to a trip It is possible to identify devel
265. tection eee eee 58 3 6 Circuit Breaker Fail Protection iii as 60 J AUTO TECOS eie Ier lo M I 60 3 7 1 Reclose Time SONO anie Er adt don opa cave pa PO avit oM e al c aoa dolet dented duca le aea T Dou Cedo dus 60 de Reclaim TIMES cunda a 60 3 13 Shots to Locko t Setting vencida ia 61 SrA Sequence Auto Tecos ii ii A ns 61 3 0 MP ey aE SUPE a lue ce ite ete ae eas 61 359 OUP REI YS ii A A a Ada se Sais age gua dos 62 3410 TosbliaulE Analysis Soviel audemus letus A ge tated enti as a e 62 3 10 1 Events Fault and Waveform Records arara 62 SN Ze NT 62 Is 10 31 VWave tor mig ers os ducc eta gos coi clictamee istae etes io ea DI SE 63 3104 dIxeyDisp lEGC 60970 5 2109 5 oir a RAE UE ua LA LE 63 Section 4 Communication Interface ice eee I chore a vo eter le C Ue En vu a Do Duo a o aus Re vo i 64 N Tais sse Te E EU P 64 4 1 1 COMMS Protocol la eO Rc 64 Becr oor A NR 64 4 2 1 Physical CONNECCION sic seach TU EE 64 422 ING CIN sas eset costa Las en c tete pasce cete t sro oxen pas ance eae utes ipod discard exer oe cL De 64 4 2 9 Recommended Cable used id vero taco eee dites ater genie A Mee ER edad es bags Dea deest unu dE ed 64 424 NetWork TODOlO9y suits ates ed te rha re o Sou bad nee aea dent td ione tue duds 65 c cde ecc 65 4 2 6 IEC Class Il Measurands ccccocccccccncccnnccccnnconnnonnnncnnnnnnonnnnnnnnnonnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnaninnos 65
266. tection Devices Limited P20007 Page 2 of 71 7SG11 Argus Technical Reference 299p JBobtbive LINE WO lado id 44 2 10 Trip Circulb SUBEIVISION squad peditiortu dai e Oase ebbe oed PE outta eoa load Rae te 45 2 11 Status Inputs and Relay OQU EDUIS cereus IHE ce iae RE eines RE qum itta a E quib estos Bad SU deb a etd ou 45 2 12 OMAN CA ON Sos Ia 47 P Data o lord Ort id 47 ZAG Event Storage iii td E i 47 SN A cee Se eee 47 2 13 3 Waveform Disturbance Records ccccccccccsseeccseseecceeececseuseecseseeseuecesseeeesseseeessuseessenseesas 48 2 13 4 Maximum Demand Function sss sese eee eee 49 ZA Mate and a as 50 21a Circuit Breaker Operations o a Le ae aan 50 2 142 Ouiput Relay Test abas ni A teca titres ee utei eade ee pes 51 2 14 3 Internal SUDEIVISION tecta pa A lado elos 52 2 Enesman ModE uma scent so aioe IR 52 sections Application Notes uou oec Soto Deu ada o 54 3 1 Selection of CharacteriStiCS ooocccconncconncoccnnccnnncconnononnnoncnnnnnnnnnnnonnnnnnnnnnnnnnnnnnnnnnnnnnrnrnnonannnnnnnnnnnnnnns 54 3 1 1 ai 0B Rec E 54 Se Direcional Sre ee e e a EN 54 3 2 1 Parallel or Ring Feeder Protection ccoocccoconccconoconcnnnnonccnanonnnnnnononcnnnnnonanonononcnnnnonanononons 54 30 wehsitive Earii raulb Profe HOD uas a o o di ca Ce bae 55 9T e lt e e Tei 56 B sbDar Zone ProteclOL icc fate sorgo e se o Sn Riot aoa tie guna of 3 5 High Impedance Restricted Earth fault Pro
267. ted to ABC 4 7 1A tap use alternative tap for 5A rated 4 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 Direction of power flow in the forward direction Rear F O Dn 794 a Da BoY d Phase rotation P300004 Argus 6 Connection Diagrams AG6 401 402 Figure 4 1 Typical Connection for 3 Directional Phase fault and Directional Earth fault 2010 Siemens Protection Devices Limited P20011 Page 21 of 22 7SG11 Argus 6 Diagrams and Parameters Notes BUSBARS A ES 1 CT circuits are shown connected to ABC S 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Application shows use of SEF REF as an SEF input Use of the input for high impedance REF requires an additional setting resistor and may also require a metrosil Direction of power flow in the forward direction Rear F O C Phase rotation P300004 Argus 6 Connection Diagrams AG6 403 404 Figure 4 2 Typical Connection for 3 Directional Phase fault and Sensitive Earth fault Notes BUSBARS us 1 CT circuits are shown connected to ABC S 1A tap use alternative tap for 5A rated CTs 2 CT and earth connections are typical only 3 Applica
268. th issue VA Tech references replaced by Siemens Protection Devices Ltd 2006 03 Third issue Additional modifications software revision histories updates Second issue Improved CBF function additional metering Modbus protocol extended timers 2004 05 added 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 R10 release date November 2005 Argus 2 500 2434H80040 R8 release date November 2005 Argus 4 and Argus 6 2 16H80005 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 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 pr
