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ABB RELION RET670 Applications Manual

Manual is about: Transformer protection

Summary of RELION RET670

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    Relion ® 670 series transformer protection ret670 ansi application manual.

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    Document id: 1mrk504116-uus issued: february 2015 revision: c product version: 1.2 © copyright 2012 abb. All rights reserved.

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    Copyright this document and parts thereof must not be reproduced or copied without written permission from abb, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and...

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    Disclaimer the data, examples and diagrams in this manual are included solely for the concept or product description and are not to be deemed as a statement of guaranteed properties. All persons responsible for applying the equipment addressed in this manual must satisfy themselves that each intende...

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    Conformity this product complies with the directive of the council of the european communities on the approximation of the laws of the member states relating to electromagnetic compatibility (emc directive 2004/108/ec) and concerning electrical equipment for use within specified voltage limits (low-...

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    Table of contents section 1 introduction..........................................................................15 introduction to the application manual....................................................15 about the complete set of manuals for an ied..................................15 about the...

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    Setting parameters............................................................................62 local human-machine interface..............................................................69 human machine interface .................................................................69 local hmi related...

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    Setting guidelines.........................................................................86 setting parameters.......................................................................86 signal matrix for binary outputs smbo ............................................86 application.....................

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    Connection examples for high impedance differential protection....................................................................................141 setting guidelines.......................................................................144 setting parameters..........................................

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    Setting parameters.....................................................................311 faulty phase identification with load encroachment fmpspdis (21)..................................................................................................311 application...................................

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    Application..................................................................................401 setting guidelines.......................................................................403 setting parameters.....................................................................413 instantaneous resid...

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    Setting guidelines.......................................................................487 setting parameters.....................................................................491 broken conductor check brcptoc (46)........................................493 application.............................

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    Frequency protection............................................................................542 underfrequency protection saptuf (81)........................................542 application..................................................................................542 setting guidelines.......

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    Configuration guidelines.............................................................617 interlocking for line bay abc_line (3).......................................617 interlocking for bus-coupler bay abc_bc (3).............................623 interlocking for transformer bay ab_trafo (3)............

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    Scheme communication logic for residual overcurrent protection ecpsch (85).................................................................729 application..................................................................................729 setting guidelines.............................................

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    Measurement...................................................................................748 application..................................................................................748 zero clamping.............................................................................750 setting gui...

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    Pulse-counter logic pcggio...........................................................802 application..................................................................................802 setting guidelines.......................................................................803 setting parameters......

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    Lon communication protocol...............................................................829 application.......................................................................................829 setting parameters..........................................................................830 spa commu...

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    14.

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    Section 1 introduction about this chapter this chapter introduces the user to the manual as such. 1.1 introduction to the application manual 1.1.1 about the complete set of manuals for an ied the user’s manual (um) is a complete set of five different manuals: iec09000744-1-en.Vsd p la nn in g & p ur...

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    The technical reference manual (trm) contains application and functionality descriptions and it lists function blocks, logic diagrams, input and output signals, setting parameters and technical data sorted per function. The technical reference manual should be used as a technical reference during th...

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    1.1.3 intended audience general the application manual is addressing the system engineer/technical responsible that is responsible for specifying the application of the ied. Requirements the system engineer/technical responsible must have a good knowledge about protection systems, protection equipme...

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    18.

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    Section 2 requirements about this chapter this chapter describes current and voltage transformer requirements. 2.1 current transformer requirements the performance of a protection function will depend on the quality of the measured current signal. Saturation of the current transformer (ct) will caus...

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    The low remanence type has a specified limit for the remanent flux. This ct is made with a small air gap to reduce the remanence to a level that does not exceed 10% of the saturation flux. The small air gap has only very limited influences on the other properties of the ct. Class pr, tpy according t...

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    It is difficult to give general recommendations for additional margins for remanence to avoid the minor risk of an additional time delay. They depend on the performance and economy requirements. When current transformers of low remanence type (for example, tpy, pr) are used, normally no additional m...

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    In isolated or high impedance grounded systems the phase-to-ground fault is not the dimensioning case and therefore the resistance of the single secondary wire always can be used in the calculation, for this case. 2.1.5 general current transformer requirements the current transformer ratio is mainly...

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    S n r a l a lre q ct l 2 pn n tf i s e e 2 i r r i i ³ = × × + + æ ö × ç ÷ è ø equation1673 v1 en (equation 2) where: i nt the rated primary current of the power transformer (a) i tf maximum primary fundamental frequency current that passes two main cts and the power transformer (a) i pn the rated p...

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    S n r a l a lre q ct l 2 pn n k ma x i i s e e r r i i ³ = × + + æ ö × ç ÷ è ø equation1675 v1 en (equation 4) s n r a l a lre q ct l 2 pn n kzone1 i i s e e r r i i ³ = × + + æ ö × ç ÷ è ø equation1676 v1 en (equation 5) where: i kmax maximum primary fundamental frequency current for close-in forwa...

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    Neutral cts and phase cts for solidly ground transformers the neutral ct and the phase cts must have a rated equivalent secondary e.M.F. E al that is larger than or equal to the maximum of the required secondary e.M.F. E alreq below: 2 30 sn r al alreq nt ct l pn r i s e e i r r i i ³ = × × × + + æ ...

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    Neutral cts and phase cts for impedance grounded transformers the neutral ct and phase cts must have a rated equivalent secondary e.M.F. E al that is larger than or equal to the required secondary e.M.F. E alreq below: 2 3 sn r al alreq etf ct l pn r i s e e i r r i i ³ = × × × + + æ ö ç ÷ è ø equat...

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    Connection) for example, in substations with breaker-and-a-half or double-busbar double- breaker arrangement or if the transformer has a t-connection to different busbars, there is a risk that the cts can be exposed for higher fault currents than the considered phase- to-ground fault currents above....

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    2 max max alreq e e > equation1383 v2 en (equation 11) 2.1.7.2 current transformers according to iec 60044-1, class px, iec 60044-6, class tps (and old british standard, class x) cts according to these classes are specified approximately in the same way by a rated knee-point e.M.F. E knee (e k for c...

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    The cts according to class c must have a calculated rated equivalent limiting secondary e.M.F. E alansi that fulfills the following: alansi alreq e max imum of e > equation1384 v1 en (equation 14) a ct according to ansi/ieee is also specified by the knee-point voltage v kneeansi that is graphically ...

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    Software. The sntp server should be stable, that is, either synchronized from a stable source like gps, or local without synchronization. Using a local sntp server without synchronization as primary or secondary server in a redundant configuration is not recommended. 2.4 iec 61850-9-2le merging unit...

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    Section 3 ied application about this chapter this chapter describes the use of the included software functions in the ied. The chapter discusses application possibilities and gives guidelines for calculating settings for a particular application. 3.1 general ied application ret670 provides fast and ...

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    Tripping from pressure relief/buchholz and temperature devices can be done through the transformer ied where pulsing, lock-out contact output and so on, is performed. The binary inputs are heavily stabilized against disturbance to prevent incorrect operations at for example dc system capacitive disc...

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    The wide application flexibility makes this product an excellent choice for both new installations and the refurbishment of existing installations. 3.2 analog inputs 3.2.1 introduction analog input channels must be configured and set properly to get correct measurement results and correct protection...

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    Setting of current channels the direction of a current to the ied is depending on the connection of the ct. Unless indicated otherwise, the main cts are supposed to be wye (star) connected and can be connected with the grounding point to the object or from the object. This information must be set in...

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    Transformer protection transformer line line setting of current input: set parameter ct_wyepoint with transformer as reference object. Correct setting is "toobject" forward reverse definition of direction for directional functions line protection setting of current input: set parameter ct_wyepoint w...

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    Transformer and line protection transformer line setting of current input: set parameter ct_wyepoint with transformer as reference object. Correct setting is "toobject" reverse forward definition of direction for directional line functions setting of current input: set parameter ct_wyepoint with tra...

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    Line and transformer protection functions are configured to the different inputs. The ct direction for the current channels to the line protection is set with the line as reference object and the directional functions of the line protection shall be set to forward to protect the line. Transformer an...

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    Busbar protection busbar 1 2 2 1 en06000196_ansi.Vsd ansi06000196 v1 en figure 6: example how to set ct_wyepoint parameters in the ied for busbar protection it is possible to set the ct_wyepoint parameters in two ways. The first solution will be to use busbar as a reference object. In that case for ...

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    Regardless which one of the above two options is selected busbar differential protection will behave correctly. The main ct ratios must also be set. This is done by setting the two parameters ctsec and ctprim for each current channel. For a 1000/5 a ct the following setting shall be used: • ctprim =...

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    It shall be noted that depending on national standard and utility practices, the rated secondary current of a ct has typically one of the following values: • 1a • 5a however in some cases the following rated secondary currents are used as well: • 2a • 10a the ied fully supports all of these rated se...

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    Protected object ct 600/5 star connected ied ansi3000002-2-en.Vsd 1 2 3 4 smai_20 a i_ a i_ b i_ c b c i_a i_b i_c ansi13000002 v2 en figure 8: wye connected three-phase ct set with wye point towards the protected object where: 1) the drawing shows how to connect three individual phase currents from...

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    3) these three connections are the links between the three current inputs and the three input channels of the preprocessing function block 4). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to the same three p...

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    Protected object ct 800/1 star connected ied ansi11000026-4-en.Vsd 4 1 2 3 a ia ib ic b c ia ib ic smai_20_2 block revrot ^grp2l1 ^grp2l2 ^grp2l3 ^grp2n ai3p ai1 ai2 ai3 ai4 ain 5 ansi11000026 v4 en figure 9: wye connected three-phase ct set with its star point away from the protected object in the ...

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    7 8 9 10 11 12 1 2 3 4 5 6 a ia ib ic b c protected object ct 800/1 wye connected ia ib ic ai 01 (i) ai 02 (i) ai 03 (i) ai 04 (i) ai 05 (i) ai 06 (i) in ied 1 3 4 2 5 ansi06000644-2-en.Vsd 6 smai2 block ai3p ai1 ai2 ai3 ai4 ain ^grp2_b ^grp2_a ^grp2_c ^grp2n type ansi06000644 v2 en figure 10: wye c...

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    5) is a connection made in the signal matrix tool (smt), application configuration tool (act), which connects the residual/neutral current input to the fourth input channel of the preprocessing function block 6). Note that this connection in smt shall not be done if the residual/ neutral current is ...

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    A ia ib ic b c protected object ied c t 6 0 0/ 5 in d e lta d a b c o nn ec te d ia-ib ib-ic ic-ia 1 2 3 4 ansi11000027-2-en.Vsd smai_20 ansi11000027 v2 en figure 11: delta dab connected three-phase ct set section 3 1mrk504116-uus c ied application 46 application manual.

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    Where: 1) shows how to connect three individual phase currents from a delta connected three-phase ct set to three ct inputs of the ied. 2) is the trm where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. Ct prim =60...

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    A ia ib ic b c protected object ied c t 8 0 0 /1 in d e lta d c a c o n ne ct ed ic-ib ib-ia ia-ic 2 3 4 ansi11000028-2-en.Vsd smai_20 ansi11000028 v2 en figure 12: delta dac connected three-phase ct set in this case, everything is done in a similar way as in the above described example, except that...

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    For correct terminal designations, see the connection diagrams valid for the delivered ied. Protected object a b c ied in p 2 4 ansi11000029-3-en.Vsd 3 c t 1 0 0 0 /1 a) b) ins ins (+) (+) (-) (-) (+) (-) 1 smai_20_2 block revrot ^grp2_a ^grp2_b ^grp2_c ^grp2_n ai3p ai1 ai2 ai3 ai4 ain ansi11000029 ...

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    Where: 1) shows how to connect single-phase ct input in the ied. 2) is trm where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. For connection (a) shown in figure 13 : ct prim = 1000 a ct sec = 1a ctwyepoint = toob...

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    A (h1) b (h2) b (x2) a (x1) a (h1) n (h2) n (x2) a (x1) b) c) a (h1) n (h2) dn (x2) da (x1) d) v pri + + v sec a) ansi11000175_1_en.Vsd ansi11000175 v1 en figure 14: commonly used markings of vt terminals where: a) is the symbol and terminal marking used in this document. Terminals marked with a dot...

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    19 20 21 22 23 24 13 14 15 16 17 18 a ai 07 (i) ai 08 (v) ai 09 (v) ai 10 (v) ai 11 (v) ai 12 (v) ied b c 66 3 110 3 kv v 1 3 2 66 3 110 3 kv v 66 3 110 3 kv v #not used 5 ansi06000599-2-en.Vsd smai2 block ^grp2_a type ai3p ai1 ai2 ai3 ai4 ain ^grp2_b ^grp2_c ^grp2n 4 ansi06000599 v2 en figure 15: a...

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    3) are three connections made in signal matrix tool (smt), which connect these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions which need this voltage information, more then one preprocessing block might be connected in pa...

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    19 20 21 22 23 24 13 14 15 16 17 18 a ai 07(i) ai08 (v) ai09 (v) ai10(v) ai11(v) ai12(v) ied b c 13.8 120 kv v 1 2 3 #not used 13.8 120 kv v 5 ansi06000600-3-en.Vsd smai2 block ^grp2_a (a-b) ^grp2_b (b-c) ^grp2_c (c-a) ^grp2n type ai3p ai1 ai2 ai3 ai4 ain 4 ansi06000600 v3 en figure 16: a two phase-...

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    3) are three connections made in the signal matrix tool (smt), application configuration tool (act), which connects these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions, which need this voltage information, more than one ...

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    19 20 21 22 23 24 13 14 15 16 17 18 a ai 07 (i) ai 08 (v) ai 09 (v) ai 10 (v) ai 11 (v) ai 12 (v) ied b c 6.6 3 110 3 kv v +3vo 6.6 3 110 3 kv v 6.6 3 110 3 kv v 1 2 4 3 # not used 5 ansi06000601-2-en.Vsd # not used # not used smai2 block ^grp2_a ^grp2_b ^grp2_c ^grp2n type ai3p ai1 ai2 ai3 ai4 ain ...

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    Where: 1) shows how to connect the secondary side of the open delta vt to one vt input on the ied. +3vo shall be connected to the ied 2) is the trm where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: 3 6.6 11.43 vtprim kv ...

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    Example how to connect the open delta vt to the ied for low impedance grounded or solidly grounded power systems figure 18 gives an example about the connection of an open delta vt to the ied for low impedance grounded or solidly grounded power systems. It shall be noted that this type of vt connect...

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    19 20 21 22 23 24 13 14 15 16 17 18 a ai07 (i) ai08 (v) ai09 (v) ai10 (v) ai11 (v) ai12 (v) ied b c 138 3 115 3 kv v +3vo 138 3 115 3 kv v 138 3 115 3 kv v 1 2 4 3 ansi06000602-2-en.Vsd 5 # not used # not used # not used smai2 block ^grp2_a ^grp2_b ^grp2_c ^grp2n type ai3p ai1 ai2 ai3 ai4 ain ansi06...

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    Where: 1) shows how to connect the secondary side of open delta vt to one vt input in the ied. +3vo shall be connected to the ied. 2) is trm where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: 138 3 138 3 vtprim kv = × = e...

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    Example on how to connect a neutral point vt to the ied figure 19 gives an example on how to connect a neutral point vt to the ied. This type of vt connection presents secondary voltage proportional to v 0 to the ied. In case of a solid ground fault in high impedance grounded or ungrounded systems t...

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    Where: 1) shows how to connect the secondary side of neutral point vt to one vt input in the ied. V 0 shall be connected to the ied. 2) is the trm or aim where this voltage input is located. For this voltage input the following setting values shall be entered: 6.6 3.81 3 vtprim kv = = equation1933 v...

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    Table 1: aisvbas non group settings (basic) name values (range) unit step default description phaseangleref trm40-ch1 trm40-ch2 trm40-ch3 trm40-ch4 trm40-ch5 trm40-ch6 trm40-ch7 trm40-ch8 trm40-ch9 trm40-ch10 trm40-ch11 trm40-ch12 trm41-ch1 trm41-ch2 trm41-ch3 trm41-ch4 trm41-ch5 trm41-ch6 trm41-ch7...

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    Table 2: trm_12i non group settings (basic) name values (range) unit step default description ct_wyepoint1 fromobject toobject - - toobject toobject= towards protected object, fromobject= the opposite ctsec1 1 - 10 a 1 1 rated ct secondary current ctprim1 1 - 99999 a 1 3000 rated ct primary current ...

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    Name values (range) unit step default description ctprim10 1 - 99999 a 1 3000 rated ct primary current ct_wyepoint11 fromobject toobject - - toobject toobject= towards protected object, fromobject= the opposite ctsec11 1 - 10 a 1 1 rated ct secondary current ctprim11 1 - 99999 a 1 3000 rated ct prim...

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    Name values (range) unit step default description vtprim8 0.05 - 2000.00 kv 0.05 400.00 rated vt primary voltage vtsec9 0.001 - 999.999 v 0.001 110.000 rated vt secondary voltage vtprim9 0.05 - 2000.00 kv 0.05 400.00 rated vt primary voltage vtsec10 0.001 - 999.999 v 0.001 110.000 rated vt secondary...

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    Table 5: trm_7i_5u non group settings (basic) name values (range) unit step default description ct_wyepoint1 fromobject toobject - - toobject toobject= towards protected object, fromobject= the opposite ctsec1 1 - 10 a 1 1 rated ct secondary current ctprim1 1 - 99999 a 1 3000 rated ct primary curren...

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    Table 6: trm_9i_3u non group settings (basic) name values (range) unit step default description ct_wyepoint1 fromobject toobject - - toobject toobject= towards protected object, fromobject= the opposite ctsec1 1 - 10 a 1 1 rated ct secondary current ctprim1 1 - 99999 a 1 3000 rated ct primary curren...

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    Name values (range) unit step default description vtprim11 0.05 - 2000.00 kv 0.05 400.00 rated vt primary voltage vtsec12 0.001 - 999.999 v 0.001 110.000 rated vt secondary voltage vtprim12 0.05 - 2000.00 kv 0.05 400.00 rated vt primary voltage 3.3 local human-machine interface 3.3.1 human machine i...

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    Iec07000077 v1 en figure 20: medium graphic hmi, 15 controllable objects 3.3.2 local hmi related functions 3.3.2.1 introduction the local hmi can be adapted to the application configuration and to user preferences. • function block localhmi • function block ledgen • setting parameters 3.3.2.2 genera...

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    Name values (range) unit step default description defaultscreen 0 - 0 - 1 0 default screen evlistsrtorder latest on top oldest on top - - latest on top sort order of event list symbolfont iec ansi - - iec symbol font for single line diagram 3.3.3 indication leds 3.3.3.1 introduction the function blo...

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    3.3.3.2 setting parameters table 8: ledgen non group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation mode for the led function trestart 0.0 - 100.0 s 0.1 0.0 defines the disturbance length tmax 0.0 - 100.0 s 0.1 0.0 maximum time fo...

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    Name values (range) unit step default description seqtypeled8 follow-s follow-f latchedack-f-s latchedack-s-f latchedcoll-s latchedreset-s - - follow-s sequence type for led 8 seqtypeled9 follow-s follow-f latchedack-f-s latchedack-s-f latchedcoll-s latchedreset-s - - follow-s sequence type for led ...

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    3.4 basic ied functions 3.4.1 self supervision with internal event list 3.4.1.1 application the protection and control ieds have many functions included . The included self- supervision with internal event list function block provides good supervision of the ied. The fault signals make it easier to ...

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    3.4.2 time synchronization 3.4.2.1 application use time synchronization to achieve a common time base for the ieds in a protection and control system. This makes it possible to compare events and disturbance data between all ieds in the system. Time-tagging of internal events and disturbances are an...

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    Timesynch when the source of the time synchronization is selected on the local hmi, the parameter is called timesynch. The time synchronization source can also be set from pcm600. The setting alternatives are: finesyncsource which can have the following values: • disabled • spa • lon • bin (binary m...

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    The parameter syncmaster defines if the ied is a master, or not a master for time synchronization in a system of ieds connected in a communication network (iec61850-8-1). The syncmaster can have the following values: • disabled • sntp -server set the course time synchronizing source (coarsesyncsrc) ...

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    Table 9: timesynchgen non group settings (basic) name values (range) unit step default description coarsesyncsrc disabled spa lon sntp dnp - - disabled coarse time synchronization source finesyncsource disabled spa lon bin gps gps+spa gps+lon gps+bin sntp gps+sntp irig-b gps+irig-b pps - - disabled ...

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    Table 12: dstbegin non group settings (basic) name values (range) unit step default description monthinyear january february march april may june july august september october november december - - march month in year when daylight time starts dayinweek sunday monday tuesday wednesday thursday frida...

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    Table 13: dstend non group settings (basic) name values (range) unit step default description monthinyear january february march april may june july august september october november december - - october month in year when daylight time ends dayinweek sunday monday tuesday wednesday thursday friday ...

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    3.4.3 parameter setting groups 3.4.3.1 application six sets of settings are available to optimize ied operation for different power system conditions. By creating and switching between fine tuned setting sets, either from the local hmi or configurable binary inputs, results in a highly adaptable ied...

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    Table 17: setgrps non group settings (basic) name values (range) unit step default description activesetgrp settinggroup1 settinggroup2 settinggroup3 settinggroup4 settinggroup5 settinggroup6 - - settinggroup1 activesettinggroup maxsetgr 1 - 6 no 1 1 max number of setting groups 1-6 3.4.4 test mode ...

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    3.4.5.1 application change lock function chnglck is used to block further changes to the ied configuration once the commissioning is complete. The purpose is to make it impossible to perform inadvertent ied configuration and setting changes. However, when activated, chnglck will still allow the foll...

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    3.4.5.2 setting parameters table 19: chnglck non group settings (basic) name values (range) unit step default description operation lockhmi and com lockhmi, enablecom enablehmi, lockcom - - lockhmi and com operation mode of change lock 3.4.6 ied identifiers 3.4.6.1 application ied identifiers (termi...

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    • iedprodtype • productdef • firmwarever • serialno • orderingno • productiondate the settings are visible on the local hmi , under main menu/diagnostics/ied status/ product identifiers they are very helpful in case of support process (such as repair or maintenance). 3.4.7.2 setting parameters the f...

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    3.4.8.1 application the rated system frequency is set under main menu/general settings/ power system/ primary values in the local hmi and pcm600 parameter setting tree. 3.4.8.2 setting guidelines set the system rated frequency. Refer to section "signal matrix for analog inputs smai" for description ...

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    3.4.10.1 application the signal matrix for binary outputs function smbo is used within the application configuration tool in direct relation with the signal matrix tool. Smbo represents the way binary outputs are sent from one ied configuration. It is important that smbo inputs are connected when sm...

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    3.4.12 signal matrix for analog inputs smai 3.4.12.1 application signal matrix for analog inputs function (smai), also known as the preprocessor function, processes the analog signals connected to it and gives information about all aspects of the analog signals connected, like the rms value, phase a...

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    Setting must still be ph-ph and this has to be accounted for when setting intblocklevel. If smai setting connectiontype is ph-n and the same voltage is connected to all three smai inputs, the positive sequence voltage will be zero and the frequency functions will not work properly. The outputs from ...

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    Connectiontype: connection type for that specific instance (n) of the smai (if it is ph- n or ph-ph). Depending on connection type setting the not connected ph-n or ph-ph outputs will be calculated. Negation: if the user wants to negate the 3ph signal, it is possible to choose to negate only the pha...

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    Iec07000197.Vsd smai instance 3 phase group smai1:1 1 smai2:2 2 smai3:3 3 smai4:4 4 smai5:5 5 smai6:6 6 smai7:7 7 smai8:8 8 smai9:9 9 smai10:10 10 smai11:11 11 smai12:12 12 task time group 1 smai instance 3 phase group smai1:13 1 smai2:14 2 smai3:15 3 smai4:16 4 smai5:17 5 smai6:18 6 smai7:19 7 smai...

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    Example 1 ansi07000198.Vsd smai1:1 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4 ain smai1:13 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4 ain smai1:25 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4...

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    Ansi07000198.Vsd smai1:13 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4 ain smai1:1 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4 ain smai1:25 block dftspfc ^grp1_a ^grp1_b ^grp1_c ^grp1_n type spfcout ai3p ai1 ai2 ai3 ai4 ain ansi0...

  • Page 100

    3.4.12.4 setting parameters table 22: smai1 non group settings (basic) name values (range) unit step default description dftrefextout internaldftref addftrefch1 addftrefch2 addftrefch3 addftrefch4 addftrefch5 addftrefch6 addftrefch7 addftrefch8 addftrefch9 addftrefch10 addftrefch11 addftrefch12 exte...

  • Page 101

    Table 24: smai2 non group settings (basic) name values (range) unit step default description dftreference internaldftref addftrefch1 addftrefch2 addftrefch3 addftrefch4 addftrefch5 addftrefch6 addftrefch7 addftrefch8 addftrefch9 addftrefch10 addftrefch11 addftrefch12 external dft ref - - internaldft...

  • Page 102

    Dftreference: the reference dft block (internaldft ref,dftrefgrp1 or external dft ref) . Freqmeasminval: the minimum value of the voltage for which the frequency is calculated, expressed as percent of vbasebase voltage setting (for each instance x). Vbase: base voltage setting. 3.4.13.3 setting para...

  • Page 103

    3.4.14.2 setting parameters the function does not have any parameters available in the local hmi or pcm600. 3.4.15 denial of service dos 3.4.15.1 application the denial of service functions (dosfrnt, dosoemab and dosoemcd) are designed to limit the cpu load that can be produced by ethernet network t...

  • Page 104

    Function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number transformer differential protection, two- winding t2wpdif 3id/i symbol-bb v1 en 87t transformer differential protection, three-winding t3wpdif 3id/i symbol-bb v1 en 87t 3.5.1.1 application the transf...

  • Page 105

    Implemented in the ied compensates for both the turns-ratio and the phase shift internally in the software. No auxiliary current transformers are necessary. The differential current should theoretically be zero during normal load or external faults if the turn-ratio and the phase shift are correctly...

  • Page 106

    Transformers have difficult operating conditions. This bias quantity gives the best stability against an unwanted operation during external faults. The usual practice for transformer protection is to set the bias characteristic to a value of at least twice the value of the expected spill current und...

  • Page 107

    The unrestrained operation level has a default value of idunre = 10pu, which is typically acceptable for most of the standard power transformer applications. In the following case, this setting need to be changed accordingly: • when ct from "t-connection" are connected to ied, as in the breaker-and-...

  • Page 108

    Section 1 operate conditionally unrestrainedlimit section 2 section 3 restrain operate unconditionally 5 4 3 2 1 0 0 1 2 3 4 5 idmin endsection1 endsection2 restrain current [ times ibase ] operate current [ times ibase ] slopesection2 slopesection3 en05000187-2.Vsd iec05000187 v2 en figure 25: repr...

  • Page 109

    Elimination of zero sequence currents a differential protection may operate unwanted due to external ground-faults in cases where the zero sequence current can flow on only one side of the power transformer. But not on the other side. This is the case when zero sequence current cannot be properly tr...

  • Page 110

    Up transformers in power stations) should be provided with an overexcitation protection based on v/hz to achieve a trip before the core thermal limit is reached. Cross-blocking between phases basic definition of the cross-blocking is that one of the three phases can block operation (that is, trippin...

  • Page 111

    The setting negseqroa represents the so-called relay operate angle, which determines the boundary between the internal and external fault regions. It can be selected in the range from 30 degrees to 90 degrees, with a step of 1 degree. The default value is 60 degrees. The default setting 60 degrees s...

  • Page 112

    The principle of the internal/external fault discriminator can be extended to autotransformers and transformers with three windings. If all three windings are connected to their respective networks then three directional comparisons are made, but only two comparisons are necessary in order to positi...

  • Page 113

    Differential current alarm differential protection continuously monitors the level of the fundamental frequency differential currents and gives an alarm if the pre-set value is simultaneously exceeded in all three phases. This feature can be used to monitor the integrity of on-load tap- changer comp...