269. that the thermal limit is not exceeded 1 Switch on the test supply and quickly raise the current to just below 95 of the set value and then switch off the test supply immediately Switch back on and then off in quick succession to prove non operation Do this five times with a delay between each test of about 10 seconds Test similarly at 10596 of setting to prove operation Switch off reset the trip indication and then switch on and off five times quickly to prove operation for each injection If a computer test set is being used then the pick up level and timing can be measured provided that the automatic test is set up to apply pulses of current to avoid exceeding the thermal limit Timing The operating time should be tested with a current of 5 times setting applied and with the required time delay set Output contacts for the Low Highsets must be programmed and a time interval meter connected to the correct terminals The timer should be started by the source and stopped by the Low Highset contacts Each phase should be tested Record the results in Table 4 9 Table 4 10 and Table 4 11 and confirm that the measured delays are within 5 of the set values 2010 Siemens Protection Devices Limited P20006 Page 20 of 37 7SG11 Argus User Manual 4 2 3 3 SEF REF Pick up and Drop off For Argus relays with the SEF REF element fitted then the current setting should be checked for this pole This can be achieved in the same manner a
270. the Edit View Group are selected in the System Configuration Menu Elsewhere in the settings menu system those settings that can be altered for different groups are indicated by the symbols G1 G2 etc in the top left of the display All other settings are common to all groups 4 2 Tests 4 2 1 Inspection Ensure that all connections are tight and correct to the wiring diagram and the scheme diagram Record any deviations Check that the Argus is correctly programmed and that it is fully inserted into the case Refer to Section 2 Operation Guide for information on programming the Argus 4 2 2 Insulation Tests Connect together all of the C T terminals and measure the insulation resistance between these terminals and all other terminals connected together and to earth Connect together the terminals of the DC auxiliary supply circuit and measure the insulation resistance between these terminals and all other terminals connected together and to earth Connect together the terminals of the DC status input circuits and measure the insulation resistance between these terminals and all other terminals connected together and to earth Connect together the terminals 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 te
271. the confirmation screen appears the edit field will be flashing N for No Use the up or down v 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 displayed pressing ENTER toggles its default instrument status on and off A default instrument is one that is displayed automatically by the Argus after no keys have been pressed for a period A number of default instruments can be set in which case they will be cycled in turn for 5 seconds each The period before the default instruments are displayed is controlled by the Default Screen Time setting in the System Config menu If an instrument is set as a default instrument this is indicated by a L1 in the top right corner of the display While a default instrument is being displayed pressing any key except TEST RESET will revert the display to that being displayed before the default instrument was activated 2 1 2 2 Resetting Counts Some instruments show count or summation values e g Trip Count Sum of These can be reset using settings within the relevant sub menus Pressing the TEST RESET key while the appropriate instrument is displayed will also reset them You will be asked to confi
272. 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 Setting name Ref Applied value System Config Menu Setting name Active Settings Group Settings Group Edit View Copy Group Power System Frequency Set Pole B Type Earth Fault Mode Select Phase Rotation P F Rating In E F Rating In SEF REF Rating In P F CT Ratio E F CT Ratio SEF REF CT Ratio VT Connection VT Primary VT Secondary Ref Applied value es 2010 Siemens Protection Devices Limited Current Display Export Power Lag VAr Sign Set Identifier Set Alarm 1 Set Alarm 2 Set Alarm 3 Set Alarm 4 Set Alarm 5 FWD Name Tag REV Name Tag Calendar Set Date Clock Set Time Clock Sync From Status Default Screen Time Change Password es E E P20009 Page 10 of 37 Protection Menu For non directional settings use the Gn g settings ignoring the forward g notation Setting name Ref Applied value mI mI Gn P F Charact Dir Control Gn A P F Charact Setting Gnl l P F Charact Gn P F Charact Time Mult 7 Gnl l P F Charact Delay sec Gn gl P F Charact Setting xin Gn P F Charact 50 1 Gn P F Charact Time Mult SE o Gnl P F Charact Delay sec Gn P F Lowset Dir Control E Gnl l P F Lowset Setting xIn Gnl l P F Lowset Delay sec Gn P F Lowset Setting
273. tion shows use of Holmgreen connection for E F circuit Use of separate ring core CT is also possible Direction of power flow in the forward direction see note 3 Rear F O C B Phase rotation P300004 Argus 6 Connection Diagrams AG6 405 406 Figure 4 3 Typical Connection for 3 Phase fault and Directional Earth fault Protection 2010 Siemens Protection Devices Limited P20011 Page 22 of 22 www siemens com energy
274. ts ARC Status and ARC Inhibits Instruments 2 9 1 1 Protection and Auto Reclose Sequences The following clauses describe the functionality of each setting in the Auto Reclose Menu for the Phase Fault sequence Identical settings and comments apply to the Earth Fault Sensitive Earth Fault and External Arc Start via Status ARC start SA sequences Each Settings Group G1 C2 G8 can have different Auto Reclose sequence settings or none applied by the User Gn Line Check Trip ON OFF Line Check Trip Switch on to fault function is activated and remains activated until the Reclaim Timer resets The Line Check function ensures that if the circuit breaker is closed onto a permanent fault or if the circuit relay will perform only one trip to Lockout The relay will trip but it will not reclose nor go through an auto reclose sequence 2010 Siemens Protection Devices Limited P20007 Page 38 of 71 7SG11 Argus Technical Reference The protection applied for Line Check Trip can be set independently for P F E F SEF REF and or SA to either settings An example of this setting s use is that after a lockout state is reached the user can set Line Check Trip to OFF so that when the Circuit Breaker is then manually closed onto a permanent fault the relay is forced to go through an auto reclosing sequence to ensure that sectionalising grading occurs to isolate a permanently faulted section of If set to IN on the relay will perform a full
275. ttom line of the display This record can be viewed again later in the Fault Data displays The five most recent faults are stored with the oldest being lost when a new fault occurs The five faults are numbered from 1 to 5 with fault 1 being the most recent 2 1 4 Software Information The identity of the software present in the Argus can be displayed as follows Ensure that the Relay Identifier is displayed on the LCD if necessary press the CANCEL key until it shows Press and hold the CANCEL key then press the TEST RESET key then release the CANCEL key and TEST RESET key together The software article numbers and revisions will now be displayed on the LCD Press any key to return to the Relay Identifier 2 1 5 Operation with Front Cover Fitted When the clear plastic cover is fitted only the down and right gt TEST RESET keys are accessible using through cover buttons These 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 v and gt 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 comms only Reydisp Evolution provides the means to achieve the following Get upload a settings file from the Argus Download a setti