  • Page 114

    Enabled it is not possible to test the 2 nd harmonic blocking feature by simply injecting one current with superimposed second harmonic. In that case the switch on to fault feature will operate and the differential protection will trip. However for a real inrush case the differential protection func...

  • Page 115

    Noted that irrespective of the main ct connections (wye or delta) on-line reading and automatic compensation for actual load tap changer position can be used in the ied. Typical main ct connections for transformer differential protection three most typical main ct connections used for transformer di...

  • Page 116

    • are increased √3 times (1.732 times) in comparison with wye connected cts • lag by 30° the primary winding currents (this ct connection rotates currents by 30° in clockwise direction) • do not contain zero sequence current component for dac delta connected main cts, ratio shall be set for √3 times...

  • Page 117

    Ct 300/5 in delta (dac) ct 800/5 wye 20.9 mva 69/12.5 kv ynd1 (yd ac ) ct 300/5 wye ct 800/5 wye 20.9 mva 69/12.5 kv ynd1 (yd ac ) en06000554_ansi.Vsd ansi06000554 v1 en figure 27: two differential protection solutions for wye-delta connected power transformer for this particular power transformer t...

  • Page 118

    4. Enter the following settings for all three ct input channels used for the lv side cts see table 28 . Table 28: ct input channels used for the lv side cts setting parameter selected value for both solutions ctprim 800 ctsec 5 ct_wyepoint toobject 5. Enter the following settings for all three ct in...

  • Page 119

    Setting parameter select value for both solution 1 (wye connected ct) selected value for both solution 2 (delta connected ct) tconfigforw1 no no tconfigforw2 no no locationoltc1 not used not used other parameters not relevant for this application. Use default value. Not relevant for this application...

  • Page 120

    Delta, as shown in the right-hand side in figure 28 , it must be ensured that the 24.9 kv currents are rotated by 30° in anti-clockwise direction. Thus, the dab ct delta connection (see figure 28 ) must be used for 24.9 kv cts in order to put 115 kv & 24.9 kv currents in phase. To ensure proper appl...

  • Page 121

    Table 32: general settings of the differential protection setting parameter selected value for both solution 1 (wye conected ct) selected value for both solution 2 (delta connected ct) ratedvoltagew1 115 kv 115 kv rated voltagew2 24.9 kv 24.9 kv ratedcurrentw1 301 a 301 a ratedcurrentw2 1391 a 1391 ...

  • Page 122

    Ct 500/5 wye 31.5/31.5/(10.5) mva 110±11×1.5% /36.75/(10.5) kv ynyn0(d5) ct 200/1 wye ct 500/5 in delta (dab) 31.5/31.5/(10.5) mva 110±11×1.5% /36.75/(10.5) kv ynyn0(d5) ct 200/1 in delta (dab) en06000558_ansi.Vsd ansi06000558 v1 en figure 29: two differential protection solutions for wye-wye connec...

  • Page 123

    Table 33: ct input channels used for the hv side cts setting parameter selected value for both solution 1 (wye connected cts) selected value for both solution 2 (delta connected cts) ctprim 200 200 115 3 = equation1891 v1 en (equation 32) ctsec 1 1 ct_wyepoint fromobject toobject to compensate for d...

  • Page 124

    Setting parameter selected value for both solution 1 (wye connected) selected value for both solution 2 (delta connected) zscurrsubtrw1 on off 1) zscurrsubtrw2 on off 1) tconfigforw1 no no tconfigforw2 no no locationolt1 winding 1 (w1) winding 1 (w1) lowtapposoltc1 1 1 ratedtapoltc1 12 12 hightappso...

  • Page 125

    Iec vector group ansi designation positive sequence no-load voltage phasor diagram required delta ct connection type on wye side of the protected power transformer and internal vector group setting in the ied ynd1 yd ac y iec06000559 v1 en dac/yy0 dyn1 d ab y y iec06000560 v1 en dab/yy0 ynd11 yd ab ...

  • Page 126

    Iec vector group ansi designation positive sequence no-load voltage phasor diagram required delta ct connection type on wye side of the protected power transformer and internal vector group setting in the ied dyn11 d ac y y iec06000562 v1 en dac/yy0 ynd5 yd150 y iec06000563 v1 en dab/yy6 dyn5 dy150 ...

  • Page 127

    Name values (range) unit step default description idunre 1.00 - 50.00 ib 0.01 10.00 unrestrained protection limit, multiple of winding 1 rated current crossblocken disabled enabled - - enabled operation off/on for cross-block logic between phases negseqdiffen disabled enabled - - enabled operation o...

  • Page 128

    Name values (range) unit step default description connecttypew1 wye (y) delta (d) - - wye (y) connection type of winding 1: y-wye or d-delta connecttypew2 wye (y) delta (d) - - wye (y) connection type of winding 2: y-wye or d-delta clocknumberw2 0 [0 deg] 1 [30 deg lag] 2 [60 deg lag] 3 [90 deg lag]...

  • Page 129

    Table 39: t3wpdif (87t) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation disable / enable sotfmode disabled enabled - - enabled operation mode for switch onto fault feature talarmdelay 0.000 - 60.000 s 0.001 10.000 time delay ...

  • Page 130

    Table 41: t3wpdif (87t) non group settings (basic) name values (range) unit step default description ratedvoltagew1 0.05 - 2000.00 kv 0.05 400.00 rated voltage of transformer winding 1 (hv winding) in kv ratedvoltagew2 0.05 - 2000.00 kv 0.05 231.00 rated voltage of transformer winding 2 in kv ratedv...

  • Page 131

    Name values (range) unit step default description ct2ratingw1 1 - 99999 a 1 3000 ct primary in a, t-branch 2, on transf. W1 side tconfigforw2 no yes - - no two ct inputs (t-config.) for winding 2, yes / no ct1ratingw2 1 - 99999 a 1 3000 ct primary rating in a, t-branch 1, on transf. W2 side ct2ratin...

  • Page 132

    Function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number restricted earth-fault protection, low impedance refpdif idn/i symbol-aa v1 en 87n 3.5.2.1 application breakdown of the insulation between a phase conductor and ground in an effectively or low impeda...

  • Page 133

    Due to its features, refpdif (87n) is often used as a main protection of the transformer winding for all faults involving ground. Transformer winding, solidly grounded the most common application is on a solidly grounded transformer winding. The connection is shown in figure 30 . Refpdif (87n) i3p i...

  • Page 134

    Ansi05000211_3_en.Vsd ansi05000211 v3 en figure 31: connection of the low impedance restricted earth-fault function refpdif for a zig-zag grounding transformer autotransformer winding, solidly grounded autotransformers can be protected with the low impedance restricted ground fault protection functi...

  • Page 135

    Ansi05000212_3_en.Vsd ansi05000212 v3 en figure 32: connection of restricted ground fault, low impedance function refpdif (87n) for an autotransformer, solidly grounded reactor winding, solidly grounded reactors can be protected with restricted ground fault protection, low impedance function refpdif...

  • Page 136

    Ansi05000213_3_en.Vsd ansi05000213 v3 en figure 33: connection of restricted earth-fault, low impedance function refpdif (87n) for a solidly grounded reactor multi-breaker applications multi-breaker arrangements including ring, one breaker-and-a-half, double breaker and mesh corner arrangements have...

  • Page 137

    En05000214_ansi.Vsd refx i3p i3pw1ct1 i3pw1ct2 c b a ind> { { 52 52 52 52 52 52 ansi05000214 v1 en figure 34: connection of restricted earth fault, low impedance function refpdif (87n) in multi-breaker arrangements ct grounding direction to make the restricted earth-fault protection refpdif (87n)ope...

  • Page 138

    I3pw1ct2: phase currents for winding1 second current transformer set for multi- breaker arrangements. When not required configure input to "grp-off". I3pw2ct1: phase currents for winding 2 first current transformer set. Used for autotransformers. I3pw2ct2: phase currents for winding 2 second current...

  • Page 139

    Idmin: the setting gives the minimum operation value. The setting is in percent of the ibase value. The neutral current must always be larger than half of this value. A normal setting is 30% of power transformer-winding rated current for the solidly grounded winding. Ctfactorpri1: a factor to allow ...

  • Page 140

    3.5.3 1ph high impedance differential protection hzpdif (87) 3.5.3.1 identification function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number 1ph high impedance differential protection hzpdif id symbol-cc v2 en 87 3.5.3.2 application the 1ph high impedance ...

  • Page 141

    Ansi05000738-2-en.Vsd 3·87 21 3·87 21 52 52 52 ansi05000738 v2 en figure 35: different applications of a 1ph high impedance differential protection hzpdif (87) function the basics of the high impedance principle the high impedance differential protection principle has been used for many years and is...

  • Page 142

    87n en05000164_ansi.Vsd ansi05000164 v1 en figure 36: example for the high impedance restricted earth fault protection application for a through fault one current transformer might saturate when the other cts still will feed current. For such a case a voltage will be developed across the stabilising...

  • Page 143

    The minimum operating voltage has to be calculated (all loops) and the ied function is set higher than the highest achieved value (setting trippickup). As the loop resistance is the value to the connection point from each ct, it is advisable to do all the ct core summations in the switchgear to have...

  • Page 144

    Table 44: 1 a channels: input with minimum operating down to 20 ma operating voltage trippi ckup stabilizing resistor r ohms operating current level 1 a stabilizing resistor r ohms operating current level 1 a stabilizing resistor r ohms operating current level 1 a 20 v 1000 0.020 a -- -- -- -- 40 v ...

  • Page 145

    Ir ied pickup current ires is the current through the voltage limiter and Σimag is the sum of the magnetizing currents from all cts in the circuit (for example, 4 for restricted earth fault protection, 2 for reactor differential protection, 3-5 for autotransformer differential protection). It should...

  • Page 146

    Ansi05000427-2-en.Vsd i> r rres rl rct rct rl vr a) through load situation b) through fault situation vr vr c) internal faults vr protected object ansi05000427 v2 en figure 37: the high impedance principle for one phase with two current transformer inputs section 3 1mrk504116-uus c ied application 1...

  • Page 147

    3.5.3.3 connection examples for high impedance differential protection warning! Use extreme caution! Dangerously high voltages might be present on this equipment, especially on the plate with resistors. Do any maintenance only if the primary object protected with this equipment is de-energized. If r...

  • Page 148

    Pos description 1 scheme grounding point note that it is of outmost importance to insure that only one grounding point exist in such scheme. 2 three-phase plate with setting resistors and metrosils. 3 necessary connection for three-phase metrosil set. Shown connections are applicable for both types ...

  • Page 149

    L1 (a) l2 (b) l3 (c) protected object ct 1500/5 star/wye connected 7 8 9 10 11 12 1 2 3 4 5 6 ai01 (i) ai02 (i) ai03 (i) ai04 (i) ai05 (i) ai06 (i) 6 7 8 ied x1 r 1 1 2 4 5 v r 2 1 3 4 2 1 2 3 n 1-ph plate with metrosil and resistor 2 3 5 4 9 n l1 (a) l2 (b) l3 (c) c t 1 50 0 /5 1 ansi09000170_2_en....

  • Page 150

    7 transformer input module where this current input is located. Note that the ct ratio for high impedance differential protection application must be set as one. • for main cts with 1a secondary rating the following setting values shall be entered: ctprim = 1a and ctsec = 1a • for main cts with 5a s...

  • Page 151

    R series: set the value of the stabilizing series resistor. Calculate the value according to the examples for each application. Adjust the resistor as close as possible to the calculated example. Measure the value achieved and set this value here. The value shall always be high impedance. This means...

  • Page 152

    It is strongly recommended to use the highest tap of the ct whenever high impedance protection is used. This helps in utilizing maximum ct capability, minimize the current, thereby reducing the stability voltage limit. Another factor is that during internal faults, the voltage developed across the s...

  • Page 153

    ( ) 3 2000 200 0 3 50 60 10 .100 5 ip approx a - = ° + × - ° × £ equation1887-ansi v1 en (equation 38) where 200ma is the current drawn by the ied circuit and 50ma is the current drawn by each ct just at pickup the magnetizing current is taken from the magnetizing curve for the current transformer c...

  • Page 154

    3·87 ansi05000173-2-en.Vsd ansi05000173 v2 en figure 41: application of the 1ph high impedance differential protection hzpdif (87) function on an autotransformer setting example it is strongly recommended to use the highest tap of the ct whenever high impedance protection is used. This helps in util...

  • Page 155

    Calculation: 1150 15 (0.3 0.1) 28.75 240 vr v > × × + = equation1760-ansi v1 en (equation 39) select a setting of trippickup =40 v the current transformer knee point voltage can roughly be calculated from the rated values, considering knee point voltage to be about 70% of the accuracy limit voltage....

  • Page 156

    3·87 ansi05000774-3-en.Vsd ansi05000774 v3 en figure 42: application of the high impedance differential function on tertiary busbar setting example it is strongly recommended to use the highest tap of the ct whenever high impedance protection is used. This helps in utilizing maximum ct capability, m...

  • Page 157

    Basic data: cable loop resistance: ct) gives loop resistance 2 · 0.05 = 0.1 ohms note! Only one way as the system grounding is limiting the ground- fault current. If high ground-fault current exists use two way cable. Max fault current: the maximum through fault current given by the transformer reac...

  • Page 158

    The magnetizing current is taken from the magnetizing curve for the current transformer cores which should be available. The value at trippickup is taken. Tertiary reactor protection for many transformers there can be a secondary system for local distribution and/or shunt compensation. The 1ph high ...

  • Page 159

    Ansi05000176-2-en.Vsd 3·87 ansi05000176 v2 en figure 43: application of the1ph high impedance differential protection hzpdif (87) function on an autotransformer setting example it is strongly recommended to use the highest tap of the ct whenever high impedance protection is used. This helps in utili...

  • Page 160

    Unused taps, owing to auto-transformer action, voltages much higher than design limits might be induced. Basic data: current transformer ratio: 100/5 a (note: must be the same at all locations) ct class: c200 secondary resistance: 0.1 ohms (at 100/5 tap) cable loop resistance: ct) to be limited to a...

  • Page 161

    Where 200ma is the current drawn by the ied circuit and 50ma is the current drawn by each ct just at pickup. The magnetizing current is taken from the magnetizing curve of the current transformer cores, which should be available. The value at trippickup is taken. Restricted earth fault protection re...

  • Page 162

    87n en05000177_ansi.Vsd ansi05000177 v1 en figure 44: application of hzpdif (87) function as a restricted earth fault ied for an ynd transformer setting example it is strongly recommended to use the highest tap of the ct whenever high impedance protection is used. This helps in utilizing maximum ct ...

  • Page 163

    Basic data: transformer rated current on hv winding: 250 a current transformer ratio: 600-300/5a a (note: must be the same at all locations) ct class: c200 cable loop resistance: and the farthest ct) to be limited to approx. 0.05 ohms at 75deg c gives loop resistance 2 · 0.05 = 0.1 ohms max fault cu...

  • Page 164

    Alarm level operation the 1ph high impedance differential protection hzpdif (87) function has a separate alarm level, which can be used to give alarm for problems with an involved current transformer circuit. The setting level is normally selected to be around 10% of the operating voltage trippickup...

  • Page 165

    3.5.3.5 setting parameters table 46: hzpdif (87) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation alarmpickup 2 - 500 v 1 10 alarm voltage level on ct secondary talarm 0.000 - 60.000 s 0.001 5.000 time delay to ...

  • Page 166

    Stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system. The distance protection function in the ied is designed to meet basic requirements for application on transmission and sub-transmission lines (solid grounded systems) ...

  • Page 167

    Z 0 is the zero sequence impedance (Ω/phase) z f is the fault impedance (Ω), often resistive z n is the ground-return impedance defined as (z 0 -z 1 )/3 the voltage on the healthy phases is generally lower than 140% of the nominal phase-to- ground voltage. This corresponds to about 80% of the nomina...

  • Page 168

    X 1 is setting of the reactive positive sequence reach the magnitude of the ground-fault current in effectively grounded networks is high enough for impedance measuring elements to detect ground faults. However, in the same way as for solidlygrounded networks, distance protection has limited possibi...

  • Page 169

    Ic ic ic il ir en05000216_ansi.Vsd ansi05000216 v1 en figure 47: high impedance grounded network the operation of high impedance grounded networks is different compared to solid grounded networks where all major faults have to be cleared very fast. In high impedance grounded networks, some system op...

  • Page 170

    The infeed factor (i a +i b )/i a can be very high, 10-20 depending on the differences in source impedances at local and remote end. 21 zl 21 es a v a va a b es b i a i b r f p*zl (1-p)*zl z sa z sb en05000217_ansi.Vsd ansi05000217 v1 en figure 48: influence of fault current infeed from remote line ...

  • Page 171

    The ied has a built in function which shapes the characteristic according to the right figure of figure 49 . The load encroachment algorithm will increase the possibility to detect high fault resistances, especially for phase-to-ground faults at remote line end. For example, for a given setting of t...

  • Page 172

    In short line applications, the major concern is to get sufficient fault resistance coverage. Load encroachment is not so common. The line length that can be recognized as a short line is not a fixed length; it depends on system parameters such as voltage and source impedance, see table 47 . Table 4...

  • Page 173

    The ied's ability to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase-to-phase and phase- to-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults at th...

  • Page 174

    From an application point of view there exists three types of network configurations (classes) that must be considered when making the settings for the protection function. The different network configuration classes are: 1. Parallel line with common positive and zero sequence network 2. Parallel ci...

  • Page 175

    Parallel line in service this type of application is very common and applies to all normal sub-transmission and transmission networks. Let us analyze what happens when a fault occurs on the parallel line see figure 51 . From symmetrical components, we can derive the impedance z at the relay point fo...

  • Page 176

    A b c z 0m z 0m z 0 - z 0m z 0 - iec09000253_1_en.Vsd iec09000253 v1 en figure 52: equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar when mutual coupling is introduced, the voltage at the relay point a ...

  • Page 177

    ( ) a l ph n 0 nm 0p v p z1 i k 3i k 3i = × + × + × equation1278 v3 en (equation 62) one can also notice that the following relationship exists between the zero sequence currents: ( ) 0 3 0 3 0 0 2 l l i z i p z p × = × - equation1279 v2 en (equation 63) simplification of equation 63 , solving it fo...

  • Page 178

    Z0m a b 21 21 en05000222_ansi.Vsd closed closed open open ansi05000222 v1 en figure 53: the parallel line is out of service and grounded when the parallel line is out of service and grounded at both line ends on the bus bar side of the line cts so that zero sequence current can flow on the parallel ...

  • Page 179

    2 0 0 0 2 2 0 0 1 m e x r r r x æ ö = · + ç ÷ + è ø document11520-img3502 v1 en (equation 67) 2 0 0 0 2 2 0 0 1 m e x x x r x æ ö = · - ç ÷ + è ø document11520-img3503 v1 en (equation 68) parallel line out of service and not grounded z0m a open 21 21 en05000223_ansi.Vsd closed open closed b ansi0500...

  • Page 180

    A b c iec09000255_1_en.Vsd i 0 i 0 z 0m z 0 - z 0m z 0m z 0 - iec09000255 v1 en figure 56: equivalent zero-sequence impedance circuit for a double-circuit line with one circuit disconnected and not grounded the reduction of the reach is equal to equation 69 . ( ) ( ) ( ) 2 1 0 0 1 0 0 1 0 1 2 3 1 1 ...

  • Page 181

    Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. Tapped line application a b 21 21 21 c t i c i a i b -i b en05000224_ansi.Vsd ansi05000224 v1 en figure 57: example of tapped line with auto transformer thi...

  • Page 182

    Where: z at and z ct is the line impedance from the a respective c station to the t point. I a and i c is fault current from a respective c station for fault between t and b. V2/v1 transformation ratio for transformation of impedance at v1 side of the transformer to the measuring side v2 (it is assu...

  • Page 183

    1.4 28707 l rarc i × = equation1456 v1 en (equation 76) where: l represents the length of the arc (in meters). This equation applies for the distance protection zone 1. Consider approximately three times arc foot spacing for the zone 2 and wind speed of approximately 30 m/h i is the actual fault cur...

  • Page 184

    In case of parallel lines, consider the influence of the mutual coupling according to section "parallel line application with mutual coupling" and select the case(s) that are valid in the particular application. By proper setting it is possible to compensate for the cases when the parallel line is i...

  • Page 185

    A b 21 c i a ib z ac z cb z cf ia+ ib ansi05000457-2-en.Vsd f ansi05000457 v2 en figure 58: setting of overreaching zone setting of reverse zone the reverse zone is applicable for purposes of scheme communication logic, current reversal logic, weak-end infeed logic, and so on. The same applies to th...

  • Page 186

    Parallel line in service – setting of zone 2 overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases. The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase-to-ground fault located at the end of a prot...

  • Page 187

    Set the values of the corresponding zone (zero-sequence resistance and reactance) equal to: r 0e r 0 1 x m0 2 r 0 2 x 0 2 + -------------------------- + è ø ç ÷ æ ö × = equation561 v1 en (equation 84) x 0e x 0 1 x m0 2 r 0 2 x 0 2 + -------------------------- – è ø ç ÷ æ ö × = equation562 v1 en (equ...

  • Page 188

    Rfpp 3 x1 £ × iecequation2306 v1 en (equation 89) load impedance limitation, without load encroachment function the following instructions are valid when phase selection with load encroachment, quadrilateral characteristic function fdpspdis (21) is not activated. To deactivate the function, the sett...

  • Page 189

    Rfpe 0.8 z load × £ equation792 v1 en (equation 92) this equation is applicable only when the loop characteristic angle for the single phase- to-ground faults is more than three times as large as the maximum expected load- impedance angle. For the case when the loop characteristic angle is less than...

  • Page 190

    Load impedance limitation, with phase selection with load encroachment, quadrilateral characteristic function activated the parameters for shaping of the load encroachment characteristic are found in the description of phase selection with load encroachment, quadrilateral characteristic function (fd...

  • Page 191

    1 2 1 2 1 2 0.8 1 0.2 1 arg re l l l l m l l v v argdir argneg s i × + × - equation1553 v2 en (equation 97) where: angdir is the setting for the lower boundary of the forward directional characteristic, by default set to 15 (= -15 degrees) and angnegres is the setting for the upper boundary of the f...

  • Page 192

    R x angdir angnegres en05000722_ansi.Vsd ansi05000722 v1 en figure 59: setting angles for discrimination of forward and reverse fault in directional impedance quadrilateral function zdrdir (21d) the reverse directional characteristic is equal to the forward characteristic rotated by 180 degrees. The...

  • Page 193

    Setting of timers for distance protection zones the required time delays for different distance protection zones are independent of each other . Distance protection zone 1 can also have a time delay, if so required for selectivity reasons. Time delays for all zones can be set in a range of 0 to 60 s...

  • Page 194

    Name values (range) unit step default description tpg 0.000 - 60.000 s 0.001 0.000 time delay of trip, ph-g iminpupp 10 - 1000 %ib 1 20 minimum pickup delta current (2 x current of lagging phase) for phase-to-phase loops iminpupg 10 - 1000 %ib 1 20 minimum pickup phase current for phase-to- ground l...

  • Page 195

    Table 51: zdrdir (21d) group settings (basic) name values (range) unit step default description ibase 1 - 99999 a 1 3000 base setting for current level vbase 0.05 - 2000.00 kv 0.05 400.00 base setting for voltage level iminpupp 5 - 30 %ib 1 10 minimum pickup delta current (2 x current of lagging pha...

  • Page 196

    The distance protection function is designed to meet basic requirements for application on transmission and sub transmission lines (solid grounded systems) although it also can be used on distribution levels. System grounding the type of system grounding plays an important roll when designing the pr...

  • Page 197

    The voltage on the healthy phases is generally lower than 140% of the nominal phase-to- ground voltage. This corresponds to about 80% of the nominal phase-to-phase voltage. The high zero sequence current in solid grounded networks makes it possible to use impedance measuring technique to detect grou...

  • Page 198

    Occurs on the protected line. The fault infeed may enlarge the fault impedance seen by the distance protection. This effect is very important to keep in mind when both planning the protection system and making the settings. With reference to figure 61 , we can draw the equation for the bus voltage v...

  • Page 199

    Impedance. This has the drawback that it will reduce the sensitivity of the protection that is, the ability to detect resistive faults. The ied has a built in function which shapes the characteristic according to the right figure 62 . The load encroachment algorithm increases the possibility to dete...

  • Page 200

    Table 52: definition of long lines line category vn vn 110 kv 500 kv long lines 45-60 miles 200-250 miles very long lines >60 miles >250 miles the possibility in ied to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings fo...

  • Page 201

    Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines. The lines need not be of the same voltage to experience mutual coupling, and some coupling exists even for lines that are separated by 100 meters or more. The reason to the introduced error in...

  • Page 202

    Parallel line applications this type of networks are defined as those networks where the parallel transmission lines terminate at common nodes at both ends. We consider the three most common operation modes: • parallel line in service • parallel line out of service and grounded • parallel line out o...

  • Page 203

    Z0m a b 21 21 en05000221_ansi.Vsd fault ansi05000221 v1 en figure 64: class 1, parallel line in service the equivalent circuit of the lines can be simplified, as shown in figure 65 . A b c z0m z0 z0 m - z0 z0 m - 99000038.Vsd iec99000038 v1 en figure 65: equivalent zero sequence impedance circuit of...

  • Page 204

    Where: knm = z0m/(3 · z1l) the second part in the parentheses is the error introduced to the measurement of the line impedance. If the current on the parallel line has negative sign compared to the current on the protected line that is, the current on the parallel line has an opposite direction comp...

  • Page 205

    Calculation for a 400 kv line, where we for simplicity have excluded the resistance, gives with x1l=0.48 ohm/mile, x0l=1.4ohms/mile, zone 1 reach is set to 90% of the line reactance p=71% that is, the protection is underreaching with approximately 20%. The zero-sequence mutual coupling can reduce th...

  • Page 206

    2 2 0 0 om e z z z z - = equation2002 v4 en (equation 111) the influence on the distance measurement can be a considerable overreach, which must be considered when calculating the settings. It is recommended to use a separate setting group for this operation condition, since it reduces the reach con...

  • Page 207

    Practice, the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 68 . The line zero-sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit. This means that the reach of the ...

  • Page 208

    ( ) ( ) ( ) ( ) 2 0 2 2 re re 1 re im m u a x k a a × = + + é ù é ù ë û ë û equation1287 v2 en (equation 117) the imaginary component of the same factor is equal to equation 118 . ( ) ( ) ( ) ( ) 2 0 2 2 im im re im m u a x k a a × = + é ù é ù ë û ë û equation1288 v2 en (equation 118) ensure that th...

  • Page 209

    This application gives rise to similar problem that was highlighted in section "fault infeed from remote end" that is, increased measured impedance due to fault current infeed. For example, for faults between the t point and b station the measured impedance at a and c is as follows: z a =z at + ·z t...

  • Page 210

    Fault resistance the performance of distance protection for single phase-to-ground faults is very important, because normally more than 70% of the faults on transmission lines are single phase-to-ground faults. At these faults, the fault resistance is composed of three parts: arc resistance, resista...

  • Page 211

    Steady state voltage regulation and increase of voltage collapse limit a series capacitor is capable of compensating the voltage drop of the series inductance in a transmission line, as shown in figure 71 . During low loading, the system voltage drop is lower and at the same time, the voltage drop o...

  • Page 212

    En06000586_ansi.Vsd 0 200 400 600 800 1000 1200 1400 1600 1800 100 200 300 400 500 p[mw] v [k v ] v limit p 0 p 3 0 p 5 0 p 7 0 ansi06000586 v1 en figure 72: voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation increased power transfer capability by raising the first...

  • Page 213

    En06000588.Vsd 0 c ea a acc a dec a sm cr p mech p mech p [p u ] p [p u ] with sc without sc a acc a dec a sm 0 c ea cr iec06000588 v1 en figure 74: equal area criterion and first swing stability without and with series compensation this means that the system is stable if a acc ≤ (a dec + a sm ). Th...