276. twork cccooooccccocccccccocconccnoconononononnnanononnancnnononcnnnnos 67 Figure 4 2 4 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 1 and Fibre optic Star Network eee eee ee 68 Figure 4 3 1 Communication to Argus Relay using Sigma 4 Local Connection 69 Figure 4 3 2 Communication to Multiple Argus Relays from Control System and Laptop with Sigma 1 and Fibre optic Star Network eee eee ee 70 Figure 4 3 3 Communication to Argus Relay using RS485 RS232 converter Local Connection n 70 Figure 4 3 4 Communication to Argus Relay using RS485 RS232 converter Multidrop reple E 70 List of Tables Table 2 1 Overview of Functional Description Sections se eee ee eee 21 Table 2 2 fne S Group s Tas NE EO a 22 2010 Siemens Protection Devices Limited P20007 Page 4 of 71 Table 2 3 Table 2 4 Table 2 5 Table 2 6 Table 2 7 Table 2 8 Table 2 9 Table 2 10 Table 2 11 Table 2 12 Table 2 13 Table 2 14 Table 2 15 Table 2 16 Table 2 17 Table 2 18 Table 2 19 Table 2 20 Table 2 21 Table 2 22 Table 2 23 Table 2 24 Table 2 25 Table 2 26 Table 2 27 Table 2 28 Table 2 29 Table 2 30 Table 2 31 Table 4 1 Table 4 2 2010 Siemens Protection Devices Limited 7SG11 Argus Technical Reference System Frequency SOU iio 23 Current and Voltage Input Settings ccooocccnconccnncnoncncnnanononnnnnnnnnnnnnonnncnn
277. u mrs je Remm jen CORE fu bem je Data Storage Menu Swamme T Setting name eame fest o eem fens EST O oner E rnr ens CB Maintenance Menu a meme LX O recens e RR ECC e rar e RN EEN e O wes pe Bram O fu r er P20011 Page 10 of 22 Setting name Power On Count Alarm O P Relay Test Linesman Menu Setting name Scada Control Hot Line Working Trip amp Lockout Ref Applied value Ref Applied value TIN EL 2010 Siemens Protection Devices Limited 7SG11 Argus 6 Diagrams and Parameters Setting name Ref Applied value es Em Trip amp Reclose Close amp Reclaim E NN Inst Lowset Trip Counter Reset P20011 Page 11 of 22 91 2 S3 S4 S5 S6 7 S8 S9 O O o O o o o O o Inverted Inputs Pick up Delay ms Drop off Delay ms SOCO DOD OO Latched inputs time delayed overcurrent P F Charact Inhib Relay Identifier 7SG11 Argus 6 Diagrams and Parameters Relay Address Settings Group Cold Load Gp R1 A200 R2 00 o R3 06 o QO QO QO QO ao R10 Qo QO O R4 R5 R6 RT O R8 R9 ORM Prot Healthy Settings Group self supervision Select 51 P F Charact A A A M A Ny A Mx A M 6 y A M a x
278. ued the trip fault trigger Phase A current was 12 32 xln On phase B the lowset delayed characteristic highset 1 and highset 2 were picked up with a current of 12 23 xin On phase C the lowset element was picked up with a current of 0 78 xin The earth fault lowset and delayed characteristic elements were picked up with a current of 0 27 xln and a General alarm BUCHHOLZ TRIP was raised Basically a Phase A to B fault with some Earth fault component Phase C unfaulted 2 13 3 Waveform Disturbance Records Waveform Record storage is a digital graphical record of analogue current and for Argus 2 type II voltage inputs status inputs and relay outputs Each record is one second in length and is triggered from a protection element operating or from a status input as 2010 Siemens Protection Devices Limited P20007 Page 48 of 71 7SG11 Argus Technical Reference phase fault P F earth fault E F SEF Status input STA and or Voltage element operation When status input Note Unless the correct settings are applied as described above then no waveform record may be stored in the event of a fault When storage is triggered some pre trigger waveform may be stored the percentage of which is specified by the 2 13 4 Maximum Demand Function This feature enables the relay to perform an average and maximum demand function of the following measured quantities Watts AG2 5 only VArs AG2 5 only There are two user configurations f
279. uirements Where necessary a single external dropper resistor in parallel can be fitted to meet ESI 48 4 ESI 1 requirements Low Burden Status Input performance Nomina Operating Range Typical burden 110 125 87 5 to 137 5 V DC 1 75 mA to 3 0 mA 175 to 280 V DC 1 75 mA to 3 0 mA 110 125 V minimum pick up voltage typically 50 60 V d c 220 250 V minimum pick up voltage typically 100 120 V d c 1 3 Output Contacts Contact rating to IEC 60255 0 20 Cary continousy BA ARO AC resistive 1250 VA Break lt 5A and x 300 V l 30 W at L R x 40ms DC inductive 50W atL R lt 10ms Minimum number of operations 1000 at maximum load Minimum recommended load 0 5 W at minimum of 10mA or 5V 1 4 Functional Performance 1 4 1 Phase fault Overcurrent Protection A time delayed characteristic IDMTL DTL and 3 instantaneous DTL characteristics Lowset Highset 1 and Highset 2 are provided 1 4 1 1 Time Delayed Characteristic Operate Level 7 000000000 Variation 47 Hz to 52 Hz 57 Hz to 62 Hz lt 5 harmonics to 550 Hz Operate Time EN Starter operate time See Figure 1 5 2 5 ms char Characteristic setting range NI IEC type A VI IEC type B El IEC type C LTI DTL 2010 Siemens Protection Devices Limited P20007 Page 9 of 71 7SG11 Argus Technical Reference Attribute Value T Time multiplier setting range 0 025 0 050 1 600 Delay setting range 0 00 0 01 20 00 20 5
280. ult on any feeder the instantaneous starter contact sends a blocking signal to inhibit operation of the high speed protection on the incomer see Figure 3 4 2 This inexpensive logic type protection has been widely applied and has an excellent operating record However if any of the outgoing circuits can feed power back on to the busbars as can happen in an interconnected network then simple non directional busbar blocking protection cannot be applied Incomer Block HS1 Inhibit a CBF trip Radial Substation HS2 FWD HS2FWD HS2 FWD HS2FWD CBF trip CBF trip CBF trip CBF trip P300005 Application Diagrams Busbar Sgl Src Figure 3 4 2 Busbar Zone Protection with Circuit Breaker Fail using Non directional Relays For use on Single source Feed Networks Where a Busbar fault can be back fed via a feeder then directional Argus relays can be installed on each circuit and employed as shown in Figure 3 4 3 Phase and Earth 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 with current above HS1 setting will be tripped Phase and Earth Fault HighSet 2 Forward elements HS
281. up oem on m m x sr setae Grup 7er on xo w swmsGmsssma ON Po T IS IE s e ww 5 o m mewsowu o o o x o Cremos ww w mewsomus on o o o w mewsomus o o x m mewsowas o o o x w sewsowar o o x w mewsomus o m m m mewsomus o m m eseou o m o m mewmomun o m m Do T IS IR E to nge on 5 o Coo T H e Tiperaicacn onjo o sa coseanareean on m m o 04 menare o m m x aan fono o m OL ILICE larar owor m 3 id Do T IS II to DE CE o 0L TT TT EXC o E nal erne mer onor a o o m sracmm owrr m 3 ETE ECC xo DIE E 3 E ETT owr m o E name owr m 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 164 02010 Siemens Protection Devices Limited P20011 Page 20 of 22 7SG11 Argus 6 Diagrams and Parameters Description 164 119 Hot line working ON OFF 20 2 oo Note Events listed as responding to a General Interrogation Gl will be raised and cleared RC other events are raised only RO and do not respond to a Gl Section 4 Application Diagrams The following pages contain example application diagrams for a variety of connections showing various hardware options Notes BUSBARS 1 CT circuits are shown connec
282. utput relays 3 changeover 2 normally open e 5 status inputs 11 output relays 3 changeover 8 normally open 2010 Siemens Protection Devices Limited P20006 Page 5 of 37 7SG11 Argus User Manual e Ostatus inputs 7 output relays 3 changeover 4 normally open Single pole Argus relays are only available with 1 status input and 7 output relays Status Inputs Status inputs can be programmed to perform one or more of the following functions Switch to an alternative settings group Trigger the storage of a waveform record Trigger a textual fault record Trigger operation of the summation and trip count features Inhibit operation of any one or more protection functions Monitor the health of the tripping circuit Synchronise the real time clock Reset of latched output contacts Reset of counter instruments Start an auto reclose sequence Register a general alarm Initiate an external circuit breaker fail condition Additionally each input can be independently programmed to operate with time delayed pick up and or time delayed drop off The status inputs have a default pick up delay setting of 20ms which provides security against operation in the presence of an a c input voltage If instantaneous operation is preferred then the pick up delay should be set to zero It is also possible to invert the operation of a status input If an input is configured to be inverted then any function assigned to that input becomes active upon de