  • Page 214

    Capacitive inductive 200 400 600 800 1000 200 400 600 q (mvar) 500 1000 1500 power flow (mw) (t.L.) (s.C.) (t.L. + s.C.) transmission line series compensation 500 kv 500 km k = 50 % en06000589.Vsd iec06000589 v1 en figure 75: self-regulating effect of reactive power balance increase in power transfe...

  • Page 215

    The effect on the power transfer when considering a constant angle difference (δ) between the line ends is illustrated in figure 77 . Practical compensation degree runs from 20 to 70 percent. Transmission capability increases of more than two times can be obtained in practice. En06000592.Vsd 0 0.1 0...

  • Page 216

    1 1 2 2 - = l c l l l x x r x r equation1899 v1 en (equation 125) reduced costs of power transmission due to decreased investment costs for new power line as shown in figure 77 the line loading can easily be increased 1.5-2 times by series compensation. Thus, the required number of transmission line...

  • Page 217

    En06000595.Vsd fw rv -jx c fw rv -jx c fw rv -jx c iec06000595 v1 en figure 80: thyristor switched series capacitor en06000596_ansi.Vsd -jx c fw rv jx l i l i v v c + - ansi06000596 v1 en figure 81: thyristor controlled series capacitor i l line current i v current through the thyristor u c voltage ...

  • Page 218

    En06000597.Vsd u c x c 0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 0.16 0.18 0.2 -2 0 2 0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 0.16 0.18 0.2 -5 0 5 0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 0.16 0.18 0.2 -50 0 50 0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 0.16 0.18 0.2 -40 -20 0 i l i v 0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 ...

  • Page 219

    En06000598.Vsd imperatriz tcsc, operating range -0.4 -0.2 0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.2 2.4 2.6 2.8 3 3.2 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 line current (arms) x tc s c /x c ( p u ) continuous 30 min. Overload 10s overload bypass mode series5 continuous 30 min 10s b c d e ...

  • Page 220

    Voltage and current inversion series capacitors influence the magnitude and the direction of fault currents in series compensated networks. They consequently influence phase angles of voltages measured in different points of series compensated networks and this performances of different protection f...

  • Page 221

    En06000605_ansi.Vsd ~ 21 x s x l1 i f v v m source fault voltage pre -fault voltage x c source voltage v’ m with bypassed capacitor with inserted capacitor f x ansi06000605 v1 en figure 84: voltage inversion on series compensated line en06000606_ansi.Vsd i f v s v ’ m = xv l xv s i f x v l v s x v c...

  • Page 222

    The ied point voltage inverses its direction due to presence of series capacitor and its dimension. It is a common practice to call this phenomenon voltage inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle. The most k...

  • Page 223

    The first case corresponds also to conditions on non compensated lines and in cases, when the capacitor is bypassed either by spark gap or by the bypass switch, as shown in phasor diagram in figure 87 . The resultant reactance is in this case of inductive nature and the fault currents lags source vo...

  • Page 224

    Based on residual (zero sequence) and negative sequence currents should be considered in studies as well. Current inversion in zero sequence systems with low zero sequence source impedance (a number of power transformers connected in parallel) must be considered as practical possibility in many mode...

  • Page 225

    ( ) ( ) ( ) ( ) 0 2 2 sin sin w l j l j w w j - × = é ù = × × + - + - × - × ê ú ë û = + × æ ö × = ç ÷ è ø l l r t l g g l l t l l l l e e i t i e z z z r l l atg r equation1906 v1 en (equation 132) the line fault current consists of two components: • the steady-state component which magnitude depend...

  • Page 226

    ( ) ( ) ( ) [ ] ( ) ( ) ( ) ( ) 1 2 2 2 1 ( 0) ( 0) ( 0) 2 2 sin cos sin 1 sin sin cos 2 1 sin 2 2 1 4 a w l j b b w w l j w l l j b l j a b - × = = = = × × + - + × × + × × × = + × - × = - × - × × × - - × - × - - = × × - × - × = × = - × × æ ö ç ÷ è ø é ù ê ú ê ú ê ú ê ú ë û t g l sc sc l l l g l t s...

  • Page 227

    0 0.02 0.04 0.06 0.08 0.1 0.12 0.14 0.16 0.18 0.2 10 5 5 10 t[ms ] i[ pu ] en06000610.Vsd iec06000610 v1 en figure 89: short circuit currents for the fault at the end of 500 km long 500 kv line without and with sc location of instrument transformers location of instrument transformers relative to th...

  • Page 228

    Ct1 and vt1 on figure 90 represent the case with bus side instrument transformers. The protection devices are in this case exposed to possible voltage and current inversion for line faults, which decreases the required dependability. In addition to this may series capacitor cause negative apparent i...

  • Page 229

    Distance ied near the feeding bus will see in different cases fault on remote end bus depending on type of overvoltage protection used on capacitor bank (spark gap or mov) and sc location on protected power line. En06000612_ansi.Vsd ~ e a 0% 33% 50% 66% k c = 80% 33% 33% 50 % 21 100 % 80 % x ansi060...

  • Page 230

    En06000614_ansi.Vsd mov protected series capacitor 0 10 20 30 40 50 60 20 10 10 20 0 10 20 30 40 50 60 100 50 50 100 0 10 20 30 40 50 60 20 10 10 20 0 10 20 30 40 50 60 20 10 10 20 line current as a function of time capacitor voltage as a function of time capacitor current as a function of time mov ...

  • Page 231

    Extensive studies at bonneville power administration in usa ( ref. Goldsworthy, d,l “a linearized model for mov-protected series capacitors” paper 86sm357–8 ieee/ pes summer meeting in mexico city july 1986) have resulted in construction of a non- linear equivalent circuit with series connected capa...

  • Page 232

    • series capacitor becomes nearly completely bridged by mov when the line current becomes higher than 10-times the protective current level (i £ 10· k p · i nc ). Impact of series compensation on protective ied of adjacent lines voltage inversion is not characteristic for the buses and ied points cl...

  • Page 233

    Equation 139 indicates the deepness of the network to which it will feel the influence of series compensation through the effect of voltage inversion. It is also obvious that the position of series capacitor on compensated line influences in great extent the deepness of voltage inversion in adjacent...

  • Page 234

    May help eliminating the basic reason for wrong measurement. The most known of them are decrease of the reach due to presence of series capacitor, which apparently decreases the line reactance, and introduction of permanent memory voltage in directional measurement. Series compensated and adjacent l...

  • Page 235

    Equation 140 is applicable for the case when the vts are located on the bus side of series capacitor. It is possible to remove x c from the equation in cases of vts installed in line side, but it is still necessary to consider the safety factor k s . If the capacitor is out of service or bypassed, t...

  • Page 236

    11 11 + c s x x x x equation1898 v1 en (equation 141) and in figure 99 a three phase fault occurs beyond the capacitor. The resultant ied impedance seen from the d b ied location to the fault may become negative (voltage inversion) until the spark gap has flashed. Distance protections of adjacent po...

  • Page 237

    En06000621_ansi.Vsd b a1 a2 a3 d b d a3 d a2 d a1 jx 11 i a1 i a2 i a3 i f -jx c jx 1 jx 2 jx 3 f x ansi06000621 v1 en figure 99: distance ied on adjacent power lines are influenced by the negative impedance normally the first zone of this protection must be delayed until the gap flashing has taken ...

  • Page 238

    Ordinary fault. However, a good protection system should be able to operate correctly before and after gap flashing occurs. En06000625.Vsd jx r x 11 x 12 x c z s iec06000625 v1 en figure 100: cross-polarized quadrilateral characteristic en06000584_small.Vsd jx r x 11 x 12 x c z s x f w x r v r fw r ...

  • Page 239

    In figure 86 and a fault occurs behind the capacitor, the resultant reactance becomes negative and the fault current will have an opposite direction compared with fault current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the...

  • Page 240

    Series compensation additionally exaggerates the effect of zero sequence mutual impedance between two circuits, see figure 103 . It presents a zero sequence equivalent circuit for a fault at b bus of a double circuit line with one circuit disconnected and grounded at both ieds. The effect of zero se...

  • Page 241

    Protection on healthy circuit and this way endangers even more the complete system stability. To avoid the unwanted tripping, some manufacturers provide a feature in their distance protection which detects that the fault current has changed in direction and temporarily blocks distance protection. An...

  • Page 242

    • the phase impedance of non transposed lines is not identical for all fault loops. The difference between the impedances for different phase-to-ground loops can be as large as 5-10% of the total line impedance. • the effect of a load transfer between the ieds of the protected fault resistance is co...

  • Page 243

    1 a b b af ac cf ac cf a a i i i z z z z z i i æ ö + = + × = + + × ç ÷ è ø equation302 v3 en (equation 150) a b 21 c i a ib z ac z cb z cf ia+ ib ansi05000457-2-en.Vsd f ansi05000457 v2 en figure 105: setting of reverse zone the reverse zone is applicable for purposes of scheme communication logic, ...

  • Page 244

    Directional control the directional function (zdsrdir) which is able to cope with the condition at voltage reversal, shall be used in all ieds with conventional distance protection (zmcpdis,zmcapdis, 21). This function is necessary in the protection on compensated lines as well as all non-compensate...

  • Page 245

    99000202.Vsd p 100 80 60 40 20 0 100 % 80 60 40 20 c % iec99000202 v1 en figure 106: reduced reach due to the expected sub-harmonic oscillations at different degrees of compensation c l x c degree of compensation x æ ö = ç ÷ ç ÷ è ø equation1894 v1 en (equation 152) x c is the reactance of the serie...

  • Page 246

    Reactive reach compensated lines with the capacitor into the zone 1 reach : x c a x lloc x l b en07000063.Vsd iec07000063 v1 en figure 107: simplified single line diagram of series capacitor located at x lloc ohm from a station section 3 1mrk504116-uus c ied application 240 application manual.

  • Page 247

    Jx r x 11 x 12 x c z s x f w x r v r fw r rv z s en06000584.Vsd iec06000584 v1 en figure 108: measured impedance at voltage inversion forward direction: where x lloc equals line reactance up to the series capacitor(in the picture approximate 33% of xline) x1 is set to (xlindex-xc) · p/100. P is defi...

  • Page 248

    When the calculation of xfw gives a negative value the zone 1 must be permanently blocked. For protection on non compensated lines facing series capacitor on next line. The setting is thus: • x1 is set to (xline-xc · k) · p/100. • k equals side infeed factor at next busbar. When the calculation of x...

  • Page 249

    The increased reach related to the one used in non compensated system is recommended for all protections in the vicinity of series capacitors to compensate for delay in the operation caused by the sub harmonic swinging. Settings of the resistive reaches are limited according to the minimum load impe...

  • Page 250

    Check the reduction of a reach for the overreaching zones due to the effect of the zero sequence mutual coupling. The reach is reduced for a factor: 0 0 1 2 1 0 m f z k z z r = - × + + equation1426 v1 en (equation 155) if the denominator in equation 155 is called b and z0m is simplified to x0m, then...

  • Page 251

    The final reach in resistive direction for phase-to-ground fault loop measurement automatically follows the values of the line-positive and zero-sequence resistance, and at the end of the protected zone is equal to equation 160 . 1 r (2 r1p g r0p g) rfp g 3 = × + + equation1716 v1 en (equation 160) ...

  • Page 252

    The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: min loa d ma x z v 3 i = × equation1719 v1 en (equation 165) minimum voltage vmin and maximum current imax are related to the same operating conditions. Minimum load impedance occurs normally un...

  • Page 253

    Rfpp 1.6 zload £ × load 1.6 z £ × rfpp equation579 v2 en (equation 168) equation 168 is applicable only when the loop characteristic angle for the phase-to- phase faults is more than three times as large as the maximum expected load- impedance angle. More accurate calculations are necessary accordin...

  • Page 254

    Setting of timers for distance protection zones the required time delays for different distance-protection zones are independent of each other. Distance protection zone1 can also have a time delay, if so required for selectivity reasons. One can set the time delays for all zones (basic and optional)...

  • Page 255

    Name values (range) unit step default description r1pg 0.01 - 1000.00 ohm/p 0.01 5.00 positive seq. Resistance for characteristic angle, ph-g x0pg 0.10 - 9000.00 ohm/p 0.01 100.00 zero sequence reactance reach, ph-g r0pg 0.01 - 3000.00 ohm/p 0.01 47.00 zero seq. Resistance for zone characteristic an...

  • Page 256

    Name values (range) unit step default description operationpg disabled enabled - - enabled operation mode disable/enable of phase- ground loops x1fwpg 0.10 - 3000.00 ohm/p 0.01 30.00 positive sequence reactance reach, ph-g, forward r1pg 0.01 - 1000.00 ohm/p 0.01 5.00 positive seq. Resistance for cha...

  • Page 257

    Name values (range) unit step default description rldfwd 1.00 - 3000.00 ohm/p 0.01 80.00 forward resistive reach for the load impedance area rldrev 1.00 - 3000.00 ohm/p 0.01 80.00 reverse resistive reach for the load impedance area ldangle 5 - 70 deg 1 30 load angle determining the load impedance ar...

  • Page 258

    3.6.3.2 application the operation of transmission networks today is in many cases close to the stability limit. The ability to accurately and reliably classify the different types of fault, so that single pole tripping and autoreclosing can be used plays an important role in this matter. Phase selec...

  • Page 259

    Rfltrevpp and rfltrevpp for phase-to-phase faults have to be increased to avoid that fdpspdis (21) characteristic shall cut off some part of the zone characteristic. The necessary increased setting of the fault resistance coverage can be derived from trigonometric evaluation of the basic characteris...

  • Page 260

    R x 60° 60° 1 2 3 5 6 6 6 6 7 7 8 8 4 iec09000043_1_en.Vsd w ( / loop) w ( / loop) 4 3 5 iec09000043 v1 en figure 109: relation between distance protection zmqpdis (21) and fdpspdis (21) for phase-to-ground fault φloop>60° (setting parameters in italic) 1 fdpspdis (21) (red line) 2 zmqpdis(21) 3 rfl...

  • Page 261

    The reactive reach in forward direction must as minimum be set to cover the measuring zone used in the teleprotection schemes, mostly zone 2. Equation 171 and equation 172 gives the minimum recommended reactive reach. Phs zm x1 1.44 x1 ³ × equation1309 v1 en (equation 171) phs zm x0 1.44 x0 ³ × equa...

  • Page 262

    The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme. In equation 174 the index zmrv references the specific zone to be coordinated to. Z...

  • Page 263

    R x 60° 60° 1 2 3 5 4 6 6 6 6 6 6 7 7 w ( /phase) iec09000257_1_en.Vsd w ( / phase) 5 3 8 4 8 iec09000257 v1 en figure 110: relation between distance protection (zmqpdis) (21) and fdpspdis (21) characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) 1 fdpspdis (21)(red l...

  • Page 264

    8 x1 zm resistive reach with load encroachment characteristic the procedure for calculating the settings for the load encroachment consist basically to define the load angle ldangle, the blinder rldfwd in forward direction and blinder rldrev in reverse direction, as shown in figure 111 . R x rldfwd ...

  • Page 265

    The resistive boundary rldrev for load encroachment characteristic in reverse direction can be calculated in the same way as rldfwd, but use maximum importing power that might occur instead of maximum exporting power and the relevant vmin voltage for this condition. Minimum operate currents fdpspdis...

  • Page 266

    Table 57: fdpspdis (21) group settings (advanced) name values (range) unit step default description operationz disabled enabled - - enabled operation of impedance based measurement operationi> disabled enabled - - disabled operation of current based measurement iph> 10 - 2500 %ib 1 120 start value f...

  • Page 267

    System grounding the type of system grounding plays an important role when designing the protection system. In the following some hints with respect to distance protection are highlighted. Solid grounded networks in solid grounded systems the transformer neutrals are connected solidly to ground with...

  • Page 268

    The high zero-sequence current in solid grounded networks makes it possible to use impedance measuring technique to detect ground fault. However, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(...

  • Page 269

    What is typical for this type of network is that the magnitude of the ground-fault current is very low compared to the short-circuit current. The voltage on the healthy phases will get a magnitude of √3 times the phase voltage during the fault. The zero- sequence voltage (3v0) will have the same mag...

  • Page 270

    Of cross-country faults, many network operators want to selectively clear one of the two ground faults. To handle this type phenomena phase preference logic function (pplphiz) is needed, which is not common to be used in transmission applications. In this type of network, it is mostly not possible t...

  • Page 271

    Load encroachment in some cases the load impedance might enter the zone characteristic without any fault on the protected line. The phenomenon is called load encroachment and it might occur when an external fault is cleared and high emergency load is transferred on the protected line. The effect of ...

  • Page 272

    R x rld rld ldangle ldangle ldangle ldangle en06000404_ansi.Vsd ansi06000404 v1 en figure 116: load encroachment of faulty phase identification with load encroachment for mho function fmpspdis (21) characteristic the use of the load encroachment feature is essential for long heavy loaded lines, wher...

  • Page 273

    In short line applications, the major concern is to get sufficient fault resistance coverage. Load encroachment is not so common. The line length that can be recognized as a short line is not a fixed length; it depends on system parameters such as voltage and source impedance, see table 47 . Table 5...

  • Page 274

    Blinder might cut off a larger part of the operating area of the circle (see to the right of figure 115 ). It is recommended to use at least one of the load discrimination functions for long heavy loaded transmission lines. Parallel line application with mutual coupling general introduction of paral...

  • Page 275

    • the possibility of different setting values that influence the ground-return compensation for different distance zones within the same group of setting parameters. • different groups of setting parameters for different operating conditions of a protected multi circuit line. Most multi circuit line...

  • Page 276

    A b c z0m z0 z0 m - z0 z0 m - 99000038.Vsd iec99000038 v1 en figure 118: equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar. If the current on the parallel line have negative sign compared to the current...

  • Page 277

    When the parallel line is out of service and grounded at both ends on the bus bar side of the line ct so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 119 . Z z0 0 m z z0 0 m z0m a b c 99000039.Vsd i 0...

  • Page 278

    When the parallel line is out of service and not grounded, the zero sequence on that line can only flow through the line admittance to the ground. The line admittance is high which limits the zero sequence current on the parallel line to very low values. In practice, the equivalent zero sequence imp...

  • Page 279

    A b 21 21 21 c t i c i a i b -i b ansi09000160-1-en.Vsd f ansi09000160 v1 en figure 123: example of tapped line with auto transformer this application gives rise to similar problem that was highlighted in section "fault infeed from remote end" , that is, increased measured impedance due to fault cur...

  • Page 280

    For this example with a fault between t and b, the measured impedance from the t point to the fault will be increased by a factor defined as the sum of the currents from t point to the fault divided by the ied current. For the ied at c, the impedance on the high voltage side v1 has to be transferred...

  • Page 281

    The setting values of all parameters that belong to zmhpdis must correspond to the parameters of the protected line and be coordinated to the selectivity plan for the network. Use different setting groups for the cases when the parallel line is in operation, out of service and not grounded and out o...

  • Page 282

    • the impedance corresponding to the protected line, plus the first zone reach of the shortest adjacent line. • the impedance corresponding to the protected line, plus the impedance of the maximum number of transformers operating in parallel on the bus at the remote end of the protected line. If the...

  • Page 283

    Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines. Equation 190 can be used to calculate the reach in reverse direction when the zone is used for blocking scheme, weak-end infeed, and so on. Zrev 1.2 zl-z2rem ³ × equation1525 v4 en (equation 190) where: ...

  • Page 284

    0 0 1 2 1 0 m f z k z z r = - × + + equation1426 v1 en (equation 193) if needed, enlarge the zone reach due to the reduction by mutual coupling. Consider also the influence on the zone reach due to fault current infeed from adjacent lines. Parallel line is out of service and grounded in both ends ap...

  • Page 285

    To avoid load encroachment for the phase-to-ground measuring elements, the set impedance reach of any distance protection zone must be less than 80% of the minimum load impedance. For setting of the ground-fault loop, the following formula can be used: load z zpe 1.6 2(1 cos( )) b £ × - equation1604...

  • Page 286

    The maximum setting for phase-to-phase fault can be defined by trigonometric analyze of the same figure 125 . The formula to avoid load encroachment for the phase-to-phase measuring elements will thus be according to equation 197 . Load z zpp 1.6 2 (1 cos( pp)) j £ × × - equation1605 v1 en (equation...

  • Page 287

    Setting of direction for offset mho if offset mho has been selected, one can select if the offset mho shall be non- directional, forward or reverse by setting the parameter offfsetmhodir. When forward or reverse operation is selected, then the operation characteristic will be cut off by the directio...

  • Page 288

    Name values (range) unit step default description zangpg 10 - 90 deg 1 80 angle for positive sequence line impedance for phase-ground loop kn 0.00 - 3.00 - 0.01 0.80 magnitud of ground return compensation factor kn knang -180 - 180 deg 1 -15 angle for ground return compensation factor kn zrevpg 0.00...

  • Page 289

    3.6.5 full-scheme distance protection, quadrilateral for earth faults zmmpdis (21), zmmapdis (21) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number fullscheme distance protection, quadrilateral for earth faults (zone 1) zmmpdis s00346 v1 en 21 fulls...

  • Page 290

    Xx05000215_ansi.Vsd ansi05000215 v1 en figure 126: solidly grounded network the ground fault current is as high or even higher than the short-circuit current. The series impedances determine the magnitude of the ground fault current. The shunt admittance has very limited influence on the ground faul...

  • Page 291

    Effectively grounded networks a network is defined as effectively grounded if the ground fault factor fe is less than 1.4. The ground fault factor is defined according to equation 52 . Max e pn v f v = ansiequation1268 v1 en (equation 199) where: v max is the highest fundamental frequency voltage on...

  • Page 292

    Voltage (3u0) will have the same magnitude in different places in the network due to low voltage drop distribution. The magnitude of the total fault current can be calculated according to the formula below: ( ) 2 2 r l c 0 3i i i i = + - equation1271 v3 en (equation 202) where: 3i0 is the ground-fau...

  • Page 293

    Preference logic (pplphiz) is needed, which is not common to be used in transmission applications. In this type of network, it is mostly not possible to use distance protection for detection and clearance of ground-faults. The low magnitude of the ground-fault current might not give start of the zer...

  • Page 294

    The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection. Load encroachment in some cases the load impedance might enter the zone characteristic without any fault on the protected line. The phenomenon is called ...

  • Page 295

    R x zm rldrev r zm rldfwd zl ansi05000495_2_en.Vsd load impedance area in forward direction ldangle ldangle ldangle ldangle ansi05000495 v2 en figure 129: load encroachment phenomena and shaped load encroachment characteristic short line application in short line applications, the major concern is t...

  • Page 296

    Long transmission line application for long transmission lines the margin to the load impedance that is, to avoid load encroachment, will normally be a major concern. It is difficult to achieve high sensitivity for phase-to-ground fault at remote end of a long lines when the line is heavy loaded. Th...

  • Page 297

    One example of class3 networks could be the mutual coupling between a 400 kv line and rail road overhead lines. This type of mutual coupling is not so common although it exists and is not treated any further in this manual. For each type of network class we can have three different topologies; the p...

  • Page 298

    Ph ph 0 1 ph 0 n ph 0 1 v v z z i 3i k i 3i 3 z z = = - + × + × × equation1275 v2 en (equation 206) where: vph is phase-to-ground voltage at the ied point iph is phase current in the faulty phase 3i0 is ground to fault current z1 is positive sequence impedance z0 is zero sequence impedance z0m a b z...

  • Page 299

    If the current on the parallel line have negative sign compare to the current on the protected line that is, the current on the parallel line has an opposite direction compare to the current on the protected line, the distance function will overreach. If the currents have the same direction, the dis...

  • Page 300

    Here the equivalent zero sequence impedance is equal to z0-z0m in parallel with (z0- z0m)/z0-z0m+z0m which is equal to equation 207 . 2 2 0 0 om e z z z z - = equation2002 v4 en (equation 207) the influence on the distance measurement will be a considerable overreach, which must be considered when c...

  • Page 301

    High which limits the zero sequence current on the parallel line to very low values. In practice, the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 134 the line zero-sequence mutual impedance does not influence the measur...

  • Page 302

    ( ) ( ) ( ) ( ) 2 0 2 2 re re 1 re im m u a x k a a × = + + é ù é ù ë û ë û equation1287 v2 en (equation 213) the imaginary component of the same factor is equal to equation 214 . ( ) ( ) ( ) ( ) 2 0 2 2 im im re im m u a x k a a × = + é ù é ù ë û ë û equation1288 v2 en (equation 214) ensure that th...

  • Page 303

    Infeed. For example for faults between the t point and b station the measured impedance at a and c will be z a =z at + ·z tf i a + i c i a document11524-img3509 v2 en (equation 215) 2 2 1 a c c trf ct tb c i i v z z z z v i = æ ö + æ ö + + × × ç ÷ ç ÷ è ø è ø equation1783-ansi v1 en (equation 216) w...

  • Page 304

    Fault resistance the performance of distance protection for single phase-to-ground faults is very important, because normally more than 70% of the faults on transmission lines are single phase-to-ground faults. At these faults, the fault resistance is composed of three parts: arc resistance, resista...

  • Page 305

    • the phase impedance of non transposed lines is not identical for all fault loops. The difference between the impedances for different phase-to-ground loops can be as large as 5-10% of the total line impedance. • the effect of a load transfer between the ieds of the protected fault resistance is co...

  • Page 306

    1 a b b af ac cf ac cf a a i i i z z z z z i i æ ö + = + × = + + × ç ÷ è ø equation302 v3 en (equation 218) a b 21 c i a ib z ac z cb z cf ia+ ib ansi05000457-2-en.Vsd f ansi05000457 v2 en figure 137: setting of reverse zone the reverse zone is applicable for purposes of scheme communication logic, ...

  • Page 307

    Parallel line in service – setting of zone1 with reference to section "parallel line applications" , the zone reach can be set to 85% of protected line. Parallel line in service – setting of zone2 overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases. The g...

  • Page 308

    Parallel line is out of service and grounded in both ends apply the same measures as in the case with a single set of setting parameters. This means that an underreaching zone must not overreach the end of a protected circuit for the single phase-to-ground faults. Set the values of the corresponding...

  • Page 309

    Load impedance limitation, without load encroachment function the following instructions is valid when the load encroachment function is not activated (operationldcmp is set to off). If the load encroachment function is to be used for all or some of the measuring zones, the load limitation for those...

  • Page 310

    This equation is applicable only when the loop characteristic angle for the single phase- to-ground faults is more than three times as large as the maximum expected load- impedance angle. More accurate calculations are necessary according to the equation below: min 2 1 0 0.8 cos sin 2 1 0 load r r r...

  • Page 311

    Setting of timers for distance protection zones the required time delays for different distance-protection zones are independent of each other. Distance protection zone1 can also have a time delay, if so required for selectivity reasons. One can set the time delays for all zones (basic and optional)...

  • Page 312

    Name values (range) unit step default description operationdir disabled non-directional forward reverse - - forward operation mode of directionality nondir / forw / rev x1 0.50 - 3000.00 ohm/p 0.01 40.00 positive sequence reactance reach r1 0.10 - 1000.00 ohm/p 0.01 5.00 positive seq. Resistance for...

  • Page 313

    Wideness of the operating sector. The sector is mirror-symmetric along the mta (maximum torque axis). Directional elements for ground-faults must operate at fault current values below the magnitude of load currents. As phase quantities are adversely affected by load, the use of sequence quantities a...

  • Page 314

    Current in the neutral of a power transformer. The relay characteristic anglerca is fixed and equals 0 degrees. Care must be taken to ensure that neutral current direction remains unchanged during all network configurations and faults, and therefore all transformer configurations/constructions are n...

  • Page 315

    3.6.6.3 setting parameters table 66: zdardir group settings (basic) name values (range) unit step default description ibase 1 - 99999 a 1 3000 base setting for current values vbase 0.05 - 2000.00 kv 0.05 400.00 base setting for voltage level in kv polmode -3u0 -v2 ipol dual -3u0comp -v2comp - - -3u0...

  • Page 316

    In the pilot channel blocking scheme a fault inception detected by a fast acting change detector is used to send a block signal to the remote end in order to block an overreaching zone. If the fault is later detected as a forward fault the earlier sent blocking signal is stopped. The blocking scheme...