283. uts Gn Clock Sync Comms Interface Menu Setting name Ref Applied value E D m 02010 Siemens Protection Devices Limited P20009 Page 13 of 37 Setting name Relay Address Line Idle Data Echo Data Storage Menu Setting name Gn Fault Trigger Gn Waveform Trig Gn Waveform Pre trigger Clear All Waveforms Clear All Events Clear All Faults Demand Window Type Demand Window Ref Applied value Ref Applied value ea l l l l l l 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Applied value CB Maintenance Menu e we en ew Setting name Ref Maximum Demand Reset Trip Counter Reset Trip Counter Alarm 21 Reset I Alarm ewe ew em Be Power On Count Reset Power On Count Alarm Energy Meter Reset O P Relay Test P20009 Page 14 of 37 81 2182 S3 S4 S5 6 7 S8 9 O O O o QO O O O 1 N ie pro T E OA es A A J Prot Healthy Ld pud RIO Settings Group self supervision PO O O O O O O O a V Starter 7SG11 Argus 2 Diagrams and Parameters Relay Identifier Inverted Inputs Relay Address Pick up Delay ms Drop off Delay ms R3 o O o eX GL R7 A A QO R10 Qo QO R11 51 P F Charact P F Starter non dir fwd
284. vention for export import of power Vb and Vn now displayed in fault screens in 3P SEF variant Vop can change setting group when starter is energised MODBUS added Added la lb lc le Isef Va Vb Vc Vn ASDU4 measurands for fault information Timers extended to 300s CBF Level detectors added Jul 2003 2434H80040 R2 Minor change Sampling buffer modified 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 Additional features introduction of new models with star connected VTs Appearance change modification to grey fascia design logo dark grey band buttons and label External change SMA fibre optic connectors replaced by sT BFOC 2 5 by default Appearance change introduction of grey fascia design to replace existing black fascia External change introduction of Epsilon case and terminal blocks Additional features introduction of new expansion board 9511 First release 2010 Siemens Protection Devices Limited 7SG11 Argus 2 Diagrams and Parameters Contents doriware Release HIStory nia Rid UOS REN EU RTI FCR Fa dU END 2 Hardware Release HIStory xs zcssksyasesasgsyasyasexaze sss eir euos esl epos sit Lado uo V pee sv epo su acu cu ao NOU ue DX inss sas PR YI DEM E REC anais 3 contenidas 4 ISU OF FIQUIOS ct E R HEE R E 4 Section Ue VaFIants
285. vercurrent Elements The earth fault pole similarly has its own Instantaneous Lowset Highset1 and Highset2 overcurrent elements with their own starter settings and selectable DTL characteristic d This diagram shows the logic for r E F Lowset Dir Control overcurrent elements in the forward C RIE Lowset Setting direction reverse Is similar On relays with no directional elements these E F Lowset Inhib inputs and settings are omitted Y E F Lowset Delay le Earth lowset starter E F Lowset Dir n E F Fwd P300008 Protection Functions Instantaneous E F Figure 2 3 4 Functional Diagram Instantaneous Earth fault Overcurrent Elements Table 2 11 Phase fault and Earth fault Overcurrent Settings Sub menu Protection Setting name Range bold default Notes SE Charact Dir OFF FWD REV TRI B Argus 2 and Argus 6 only Gn P F E F Charact Setting Gn PIFIEF Characi Gn PIF E F Charact Time Mult 0 025 0 050 1 000 1 600 xt ee note 1 below Gn P F E F Charact Delay 0 00 0 01 5 00 20 00 20 5 100 101 300 Gn P F E F Lowset Setting OFF 0 05 0 10 1 00 3 00 PM 9 5 4 0 52 5 Gn P F E F Lowset Delay 0 00 0 01 20 00 20 5 100 101 300 CE EIE Highset 1 Dir OFF FWD REV TRI Argus 2 and Argus 6 only Gn P F E F Highset 1Setting AU d xin see note 1 below 2010 Siemens Protection Devices Limited P20007 Page 28 of 71 7SG11 Argus Technical Reference Gn P F LE H
286. wn keys to select Y and confirm Table 2 29 Internal Supervision Setting Sub menu O P Relay Config Gn Prot Healthy _ 1 for each output contact Gn PowerOn Count _ 1 for each output contact default 1 ia menu CB Maintenance Power BM a Count Reset NO YES eem YES NO confirmation is required Power On Count Alarm OFF 1 2 999 2 15 Linesman Mode Argus 4 and Argus 6 only Linesman mode is a special mode available on Argus 4 and Argus 6 relays which provides a limited command set that is intended to allow a user Linesman simple access to enable and disable various features when working on the line particularly for live line ind menu together with some commands These settings differ slightly from other settings in that they are not password protected and can be accessed and changed using the right gt key this allows them to be set with the relay front cover in place 02010 Siemens Protection Devices Limited P20007 Page 52 of 71 7SG11 Argus Technical Reference The linesman mode is id reached from the n of the menu tree ee the down v ma accidentally or easily be turned back on again Table 2 30 Linesman Mode Setting Sub menu System Config Linesman Display If attempts are made to access Linesman mode when it is set to VISIBLE HIDDEN Hidden the Display will show Linesman Display hidden Table 2 31 Linesman Mode Settings and Commands Setting name Range bold default Note
287. y has a reset that can be user programmed to be either instantaneous or delayed from 1 to 60 seconds in 1 second steps Where Argus relays are used to protect cable feeders it is recommended that a 60 second reset delay be used On overhead line networks particularly where reclosers are incorporated in the protected system instantaneous resetting is desirable to ensure that on multiple shot reclosing schemes correct grading between the source relays and the relays associated with the reclosers is maintained 3 2 Directional Protection Argus 2 and Argus 6 relays incorporate discrete directional elements with comprehensive selection so that each of the 4 current measuring devices can be selected to be either non directional forward directional reverse directional or bi directional In the bi directional mode separate sets of settings can be assigned to the forward and reverse elements For example the IDMTL function could be set to be 100 0 4 time multiplier in the forward direction and 15 0 1 time multiplier in the reverse direction Similarly each of the Low Set and High Set elements can have different current and time settings in each direction and each of the elements can be mapped to any output relay s Convention dictates that forward direction refers to power flow away from the busbar while reverse direction refers to power flowing towards the busbar 3 2 1 Parallel or Ring Feeder Protection Consider the network shown in Figure 3
288. ync E Gn Status 1 P U Delay Gn Status 1 D O Delay Gn Status 2 P U Delay Gn Status 2 D O Delay Gn Status 3 P U Delay Gn Status 3 D O Delay Gn Status 4 P U Delay Gn Status 4 D O Delay Gn Status 5 P U Delay Gn Status 5 D O Delay Gn Status 6 P U Delay Gn Status 6 D O Delay Gn Status 7 P U Delay Gn Status 7 D O Delay Gn Status 8 P U Delay Gn Status 8 D O Delay Gn Status 9 P U Delay Gn Status 9 D O Delay Gn Alarm d eoo azs 2010 Siemens Protection Devices Limited 7SG11 Argus 1 Diagrams and Parameters Setting name Ref Applied value The text of these setting names reflects the value applied to the Set Alarm n settings in the System Config menu Comms Interface Menu Setting name Ref Applied value Comms Protocol a po IEC Class 2 Measurand azo fo Class 2 Update Period Sec IEC Class 2 Scaling azs Comms Baud Rate Comms Parity az Relay Address aza Line Idle az Data Echo aza o Data Storage Menu Setting name Ref Applied value Gn Fault Trigger Sae o Gn Waveform Trig E MN Gn Waveform Pre trigger Clear All Waveforms A Clear All Events E Clear All Faults am2 ooo Demand Window Type A Demand Window zasa Maximum Demand Reset A P20008 Page 13 of 33 7SG11 Argus 1 Diagrams and Parameters CB Maintenance Menu Setting name Ref Applied value Trip Counter Reset 2 14 1 DDN Trip Counter Alarm 2 14 1 Pos Power On Count Reset ew Power On Count Alarm pus O P Relay Test au2 00

Download Pdf Manuals

Related Search

Related Contents

WIRELESS REMOTE CONTROLLER INSTALLATION MANUAL  33-827型 38-506型 38-507型 取扱説明書 ガス湯沸器（レンジフード型  DUAL GAUGE DSP USER`S MANUAL  取 扱 説 明 書  StarTech.com VGA Cat5 Receiver  Course Outline DIT (Revised 2012)  カタログダウンロード (PDF形式、2926kバイト)  Xerox DocuMate 632 Colour Scanner  XF THE ESSENCE OF ACCESSORIES （2013年1月～）  Sea Gull Lighting 8335-12 Installation Guide  

Copyright © All rights reserved. Failed to retrieve file