  • Page 317

    Sirlevel: the setting of the parameter sirlevel is by default set to 10. This is a suitable setting for applications with cvt to avoid transient overreach due to the cvt dynamics. If magnetic voltage transformers are used, set sirlevel to 15 the highest level. Iminop: the minimum operate current for...

  • Page 318

    3.6.8.1 application the operation of transmission networks today is in many cases close to the stability limit. Due to environmental considerations the rate of expansion and reinforcement of the power system is reduced for example, difficulties to get permission to build new power lines. The ability...

  • Page 319

    I1lowlevel: the setting of the positive current threshold i1lowlevel used in the sequence based part of the phase selector for identifying three-phase fault, is by default set to 10% of ibase. The default setting is suitable in most cases, but must be checked against the minimum three-phase current ...

  • Page 320

    R x rldfw rldrv ldangle ldangle ldangle ansi10000192_1_en.Vsd ldangle ansi10000192 v1 en figure 138: load encroachment characteristic the calculation of the apparent load impedance z load and minimum load impedance z loadmin can be done according to equations: min max 3 i v zload = × equation1754-an...

  • Page 321

    Max cos max p ldangle a s æ ö = ç ÷ è ø equation1623-ansi v1 en (equation 240) where: pmax is the maximal active power transfer during emergency conditions and smax is the maximal apparent power transfer during emergency conditions. The rld can be calculated according to equation 241 : cos( ) rld zl...

  • Page 322

    Name values (range) unit step default description v2minop 1 - 100 %vb 1 5 minimum operate negative sequence voltage for ph sel inrelpg 10 - 100 %ib 1 20 3i0 limit for release ph-g measuring loops in % of max phase current 3i0blk_pp 10 - 100 %ib 1 40 3i0 limit for blocking phase-to-phase measuring lo...

  • Page 323

    System grounding the type of system grounding plays an important role when designing the protection system. Some hints with respect to distance protection are highlighted below. Solid grounded networks in solidly grounded systems, the transformer neutrals are connected solidly to ground without any ...

  • Page 324

    The high zero sequence current in solid grounded networks makes it possible to use impedance measuring technique to detect ground-fault. However, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(...

  • Page 325

    Detect high resistance faults and should therefore always be complemented with other protection function(s) that can carry out the fault clearance in this case. High impedance grounded networks in high impedance networks, the neutral of the system transformers are connected to the ground through hig...

  • Page 326

    Ic ic ic il ir en05000216_ansi.Vsd ansi05000216 v1 en figure 140: high impedance grounded network. The operation of high impedance grounded networks is different compared to solid grounded networks where all major faults have to be cleared very fast. In high impedance grounded networks, some system ...

  • Page 327

    The infeed factor (i a +i b )/i a can be very high, 10-20 depending on the differences in source impedances at local and remote end. 21 zl 21 es a v a va a b es b i a i b r f p*zl (1-p)*zl z sa z sb en05000217_ansi.Vsd ansi05000217 v1 en figure 141: influence of fault current infeed from remote line...

  • Page 328

    Necessary sensitivity of the distance protection. The function can also preferably be used on heavy loaded medium long lines. For short lines, the major concern is to get sufficient fault resistance coverage and load encroachment is not a major problem. So, for short lines, the load encroachment fun...

  • Page 329

    The ied's ability to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase-to-phase and phase- to-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults witho...

  • Page 330

    Experience mutual coupling, and some coupling exists even for lines that are separated by 100 meters or more. The mutual coupling does influence the zero sequence impedance to the fault point but it does not normally cause voltage inversion. It can be shown from analytical calculations of line imped...

  • Page 331

    1. Parallel line in service. 2. Parallel line out of service and grounded. 3. Parallel line out of service and not grounded. Parallel line in service this type of application is very common and applies to all normal sub-transmission and transmission networks. Let us analyze what happens when a fault...

  • Page 332

    Z0m a b 21 21 en05000221_ansi.Vsd fault ansi05000221 v1 en figure 143: class 1, parallel line in service. The equivalent zero sequence circuit of the lines can be simplified, see figure 52 . A b c z 0m z 0m z 0 - z 0m z 0 - iec09000253_1_en.Vsd iec09000253 v1 en figure 144: equivalent zero sequence ...

  • Page 333

    The second part in the parentheses is the error introduced to the measurement of the line impedance. If the current on the parallel line has negative sign compared to the current on the protected line, that is, the current on the parallel line has an opposite direction compared to the current on the...

  • Page 334

    The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation. The reduction of the reach is most pronounced with no current infeed in the ied closest to the fault. This reach reduction is normally less than 15%. ...

  • Page 335

    The influence on the distance measurement will be a considerable overreach, which must be considered when calculating the settings. It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation. All expression...

  • Page 336

    A b c iec09000255_1_en.Vsd i 0 i 0 z 0m z 0 - z 0m z 0m z 0 - iec09000255 v1 en figure 148: equivalent zero sequence impedance circuit for a double-circuit line with one circuit disconnected and not grounded. Tapped line application a b 21 21 21 c t i c i a i b -i b en05000224_ansi.Vsd ansi05000224 ...

  • Page 337

    Z a =z at + ·z tf i a + i c i a document11524-img3509 v2 en (equation 260) a c 2 c trf ct tb c i i v2 z z (z z ) ( ) v1 i + = + + × × equation1714 v1 en (equation 261) where: z at and z ct is the line impedance from the a respective c station to the t point. I a and i c is fault current from a respe...

  • Page 338

    Single phase-to-ground faults. At these faults, the fault resistance is composed of three parts: arc resistance, resistance of a tower construction, and tower-footing resistance.The resistance is also depending on the presence of ground shield conductor at the top of the tower, connecting tower-foot...

  • Page 339

    Setting of zone 1 the different errors mentioned earlier usually require a limitation of the underreaching zone (normally zone 1) to 75 - 90% of the protected line. In case of parallel lines, consider the influence of the mutual coupling according to section "parallel line application with mutual co...

  • Page 340

    A b 21 c i a ib z ac z cb z cf ia+ ib ansi05000457-2-en.Vsd f ansi05000457 v2 en figure 150: setting of overreaching zone setting of reverse zone the reverse zone is applicable for purposes of scheme communication logic, current reversal logic, weak-end infeed logic, and so on. The same applies to t...

  • Page 341

    Parallel line in service – setting of zone 2 overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases. The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase-to-ground fault located at the end of a prot...

  • Page 342

    Set the values of the corresponding zone (zero-sequence resistance and reactance) equal to: r 0e r 0 1 x m0 2 r 0 2 x 0 2 + -------------------------- + è ø ç ÷ æ ö × = equation561 v1 en (equation 270) x 0e x 0 1 x m0 2 r 0 2 x 0 2 + -------------------------- – è ø ç ÷ æ ö × = equation562 v1 en (eq...

  • Page 343

    Rfpp 3 x1 £ × iecequation2306 v1 en (equation 275) load impedance limitation, without load encroachment function the following instructions are valid when phase selection with load enchroachment, quadrilateral characteristic function frpspdis (21) is not activated. To deactivate the function, the se...

  • Page 344

    Loa d rfp g 0.8 z £ × equation1720 v1 en (equation 278) this equation is applicable only when the loop characteristic angle for the single phase- to-ground faults is more than three times as large as the maximum expected load- impedance angle. For the case when the loop characteristic angle is less ...

  • Page 345

    Load impedance limitation, with phase selection with load encroachment, quadrilateral characteristic function activated the parameters for shaping of the load encroachment characteristic are found in the description of phase selection with load encroachment, quadrilateral characteristic function (fr...

  • Page 346

    Name values (range) unit step default description x1pp 0.10 - 3000.00 ohm/p 0.01 30.00 positive sequence reactance reach ph-ph r1pp 0.01 - 1000.00 ohm/p 0.01 5.00 positive seq. Resistance for characteristic angle, ph-ph rfpp 0.10 - 3000.00 ohm/l 0.01 30.00 fault resistance reach in ohm/loop, ph-ph x...

  • Page 347

    Name values (range) unit step default description rfpp 0.10 - 3000.00 ohm/l 0.01 30.00 fault resistance reach in ohm/loop, ph-ph x1pg 0.10 - 3000.00 ohm/p 0.01 30.00 positive sequence reactance reach ph-g r1pg 0.01 - 1000.00 ohm/p 0.01 5.00 positive seq. Resistance for characteristic angle, ph-g x0p...

  • Page 348

    The heavy load transfer that is common in many transmission networks may in some cases be in opposite to the wanted fault resistance coverage. Therefore, the function has a built in algorithm for load encroachment, which gives the possibility to enlarge the resistive setting of both the phase select...

  • Page 349

    R x rldfwd rldrev ldangle ldangle ldangle ldangle en05000196_ansi.Vsd ansi05000196 v1 en figure 151: characteristic of load encroachment function the influence of load encroachment function on the operation characteristic is dependent on the chosen operation mode of the frpspdis (21) function. When ...

  • Page 350

    R x phselz dlecnd r x ansi10000099-1-en.Vsd ansi10000099 v1 en figure 152: operating characteristic when load encroachment is activated when the "phase selection" is set to operate together with a distance measuring zone the resultant operate characteristic could look something like in figure 153 . ...

  • Page 351

    R x distance measuring zone directional line load encroachment characteristic "phase selection" "quadrilateral" zone en05000673.Vsd iec05000673 v1 en figure 153: operation characteristic in forward direction when load encroachment is enabled figure 153 is valid for phase-to-ground. During a three-ph...

  • Page 352

    R x distance measuring zone phase selection ”quadrilateral” zone (ohm/phase) (ohm/phase) en05000674.Vsd iec05000674 v1 en figure 154: operation characteristic for frpspdis (21) in forward direction for three-phase fault, ohm/phase domain the result from rotation of the load characteristic at a fault...

  • Page 353

    R x iec08000437.Vsd iec08000437 v1 en figure 155: rotation of load characteristic for a fault between two phases this rotation may seem a bit awkward, but there is a gain in selectivity by using the same measurement as for the quadrilateral characteristic since not all phase-to-phase loops will be f...

  • Page 354

    For normal overhead lines, the angle for the loop impedance φ for phase-to-ground fault defined according to equation 170 . L l x1 arctan r1 + j = + xn rn equation2115 v1 en (equation 282) but in some applications, for instance cable lines, the angle of the loop might be less than the set angle. In ...

  • Page 355

    Rfpg zm x1 zm +xn zm x1 zm +xn zm rfpg zm r1 zm +rn rfpg zm rfpg zm r x phs zm 90° r1 zm +rn x1 phs +xn phs x1 phs +xn phs rffwdpg phs rfrevpg phs loop φ loop φ ansi08000435-1-en.Vsd (ohm/loop) 1 phs phs r pg rn + (minimum setting) 0 1 3 phs phs phs r pg r pg rn - = ansi08000435 v1 en figure 156: re...

  • Page 356

    Phs zm x0 1.44 x0 ³ × equation1310 v1 en (equation 284) where: x1 zm is the reactive reach for the zone to be covered by frpspdis (21), and the constant 1.44 is a safety margin x0 zm is the zero-sequence reactive reach for the zone to be covered by frpspdis (21) the reactive reach in reverse directi...

  • Page 357

    Resistive reach the resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme. In equation 174 the index zmrv references the specific zone to be c...

  • Page 358

    Where: rfpp zm is the setting of the longest reach of the overreaching zones that must be covered by frpspdis (21). Equation 288 and 289 are is also valid for three-phase fault. The proposed margin of 25% will cater for the risk of cut off of the zone measuring characteristic that might occur at thr...

  • Page 359

    R1 zm x1 zm x1 zm 0.5*rfpp zm r1 zm 0.5*rfpp zm 0.5*rfpp zm 0.5*rfpp pm 0.5*rfpp zm r 70 j ) phase / ( w 70 j phs zm 0.5 rffwdpp × 0.5 re rf vpp × 0.5 re rf vpp × 0.5*rfpp zm ansi08000249-1- en.Vsd tan 70° 1 x phs tan 70° 1 x phs x1 r1pp= r1pp= x ) phase / ( w ansi08000249 v1 en figure 157: relation...

  • Page 360

    Resistive reach with load encroachment characteristic the procedure for calculating the settings for the load encroachment consist basically to define the load angle ldangle, the blinder rldfwd in forward direction and blinder rldrev in reverse direction, as shown in figure 111 . R x rldfwd rldrev l...

  • Page 361

    Power that might occur instead of maximum exporting power and the relevant vmin voltage for this condition. Minimum operate currents frpspdis (21) has two current setting parameters, which blocks the respective phase- to-ground loop and phase-to-phase loop if the rms value of the phase current (iln)...

  • Page 362

    Name values (range) unit step default description rfltrevpg 1.00 - 9000.00 ohm/l 0.01 100.00 fault resistance reach, ph-g, reverse iminpupp 5 - 500 %ib 1 10 minimum pickup delta current (2 x current of lagging phase) for phase-to-phase loops iminpupg 5 - 500 %ib 1 5 minimum pickup phase current for ...

  • Page 363

    In the power system, which reflects further on in oscillating power flow between two parts of the system - the power swings from one part to another - and vice versa. Distance ieds located in interconnected networks see these power swings as the swinging of the measured impedance in relay points. Th...

  • Page 364

    3.6.11.2 setting guidelines setting guidelines are prepared in the form of a setting example for the protected power line as part of a two-machine system presented in figure 160 . 99001019_ansi.Vsd ~ ~ e a d a = const d b = f(t) e b a b z sa z sb z l r ansi99001019 v1 en figure 160: protected power ...

  • Page 365

    1200 p i a = equation1326 v1 en rated primary current of current protection transformers used 5 s i a = equation1734 v1 en rated secondary current of current protection transformers used ( ) 1 10.71 75.6 l z j = + w equation1328 v1 en line positive sequence impedance ( ) 1 1.15 43.5 sa z j = + w equ...

  • Page 366

    2 2 min min max 380 144.4 1000 l v z s = = = w equation1736-ansi v1 en (equation 293) the minimum load resistance r lmin at maximum load and minimum system voltage is equal to equation 294 . ( ) min min max cos 144.4 0.95 137.2 l l r z j = × = × = w equation1338 v1 en (equation 294) the system imped...

  • Page 367

    Ansi05000283 v1 en figure 161: impedance diagrams with corresponding impedances under consideration the outer boundary of oscillation detection characteristic in forward direction rldoutfw should be set with certain safety margin k l compared to the minimum expected load resistance r lmin . When the...

  • Page 368

    Is not known, the following approximations may be considered for lines with rated voltage 400 kv: • k l = 0.9 for lines longer than 100 miles • k l = 0.85 for lines between 50 and 100 miles • k l = 0.8 for lines shorter than 50 miles multiply the required resistance for the same safety factor k l wi...

  • Page 369

    76.5 64.5 1 13.3 360 2.5 360 in out si tp ms f d d - ° - ° = = = × ° × ° equation1347 v1 en (equation 303) the general tendency should be to set the tp1 time to at least 30 ms, if possible. Since it is not possible to further increase the external load angle δ out , it is necessary to reduce the inn...

  • Page 370

    Tp2 = 10 ms consider rldinfw = 75.0Ω. Do not forget to adjust the setting of load encroachment resistance rldfwd in phase selection with load encroachment (fdpspdis, 21 or frpspdis, 21) to the value equal to or less than the calculated value rldinfw. It is at the same time necessary to adjust the lo...

  • Page 371

    System studies should determine the settings for the hold timer th. The purpose of this timer is, to secure continuous output signal from power swing detection function (zmrpsb, 68) during the power swing, even after the transient impedance leaves zmrpsb (68) operating characteristic and is expected...

  • Page 372

    Name values (range) unit step default description tgf 0.000 - 60.000 s 0.001 3.000 timer for overcoming single-pole reclosing dead time iminpupg 5 - 30 %ib 1 10 minimum operate current in % of ibase ibase 1 - 99999 a 1 3000 base setting for current level settings table 79: zmrpsb (68) group settings...

  • Page 373

    Distance protection. The second fault can, but does not need to, occur within this time interval. • fault on an adjacent line (behind the b substation, see figure 162 ) causes the measured impedance to enter the operate area of zmrpsb (68) function and, for example, the zone 2 operating characterist...

  • Page 374

    R jx b a measured impedance at initital fault position impedance locus at initial power swing after the fault clearance zmrpsb operating characteristic zone 2 zone 1 iec99000181_2_en.Vsd iec99000181 v2 en figure 163: impedance trajectory within the distance protection zones 1 and 2 during and after ...

  • Page 375

    Communication and tripping logic as used by the power swing distance protection zones is schematically presented in figure 164 . The operation of the power swing zones is conditioned by the operation of power swing detection (zmrpsb, 68) function. They operate in putt or pott communication scheme wi...

  • Page 376

    Configuration configure the block input to any combination of conditions, which are supposed to block the operation of logic. Connection to detected fuse failure conditions is required as a minimum. The pudog functional input should be configured to the pickup signal of any line ground fault overcur...

  • Page 377

    Set the reactive reach for the power swing zones according to the system selectivity planning. The reach of the underreaching zone should not exceed 85% of the protected line length. The reach of the overreaching zone should be at least 120% of the protected line length. Resistive reach setting of c...

  • Page 378

    Time delay for the overreaching power swing zone is not an important parameter, if the zone is used only for the protection purposes at power-swings. Consider the normal time grading, if the overreaching zone serves as a time delayed back- up zone, which is not blocked by the operation of power swin...

  • Page 379

    Puzmur block and puzmor puzmpsd pupsd 0-tdz 0-tzl and or and and and -loop or puzmurps blkzmor and en06000237_ansi.Vsd 0 0 ansi06000237 v1 en figure 165: blocking and tripping logic for evolving power swings no system oscillation should be detected in power system. Configure for this reason the pups...

  • Page 380

    Of the faults on adjacent power lines. It is necessary to consider the possibility for the faults to occur close to the set reach of the underreaching distance protection zone, which might result in prolonged operate times of zone 1 (underreaching zone) compared to zone 2 pickuped time (overreaching...

  • Page 381

    The situation with pole slip of a generator can be caused by different reasons. A short circuit occurs in the external power grid, close to the generator. If the fault clearance time is too long, the generator will accelerate so much, so the synchronism cannot be maintained. The relative generator p...

  • Page 382

    The generator itself, the generator should be tripped as fast as possible. If the locus of the out of step centre is located in the power system outside the generators the power system should, if possible, be split into two parts, and the generators should be kept in service. This split can be made ...

  • Page 383

    The operation of a generator having pole slip will give risk of damages to the generator block. • at each pole slip there will be significant torque impact on the generator-turbine shaft. • in asynchronous operation there will be induction of currents in parts of the generator normally not carrying ...

  • Page 384

    Iec06000548_2_en.Vsd ied b a e b e a x’ d x t z s zone 1 zone 2 jx r zb za pole slip impedance movement zone 2 zone 1 warnangle tripangle f zc iec06000548 v2 en figure 168: settings for the pole slip detection function the impedanceza is the forward impedance as show in figure 168 . Za should be the...

  • Page 385

    The impedancezb is the reverse impedance as show in figure 168 . Zb should be equal to the generator transient reactance x'd. The impedance is given in % of the base impedance, see equation 316 . The impedancezc is the forward impedance giving the borderline between zone 1 and zone 2. Zc should be e...

  • Page 386

    Ied zb line impedance = zc za = forward source impedance iec07000014_2_en.Vsd iec07000014 v2 en figure 169: line application of pole slip protection if the apparent impedance crosses the impedance line zb – za this is the detection criterion of out of step conditions, see figure 170 . Section 3 1mrk...

  • Page 387

    R x apparent impedance at normal load z c z a z b anglephi iec07000015_2_en.Vsd iec07000015 v2 en figure 170: impedances to be set for pole slip protection the setting parameters of the protection is: z a : line + source impedance in the forward direction z b : the source impedance in the reverse di...

  • Page 388

    With all phase voltages and phase currents available and fed to the protection ied, it is recommended to set the measuremode to positive sequence. The impedance settings are set in pu with zbase as reference: 2 2 400 160 1000 = = = ubase zbase ohm sbase equation1960 v1 en (equation 317) 2 400 ( ) ( ...

  • Page 389

    The warning angle (startangle) should be chosen not to cross into normal operating area. The maximum line power is assumed to be 2000 mva. This corresponds to apparent impedance: 2 2 400 80 2000 u z ohm s = = = equation1967 v1 en (equation 323) simplified, the example can be shown as a triangle, see...

  • Page 390

    For the tripangle it is recommended to set this parameter to 90° to assure limited stress for the circuit breaker. In a power system it is desirable to split the system into predefined parts in case of pole slip. The protection is therefore situated at lines where this predefined split shall take pl...

  • Page 391

    R x apparent impedance at normal load z c z a z b anglephi iec07000015_2_en.Vsd iec07000015 v2 en figure 173: impedances to be set for pole slip protection pspppam (78) the setting parameters of the protection are: z a block transformer + source impedance in the forward direction z b the generator t...

  • Page 392

    Use the following block transformer data: vbase : 20 kv (low voltage side) sbase set to 200 mva e k : 15% short circuit power from the external network without infeed from the protected line: 5000 mva (assumed to a pure reactance). We have all phase voltages and phase currents available and fed to t...

  • Page 393

    2 20 0.15 0.3 200 t zc jx j j ohm = = × = equation1974 v1 en (equation 330) this corresponds to: 0.3 0.15 0.15 90 2.0 j zc j pu pu = = = Ð o equation1975 v2 en (equation 331) set zc to 0.15 and anglephi to 90°. The warning angle (startangle) should be chosen not to cross into normal operating area. ...

  • Page 394

    Za zb zload r x en07000016.Vsd iec07000016 v1 en figure 174: simplified figure to derive startangle 0 0 arctan arctan arctan + arctan = 7.1 + 5.4 0.25 0.19 13 2 2 ³ = » zb za anglestart + zload zload equation1977 v2 en (equation 333) in case of minor damped oscillations at normal operation we do not...

  • Page 395

    3.6.13.3 setting parameters table 81: pspppam (78) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation enable / disable operationz1 disabled enabled - - enabled operation enable/disable zone z1 operationz2 disabled enabled - - en...

  • Page 396

    3.6.14.1 application phase preference logic function pplphiz is an auxiliary function to distance protection zone, quadrilateral characteristic zmqpdis (21) and phase selection with load encroachment, quadrilateral characteristic function fdpspdis (21). The purpose is to create the logic in resonanc...

  • Page 397

    3v 0 v a vb vc v b f v c f v c f en06000551_ansi.Vsd ansi06000551 v1 en figure 176: the voltage increase on healthy phases and occurring neutral point voltage (3v0) at a single phase-to-ground fault and an occurring cross- country fault on different feeders in a sub-transmission network, high impeda...

  • Page 398

    I3p* v3p* block lovbz blktr phsel dircnd w2_ct_b_i3p w2_vt_b_v3p false w2_fsd1-blkz false i3p* v3p* block lovbz blktr phsel dircnd w2_ct_b_i3p w2_vt_b_v3p false w2_fsd1-blkz false w2_ct_b_i3p w2_vt_b_v3p false false false false phs_l1 phs_l2 phs_l3 ansi06000552-2-en.Vsd zmqapdis (21) trip tr_a tr_b ...

  • Page 399

    Ic=ig ia=ig en06000553_ansi.Vsd ansi06000553 v1 en figure 178: the currents in the phases at a double ground fault the function has a block input (block) to block start from the function if required in certain conditions. 3.6.14.2 setting guidelines the parameters for the phase preference logic func...

  • Page 400

    Ibase: base current level in a. The base current is used as reference for the neutral current setting factor. Normally it is set to the current transformer rated current. Pu27pn: the setting of the phase-to- ground voltage level (phase voltage) which is used by the evaluation logic to verify that a ...

  • Page 401

    3.6.14.3 setting parameters table 84: pplphiz group settings (basic) name values (range) unit step default description ibase 1 - 99999 a 1 3000 base current vbase 0.05 - 2000.00 kv 0.01 400.00 base voltage opermode no filter nopref 1231c 1321c 123a 132a 213a 231a 312a 321a - - no filter operating mo...

  • Page 402

    3.7.1.1 application long transmission lines often transfer great quantities of electric power from production to consumption areas. The unbalance of the produced and consumed electric power at each end of the transmission line is very large. This means that a fault on the line can easily endanger th...

  • Page 403

    Ibase: base current in primary a. This current is used as reference for current setting. If possible to find a suitable value the rated current of the protected object is chosen. Opmodesel: this parameter can be set to 2 out of 3 or 1 out of 3. The setting controls the minimum number of phase curren...

  • Page 404

    Ansi09000023-1-en.Vsd ~ ~ z a z b z l a b ied i fa fault ansi09000023 v1 en figure 180: through fault current from b to a: i fa the ied must not trip for any of the two through-fault currents. Hence the minimum theoretical current setting (imin) will be: imin max i fa i fb , ( ) ³ equation78 v1 en (...

  • Page 405

    Ansi09000024-1-en.Vsd ~ ~ z a z b z l a b i f fault ied ansi09000024 v1 en figure 181: fault current: i f the ied setting value pickup is given in percentage of the primary base current value, ibase. The value for pickup is given from this formula: 100 is pickup ibase = × ansiequation1147 v1 en (equ...

  • Page 406

    ~ ~ z a z b z l1 a b i m fault ied z l2 m c line 1 line 2 ansi09000025_2_en.Vsd ansi09000025 v2 en figure 182: two parallel lines. Influence from parallel line to the through fault current: i m the minimum theoretical current setting for the overcurrent protection function (imin) will be: imin max i...

  • Page 407

    3.7.1.3 setting parameters table 85: phpioc (50) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation ibase 1 - 99999 a 1 3000 base current opmodesel 2 out of 3 1 out of 3 - - 1 out of 3 select operation mode (2 of ...

  • Page 408

    If vt inputs are not available or not connected, setting parameter dirmodeselx (x = step 1, 2, 3 or 4) shall be left to default value non- directional. In many applications several steps with different current pick up levels and time delays are needed. Oc4ptoc (51_67) can have up to four different, ...

  • Page 409

    Ground fault protection. Therefore it is possible to make a choice how many phases, at minimum, that have to have current above the pick-up level, to enable operation. If set 1 of 3 it is sufficient to have high current in one phase only. If set 2 of 3 or 3 of 3 single- phase ground faults are not d...

  • Page 410

    2ndharmstab: operate level of 2nd harmonic current restrain set in % of the fundamental current. The setting range is 5 - 100% in steps of 1%. Default setting is 20%. V ref i dir ansi09000636-1-en.Vsd 1 2 2 3 4 ansi09000636 v1 en figure 183: directional function characteristic 1. Rca = relay charact...

  • Page 411

    Dirmodeselx: the directional mode of step x. Possible settings are disabled/non- directional/forward/reverse. Characteristx: selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available according to table 87 . Table 87: inverse ti...

  • Page 412

    Multpux: multiplier for scaling of the current setting value. If a binary input signal (enablemultiplier) is activated the current operation level is increase by this setting constant. Setting range: 1.0-10.0 txmin: minimum operate time for all inverse time characteristics. At high currents the inve...

  • Page 413

    Table 88: reset possibilities curve name curve index no. Instantaneous 1 iec reset (constant time) 2 ansi reset (inverse time) 3 the delay characteristics are described in the technical reference manual. There are some restrictions regarding the choice of reset delay. For the definite time delay cha...

  • Page 414

    2nd harmonic restrain if a power transformer is energized there is a risk that the transformer core will saturate during part of the period, resulting in an inrush transformer current. This will give a declining residual current in the network, as the inrush current is deviating between the phases. ...

  • Page 415

    Pickup current current i the ied does not reset line phase current time t reset current ansi09000146-en-1.Vsd ansi09000146 v1 en figure 185: pickup and reset current for an overcurrent protection the lowest setting value can be written according to equation 341 . Im ax ipu 1.2 k ³ × equation1262 v2 ...

  • Page 416

    The maximum load current on the line has to be estimated. There is also a demand that all faults, within the zone that the protection shall cover, must be detected by the phase overcurrent protection. The minimum fault current iscmin, to be detected by the protection, must be calculated. Taking this...

  • Page 417

    The operate times of the phase overcurrent protection has to be chosen so that the fault time is so short that protected equipment will not be destroyed due to thermal overload, at the same time as selectivity is assured. For overcurrent protection, in a radial fed network, the time setting can be c...

  • Page 418

    Protection operation time: 15-60 ms protection resetting time: 15-60 ms breaker opening time: 20-120 ms example for time coordination assume two substations a and b directly connected to each other via one line, as shown in the figure 187 . Consider a fault located at another line from the station b...

  • Page 419

    There are uncertainties in the values of protection operation time, breaker opening time and protection resetting time. Therefore a safety margin has to be included. With normal values the needed time difference can be calculated according to equation 345 . 40 100 40 40 220 t ms ms ms ms ms d ³ + + ...

  • Page 420

    Name values (range) unit step default description characterist1 ansi ext. Inv. Ansi very inv. Ansi norm. Inv. Ansi mod. Inv. Ansi def. Time l.T.E. Inv. L.T.V. Inv. L.T. Inv. Iec norm. Inv. Iec very inv. Iec inv. Iec ext. Inv. Iec s.T. Inv. Iec l.T. Inv. Iec def. Time reserved programmable ri type rd...

  • Page 421

    Name values (range) unit step default description t2 0.000 - 60.000 s 0.001 0.400 definitive time delay of step 2 td2 0.05 - 999.00 - 0.01 0.05 time multiplier for the inverse time delay for step 2 imin2 1 - 10000 %ib 1 50 minimum operate current for step2 in % of ibase t2min 0.000 - 60.000 s 0.001 ...

  • Page 422

    Name values (range) unit step default description characterist4 ansi ext. Inv. Ansi very inv. Ansi norm. Inv. Ansi def. Time l.T.E. Inv. L.T.V. Inv. L.T. Inv. Iec norm. Inv. Iec very inv. Iec inv. Iec ext. Inv. Iec s.T. Inv. Iec l.T. Inv. Iec def. Time reserved programmable ri type rd type - - ansi ...

  • Page 423

    Name values (range) unit step default description tccrv1 0.1 - 10.0 - 0.1 1.0 parameter c for customer programmable curve for step 1 tprcrv1 0.005 - 3.000 - 0.001 0.500 parameter pr for customer programmable curve for step 1 ttrcrv1 0.005 - 100.000 - 0.001 13.500 parameter tr for customer programmab...

  • Page 424

    Name values (range) unit step default description ttrcrv3 0.005 - 100.000 - 0.001 13.500 parameter tr for customer programmable curve for step 3 tcrcrv3 0.1 - 10.0 - 0.1 1.0 parameter cr for customer programmable curve for step 3 harmrestrain3 disabled enabled - - disabled enable block of step3 from...

  • Page 425

    3.7.3.1 application in many applications, when fault current is limited to a defined value by the object impedance, an instantaneous ground-fault protection can provide fast and selective tripping. The instantaneous residual overcurrent efpioc (50n), which can operate in 15 ms (50 hz nominal system ...

  • Page 426

    Ansi09000023-1-en.Vsd ~ ~ z a z b z l a b ied i fa fault ansi09000023 v1 en figure 189: through fault current from b to a: i fa the function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (imin) will be: imin max i fa i fa , ( ) ³ equa...

  • Page 427

    ~ ~ z a z b z l1 a b i m fault ied z l2 m c line 1 line 2 ansi09000025_2_en.Vsd ansi09000025 v2 en figure 190: two parallel lines. Influence from parallel line to the through fault current: i m the minimum theoretical current setting (imin) will in this case be: i m in m a x i fa i fb i m , , ( ) ³ ...

  • Page 428

    3.7.3.3 setting parameters table 92: efpioc (50n) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation ibase 1 - 99999 a 1 3000 base current pickup 1 - 2500 %ib 1 200 operate residual current level in % of ibase tab...

  • Page 429

    Directional function uses the polarizing quantity as decided by setting. Voltage polarizing (-3v 0 is most commonly used, but alternatively current polarizing where currents in transformer neutrals providing the neutral (zero sequence) source (zn) is used to polarize (in · zn) the function. Dual pol...

  • Page 430

    For some protection applications there can be a need to change the current pickup level for some time. Therefore there is a possibility to give a setting of a multiplication factor inxmult to the residual current pick-up level. This multiplication factor is activated from a binary input signal multp...

  • Page 431

    Characteristx: selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available. Inverse time characteristic enables fast fault clearance of high current faults at the same time as selectivity to other inverse time phase overcurrent p...

  • Page 432

    Current operate time iminx txmin iec10000058-1-en.Vsd iec10000058 v1 en figure 191: minimum operate current and operate time for inverse time characteristics in order to fully comply with curves definition the setting parameter txmin shall be set to the value which is equal to the operate time of th...

  • Page 433

    Further description can be found in the technical reference manual. Tprcrvx, ttrcrvx, tcrcrvx: parameters for user programmable of inverse reset time characteristic curve. Further description can be found in the technical reference manual. Common settings for all steps tx: definite time delay for st...

  • Page 434

    Current polarizing is useful when the local source is strong and a high sensitivity is required. In such cases the polarizing voltage (3v 0 ) can be below 1% and it is then necessary to use current polarizing or dual polarizing. Multiply the required set current (primary) with the minimum impedance ...

  • Page 435

    2ndharmstab: the rate of 2nd harmonic current content for activation of the 2nd harmonic restrain signal. The setting is given in % of the fundamental frequency residual current. Harmrestrainx: enable block of step x from the harmonic restrain function. Parallel transformer inrush current logic in c...

  • Page 436

    Switch onto fault logic in case of energizing a faulty object there is a risk of having a long fault clearance time, if the fault current is too small to give fast operation of the protection. The switch on to fault function can be activated from auxiliary signals from the circuit breaker, either th...

  • Page 437

    The protected winding will feed ground-fault (residual) current to ground faults in the connected power system. The residual current fed from the transformer at external phase- to-ground faults, is highly dependent of the total positive and zero-sequence source impedances as well as the residual cur...

  • Page 438

    The transformer inrush current will have a large residual current component. To prevent unwanted function of the ground-fault overcurrent protection, the 2nd harmonic restrain blocking should be used, at least for the sensitive step 2. If the protected winding will not feed ground-fault (residual) c...

  • Page 439

    51n three phase ct summated single ct yn/d or yn/y transformer single phase- to-ground fault ansi05000492_3_en.Vsd 0 3i alt ansi05000492 v3 en figure 196: step 1 fault calculation 1 this calculation gives the current fed to the protection: 3i 0fault1 . To assure that step 1, selectivity to other gro...

  • Page 440

    67n three phase ct summated single ct yn/d or yn/y transformer single phase- to- ground fault ansi05000493_3_en.Vsd 0 3i alt ansi05000493 v3 en figure 197: step 1 fault calculation 1 the fault is located at the borderline between instantaneous and delayed operation of the line protection, such as di...

  • Page 441

    Can be chosen very low. As it is required to detect ground faults in the transformer winding, close to the neutral point, values down to the minimum setting possibilities can be chosen. However, one must consider zero-sequence currents that can occur during normal operation of the power system. Such...

  • Page 442

    Name values (range) unit step default description stepforsotf step 2 step 3 - - step 2 selection of step used for sotf enharmrestsotf disabled enabled - - disabled enable harmonic restrain function in sotf tsotf 0.000 - 60.000 s 0.001 0.200 time delay for sotf t4u 0.000 - 60.000 s 0.001 1.000 switch...

  • Page 443

    Name values (range) unit step default description tpcrv1 0.005 - 3.000 - 0.001 1.000 parameter p for customer programmable curve for step 1 tacrv1 0.005 - 200.000 - 0.001 13.500 parameter a for customer programmable curve for step 1 tbcrv1 0.00 - 20.00 - 0.01 0.00 parameter b for customer programmab...

  • Page 444

    Name values (range) unit step default description treset2 0.000 - 60.000 s 0.001 0.020 reset time delay for step 2 harmrestrain2 disabled enabled - - enabled enable block of step 2 from harmonic restrain tpcrv2 0.005 - 3.000 - 0.001 1.000 parameter p for customer programmable curve for step 2 tacrv2...

  • Page 445

    Name values (range) unit step default description resettypecrv3 instantaneous iec reset ansi reset - - instantaneous reset curve type for step 3 treset3 0.000 - 60.000 s 0.001 0.020 reset time delay for step 3 harmrestrain3 disabled enabled - - enabled enable block of step 3 from harmonic restrain t...

  • Page 446

    Name values (range) unit step default description multpu4 1.0 - 10.0 - 0.1 2.0 multiplier for scaling the current setting value for step 4 resettypecrv4 instantaneous iec reset ansi reset - - instantaneous reset curve type for step 4 treset4 0.000 - 60.000 s 0.001 0.020 reset time delay for step 4 h...

  • Page 447

    • ground-fault and phase-phase short circuit protection of feeders in effectively grounded distribution and subtransmission systems. Normally these feeders have radial structure. • back-up ground-fault and phase-phase short circuit protection of transmission lines. • sensitive ground-fault protectio...

  • Page 448

    Curve name ansi moderately inverse ansi/ieee definite time ansi long time extremely inverse ansi long time very inverse ansi long time inverse iec normal inverse iec very inverse iec inverse iec extremely inverse iec short time inverse iec long time inverse iec definite time user programmable asea r...

  • Page 449

    Vbase: base voltage level in kv. This voltage is given as a phase-to-phase voltage and this is the reference for voltage related settings of the function. This voltage is internally divided by √3. When inverse time overcurrent characteristic is selected, the operate time of the stage will be the sum...

  • Page 450

    Curve name user programmable asea ri rxidg (logarithmic) the different characteristics are described in the technical reference manual (trm). Pickupx: operation negative sequence current level for step x given in % of ibase. Tx: definite time delay for step x. Used if definite time characteristic is...

  • Page 451

    For iec inverse time delay characteristics the possible delay time settings are instantaneous (1) and iec (2 = set constant time reset). For the programmable inverse time delay characteristics all three types of reset time characteristics are available; instantaneous (1), iec (2 = set constant time ...

  • Page 452

    Anglerca forward area iop = i2 vpol=-v2 reverse area ansi10000031-1-en.Vsd ansi10000031 v1 en figure 198: relay characteristic angle given in degree in a transmission network a normal value of rca is about 80°. Vpolmin: minimum polarization (reference) voltage % of vbase. I>dir: operate residual cur...

  • Page 453

    Name values (range) unit step default description anglerca -180 - 180 deg 1 65 relay characteristic angle (rca) polmethod voltage dual - - voltage type of polarization vpolmin 1 - 100 %vb 1 5 minimum voltage level for polarization in % of vbase ipolmin 2 - 100 %ib 1 5 minimum current level for polar...

  • Page 454

    Name values (range) unit step default description treset1 0.000 - 60.000 s 0.001 0.020 reset time delay for step 1 tpcrv1 0.005 - 3.000 - 0.001 1.000 parameter p for customer programmable curve for step 1 tacrv1 0.005 - 200.000 - 0.001 13.500 parameter a for customer programmable curve for step 1 tb...

  • Page 455

    Name values (range) unit step default description resettypecrv2 instantaneous iec reset ansi reset - - instantaneous reset curve type for step 2 treset2 0.000 - 60.000 s 0.001 0.020 reset time delay for step 2 tpcrv2 0.005 - 3.000 - 0.001 1.000 parameter p for customer programmable curve for step 2 ...

  • Page 456

    Name values (range) unit step default description multpu3 1.0 - 10.0 - 0.1 2.0 multiplier for scaling the current setting value for step 3 resettypecrv3 instantaneous iec reset ansi reset - - instantaneous reset curve type for step 3 treset3 0.000 - 60.000 s 0.001 0.020 reset time delay for step 3 t...

  • Page 457

    Name values (range) unit step default description t4min 0.000 - 60.000 s 0.001 0.000 minimum operate time in inverse curves step 4 multpu4 1.0 - 10.0 - 0.1 2.0 multiplier for scaling the current setting value for step 4 resettypecrv4 instantaneous iec reset ansi reset - - instantaneous reset curve t...

  • Page 458

    The residual voltage (-3v 0 ), compensated with a characteristic angle. Alternatively, the function can be set to strict 3i 0 level with a check of angle 3i 0 and cos φ. Directional residual power can also be used to detect and give selective trip of phase-to- ground faults in high impedance grounde...

  • Page 459

    Phase currents phase- ground voltages in un iec13000013-1-en.Vsd iec13000013 v1 en figure 199: connection of sdepsde to analog preprocessing function block over current functionality uses true 3i0, i.E. Sum of grpxl1, grpxl2 and grpxl3. For 3i0 to be calculated, connection is needed to all three pha...

  • Page 460

    Phase 0 f 0 v v 3 r 1 z = × + equation2020-ansi v1 en (equation 353) where v phase is the phase voltage in the fault point before the fault, r f is the resistance to ground in the fault point and z 0 is the system zero sequence impedance to ground the fault current, in the fault point, can be calcul...

  • Page 461

    C n 0 c n jx 3r z jx 3r - × = - + equation1946 v1 en (equation 356) where r n is the resistance of the neutral point resistor in many systems there is also a neutral point reactor (petersen coil) connected to one or more transformer neutral points. In such a system the impedance z 0 can be calculate...

  • Page 462

    Substation a substation b z lineab,1 (pos. Seq) z lineab,0 (zero seq) z linebc,1 (pos. Seq) z linebc,0 (zero seq) v 0a v 0b 3i 0 phase to ground fault r n z t,1 (pos. Seq) z t,0 (zero seq) source impedance z sc (pos. Seq) en06000654_ansi.Vsd ansi06000654 v1 en figure 200: equivalent of power system ...

  • Page 463

    0a 0 t,0 n v 3i (z 3r ) = × + equation2024-ansi v1 en (equation 359) ob 0 t ,0 n lineab,0 v 3i (z 3r z ) = × + + equation2025-ansi v1 en (equation 360) the residual power, measured by the sensitive ground-fault protections in a and b will be: 0a 0a 0 s 3v 3i = × equation2026-ansi v1 en (equation 361...

  • Page 464

    The setting ibase gives the base current in a. Normally the primary rated current of the ct feeding the protection should be chosen. The setting vbase gives the base voltage in kv. Normally the system phase to ground voltage is chosen. The setting sbase gives the base voltage in kva. Normally ibase ...

  • Page 465

    -3v 0 3i 0 rca = -90 °, roa = 90° = ang(3i 0 ) – ang(v ref ) 3i 0 cos v ref en06000649_ansi.Vsd ansi06000649 v1 en figure 202: characteristic for rcadir equal to -90° when opmodesel is set to 3i03v0cosfi the apparent residual power component in the direction is measured. When opmodesel is set to 3i0...

  • Page 466

    V ref =-3v 0 operate area 3i 0 rca = 0º roa = 80º ansi06000652-2-en.Vsd ansi06000652 v2 en figure 203: characteristic for rcadir = 0° and roadir = 80° dirmode is set forward or reverse to set the direction of the trip function from the directional residual current function. All the directional prote...

  • Page 467

    Prevent unwanted function for non-faulted feeders, with large capacitive ground-fault current contributions, due to ct phase angle error. Incosphipu is the operate current level for the directional function when opmodesel is set 3i0cosfi. The setting is given in % of ibase. The setting should be bas...

  • Page 468

    Table 99: inverse time characteristics curve name ansi extremely inverse ansi very inverse ansi normal inverse ansi moderately inverse ansi/ieee definite time ansi long time extremely inverse ansi long time very inverse ansi long time inverse iec normal inverse iec very inverse iec inverse iec extre...

  • Page 469

    3.7.6.3 setting parameters table 100: sdepsde (67n) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation disable / enable opmodesel 3i0cosfi 3i03v0cosfi 3i0 and fi - - 3i0cosfi selection of operation mode for protection dirmode fo...

  • Page 470

    Name values (range) unit step default description timechar ansi ext. Inv. Ansi very inv. Ansi norm. Inv. Ansi mod. Inv. Ansi def. Time l.T.E. Inv. L.T.V. Inv. L.T. Inv. Iec norm. Inv. Iec very inv. Iec inv. Iec ext. Inv. Iec s.T. Inv. Iec l.T. Inv. Iec def. Time reserved programmable ri type rd type...

  • Page 471

    Table 102: sdepsde (67n) non group settings (basic) name values (range) unit step default description ibase 1 - 99999 a 1 100 base current, in a vbase 0.05 - 2000.00 kv 0.05 63.50 base voltage, in kv phase to neutral sbase 0.05 - 200000000.00 kva 0.05 6350.00 base power, in kva. Ibase*ubase table 10...

  • Page 472

    • oa: the air is naturally circulated to the coolers without fans and the oil is naturally circulated without pumps. • foa: the coolers have fans to force air for cooling and pumps to force the circulation of the transformer oil. The protection can have two sets of parameters, one for non-forced coo...

  • Page 473

    Irefmult: if a binary input enmult is activated the reference current value can be multiplied by the factor irefmult. The activation could be used in case of deviating ambient temperature from the reference value. In the standard for loading of a transformer an ambient temperature of 20°c is used. F...

  • Page 474

    While it is deactivated at low current. The setting of the parameters below enables automatic adjustment of the time constant. Tau1high: multiplication factor to adjust the time constant tau1 if the current is higher than the set value ihightau1. Ihightau1 is set in % of ibase1. Tau1low: multiplicat...

  • Page 475

    Warning: if the calculated time to trip factor is below the setting warning a warning signal is activated. The setting is given in minutes. 3.7.7.3 setting parameters table 104: trpttr (49) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabl...

  • Page 476

    Name values (range) unit step default description thetainit 0.0 - 95.0 % 1.0 50.0 initial heat content, in % of heat content trip value warning 1.0 - 500.0 min 0.1 30.0 time setting, below which warning would be set (in min) tpulse 0.01 - 0.30 s 0.01 0.10 length of the pulse for trip signal (in msec...

  • Page 477

    Operation: disabled/enabled ibase: base current in primary a. This current is used as reference for current setting. It can be suitable to set this parameter to the rated primary current of the current transformer where the current measurement is made. Functionmode this parameter can be set current ...

  • Page 478

    Applications 1 out of 3 is sufficient. For contact operation means back-up trip is done when circuit breaker is closed (breaker position is used). Pickup_ph: current level for detection of breaker failure, set in % of ibase. This parameter should be set so that faults with small fault current can be...

  • Page 479

    It is often required that the total fault clearance time shall be less than a given critical time. This time is often dependent of the ability to maintain transient stability in case of a fault close to a power plant. Time the fault occurs protection operate time trip and pickup ccrbrf (50bf) normal...

  • Page 480

    Tpulse: trip pulse duration. This setting must be larger than the critical impulse time of circuit breakers to be tripped from the breaker failure protection. Typical setting is 200 ms. 3.7.8.3 setting parameters table 106: ccrbrf (50bf) group settings (basic) name values (range) unit step default d...

  • Page 481

    Function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number pole discrepancy protection ccrpld pd symbol-s v1 en 52pd 3.7.9.1 application there is a risk that a circuit breaker will get discrepancy between the poles at circuit breaker operation: closing or op...

  • Page 482

    Ibase: base current in primary a. This current is used as reference for current setting. It can be suitable to set this parameter to the rated primary current of the protected object where the current measurement is made. Ttrip: time delay of the operation. Contactsel: operation of the contact based...

  • Page 483

    3.7.10 directional underpower protection guppdup (37) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number directional underpower protection guppdup p symbol-ll v1 en 37 3.7.10.1 application the task of a generator in a power plant is to convert mechan...

  • Page 484

    Blades. When a steam turbine rotates without steam supply, the electric power consumption will be about 2% of rated power. Even if the turbine rotates in vacuum, it will soon become overheated and damaged. The turbine overheats within minutes if the turbine loses the vacuum. The critical time to ove...

  • Page 485

    Underpower protection overpower protection q q p p operating point without turbine torque margin margin operate line operate line operating point without turbine torque iec09000019-2-en.Vsd iec09000019 v2 en figure 205: reverse power protection with underpower or overpower protection 3.7.10.2 settin...

  • Page 486

    Set value mode formula used for complex power calculation ab * * ( ) ab a b s v i i = × - equation2058-ansi v1 en (equation 374) bc * * ( ) bc b c s v i i = × - equation2059-ansi v1 en (equation 375) ca * * ( ) ca c a s v i i = × - equation2060-ansi v1 en (equation 376) a * 3 a a s v i = × × equatio...

  • Page 487

    Operate angle1(2) power1(2) p q en06000441.Vsd iec06000441 v1 en figure 206: underpower mode the setting power1(2) gives the power component pick up value in the angle1(2) direction. The setting is given in p.U. Of the generator rated power, see equation 380 . Minimum recommended setting is 0.2% of ...

  • Page 488

    Operate angle1(2) = 0 ° power1(2) p q en06000556.Vsd iec06000556 v1 en figure 207: for low forward power the set angle should be 0° in the underpower function tripdelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.U. Of generator rate...

  • Page 489

    The value of k=0.92 is recommended in generator applications as the trip delay is normally quite long. The calibration factors for current and voltage measurement errors are set % of rated current/voltage: imagcomp5, imagcomp30, imagcomp100 vmagcomp5, vmagcomp30, vmagcomp100 imagcomp5, imagcomp30, i...

  • Page 490

    Name values (range) unit step default description imagcomp5 -10.000 - 10.000 % 0.001 0.000 magnitude factor to calibrate current at 5% of in imagcomp30 -10.000 - 10.000 % 0.001 0.000 magnitude factor to calibrate current at 30% of in imagcomp100 -10.000 - 10.000 % 0.001 0.000 magnitude factor to cal...

  • Page 491

    3.7.11.1 application the task of a generator in a power plant is to convert mechanical energy available as a torque on a rotating shaft to electric energy. Sometimes, the mechanical power from a prime mover may decrease so much that it does not cover bearing losses and ventilation losses. Then, the ...

  • Page 492

    Power to the power plant auxiliaries may come from a station service transformer connected to the primary side of the step-up transformer. Power may also come from a start-up service transformer connected to the external network. One has to design the reverse power protection so that it can detect r...

  • Page 493

    Underpower ied overpower ied q q p p operating point without turbine torque margin margin operate line operate line operating point without turbine torque iec06000315-2-en.Vsd iec06000315 v2 en figure 208: reverse power protection with underpower ied and overpower ied 3.7.11.2 setting guidelines ope...

  • Page 494

    Set value mode formula used for complex power calculation a,b * a b ab * s v (i i ) = × - equation2041 v1 en (equation 387) b,c * b c bc * s v (i i ) = × - equation2042 v1 en (equation 388) c,a * c a ca * s v (i i ) = × - equation2043 v1 en (equation 389) a * a a s 3 v i = × × equation2044 v1 en (eq...

  • Page 495

    Operate angle1(2) power1(2) p q en06000440.Vsd iec06000440 v1 en figure 209: overpower mode the setting power1(2) gives the power component pick up value in the angle1(2) direction. The setting is given in p.U. Of the generator rated power, see equation 393 . Minimum recommended setting is 0.2% of s...

  • Page 496

    Operate angle1(2 ) = 180 o power1(2) p q iec06000557-2-en.Vsd iec06000557 v2 en figure 210: for reverse power the set angle should be 180° in the overpower function tripdelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.U. Of generato...

  • Page 497

    S td s td s old calculated = ⋅ + − ( ) ⋅ 1 equation1893-ansi v1 en (equation 395) where s is a new measured value to be used for the protection function s old is the measured value given from the function in previous execution cycle s calculated is the new calculated value in the present execution c...

  • Page 498

    Name values (range) unit step default description angle2 -180.0 - 180.0 deg 0.1 0.0 angle for stage 2 tripdelay2 0.010 - 6000.000 s 0.001 1.000 trip delay for stage 2 dropdelay2 0.010 - 6000.000 s 0.001 0.060 drop delay for stage 2 table 115: goppdop (32) group settings (advanced) name values (range...

  • Page 499

    3.7.12 broken conductor check brcptoc (46) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number broken conductor check brcptoc - 46 3.7.12.1 application conventional protection functions can not detect the broken conductor condition. Broken conductor c...

  • Page 500

    3.7.12.3 setting parameters table 117: brcptoc (46) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation disable / enable ibase 0 - 99999 a 1 3000 ibase pickup_ub 50 - 90 %im 1 50 unbalance current operation value in percent of ma...

  • Page 501

    Insulated from the other by insulators because the can casing within each rack are at a certain potential. Refer figure 211 for an example: capacitor unit (can) rack iec09000753_1_en.Vsd iec09000753 v1 en figure 211: replacement of a faulty capacitor unit within scb there are four types of the capac...

  • Page 502

    Which type of fusing is used may depend on can manufacturer or utility preference and previous experience. Because the scbs are built from the individual capacitor units the overall connections may vary. Typically used scb configurations are: 1. Delta-connected banks (generally used only at distribu...

  • Page 503

    Capable of continuous operation under contingency system and bank conditions, provided the following limitations are not exceeded: 1. Capacitor units should be capable of continuous operation including harmonics, but excluding transients, to 110% of rated ied root-mean-square (rms) voltage and a cre...

  • Page 504

    5. Undercurrent protection for scb 6. Reconnection inhibit protection for scb 7. Restrike condition detection cbpgapc function can be used to provide the last four types of protection mentioned in the above list. 3.7.13.2 setting guidelines this setting example will be done for application as shown ...

  • Page 505

    _ ec 289 0.578 500 1 r s a i a = = iec09000756 v1 en (equation 397) note that the scb rated current on the secondary ct side is important for secondary injection of the function. The parameters for the capacitor bank protection function cbpgapc are set via the local hmi or pcm600. The following sett...

  • Page 506

    Undercurrent feature is blocked by operation of reconnection inhibit feature. Reactive power overload feature: operation qol =enabled; to enable this feature up_qol =130% (of scb mvar rating); reactive power level required for pickup. Selected value gives pickup recommended by international standard...

  • Page 507

    Therefore simple logic can be created in the application configuration tool to detect such cb behavior. Such cb condition can be just alarmed, and if required, the built in disturbance recorder can also be triggered. To create this logic, a binary signal that the cb is going to be opened (but not tr...

  • Page 508

    3.7.14 negativ sequence time overcurrent protection for machines ns2ptoc (46i2) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number negative sequence time overcurrent protection for machines ns2ptoc 2i2> 46i2 3.7.14.1 application negative sequence ove...

  • Page 509

    A separate output is available as an alarm feature to warn the operator of a potentially dangerous situation. Features negative-sequence time overcurrent protection ns2ptoc (46i2) is designed to provide a reliable protection for generators of all types and sizes against the effect of unbalanced syst...

  • Page 510

    Table 120: ansi requirements for unbalanced faults on synchronous machines types of synchronous machine permissible [ ] 2 2 i t k s = salient pole generator 40 synchronous condenser 30 cylindrical rotor generators: indirectly cooled 30 directly cooled (0 – 800 mva) 10 directly cooled (801 – 1600 mva...

  • Page 511

    Table 121: continous i 2 capability type of generator permissible i 2 (in percent of rated generator current) salient pole: with damper winding 10 without damper winding 5 cylindrical rotor indirectly cooled 10 directly cooled to 960 mva 8 961 to 1200 mva 6 1201 to 1500 mva 5 as it is described in t...

  • Page 512

    Definite time delay. Thus, if only the inverse time delay is required, it is of utmost importance to set the definite time delay for that stage to zero. Operate time characteristic negative sequence time overcurrent protection for machines ns2ptoc (46i2) provides two operating time delay characteris...

  • Page 513

    Negative sequence inverse time characteristic negative sequence current t im e de la y i2 tmax tmin iec08000355-2-en.Vsd 1 10 100 1000 10000 0.01 0.1 1 10 100 iec08000355 v2 en figure 214: inverse time delay characteristic the example in figure 214 indicates that the protection function has a set mi...

  • Page 514

    3.7.14.3 setting parameters table 122: ns2ptoc (46i2) group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation ibase 1 - 99999 a 1 3000 rated generator current in primary amps talarm 0.00 - 6000.00 s 0.01 3.00 time dela...

  • Page 515

    3.8 voltage protection 3.8.1 two step undervoltage protection uv2ptuv (27) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number two step undervoltage protection uv2ptuv 3u symbol-r-2u-greater-than v2 en 27 3.8.1.1 application two-step undervoltage prot...

  • Page 516

    Cases, it is a useful function in circuits for local or remote automation processes in the power system. 3.8.1.2 setting guidelines all the voltage conditions in the system where uv2ptuv (27) performs its functions should be considered. The same also applies to the associated equipment, its voltage ...

  • Page 517

    Conntype: sets whether the measurement shall be phase-to-ground fundamental value, phase-to-phase fundamental value, phase-to-ground rms value or phase-to-phase rms value. Operation: disabled or enabled. Vbase: base voltage phase-to-phase in primary kv. This voltage is used as reference for voltage ...

  • Page 518

    Tn: time delay of step n, given in s. This setting is dependent of the protection application. In many applications the protection function shall not directly trip when there is a short circuit or ground faults in the system. The time delay must be coordinated to the short circuit protections. Trese...

  • Page 519

    Tblkuvn: time delay to block the undervoltage step n when the voltage level is below intblkstvaln, given in s. It is important that this delay is shorter than the operate time delay of the undervoltage protection step. 3.8.1.3 setting parameters table 123: uv2ptuv (27) group settings (basic) name va...

  • Page 520

    Name values (range) unit step default description t2 0.000 - 60.000 s 0.001 5.000 definitive time delay of step 2 t2min 0.000 - 60.000 s 0.001 5.000 minimum operate time for inverse curves for step 2 td2 0.05 - 1.10 - 0.01 0.05 time multiplier for the inverse time delay for step 2 intblksel2 disable...

  • Page 521

    Name values (range) unit step default description bcrv2 0.50 - 100.00 - 0.01 1.00 parameter b for customer programmable curve for step 2 ccrv2 0.0 - 1.0 - 0.1 0.0 parameter c for customer programmable curve for step 2 dcrv2 0.000 - 60.000 - 0.001 0.000 parameter d for customer programmable curve for...

  • Page 522

    Thereby decreasing the voltage. The function has a high measuring accuracy and hysteresis setting to allow applications to control reactive load. Ov2ptov (59) is used to disconnect apparatuses, like electric motors, which will be damaged when subject to service under high voltage conditions. It deal...

  • Page 523

    The hysteresis is for overvoltage functions very important to prevent that a transient voltage over set level is not “sealed-in” due to a high hysteresis. Typical values should be ≤ 0.5%. Equipment protection, such as for motors, generators, reactors and transformers high voltage will cause overexci...

  • Page 524

    (%) ( ) / 3 v vbase kv > × equation1713 v2 en (equation 401) and operation for phase-to-phase voltage over: vpickup (%) vbase(kv) > × equation1992-ansi v1 en (equation 402) the below described setting parameters are identical for the two steps (n = 1 or 2). Therefore the setting parameters are descr...

  • Page 525

    Tiresetn: reset time for step n if inverse time delay is used, given in s. The default value is 25 ms. Tdn: time multiplier for inverse time characteristic. This parameter is used for co- ordination between different inverse time delayed undervoltage protections. Acrvn, bcrvn, ccrvn, dcrvn, pcrvn: p...

  • Page 526

    Name values (range) unit step default description t1 0.00 - 6000.00 s 0.01 5.00 definitive time delay of step 1 t1min 0.000 - 60.000 s 0.001 5.000 minimum operate time for inverse curves for step 1 td1 0.05 - 1.10 - 0.01 0.05 time multiplier for the inverse time delay for step 1 hystabs1 0.0 - 100.0...

  • Page 527

    Name values (range) unit step default description crvsat1 0 - 100 % 1 0 tuning param for programmable over voltage tov curve, step 1 treset2 0.000 - 60.000 s 0.001 0.025 reset time delay used in iec definite time curve step 2 resettypecrv2 instantaneous frozen timer linearly decreased - - instantane...

  • Page 528

    Ground fault related functions, the residual overvoltage signal can be used as a release signal. The residual voltage can be measured either at the transformer neutral or from a voltage transformer open delta connection. The residual voltage can also be calculated internally, based on measurement of...

  • Page 529

    Equipment protection, capacitors high voltage will deteriorate the dielectric and the insulation. Two step residual overvoltage protection (rov2ptov, 59n) has to be connected to a neutral or open delta winding. The setting must be above the highest occurring "normal" residual voltage and below the h...

  • Page 530

    3v 0 v _a v_b v_ c v _b f v _c f v _c f ansi07000190-1-en.Vsd ansi07000190 v1 en figure 215: ground fault in non-effectively grounded systems direct grounded system in direct grounded systems, an ground fault on one phase indicates a voltage collapse in that phase. The two healthy phases will have n...

  • Page 531

    V _a v_b v_ c v _a f il 1 f v_b v _c 3v 0 ansi07000189-1-en.Vsd ansi07000189 v1 en figure 216: ground fault in direct grounded system settings for two step residual overvoltage protection operation: disabled or enabled vbase is used as voltage reference for the voltage. The voltage can be fed to the...

  • Page 532

    The below described setting parameters are identical for the two steps (n = step 1 and 2). Therefore the setting parameters are described only once. Characteristicn: selected inverse time characteristic for step n. This parameter gives the type of time delay to be used. The setting can be, definite ...

  • Page 533

    Acrvn, bcrvn, ccrvn, dcrvn, pcrvn: parameters for step n, to set to create programmable undervoltage inverse time characteristic. Description of this can be found in the technical reference manual. Crvsatn: set tuning parameter for step n. When the denominator in the expression of the programmable c...

  • Page 534

    Name values (range) unit step default description characterist2 definite time inverse curve a inverse curve b inverse curve c prog. Inv. Curve - - definite time selection of time delay curve type for step 2 pickup2 1 - 100 %vb 1 45 voltage setting/pickup value (dt & tov), step 2 in % of vbase t2 0.0...

  • Page 535

    Name values (range) unit step default description ccrv2 0.0 - 1.0 - 0.1 0.0 parameter c for customer programmable curve for step 2 dcrv2 0.000 - 60.000 - 0.001 0.000 parameter d for customer programmable curve for step 2 pcrv2 0.000 - 3.000 - 0.001 1.000 parameter p for customer programmable curve f...

  • Page 536

    Capable of operating continuously at an applied voltage 110% of rated value at no load, reduced to 105% at rated secondary load current. According to ansi/ieee standards, the transformers shall be capable of delivering rated load current continuously at an output voltage of 105% of rated value (at r...

  • Page 537

    Some different connection alternatives are shown in figure 217 . G 24 en05000208_ansi.Vsd 24 24 ansi05000208 v1 en figure 217: alternative connections of an overexcitation protection oexpvph (24) (volt/hertz) 3.8.4.2 setting guidelines recommendations for input and output signals recommendations for...

  • Page 538

    Bfi: the bfi output indicates that the level pickup1> has been reached. It can be used to initiate time measurement. Trip: the trip output is activated after the operate time for the v/f level has expired. Trip signal is used to trip the circuit breaker(s). Alarm: the output is activated when the al...

  • Page 539

    Curvetype: selection of the curve type for the inverse delay. The ieee curves or tailor made curve can be selected depending of which one matches the capability curve best. Tdforieeecurve: the time constant for the inverse characteristic. Select the one giving the best match to the transformer capab...

  • Page 540

    When the overexcitation is equal to the set value of pickup2, tripping is obtained after a time equal to the setting of t6. A suitable setting would be pickup2 = 140% and t6 = 4 s. The interval between pickup2 and pickup1 is automatically divided up in five equal steps, and the time delays t2 to t5 ...

  • Page 541

    1 2 5 50 200 110 120 130 140 150 100 0.05 0.1 0.2 0.5 10 20 100 v/hz % continous time (minutes) t6 t5 t4 t3 t2 t1 transformer capability curve relay operate characteristic en01000377.Vsd iec01000377 v1 en figure 218: example on overexcitation capability curve and v/hz protection settings for power t...

  • Page 542

    Name values (range) unit step default description t_maxtripdelay 0.00 - 9000.00 s 0.01 1800.00 maximum trip delay for v/hz inverse curve, in sec t_coolingk 0.10 - 9000.00 s 0.01 1200.00 transformer magnetic core cooling time constant, in sec curvetype ieee tailor made - - ieee inverse time curve sel...

  • Page 543

    3.8.5.1 application the voltage differential protection vdcptov (60) functions can be used in some different applications. • voltage unbalance protection for capacitor banks. The voltage on the bus is supervised with the voltage in the capacitor bank, phase- by phase. Difference indicates a fault, e...

  • Page 544

    Fuse failure supervision (sddrfuf) function for voltage transformers. In many application the voltages of two fuse groups of the same voltage transformer or fuse groups of two separate voltage transformers measuring the same voltage can be supervised with this function. It will be an alternative for...

  • Page 545

    Rflx: is the setting of the voltage ratio compensation factor where possible differences between the voltages is compensated for. The differences can be due to different voltage transformer ratios, different voltage levels e.G. The voltage measurement inside the capacitor bank can have a different v...

  • Page 546

    Talarm: the time delay for alarm is set by this parameter. Normally, few seconds delay can be used on capacitor banks alarm. For fuse failure supervision (sddrfuf) the alarm delay can be set to zero. 3.8.5.3 setting parameters table 135: vdcptov (60) group settings (basic) name values (range) unit s...

  • Page 547

    3.8.6.1 application the trip of the circuit breaker at a prolonged loss of voltage at all the three phases is normally used in automatic restoration systems to facilitate the system restoration after a major blackout. Loss of voltage check (lovptuv, 27) generates a trip signal only if the voltage in...

  • Page 548

    Table 138: lovptuv (27) group settings (advanced) name values (range) unit step default description tpulse 0.050 - 60.000 s 0.001 0.150 duration of trip pulse tblock 0.000 - 60.000 s 0.001 5.000 time delay to block when all 3ph voltages are not low trestore 0.000 - 60.000 s 0.001 3.000 time delay fo...

  • Page 549

    3.9.1.2 setting guidelines all the frequency and voltage magnitude conditions in the system where saptuf (81) performs its functions should be considered. The same also applies to the associated equipment, its frequency and time characteristic. There are especially two specific application areas for...

  • Page 550

    Power system protection, by load shedding the setting has to be well below the lowest occurring "normal" frequency and well above the lowest acceptable frequency for power stations, or sensitive loads. The setting level, the number of levels and the distance between two levels (in time and/or in fre...

  • Page 551

    3.9.2 overfrequency protection saptof (81) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number overfrequency protection saptof f > symbol-o v1 en 81 3.9.2.1 application overfrequency protection function saptof (81) is applicable in all situations, whe...

  • Page 552

    Equipment protection, such as for motors and generators the setting has to be well above the highest occurring "normal" frequency and well below the highest acceptable frequency for the equipment. Power system protection, by generator shedding the setting must be above the highest occurring "normal"...

  • Page 553

    3.9.3 rate-of-change frequency protection sapfrc (81) function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number rate-of-change frequency protection sapfrc df/dt > symbol-n v1 en 81 3.9.3.1 application rate-of-change frequency protection (sapfrc, 81), is app...

  • Page 554

    Place very quickly, and there might not be enough time to wait until the frequency signal has reached an abnormal value. Actions are therefore taken at a frequency level closer to the primary nominal level, if the rate-of-change frequency is large (with respect to sign). Sapfrc (81)pickup value is s...

  • Page 555

    3.10 multipurpose protection 3.10.1 general current and voltage protection cvgapc function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number general current and voltage protection cvgapc - - 3.10.1.1 application a breakdown of the insulation between phase co...

  • Page 556

    Or reverse). Its behavior during low-level polarizing voltage is settable (non- directional,block,memory) • voltage restrained/controlled feature is available in order to modify the pick- up level of the overcurrent stage(s) in proportion to the magnitude of the measured voltage • current restrained...

  • Page 557

    Set value for parameter "currentinput” comment 4 posseq cvgapc function will measure internally calculated positive sequence current phasor 5 negseq cvgapc function will measure internally calculated negative sequence current phasor 6 3 · zeroseq cvgapc function will measure internally calculated ze...

  • Page 558

    Set value for parameter "voltageinput" comment 5 -negseq cvgapc function will measure internally calculated negative sequence voltage phasor. This voltage phasor will be intentionally rotated for 180° in order to enable easier settings for the directional feature when used. 6 -3*zeroseq cvgapc funct...

  • Page 559

    Base quantities for cvgapc function the parameter settings for the base quantities, which represent the base (100%) for pickup levels of all measuring stages shall be entered as setting parameters for every cvgapc function. Base current shall be entered as: 1. Rated phase current of the protected ob...

  • Page 560

    • turn-to-turn & differential backup protection (directional negative sequence. Overcurrent protection connected to generator hv terminal cts looking into generator) (67q) • stator overload protection (49s) • rotor overload protection (49r) • loss of excitation protection (directional pos. Seq. Oc p...

  • Page 561

    For big and important machines, fast protection against inadvertent energizing should, therefore, be included in the protective scheme. The protection against inadvertent energization can be made by a combination of undervoltage, overvoltage and overcurrent protection functions. The undervoltage fun...

  • Page 562

    This functionality can be achieved by using one cvgapc function. The following shall be done to ensure proper operation of the function: 1. Connect three-phase power line currents and three-phase power line voltages to one cvgapc instance (for example, gf04) 2. Set currentinput to negseq (please not...

  • Page 563

    • the set values for rcadir and roadir settings will be as well applicable for oc2 stage • setting dirmode_oc2 shall be set to reverse • setting parameter pickupcurr_oc2 shall be made more sensitive than pickup value of forward oc1 element (that is, typically 60% of oc1 set pickup level) in order to...

  • Page 564

    7% 0.07 = = x pu equation1756-ansi v1 en (equation 407) equation 406 can be re-written in the following way without changing the value for the operate time of the negative sequence inverse overcurrent ied: op 2 ns r 2 td t i x i 1 x × = × æ ö ç ÷ è ø equation1741-ansi v1 en (equation 408) in order t...

  • Page 565

    Then the oc1 step of the cvgapc function can be used for generator negative sequence inverse overcurrent protection. For this particular example the following settings shall be entered to insure proper function operation: 1. Select negative sequence current as measuring quantity for this cvgapc func...

  • Page 566

    This formula is applicable only when measured current (for example, positive sequence current) exceeds a pre-set value (typically in the range from 105 to 125% of the generator rated current). By defining parameter x equal to the per unit value for the desired pickup for the overload ied in accordan...

  • Page 567

    When the equation 412 is compared with the equation 413 for the inverse time characteristic of the oc1 step in it is obvious that if the following rules are followed: 1. Set td equal to the iec or ansi standard generator capability value 2. Set parameter a_oc1 equal to the value 1/x2 3. Set paramete...

  • Page 568

    1. Connect three-phase currents from the protected object to one cvgapc instance (for example, gf03) 2. Set currentinput to value unbalanceph 3. Set enrestraincurr to on 4. Set restrcurrinput to maxph 5. Set restrcurrcoeff to value 0.97 6. Set base current value to the rated current of the protected...

  • Page 569

    7. Select curvetype_oc1 to value ansi very inv 8. If required set minimum operating time for this curve by using parameter tmin_oc1 (default value 0.05s) 9. Set pickupcurr_oc1 to value 185% 10. Set vcntrlmode_oc1 to on 11. Set vdepmode_oc1 to slope 12. Set vdepfact_oc1 to value 0.25 13. Set vhighlim...

  • Page 570

    Proper operation of the cvgapc function made in this way can easily be verified by secondary injection. All other settings can be left at the default values. However it shall be noted that set values for rca & roa angles will be applicable for oc2 step if directional feature is enabled for this step...

  • Page 571

    3.10.1.3 setting parameters table 144: cvgapc group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation currentinput phase a phase b phase c posseq negseq 3*zeroseq maxph minph unbalanceph phase ab phase bc phase ca maxp...

  • Page 572

    Name values (range) unit step default description lowvolt_vm 0.0 - 5.0 %vb 0.1 0.5 below this level in % of vbase setting actlowvolt takes over operation_oc1 disabled enabled - - disabled disable/enable operation of oc1 pickupcurr_oc1 2.0 - 5000.0 %ib 1.0 120.0 pickup current for oc1 in % of ibase c...

  • Page 573

    Name values (range) unit step default description operation_oc2 disabled enabled - - disabled disable/enable operation od oc2 pickupcurr_oc2 2.0 - 5000.0 %ib 1.0 120.0 pickup current for oc2 in % of ibase curvetype_oc2 ansi ext. Inv. Ansi very inv. Ansi norm. Inv. Ansi mod. Inv. Ansi def. Time l.T.E...

  • Page 574

    Name values (range) unit step default description operation_uc1 disabled enabled - - disabled disable/enable operation of uc1 enblklowi_uc1 disabled enabled - - disabled enable internal low current level blocking for uc1 blklowcurr_uc1 0 - 150 %ib 1 20 internal low current blocking level for uc1 in ...

  • Page 575

    Name values (range) unit step default description tdef_ov2 0.00 - 6000.00 s 0.01 1.00 operate time delay in sec for definite time use of ov2 tmin_ov2 0.00 - 6000.00 s 0.01 0.05 minimum operate time for inverse-time curves for ov2 td_ov2 0.05 - 999.00 - 0.01 0.30 time multiplier for the dependent tim...

  • Page 576

    Table 145: cvgapc group settings (advanced) name values (range) unit step default description multpu_oc1 1.0 - 10.0 - 0.1 2.0 multiplier for scaling the current setting value for oc1 rescrvtype_oc1 instantaneous iec reset ansi reset - - instantaneous selection of reset curve type for oc1 tresetdef_o...

  • Page 577

    Name values (range) unit step default description rescrvtype_ov1 instantaneous frozen timer linearly decreased - - instantaneous selection of reset curve type for ov1 tresetdef_ov1 0.00 - 6000.00 s 0.01 0.00 reset time delay in sec for definite time use of ov1 tresetidmt_ov1 0.00 - 6000.00 s 0.01 0....

  • Page 578

    Name values (range) unit step default description c_uv1 0.000 - 1.000 - 0.001 1.000 parameter c for customer programmable curve for uv1 d_uv1 0.000 - 10.000 - 0.001 0.000 parameter d for customer programmable curve for uv1 p_uv1 0.001 - 10.000 - 0.001 0.020 parameter p for customer programmable curv...

  • Page 579

    In case of large currents, unequal transient saturation of ct cores with different remanence or different saturation factor may result in differences in the secondary currents from the two ct sets. Unwanted blocking of protection functions during the transient stage must then be avoided. Current cir...

  • Page 580

    Table 147: ccsrdif (87) group settings (advanced) name values (range) unit step default description pickup_block 5 - 500 %ib 1 150 block of the function at high phase current, in % of ibase 3.11.2 fuse failure supervision sddrfuf function description iec 61850 identification iec 60617 identification...

  • Page 581

    Where the line can have a weak-infeed of zero sequence current this function shall be avoided. A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure. This is beneficial for example during ...

  • Page 582

    Uzsizs for zero sequence based algorithm. If system studies or field experiences shows that there is a risk that the fuse failure function will not be activated due to the system conditions, the dependability of the fuse failure function can be increased if the opmodesel is set to uzsizs or unsins o...

  • Page 583

    Zero sequence based the ied setting value 3v0pu is given in percentage of the base voltage vbase, where vbase is the primary base voltage, normally the rated voltage of the primary potential voltage transformer winding. The setting of 3v0pu should not be set lower than according to equation 416 . 3 ...

  • Page 584

    Vsetprim dvpu 100 vbase = × equation1765-ansi v1 en (equation 418) 100 = × isetprim dipu ibase ansiequation2385 v1 en (equation 419) the voltage thresholds vppu is used to identify low voltage condition in the system. Set vppu below the minimum operating voltage that might occur during emergency con...

  • Page 585

    Name values (range) unit step default description 3i0pu 1 - 100 %ib 1 10 pickup of residual undercurrent element in % of ibase 3v2pu 1 - 100 %vb 1 30 pickup of negative sequence overvoltage element in % of vbase 3i2pu 1 - 100 %ib 1 10 pickup of negative sequence undercurrent element in % of ibase op...

  • Page 586

    3.12.1.1 application synchronizing to allow closing of breakers between asynchronous networks a synchronizing function is provided. The breaker close command is issued at the optimum time when conditions across the breaker are satisfied in order to avoid stress on the network and its components. The...

  • Page 587

    Synchronism check the main purpose of the synchronism check function is to provide control over the closing of circuit breakers in power networks in order to prevent closing if conditions for synchronism are not detected. It is also used to prevent the re-connection of two systems, which are divided...

  • Page 588

    Bigger phase angle difference can be allowed as this is sometimes the case in a long and loaded parallel power line. For this application we accept a synchronism check with a long operation time and high sensitivity regarding the frequency difference. The phase angle difference setting can be set fo...

  • Page 589

    The energizing check function measures the bus and line voltages and compares them to both high and low threshold values. The output is given only when the actual measured conditions match the set conditions. Figure 224 shows two substations, where one (1) is energized and the other (2) is not energ...

  • Page 590

    Voltage selection the voltage selection function is used for the connection of appropriate voltages to the synchronism check and energizing check functions. For example, when the ied is used in a double bus arrangement, the voltage that should be selected depends on the status of the breakers and/or...

  • Page 591

    Ansi09000171_1_en.Vsd sesrsyn (25) menmode intone psto swposn name1 name2 off dl db dlb slggio name3 name4 ansi09000171 v1 en figure 225: selection of the energizing direction from a local hmi symbol through a selector switch function block. 3.12.1.2 application examples the synchronism check functi...

  • Page 592

    Single circuit breaker with single busbar linevoltage/1/2/3 bus 1voltage bus 1 189 line v ref 1 fuse vt fuse vt 152 ansi0000093-1-en.Vsd va/vb/vc sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blkenerg bus1_op bus1_cl bus2_op bus2_cl line1_op line1_cl line2_op line2_cl vb1ok vb1ff vb2...

  • Page 593

    Single circuit breaker with double busbar, external voltage selection line voltag e 1/2/3 bus voltage bus 1 bus 2 189 289 line fuse vt fuse vt fuse vt 152 ansi10000094-1-en.Vsd vref1 va/vb/ v c sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blkenerg bus1_op bus1_cl bus2_op bus2_cl lin...

  • Page 594

    Single circuit breaker with double busbar, internal voltage selection linevoltage/1/2/3 bus1voltage bus2voltage bus 1 bus 2 189 289 line vref1 vref2 va/vb/vc fuse vt fuse vt fuse vt 152 ansi10000095-1-en.Vsd sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blkenerg bus1_op bus1_cl bus2_...

  • Page 595

    Double circuit breaker linevoltage/1/2/3 bus 1 voltage bus 2 voltage bus 1 bus 2 line 252 fuse vt fuse vt fuse vt 152 252 152 ansi10000096-1-en.Vsd vref1 vref2 va/vb/vc sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blkenerg bus1_op bus1_cl bus2_op bus2_cl line1_op line1_cl line2_op l...

  • Page 596

    A double breaker arrangement requires two function blocks, sesrsyn1 for breaker qa1 and sesrsyn2 for breaker qa2. No voltage selection is necessary, because the voltage from busbar 1 vt is connected to v3pbb1 on sesrsyn1 and the voltage from busbar 2 vt is connected tov3pbb1 on sesrsyn2. The voltage...

  • Page 597

    Tie cb bus 1 cb ansi10000097-1-en.Vsd vref1 vref2 bus1 voltage bus 2voltage line 1 voltage 1/2/3 line 2 voltage 989 989 line 1 line 2 vref3 bus 1 bus 2 289 189 152 289 189 152 fuse vt fuse vt 6189 6289 152 fuse vt fuse vt va/vb/vc sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blkener...

  • Page 598

    Ansi10000098-1-en.Vsd tie cb bus 2 cb vt fuse vt 1/2/3 line 1 line 2 bus 1 bus 2 289 189 152 289 189 152 6189 6289 152 989 989 bus 1 voltage line 2 voltage line1voltage bus2 voltage fuse fuse vt fuse vt v ref2 v ref1 v ref3 va/vb/vc sesrsyn (25) v3pb1* v3pb2* v3pl1* v3pl2* block blksynch blksc blken...

  • Page 599

    Function blocks, sesrsyn1 for busbar2 cb and sesrsyn2 for the tie cb. The voltage from busbar1 vt is connected to v3pb2 on both function blocks and the voltage from busbar2 vt is connected to v3pb1 on both function blocks. The voltage from line1 vt is connected to v3pl2 on both function blocks and t...

  • Page 600

    3.12.1.3 setting guidelines the setting parameters for the synchronizing, synchronism check and energizing check function sesrsyn (25) are set via the local hmi (lhmi) or pcm600. This setting guidelines describes the settings of the sesrsyn (25) function via the lhmi. The sesrsyn function has the fo...

  • Page 601

    This configuration setting is used to define type of voltage selection. Type of voltage selection can be selected as: • no voltage selection • single circuit breaker with double bus • breaker-and-a-half arrangement with the breaker connected to busbar 1 • breaker-and-a-half arrangement with the brea...

  • Page 602

    Setting of the voltage difference between the line voltage and the bus voltage. The difference is set depending on the network configuration and expected voltages in the two networks running asynchronously. A normal setting is 0.10-0.15 p.U. Freqdiffmin the setting freqdiffmin is the minimum frequen...

  • Page 603

    The setting tmaxsynch is set to reset the operation of the synchronizing function if the operation does not take place within this time. The setting must allow for the setting of freqdiffmin, which will decide how long it will take maximum to reach phase equality. At the setting of 10 ms, the beat t...

  • Page 604

    The phase angle difference level settings, phasediffm and phasediffa, are also chosen depending on conditions in the network. The phase angle setting must be chosen to allow closing under maximum load. A typical maximum value in heavy-loaded networks can be 45 degrees, whereas in most networks the m...

  • Page 605

    Vdeadbusenerg and vdeadlineenerg the threshold voltages vdeadbusenerg and vdeadlineenerg, have to be set to a value greater than the value where the network is considered not to be energized. A typical value can be 40% of the base voltages. A disconnected line can have a considerable potential due t...

  • Page 606

    Name values (range) unit step default description phaseshift -180 - 180 deg 5 0 phase shift vratio 0.040 - 25.000 - 0.001 1.000 voltage ratio operationsynch disabled enabled - - disabled operation for synchronizing function off/on vhighbussynch 50.0 - 120.0 %vbb 1.0 80.0 voltage high limit bus for s...

  • Page 607

    Name values (range) unit step default description manenerg disabled dllb dbll both - - both manual energizing check mode manenergdbdl disabled enabled - - disabled manual dead bus, dead line energizing vlivebusenerg 50.0 - 120.0 %vbb 1.0 80.0 voltage high limit bus for energizing check in % of ubase...

  • Page 608

    Table 150: sesrsyn (25) non group settings (basic) name values (range) unit step default description selphasebus1 phase l1 for busbar1 phase l2 for busbar1 phase l3 for busbar1 phase l1l2 for busbar1 phase l2l3 for busbar1 phase l3l1 for busbar1 pos. Sequence for busbar1 - - phase l1 for busbar1 sel...

  • Page 609

    3.12.2.1 application the apparatus control is a function for control and supervising of circuit breakers, disconnectors, and grounding switches within a bay. Permission to operate is given after evaluation of conditions from other functions such as interlocking, synchronism check, operator place sel...

  • Page 610

    • pole discrepancy supervision • operation counter • suppression of mid position the apparatus control function is realized by means of a number of function blocks designated: • switch controller scswi • circuit breaker sxcbr • circuit switch sxswi • bay control qcbay • position evaluation pos_eval ...

  • Page 611

    En05000116_ansi.Vsd sxcbr scswi scilo sxcbr sxcbr scswi scilo sxswi 189 989 iec 61850 qcbay 152 ansi05000116 v1 en figure 233: signal flow between apparatus control function blocks the iec 61850 communication has always priority over binary inputs, e.G. A block command on binary inputs will not prev...

  • Page 612

    • a request initiates to reserve other bays to prevent simultaneous operation. • actual position inputs for interlocking information are read and evaluated if the operation is permitted. • the synchronism check/synchronizing conditions are read and checked, and performs operation upon positive respo...

  • Page 613

    • supervision timer that the primary device starts moving after a command • supervision of allowed time for intermediate position • definition of pulse duration for open/close command respectively the realization of this function is performed with sxcbr representing a circuit breaker and with sxswi ...

  • Page 614

    Another bay or the acknowledgment from each bay respectively, which have received a request from this bay. Also the information of valid transmission over the station bus must be received. En 05000117_ansi.Vsd ied ied from other scswi in the bay to other scswi in the bay 3 station bus . . . . . . . ...

  • Page 615

    The solution in figure 235 can also be realized over the station bus according to the application example in figure 236 . The solutions in figure 235 and figure 236 do not have the same high security compared to the solution in figure 234 , but have instead a higher availability. This because no ack...

  • Page 616

    • the logical node interlocking (scilo, 3) provides the information to scswi whether it is permitted to operate due to the switchyard topology. The interlocking conditions are evaluated with separate logic and connected to scilo (3). • the synchronism, energizing check, and synchronizing (sesrsyn, 2...

  • Page 617

    En05000120_ansi.Vsd zmqpdis (distance) sxcbr (circuit breaker) interlocking function block (not a ln) scswi (switching control) qcbay (bay control) smbrrec (auto- reclosure) i/o trip close rel. Res. Req. In iti at e a r close cb position res. Granted operator place selection scswi (switching control...

  • Page 618

    Switch controller (scswi) the parameter ctlmodel specifies the type of control model according to iec 61850. For normal control of circuit breakers, disconnectors and grounding switches the control model is set to sbo enh (select-before-operate) with enhanced security. When the operation shall be pe...

  • Page 619

    During the tintermediate time the position indication is allowed to be in an intermediate (00) state. When the time has expired, the switch function is reset. The indication of the mid-position at scswi is suppressed during this time period when the position changes from open to close or vice-versa....

  • Page 620

    Name values (range) unit step default description tsynchronizing 0.00 - 600.00 s 0.01 0.00 supervision time to get the signal synchronizing in progress texecutionfb 0.00 - 600.00 s 0.01 30.00 maximum time from command execution to termination tpolediscord 0.000 - 60.000 s 0.001 2.000 allowed time to...

  • Page 621

    Table 154: qcrsv non group settings (basic) name values (range) unit step default description tcancelres 0.000 - 60.000 s 0.001 10.000 supervision time for canceling the reservation paramrequest1 other bays res. Only own bay res. - - only own bay res. Reservation of the own bay only, at selection of...

  • Page 622

    This section only deals with the first point, and only with restrictions caused by switching devices other than the one to be controlled. This means that switch interlock, because of device alarms, is not included in this section. Disconnectors and grounding switches have a limited switching capacit...

  • Page 623

    For switches with an individual operation gear per phase, the evaluation must consider possible phase discrepancies. This is done with the aid of an and-function for all three phases in each apparatus for both open and close indications. Phase discrepancies will result in an unknown double indicatio...

  • Page 624

    The signals from other bays connected to the module abc_line (3) are described below. Signals from bypass busbar to derive the signals: signal bb7_d_op all line disconnectors on bypass wa7 except in the own bay are open. Vp_bb7_d the switch status of disconnectors on bypass busbar wa7 are valid. Exd...

  • Page 625

    Signals from bus-coupler if the busbar is divided by bus-section disconnectors into bus sections, the busbar- busbar connection could exist via the bus-section disconnector and bus-coupler within the other bus section. Section 1 section 2 a1a2_dc(bs) b1b2_dc(bs) abc_line abc_bc abc_line abc_bc (wa1)...

  • Page 626

    Signal bc27cltr a bus-coupler connection through the own bus-coupler exists between busbar wa2 and wa7. Vpbc12tr the switch status of bc_12 is valid. Vpbc17tr the switch status of bc_17 is valid. Vpbc27tr the switch status of bc_27 is valid. Exdu_bc no transmission error from the bay that contains t...

  • Page 627

    Bc12cltr (sect.1) dccltr (a1a2) dccltr (b1b2) or and bc12cltr (sect.2) vpbc12tr (sect.1) vpdctr (a1a2) vpdctr (b1b2) vpbc12tr (sect.2) or bc17optr (sect.1) dcoptr (a1a2) bc17optr (sect.2) bc17cltr (sect.1) dccltr (a1a2) bc17cltr (sect.2) vpbc17tr (sect.1) vpdctr (a1a2) vpbc17tr (sect.2) bc27optr (se...

  • Page 628

    Configuration setting if there is no bypass busbar and therefore no 789 disconnector, then the interlocking for 789 is not used. The states for 789, 7189g, bb7_d, bc_17, bc_27 are set to open by setting the appropriate module inputs as follows. In the functional block diagram, 0 and 1 are designated...

  • Page 629

    3.12.3.3 interlocking for bus-coupler bay abc_bc (3) application the interlocking for bus-coupler bay (abc_bc, 3) function is used for a bus-coupler bay connected to a double busbar arrangement according to figure 242 . The function can also be used for a single busbar arrangement with transfer busb...

  • Page 630

    For bus-coupler bay n, these conditions are valid: 1289optr (bay 1) 1289optr (bay 2) . . . . . . 1289optr (bay n-1) and bbtr_op vp1289tr (bay 1) vp1289tr (bay 2) . . . . . . Vp1289tr (bay n-1) and vp_bbtr exdu_12 (bay 1) exdu_12 (bay 2) . . . . . . Exdu_12 (bay n-1) and exdu_12 en04000481_ansi.Vsd a...

  • Page 631

    Signal dcoptr the bus-section disconnector is open. Vpdctr the switch status of bus-section disconnector dc is valid. Exdu_dc no transmission error from the bay that contains the above information. If the busbar is divided by bus-section circuit breakers, the signals from the bus-section coupler bay...

  • Page 632

    Signals from bus-coupler if the busbar is divided by bus-section disconnectors into bus-sections, the signals bc_12 from the busbar coupler of the other busbar section must be transmitted to the own busbar coupler if both disconnectors are closed. En04000484_ansi.Vsd section 1 section 2 a1a2_dc(bs) ...

  • Page 633

    If the busbar is divided by bus-section circuit breakers, the signals from the bus-section coupler bay (a1a2_bs), rather than the bus-section disconnector bay (a1a2_dc), must be used. For b1b2_bs, corresponding signals from busbar b are used. The same type of module (a1a2_bs) is used for different b...

  • Page 634

    • 7189g_op = 1 • 7189g_cl = 0 if there is no second busbar b and therefore no 289 and 2089 disconnectors, then the interlocking for 289 and 2089 are not used. The states for 289, 2089, 2189g, bc_12, bbtr are set to open by setting the appropriate module inputs as follows. In the functional block dia...

  • Page 635

    189 289 189g 289g wa1 (a) wa2 (b) 389g 489g 489 389 252 and 489g are not used in this interlocking ab_trafo en04000515_ansi.Vsd 252 152 ansi04000515 v1 en figure 248: switchyard layout ab_trafo (3) the signals from other bays connected to the module ab_trafo are described below. Signals from bus-cou...

  • Page 636

    The project-specific logic for input signals concerning bus-coupler are the same as the specific logic for the line bay (abc_line): signal bc_12_cl a bus-coupler connection exists between busbar wa1 and wa2. Vp_bc_12 the switch status of bc_12 is valid. Exdu_bc no transmission error from bus-coupler...

  • Page 637

    En04000489_ansi.Vsd section 1 section 2 a1a2_bs b1b2_bs abc_line abc_bc abc_line abc_bc (wa1)a1 (wa2)b1 (wa7)c c b2 a2 ab_trafo ab_trafo ansi04000489 v1 en figure 250: busbars divided by bus-section circuit breakers to derive the signals: signal bbtr_op no busbar transfer is in progress concerning t...

  • Page 638

    For a bus-section circuit breaker between a1 and a2 section busbars, these conditions are valid: en04000490_ansi.Vsd s1s2optr (b1b2) bc12optr (sect.1) 1289optr (bay 1/sect.2) 1289optr (bay n/sect.2) s1s2optr (b1b2) bc12optr (sect.2) 1289optr (bay 1/sect.1) 1289optr (bay n /sect.1) bbtr_op vp_bbtr ex...

  • Page 639

    En04000491_ansi.Vsd s1s2optr (a1a2) bc12optr (sect.1) 1289optr (bay 1/sect.2) 1289optr (bay n/sect.2) s1s2optr (a1a2) bc12optr (sect.2) 1289optr (bay 1/sect.1) 1289optr (bay n /sect.1) bbtr_op vp_bbtr exdu_12 or and or and . . . . . . . . . . . . And and vps1s2tr (a1a2) vpbc12tr (sect.1) vp1289tr (b...

  • Page 640

    Application the interlocking for bus-section disconnector (a1a2_dc, 3) function is used for one bus-section disconnector between section 1 and 2 according to figure 253 . A1a2_dc (3) function can be used for different busbars, which includes a bus-section disconnector. Wa1 (a1) wa2 (a2) 189g 289g a1...

  • Page 641

    These signals from each line bay (abc_line), each transformer bay (ab_trafo), and each bus-coupler bay (abc_bc) are needed: signal 189optr 189 is open. 289optr 289 is open (ab_trafo, abc_line). 22089otr 289 and 2089 are open (abc_bc). Vp189tr the switch status of 189 is valid. Vp289tr the switch sta...

  • Page 642

    189optr (bay 1/sect.A1) s1dc_op vps1_dc exdu_bb en04000494_ansi.Vsd and 189optr (bay n/sect.A1) . . . . . . . . . Vp189tr (bay 1/sect.A1) vp189tr (bay n/sect.A1) exdu_bb (bay 1/sect.A1) exdu_bb (bay n/sect.A1) . . . . . . . . . . . . . . . . . . And and ansi04000494 v1 en figure 255: signals from an...

  • Page 643

    En04000496_ansi.Vsd 289optr (22089otr)(bay 1/sect.B1) s1dc_op vps1_dc exdu_bb 289optr (22089otr)(bay n/sect.B1) . . . . . . . . . Vp289tr (v22089tr)(bay 1/sect.B1) vp289tr (v22089tr)(bay n/sect.B1) exdu_bb (bay 1/sect.B1) exdu_bb (bay n/sect.B1) . . . . . . . . . . . . . . . . . . And and and ansi04...

  • Page 644

    The same type of module (a1a2_dc) is used for different busbars, that is, for both bus- section disconnector a1a2_dc and b1b2_dc. But for b1b2_dc, corresponding signals from busbar b are used. En04000498_ansi.Vsd section 1 section 2 a1a2_dc(bs) b1b2_dc(bs) db_bus db_bus db_bus db_bus (wa1)a1 (wa2)b1...

  • Page 645

    En04000499_ansi.Vsd 189optr (bay 1/sect.A1) s1dc_op vps1_dc exdu_bb and 189optr (bay n/sect.A1) . . . . . . . . . Vp189tr (bay 1/sect.A1) vp189tr (bay n/sect.A1) exdu_db (bay 1/sect.A1) exdu_db (bay n/sect.A1) . . . . . . . . . . . . . . . . . . And and ansi04000499 v1 en figure 260: signals from do...

  • Page 646

    En04000501_ansi.Vsd 289optr (bay 1/sect.B1) s1dc_op vps1_dc exdu_bb and 289optr (bay n/sect.B1) . . . . . . . . . Vp289tr (bay 1/sect.B1) vp289tr (bay n/sect.B1) exdu_db (bay 1/sect.B1) exdu_db (bay n/sect.B1) . . . . . . . . . . . . . . . . . . And and ansi04000501 v1 en figure 262: signals from do...

  • Page 647

    En04000503_ansi.Vsd section 1 section 2 a1a2_dc(bs) b1b2_dc(bs) bh_line (wa1)a1 (wa2)b1 b2 a2 bh_line bh_line bh_line ansi04000503 v1 en figure 264: busbars divided by bus-section disconnectors (circuit breakers) the project-specific logic is the same as for the logic for the double-breaker configur...

  • Page 648

    En04000505_ansi.Vsd section 1 section 2 a1a2_dc(bs) b1b2_dc(bs) ab_trafo abc_line bb_es abc_line (wa1)a1 (wa2)b1 (wa7)c c b2 a2 bb_es abc_bc ansi04000505 v1 en figure 266: busbars divided by bus-section disconnectors (circuit breakers) to derive the signals: signal bb_dc_op all disconnectors on this...

  • Page 649

    If no bus-section disconnector exists, the signal dcoptr, vpdctr and exdu_dc are set to 1 (true). If the busbar is divided by bus-section circuit breakers, the signals from the bus-section coupler bay (a1a2_bs) rather than the bus-section disconnector bay (a1a2_dc) must be used. For b1b2_bs, corresp...

  • Page 650

    189optr (bay 1/sect.A2) bb_dc_op vp_bb_dc exdu_bb en04000507_ansi.Vsd 189optr (bay n/sect.A2) . . . . . . . . . Vp189tr (bay 1/sect.A2) vp189tr (bay n/sect.A2) vpdctr (a1/a2) exdu_bb (bay n/sect.A2) . . . . . . . . . . . . . . . . . . And dcoptr (a1/a2) exdu_bb (bay 1/sect.A2) exdu_dc (a1/a2) and an...

  • Page 651

    289optr(22089otr)(bay 1/sect.B1) bb_dc_op vp_bb_dc exdu_bb en04000508_ansi.Vsd 289ptr (22089otr)(bay n/sect.B1) . . . . . . . . . Vp289tr(v22089tr) (bay 1/sect.B1) vp289tr(v22089tr) (bay n/sect.B1) vpdctr (b1/b2) exdu_bb (bay n/sect.B1) . . . . . . . . . . . . . . . . . . And and and dcoptr (b1/b2) ...

  • Page 652

    289optr(22089otr) (bay 1/sect.B2) bb_dc_op vp_bb_dc exdu_bb en04000509_ansi.Vsd 289optr(22089otr) (bay n/sect.B2) . . . . . . . . . Vp289tr(v22089tr) (bay 1/sect.B2) vp289tr(v22089tr) (bay n/sect.B2) vpdctr (b1/b2) exdu_bb (bay n/sect.B2) . . . . . . . . . . . . . . . . . . And dcoptr (b1/b2) exdu_b...

  • Page 653

    Signals in double-breaker arrangement the busbar grounding switch is only allowed to operate if all disconnectors of the bus section are open. En04000511_ansi.Vsd section 1 section 2 a1a2_dc(bs) b1b2_dc(bs) bb_es bb_es db_bus (wa1)a1 (wa2)b1 b2 a2 db_bus ansi04000511 v1 en figure 272: busbars divide...

  • Page 654

    The logic is identical to the double busbar configuration described in section “signals in single breaker arrangement”. Signals in breaker and a half arrangement the busbar grounding switch is only allowed to operate if all disconnectors of the bus- section are open. En04000512_ansi.Vsd section 1 se...

  • Page 655

    Wa1 (a) wa2 (b) 189 189g 289g 989g 6189 989 289 489g 589g 389g 6289 db_bus_b db_line db_bus_a en04000518_ansi.Vsd 252 152 ansi04000518 v1 en figure 274: switchyard layout double circuit breaker three types of interlocking modules per double circuit breaker bay are defined. Db_line (3) is the connect...

  • Page 656

    • 989_op = volt_off • 989_cl = volt_on if there is no voltage supervision, then set the corresponding inputs as follows: • volt_off = 1 • volt_on = 0 3.12.3.9 interlocking for breaker-and-a-half diameter bh (3) application the interlocking for breaker-and-a-half diameter (bh_conn(3), bh_line_a(3), b...

  • Page 657

    Connection between the two lines of the diameter in the breaker-and-a-half switchyard layout. For a breaker-and-a-half arrangement, the modules bh_line_a, bh_conn and bh_line_b must be used. Configuration setting for application without 989 and 989g, just set the appropriate inputs to open state and...

  • Page 658

    Function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number automatic voltage control for tap changer, single control tr1atcc u iec10000165 v1 en 90 automatic voltage control for tap changer, parallel control tr8atcc u iec10000166 v1 en 90 tap changer control...

  • Page 659

    Of these alternatives, the first and the last require communication between the function control blocks of the different transformers, whereas the middle alternative does not require any communication. The voltage control includes many extra features such as possibility to avoid simultaneous tapping...

  • Page 660

    Qcbay function block to the input psto of the tr1atcc (90) or tr8atcc (90) function block. Control mode the control mode of the automatic voltage control for tap changer function, tr1atcc (90) for single control and tr8atcc (90) for parallel control can be: • manual • automatic the control mode can ...

  • Page 661

    Ansi10000044-1-en.Vsd l oa d t ap c h an g e r raise,lower signals/alarms position mim bom ied trm 3ph or ph-ph or 1ph currents high voltage side low voltage side line impedance r+jx load center 3ph or ph-ph or 1ph voltages i a ,i b ,i c (load current) i l vl (load point voltage) vb (busbar voltage)...

  • Page 662

    Automatic voltage control for a single transformer automatic voltage control for tap changer, single control tr1atcc (90) measures the magnitude of the busbar voltage vb. If no other additional features are enabled (line voltage drop compensation), this voltage is further used for voltage regulation...

  • Page 663

    When v b falls below setting vblock, or alternatively, falls below setting vmin but still above vblock, or rises above vmax, actions will be taken in accordance with settings for blocking conditions (refer to table 161 ). If the busbar voltage rises above vmax, tr1atcc (90) can initiate one or more ...

  • Page 664

    T 1 tmin d = equation1848 v2 en (equation 422) where: da absolute voltage deviation from the set point d relative voltage deviation in respect to set deadband value for the last equation, the condition t1 > tmin shall also be fulfilled. This practically means that tmin will be equal to the set t1 va...

  • Page 665

    Line voltage drop the purpose with the line voltage drop compensation is to control the voltage, not at the power transformer low voltage side, but at a point closer to the load point. Figure 279 shows the vector diagram for a line modelled as a series impedance with the voltage v b at the lv busbar...

  • Page 666

    The calculated load voltage v l is shown on the local hmi as value uload under main menu/test/function status/control/transformervoltagecontrol(atcc,90)/ tr1atcc:x/tr8atcc:x. Load voltage adjustment due to the fact that most loads are proportional to the square of the voltage, it is possible to prov...

  • Page 667

    It shall be noted that the adjustment factor is negative in order to decrease the load voltage and positive in order to increase the load voltage. After this calculation v set, adjust will be used by tr1atcc (90) or tr8atcc (90) for voltage regulation instead of the original value vset. The calculat...

  • Page 668

    Parallel control with the master-follower method in the master-follower method, one of the transformers is selected to be master, and will regulate the voltage in accordance with the principles for automatic voltage control. Selection of the master is made by activating the binary input forcmast in ...

  • Page 669

    Load t1 i l t2 v b v l i t1 i t2 en06000486_ansi.Vsd ansi06000486 v1 en figure 281: parallel transformers with equal rated data. In the reverse reactance method, the line voltage drop compensation is used. The purpose is to control the voltage at a load point further out in the network. The very sam...

  • Page 670

    A comparison with figure 279 gives that the line voltage drop compensation for the purpose of reverse reactance control is made with a value with opposite sign on x l , hence the designation “reverse reactance” or “negative reactance”. Effectively this means that, whereas the line voltage drop compe...

  • Page 671

    In other words, the transformer with the higher tap position will have the higher v l value and the transformer with the lower tap position will have the lower v l value. Consequently, when the busbar voltage increases, t1 will be the one to tap down, and when the busbar voltage decreases, t2 will b...

  • Page 672

    The calculated mean busbar voltage v bmean is shown on the local hmi as a service value busvolt under main menu/test/function status/control/ transformervoltagecontrol(atcc,90)/tr8atcc:x. Measured current values for the individual transformers must be communicated between the participating tr8atcc (...

  • Page 673

    Calculated no-load voltages for all transformers in the parallel group are inside the outer deadband. In parallel operation with the circulating current method, different vset values for individual transformers can cause the voltage regulation to be unstable. For this reason, the mean value of vset ...

  • Page 674

    Avoidance of simultaneous tapping (operation with the master follower method) a time delay for the follower in relation to the command given from the master can be set when the setting mfmode is follow tap that is, when the follower follows the tap position (with or without an offset) of the master....

  • Page 675

    When the circulating current method is used, it is also possible to manually control the transformers as a group. To achieve this, the setting operationadapt must be set enabled, then the control mode for one tr8atcc (90) shall be set to “manual” via the binary input manctrl or the local hmi under m...

  • Page 676

    Plant with capacitive shunt compensation (for operation with the circulating current method) if significant capacitive shunt generation is connected in a substation and it is not symmetrically connected to all transformers in a parallel group, the situation may require compensation of the capacitive...

  • Page 677

    Load t1 i l t2 i cc....T2 i cc....T1 v b v l i t1 i t2 i c i t 2 -i c load t1 i l t2 i cc....T2 i cc....T1 v b v l i t1 i t2 i t2 i t1 i t1 i c en06000512_ansi.Vsd ansi06000512 v1 en figure 284: capacitor bank on the lv-side from figure 284 it is obvious that the two different connections of the cap...

  • Page 678

    2 c v q1 x = equation1981-ansi v1 en (equation 426) thereafter the current i c at the actual measured voltage vb can be calculated as: b c c v x i 3 × = equation1982-ansi v1 en (equation 427) in this way the measured lv currents can be adjusted so that the capacitor bank current will not influence t...

  • Page 679

    Atcc ied hv-side pforward lv-side ansi06000536-2-en.Vsd qforward (inductive) ansi06000536 v2 en figure 285: power direction references with the four outputs in the function block available, it is possible to do more than just supervise a level of power flow in one direction. By combining the outputs...

  • Page 680

    T1 t2 t3 99000952.Vsd v 1 v 2 v 3 z 1 z 2 z 3 i 1 i 2 i 3 =0 i l =i 1 +i 2 ansi99000952 v1 en figure 286: disconnection of one transformer in a parallel group when the busbar arrangement is more complicated with more buses and bus couplers/ bus sections, it is necessary to engineer a specific statio...

  • Page 681

    Tcmyltc or tclyltc (84) function block for the same transformer as tr8atcc (90) block belongs to. There are 10 binary signals and 6 analog signals in the data set that is transmitted from one tr8atcc (90) block to the other tr8atcc (90) blocks in the same parallel group: table 158: binary signals si...

  • Page 682

    • setv • vctrstatus • x2 the transformers controlled in parallel with the circulating current method or the master- follower method must be assigned unique identities. These identities are entered as a setting in each tr8atcc (90), and they are predefined as t1, t2, t3,..., t8 (transformers 1 to 8)....

  • Page 683

    Partial block: prevents operation of the tap changer only in one direction (only vraise or vlower command is blocked) in manual and automatic control mode. Auto block: prevents automatic voltage regulation, but the tap changer can still be controlled manually. Total block: prevents any tap changer o...

  • Page 684

    Setting values (range) description revactpartbk(auto matically reset) alarm auto block the risk of voltage instability increases as transmission lines become more heavily loaded in an attempt to maximize the efficient use of existing generation and transmission facilities. In the same time lack of r...

  • Page 685

    Setting values (range) description tapchgbk (manually reset alarm auto block auto&man block if the input tcinprog of tcmyltc or tclyltc (84) function block is connected to the tap changer mechanism, then this blocking condition will be active if the tcinprog input has not reset when the ttctimeout t...

  • Page 686

    Setting values (range) description tapposbk (automatically reset/manually reset) alarm auto block auto&man block this blocking/alarm is activated by either: 1. The tap changer reaching an end position i.E. One of the extreme positions according to the setting parameters lowvolttap and highvolttap . ...

  • Page 687

    Setting parameters for blocking that can be set in tr1atcc (90) or tr8atcc (90) under setting group nx in pst/ local hmi are listed in table 162 . Table 162: blocking settings setting value (range) description totalblock (manually reset) enabled / disabled tr1atcc (90) or tr8atcc (90) function can b...

  • Page 688

    Table 164: blockings without setting possibilities activation type of blocking description disconnected transformer (automatically reset) auto block automatic control is blocked for a transformer when parallel control with the circulating current method is used, and that transformer is disconnected ...

  • Page 689

    The following conditions in any one of tr8atccs (90) in the group will cause mutual blocking when the circulating current method is used: • over-current • total block via settings • total block via configuration • analog input error • automatic block via settings • automatic block via configuration ...

  • Page 690

    The mutual blocking remains until tr8atcc (90) that dispatched the mutual block signal is de-blocked. Another way to release the mutual blocking is to force tr8atcc (90), which caused mutual blocking to single mode operation. This is done by activating the binary input snglmode on tr8atcc (90) funct...

  • Page 691

    Input tcinprog, and it can then be used by tcmyltc (84) or tclyltc (84) function in three ways, which is explained below with the help of figure 287 . Vraise/vlower ttctimeout tcinprog a h d e f g c b en06000482_ansi.Vsd ansi06000482 v1 en figure 287: timing of pulses for tap changer operation monit...

  • Page 692

    The second use is to detect a jammed tap changer. If the timer ttctimeout times out before the tcinprog signal is set back to zero, the output signal tcerral is set high and tr1atcc (90) or tr8atcc (90) function is blocked. The third use is to check the proper operation of the tap changer mechanism....

  • Page 693

    Wearing of the tap changer contacts two counters, contactlife and noofoperations are available within the tap changer control and supervision function, 6 binary inputs tcmyltc or 32 binary inputs tclyltc (84). They can be used as a guide for maintenance of the tap changer mechanism. The contactlife ...

  • Page 694

    Means that different time delays can be used in the different followers in order to avoid simultaneous tapping if this is wanted. It shall be observed that it is not applicable in the follow command mode. Operationadapt: this setting enables or disables adapt mode for parallel control with the circu...

  • Page 695

    Measmode: selection of single phase, or phase-phase, or positive sequence quantity to be used for voltage and current measurement on the lv-side. The involved phases are also selected. Thus, single phase as well as phase-phase or three-phase feeding on the lv-side is possible but it is commonly sele...

  • Page 696

    Vbase. If uvpartbk is set to auto block orauto&manblock, then busbar voltages below vmin will result in a partial blocking such that only raise commands are permitted. Vblock: voltages below vblock normally correspond to a disconnected transformer and therefore it is recommended to block automatic c...

  • Page 697

    Controlled in a parallel group with the reverse reactance method and with no circulation (for example, assume two equal transformers on the same tap position). The load current lags the busbar voltage v b with the power factor j and the argument of the impedance rline and xline is designated j1. V b...

  • Page 698

    0 0 0 1 ( 37 ) 90 53 j = - - - = - equation1939 v1 en (equation 430) to achieve a more correct regulation, an adjustment to a value of j2 slightly less than -90° (2 – 4° less) can be made. The effect of changing power factor of the load will be that j2 will no longer be close to -90° resulting in v ...

  • Page 699

    Only a small difference in tap position, but the voltage regulation as such will be more sensitive to a deviation from the anticipated power factor. A too high setting of xline can cause a hunting situation as the transformers will then be prone to over react on deviations from the target value. The...

  • Page 700

    Tap changer control (tcctrl) iblock: current setting of the over current blocking function. In case, the transformer is carrying a current exceeding the rated current of the tap changer for example, because of an external fault. The tap changer operations shall be temporarily blocked. This function ...

  • Page 701

    Setting. Reference is made to figure 285 for definition of forward and reverse direction of power through the transformer. En06000635_2_en.Vsd p p iec06000635 v2 en figure 291: setting of a positive value for p q>: when the reactive power exceeds the value given by this setting, the output qgtfwd wi...

  • Page 702

    2 v comp a 100% n p ´ d = ´ ´ ´ equation1984-ansi v1 en (equation 431) where: • dv is the deadband setting in percent. • n denotes the desired number of difference in tap position between the transformers, that shall give a voltage deviation v di which corresponds to the dead- band setting. • p is t...

  • Page 703

    T1rxop.......T8rxop: this setting is set enabled for every transformer that can participate in a parallel group with the transformer in case. For this transformer (own transformer), the setting must always be disabled. Tapposoffs: this setting gives the tap position offset in relation to the master ...

  • Page 704

    Counter that is, the total number of operations at rated load that the tap changer is designed for. Enabtapcmd: this setting enables/disables the lower and raise commands to the tap changer. It shall be enabled for voltage control, and disabled for tap position feedback to the transformer differenti...

  • Page 705

    Name values (range) unit step default description vset 85.0 - 120.0 %vb 0.1 100.0 voltage control set voltage, % of rated voltage vdeadband 0.2 - 9.0 %vb 0.1 1.2 outer voltage deadband, % of rated voltage vdeadbandinner 0.1 - 9.0 %vb 0.1 0.9 inner voltage deadband, % of rated voltage vmax 80 - 180 %...

  • Page 706

    Name values (range) unit step default description p> -9999.99 - 9999.99 mw 0.01 1000 alarm level of active power in forward direction p -9999.99 - 9999.99 mw 0.01 -1000 alarm level of active power in reverse direction q> -9999.99 - 9999.99 mvar 0.01 1000 alarm level of reactive power in forward dire...

  • Page 707

    Name values (range) unit step default description measmode a b c ab bc ca posseq - - posseq selection of measured voltage and current q1 -9999.99 - 9999.99 mvar 0.01 0 size of cap/reactor bank 1 in mvar, >0 for c and q2 -9999.99 - 9999.99 mvar 0.01 0 size of cap/reactor bank 2 in mvar, >0 for c and ...

  • Page 708

    Name values (range) unit step default description lvaconst2 -20.0 - 20.0 %vb 0.1 0.0 constant 2 for lva, % of regulated voltage lvaconst3 -20.0 - 20.0 %vb 0.1 0.0 constant 3 for lva, % of regulated voltage lvaconst4 -20.0 - 20.0 %vb 0.1 0.0 constant 4 for lva, % of regulated voltage vrauto -20.0 - 2...

  • Page 709

    Name values (range) unit step default description tvtmismatch 1 - 600 s 1 10 time delay for vt supervision alarm t1rxop disabled enabled - - disabled receive block operation from parallel transformer1 t2rxop disabled enabled - - disabled receive block operation from parallel transformer2 t3rxop disa...

  • Page 710

    Name values (range) unit step default description cmderrbk alarm auto block auto&man block - - auto block alarm, auto block or auto&man block for command error ocbk alarm auto block auto&man block - - auto&man block alarm, auto block or auto&man block for overcurrent mfposdiffbk alarm auto block - -...

  • Page 711

    Name values (range) unit step default description codetype bin bcd gray single ma - - bin type of code conversion useparity disabled enabled - - disabled enable parity check tstable 1 - 60 s 1 2 time after position change before the value is accepted clfactor 1.0 - 3.0 - 0.1 2.0 adjustable factor fo...

  • Page 712

    3.12.5 logic rotating switch for function selection and lhmi presentation slggio function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number logic rotating switch for function selection and lhmi presentation slggio - - 3.12.5.1 application the logic rotating ...

  • Page 713

    Tpulse: in case of a pulsed output, it gives the length of the pulse (in seconds). Tdelay: the delay between the up or down activation signal positive front and the output activation. Stopatextremes: sets the behavior of the switch at the end positions – if set to disabled, when pressing up while on...

  • Page 714

    An example where vsggio is configured to switch autorecloser enabled–disabled from a button symbol on the local hmi is shown in figure 292 . The close and open buttons on the local hmi are normally used for enable–disable operations of the circuit breaker. Iec07000112-2-en_ansi.Vsd psto cmdpos12 ipo...

  • Page 715

    3.12.7 iec61850 generic communication i/o functions dpggio function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number iec 61850 generic communication i/o functions dpggio - - 3.12.7.1 application the iec61850 generic communication i/o functions (dpggio) func...

  • Page 716

    3.12.8.2 setting guidelines the parameters for the single point generic control 8 signals (spc8ggio) function are set via the local hmi or pcm600. Operation: turning the function operation enabled/disabled. There are two settings for every command output (totally 8): latchedx: decides if the command...

  • Page 717

    3.12.9 automationbits, command function for dnp3.0 autobits function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number automationbits, command function for dnp3 autobits - - 3.12.9.1 application automation bits, command function for dnp3 (autobits) is used w...

  • Page 718

    Table 177: chserrs485 non group settings (basic) name values (range) unit step default description operation disabled serial-mode - - disabled operation mode baudrate 300 bd 600 bd 1200 bd 2400 bd 4800 bd 9600 bd 19200 bd - - 9600 bd baud-rate for serial port wiremode four-wire two-wire - - two-wire...

  • Page 719

    Table 180: ch2tcp non group settings (advanced) name values (range) unit step default description aplaymaxrxsize 20 - 2048 - 1 2048 application layer maximum rx fragment size aplaymaxtxsize 20 - 2048 - 1 2048 application layer maximum tx fragment size table 181: ch3tcp non group settings (basic) nam...

  • Page 720

    Table 185: ch5tcp non group settings (basic) name values (range) unit step default description operation disabled tcp/ip udp-only - - disabled operation mode tcpiplisport 1 - 65535 - 1 20000 tcp/ip listen port udpportaccdata 1 - 65535 - 1 20000 udp port to accept udp datagrams from master udpportini...

  • Page 721

    Name values (range) unit step default description obj22defvar 1:bincnt32evwout t 2:bincnt16evwout t 5:bincnt32evwith t 6:bincnt16evwith t - - 1:bincnt32evwou tt object 22, default variation obj30defvar 1:ai32int 2:ai16int 3:ai32intwithoutf 4:ai16intwithoutf 5:ai32fltwithf 6:ai64fltwithf - - 3:ai32in...

  • Page 722

    Name values (range) unit step default description turretrydelay 0.00 - 60.00 s 0.01 5.00 unsolicited response retry delay in s turofflrtrydel 0.00 - 60.00 s 0.01 30.00 unsolicited response off-line retry delay in s urevcntthold1 1 - 100 - 1 5 unsolicited response class 1 event count report treshold ...

  • Page 723

    Name values (range) unit step default description obj2defvar 1:bichwithouttim e 2:bichwithtime 3:bichwithreltim e - - 3:bichwithreltim e object 2, default variation obj3defvar 1:diwithoutflag 2:diwithflag - - 1:diwithoutflag object 3, default variation obj4defvar 1:dichwithouttim e 2:dichwithtime 3:...

  • Page 724

    Name values (range) unit step default description confmultfrag no yes - - yes confirm each multiple fragment urenable no yes - - yes unsolicited response enabled urevclassmask disabled class 1 class 2 class 1 and 2 class 3 class 1 and 3 class 2 and 3 class 1, 2 and 3 - - disabled unsolicited respons...

  • Page 725

    Table 191: mst2tcp non group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation slaveaddress 0 - 65519 - 1 1 slave address masteraddres 0 - 65519 - 1 1 master address valmasteraddr no yes - - yes validate source (master...

  • Page 726

    Name values (range) unit step default description obj22defvar 1:bincnt32evwout t 2:bincnt16evwout t 5:bincnt32evwith t 6:bincnt16evwith t - - 1:bincnt32evwou tt object 22, default variation obj30defvar 1:ai32int 2:ai16int 3:ai32intwithoutf 4:ai16intwithoutf 5:ai32fltwithf 6:ai64fltwithf - - 3:ai32in...

  • Page 727

    Name values (range) unit step default description turevbuftout1 0.00 - 60.00 s 0.01 5.00 unsolicited response class 1 event buffer timeout urevcntthold2 1 - 100 - 1 5 unsolicited response class 2 event count report treshold turevbuftout2 0.00 - 60.00 s 0.01 5.00 unsolicited response class 2 event bu...

  • Page 728

    Name values (range) unit step default description obj2defvar 1:bichwithouttim e 2:bichwithtime 3:bichwithreltim e - - 3:bichwithreltim e object 2, default variation obj3defvar 1:diwithoutflag 2:diwithflag - - 1:diwithoutflag object 3, default variation obj4defvar 1:dichwithouttim e 2:dichwithtime 3:...

  • Page 729

    Name values (range) unit step default description confmultfrag no yes - - yes confirm each multiple fragment urenable no yes - - yes unsolicited response enabled urevclassmask disabled class 1 class 2 class 1 and 2 class 3 class 1 and 3 class 2 and 3 class 1, 2 and 3 - - disabled unsolicited respons...

  • Page 730

    Table 195: mst4tcp non group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled disable/enable operation slaveaddress 0 - 65519 - 1 1 slave address masteraddres 0 - 65519 - 1 1 master address valmasteraddr no yes - - yes validate source (master...

  • Page 731

    Name values (range) unit step default description obj22defvar 1:bincnt32evwout t 2:bincnt16evwout t 5:bincnt32evwith t 6:bincnt16evwith t - - 1:bincnt32evwou tt object 22, default variation obj30defvar 1:ai32int 2:ai16int 3:ai32intwithoutf 4:ai16intwithoutf 5:ai32fltwithf 6:ai64fltwithf - - 3:ai32in...

  • Page 732

    Name values (range) unit step default description turevbuftout1 0.00 - 60.00 s 0.01 5.00 unsolicited response class 1 event buffer timeout urevcntthold2 1 - 100 - 1 5 unsolicited response class 2 event count report treshold turevbuftout2 0.00 - 60.00 s 0.01 5.00 unsolicited response class 2 event bu...

  • Page 733

    Outputs that can be used, for example, to control high voltage apparatuses in switchyards. For local control functions, the local hmi can also be used. Together with the configuration logic circuits, the user can govern pulses or steady output signals for control purposes within the ied or via binar...

  • Page 734

    Single command function singlecmd cmdouty outy function n en04000207.Vsd function n iec04000207 v2 en figure 294: application example showing a logic diagram for control of built-in functions single command function singlesmd cmdouty outy device 1 user- defined conditions configuration logic circuit...

  • Page 735

    3.12.10.2 setting guidelines the parameters for single command, 16 signals (singlecmd) are set via the local hmi or pcm600. Parameters to be set are mode, common for the whole block, and cmdouty which includes the user defined name for each output signal. The mode input sets the outputs to be one of...

  • Page 736

    One communication channel is used in each direction, which can transmit an on/off signal if required. The performance and security of this function is directly related to the transmission channel speed and security against false or lost signals. In the directional scheme, information of the fault cu...

  • Page 737

    Tcoord: delay time for trip from ecpsch (85) function. For permissive under/ overreaching schemes, this timer shall be set to at least 20 ms plus maximum reset time of the communication channel as a security margin. For blocking scheme, the setting should be > maximum signal transmission time +10 ms...

  • Page 738

    3.13.2.1 application fault current reversal logic figure 296 and figure 297 show a typical system condition, which can result in a fault current reversal. Note that the fault current is reversed in line l2 after the breaker opening. This can cause an unselective trip on line l2 if the current revers...

  • Page 739

    Weak-end infeed logic figure 298 shows a typical system condition that can result in a missing operation. Note that there is no fault current from node b. This causes that the ied at b cannot detect the fault and trip the breaker in b. To cope with this situation, a selectable weak- end infeed logic...

  • Page 740

    Teleprotection equipment typical decision time is in the range 10 – 30 ms. For digital teleprotection equipment this time is in the range 2 – 10 ms. If the teleprotection equipment is integrated in the protection ied the decision time can be slightly reduced. Below the principle time sequence of sig...

  • Page 741

    3.13.2.3 setting parameters table 200: ecrwpsch (85) group settings (basic) name values (range) unit step default description currrev disabled enabled - - disabled operating mode of current reversal logic tpickuprev 0.000 - 60.000 s 0.001 0.020 pickup time for current reversal logic tdelayrev 0.000 ...

  • Page 742

    Tripping command when phase selection within the operating protection functions is not possible, or when external conditions request three-pole tripping. • two-pole tripping for two-phase faults. The three-pole trip for all faults offers a simple solution and is often sufficient in well meshed trans...

  • Page 743

    Set the function block to program = 3ph and set the required length of the trip pulse to for example, ttripmin = 150ms. For special applications such as lock-out refer to the separate section below. The typical connection is shown below in figure 300 . Signals that are not used are dimmed. Block blk...

  • Page 744

    When single-pole tripping schemes are used a single-phase autoreclosing attempt is expected to follow. For cases where the autoreclosing is not in service or will not follow for some reason, the input prepare three-pole trip p3ptr must be activated. This is normally connected to the respective outpu...

  • Page 745

    Block blklkout trin_3p trinp_a trin_b trinl3 ps_a ps_b ps_c 1ptrz 1ptref p3ptr setlkout rstlkout smpptrc (94) trip tr_a tr_b tr_c tr1p tr2p tr3p cllkout tr3p smbrrec (79) prep3p tr3p phase selection ps_a ps_b ps_c distance protection zone 1 trip distance protection zone 2 trip distance protection zo...

  • Page 746

    Will result in lock-out. This is normally the case for overhead line protection where most faults are transient. Unsuccessful autoreclose and back-up zone tripping can in such cases be connected to initiate lock-out by activating the input setlkout. Blocking of the function block the function block ...

  • Page 747

    3.14.1.3 setting parameters table 201: smpptrc (94) group settings (basic) name values (range) unit step default description operation disabled enabled - - enabled disable/enable operation program 3 phase 1p/3p 1p/2p/3p - - 1p/3p three pole; single or three pole; single, two or three pole trip ttrip...

  • Page 748

    Pulsetime: defines the pulse time delay. When used for direct tripping of circuit breaker(s) the pulse time delay shall be set to approximately 0.150 seconds in order to obtain satisfactory minimum duration of the trip pulse to the circuit breaker trip coils. Ondelay: used to prevent output signals ...

  • Page 749

    For controllable gates, settable timers and sr flip-flops with memory, the setting parameters are accessible via the local hmi or via the pst tool. Configuration logic is configured using the act configuration tool in pcm600. Execution of functions as defined by the configurable logic blocks runs ac...

  • Page 750

    Table 205: pulsetimer non group settings (basic) name values (range) unit step default description t 0.000 - 90000.000 s 0.001 0.010 time delay of function table 206: srmemory group settings (basic) name values (range) unit step default description memory disabled enabled - - enabled operating mode ...

  • Page 751

    Example for use of grp_off signal in fxdsign the restricted earth fault function refpdif (87n) can be used both for auto- transformers and normal transformers. When used for auto-transformers, information from both windings parts, together with the neutral point current, needs to be available to the...

  • Page 752

    3.14.4.2 setting parameters the function does not have any parameters available in local hmi or protection and control ied manager (pcm 600) 3.14.5 boolean 16 to integer conversion b16i function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number boolean 16 to...

  • Page 753

    3.14.6.2 setting guidelines the function does not have any parameters available in the local hmi or protection and control ied manager (pcm600). 3.14.7 integer to boolean 16 conversion ib16 function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number integer t...

  • Page 754

    3.14.8.2 setting parameters the function does not have any parameters available in the local hmi or protection and control ied manager (pcm600) 3.15 monitoring 3.15.1 measurement function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number measurements cvmmxn ...

  • Page 755

    Example, via iec 61850. The possibility to continuously monitor measured values of active power, reactive power, currents, voltages, frequency, power factor etc. Is vital for efficient production, transmission and distribution of electrical energy. It provides to the system operator fast and easy ov...

  • Page 756

    The power system quantities provided, depends on the actual hardware, (trm) and the logic configuration made in pcm600. The measuring functions cmsqi and vmsqi provide sequence component quantities: • i: sequence currents (positive, zero, negative sequence, magnitude and angle) • v: sequence voltage...

  • Page 757

    It can be seen that: • when system voltage falls below ugenzerodb, the shown value for s, p, q, pf, ilag, ilead, u and f on the local hmi is forced to zero • when system current falls below igenzerodb, the shown value for s, p, q, pf, ilag, ilead, u and f on the local hmi is forced to zero • when th...

  • Page 758

    Vbase: base voltage in primary kv. This voltage is used as reference for voltage setting. It can be suitable to set this parameter to the rated primary voltage supervised object. Ibase: base current in primary a. This current is used as reference for current setting. It can be suitable to set this p...

  • Page 759

    Xmin: minimum value for analog signal x set directly in applicable measuring unit. Xmax: maximum value for analog signal x. Xzerodb: zero point clamping. A signal value less than xzerodb is forced to zero. Observe the related zero point clamping settings in setting group n for cvmmxn (vgenzerodb and...

  • Page 760

    100 30 5 imagcomp5 imagcomp30 imagcomp100 -10 +10 magnitude compensation % of in measured current % of in 0-5%: constant 5-30-100%: linear >100%: constant 100 30 5 iangcomp5 iangcomp30 iangcomp100 -10 +10 angle compensation degrees measured current % of in ansi05000652_3_en.Vsd ansi05000652 v3 en fi...

  • Page 761

    Measurement function application for a 380 kv ohl single line diagram for this application is given in figure 306 : 380kv busbar 380kv ohl p q 800/5 a ansi09000039-1-en.Vsd 380kv 120v / 3 3 kv ied ansi09000039 v1 en figure 306: single line diagram for 380 kv ohl application in order to monitor, supe...

  • Page 762

    Table 210: general settings parameters for the measurement function setting short description selected value comments operation operation off/on on function must be on powampfact amplitude factor to scale power calculations 1.000 it can be used during commissioning to achieve higher measurement accu...

  • Page 763

    Setting short description selected value comments plowlim low limit (physical value) -800 low warning limit. Not active plowlowllim low low limit (physical value) -800 low alarm limit. Not active plimhyst hysteresis value in % of range (common for all limits) 2 set ±Δ hysteresis mw that is, 2% table...

  • Page 764

    132kv busbar 200/5 33kv busbar 500/5 p q 31.5 mva ansi09000040-1-en.Vsd 33kv 120v / 3 3 v ab ied ansi09000040 v1 en figure 307: single line diagram for transformer application in order to measure the active and reactive power as indicated in figure 307 , it is necessary to do the following: 1. Set c...

  • Page 765

    Table 213: general settings parameters for the measurement function setting short description selected value comment operation operation disabled / enabled enabled function must be enabled powampfact magnitude factor to scale power calculations 1.000 typically no scaling is required powangcomp angle...

  • Page 766

    230kv busbar 300/5 4000/5 100 mva g p q 100 mva 15.65kv ansi09000041-1-en.Vsd 15/0.12kv v ab , v bc , ied ansi09000041 v1 en figure 308: single line diagram for generator application in order to measure the active and reactive power as indicated in figure 308 , it is necessary to do the following: 1...

  • Page 767

    Table 214: general settings parameters for the measurement function setting short description selected value comment operation operation off/on on function must be on powampfact amplitude factor to scale power calculations 1.000 typically no scaling is required powangcomp angle compensation for phas...

  • Page 768

    Name values (range) unit step default description qreptyp cyclic dead band int deadband - - cyclic reporting type pfmin -1.000 - 1.000 - 0.001 -1.000 minimum value pfmax -1.000 - 1.000 - 0.001 1.000 maximum value pfreptyp cyclic dead band int deadband - - cyclic reporting type vmin 0.0 - 200.0 %vb 0...

  • Page 769

    Table 216: cvmmxn non group settings (advanced) name values (range) unit step default description sdbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s szerodb 0 - 100000 m% 1 500 zero point clamping in 0.001% of range shihilim 0.0 - 2000.0 %sb 0.1 150.0 high high l...

  • Page 770

    Name values (range) unit step default description vlowlim 0.0 - 200.0 %vb 0.1 80.0 low limit in % of ubase vlowlowlim 0.0 - 200.0 %vb 0.1 60.0 low low limit in % of ubase vlimhyst 0.000 - 100.000 % 0.001 5.000 hysteresis value in % of range (common for all limits) idbrepint 1 - 300 type 1 10 cycl: r...

  • Page 771

    Table 217: cmmxu non group settings (basic) name values (range) unit step default description ia_dbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s operation disabled enabled - - disabled disbled/enabled operation ibase 1 - 99999 a 1 3000 base setting for current ...

  • Page 772

    Name values (range) unit step default description ia_lowlim 0.000 - 10000000000.000 a 0.001 0.000 low limit (physical value) ia_lowlowlim 0.000 - 10000000000.000 a 0.001 0.000 low low limit (physical value) imagcomp100 -10.000 - 10.000 % 0.001 0.000 magnitude factor to calibrate current at 100% of i...

  • Page 773

    Table 219: vnmmxu non group settings (basic) name values (range) unit step default description va_dbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s operation disabled enabled - - disabled disbled/enabled operation vbase 0.05 - 2000.00 kv 0.05 400.00 base setting ...

  • Page 774

    Table 220: vnmmxu non group settings (advanced) name values (range) unit step default description va_zerodb 0 - 100000 m% 1 0 zero point clamping in 0.001% of range va_hihilim 0.000 - 10000000000.000 v 0.001 260000.000 high high limit (physical value) va_hilim 0.000 - 10000000000.000 v 0.001 240000....

  • Page 775

    Table 221: vmmxu non group settings (basic) name values (range) unit step default description vab_dbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s operation disabled enabled - - disabled disbled/enabled operation vbase 0.05 - 2000.00 kv 0.05 400.00 base setting ...

  • Page 776

    Name values (range) unit step default description vmagcomp100 -10.000 - 10.000 % 0.001 0.000 magnitude factor to calibrate voltage at 100% of vn vab_min 0.000 - 10000000000.000 v 0.001 0.000 minimum value vab_limhys 0.000 - 100.000 % 0.001 5.000 hysteresis value in % of range and is common for all l...

  • Page 777

    Name values (range) unit step default description 3i0reptyp cyclic dead band int deadband - - cyclic reporting type 3i0limhys 0.000 - 100.000 % 0.001 5.000 hysteresis value in % of range and is common for all limits 3i0angdbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int d...

  • Page 778

    Table 224: cmsqi non group settings (advanced) name values (range) unit step default description 3i0zerodb 0 - 100000 m% 1 0 zero point clamping in 0.001% of range 3i0hihilim 0.000 - 10000000000.000 a 0.001 900.000 high high limit (physical value) 3i0hilim 0.000 - 10000000000.000 a 0.001 800.000 hig...

  • Page 779

    Table 225: vmsqi non group settings (basic) name values (range) unit step default description 3v0dbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s 3v0min 0.000 - 10000000000.000 v 0.001 0.000 minimum value 3v0max 0.000 - 10000000000.000 v 0.001 300000.000 maximum...

  • Page 780

    Name values (range) unit step default description v2limhys 0.000 - 100.000 % 0.001 5.000 hysteresis value in % of range and is common for all limits v2angdbrepint 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s v2angmin -180.000 - 180.000 deg 0.001 -180.000 minimum valu...

  • Page 781

    Name values (range) unit step default description v2zerodb 0 - 100000 m% 1 0 zero point clamping in 0.001% of range v2hihilim 0.000 - 10000000000.000 v 0.001 260000.000 high high limit (physical value) v2hilim 0.000 - 10000000000.000 v 0.001 240000.000 high limit (physical value) v2lowlim 0.000 - 10...

  • Page 782

    3.15.3.1 introduction when using a substation automation system with lon or spa communication, time- tagged events can be sent at change or cyclically from the ied to the station level. These events are created from any available signal in the ied that is connected to the event function (event). The...

  • Page 783

    3.15.3.3 setting parameters table 227: event non group settings (basic) name values (range) unit step default description spachannelmask disabled channel 1-8 channel 9-16 channel 1-16 - - disabled spa channel mask lonchannelmask disabled channel 1-8 channel 9-16 channel 1-16 - - disabled lon channel...

  • Page 784

    Name values (range) unit step default description eventmask9 noevents onset onreset onchange autodetect - - autodetect reporting criteria for input 9 eventmask10 noevents onset onreset onchange autodetect - - autodetect reporting criteria for input 10 eventmask11 noevents onset onreset onchange auto...

  • Page 785

    Name values (range) unit step default description minrepintval10 0 - 3600 s 1 2 minimum reporting interval input 10 minrepintval11 0 - 3600 s 1 2 minimum reporting interval input 11 minrepintval12 0 - 3600 s 1 2 minimum reporting interval input 12 minrepintval13 0 - 3600 s 1 2 minimum reporting inte...

  • Page 786

    3.15.4.2 setting guidelines the pulse time t is the only setting for the logical signal status report (binstatrep). Each output can be set or reset individually, but the pulse time will be the same for all outputs in the entire binstatrep function. 3.15.4.3 setting parameters table 228: binstatrep n...

  • Page 787

    Function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number analog input signals a41radr - - disturbance report drprdre - - disturbance report a1radr - - disturbance report a4radr - - disturbance report b1rbdr - - 3.15.6.1 application to get fast, complete an...

  • Page 788

    (using wavewin, that can be found on the pcm600 installation cd). The user can also upload disturbance report files using ftp or mms (over 61850–8–1) clients. If the ied is connected to a station bus (iec 61850-8-1), the disturbance recorder (record made and fault number) and the fault locator infor...

  • Page 789

    Trip value rec sequential of events event recorder indications disturbance recorder a1-4radr b1-6rbdr disturbance report binary signals analog signals a4radr b6rbdr drprdre ansi09000337-1-en.Vsd ansi09000337 v1 en figure 310: disturbance report functions and related function blocks for disturbance r...

  • Page 790

    Operation the operation of disturbance report function drprdre has to be set enabled or disabled. If disabled is selected, note that no disturbance report is registered, and none sub-function will operate (the only general parameter that influences sequential of events (soe)). Operation = disabled: ...

  • Page 791

    Postfault recording time (postfaultrect) is the maximum recording time after the disappearance of the trig-signal (does not influence the trip value recorder (tvr) function). Recording time limit (timelimit) is the maximum recording time after trig. The parameter limits the recording time if some tr...

  • Page 792

    Info103n: information number (0-255) for binary input n according to iec-60870-5-103, that is, 69-71: trip l1-l3, 78-83: zone 1-6. See also description in the chapter iec 60870-5-103. Analog input signals up to 40 analog signals can be selected among internal analog and analog input signals. Pcm600 ...

  • Page 793

    If operationm = disabled, no waveform (samples) will be recorded and reported in graph. However, trip value, pre-fault and fault value will be recorded and reported. The input channel can still be used to trig the disturbance recorder. If operationm = enabled, waveform (samples) will also be recorde...

  • Page 794

    Remember that values of parameters set elsewhere are linked to the information on a report. Such parameters are, for example, station and object identifiers, ct and vt ratios. 3.15.6.3 setting parameters table 229: drprdre non group settings (basic) name values (range) unit step default description ...

  • Page 795

    Name values (range) unit step default description operation03 disabled enabled - - disabled operation on/off nomvalue03 0.0 - 999999.9 - 0.1 0.0 nominal value for analog channel 3 undertrigop03 disabled enabled - - disabled use under level trig for analog cha 3 (on) or not (off) undertrigle03 0 - 20...

  • Page 796

    Name values (range) unit step default description undertrigop07 disabled enabled - - disabled use under level trig for analog cha 7 (on) or not (off) undertrigle07 0 - 200 % 1 50 under trigger level for analog cha 7 in % of signal overtrigop07 disabled enabled - - disabled use over level trig for an...

  • Page 797

    Table 231: a4radr non group settings (basic) name values (range) unit step default description operation31 disabled enabled - - disabled operation on/off nomvalue31 0.0 - 999999.9 - 0.1 0.0 nominal value for analog channel 31 undertrigop31 disabled enabled - - disabled use under level trig for analo...

  • Page 798

    Name values (range) unit step default description overtrigle34 0 - 5000 % 1 200 over trigger level for analog cha 34 in % of signal operation35 disabled enabled - - disabled operation on/off nomvalue35 0.0 - 999999.9 - 0.1 0.0 nominal value for analog channel 35 undertrigop35 disabled enabled - - di...

  • Page 799

    Name values (range) unit step default description overtrigle38 0 - 5000 % 1 200 over trigger level for analog cha 38 in % of signal operation39 disabled enabled - - disabled operation on/off nomvalue39 0.0 - 999999.9 - 0.1 0.0 nominal value for analog channel 39 undertrigop39 disabled enabled - - di...

  • Page 800

    Name values (range) unit step default description operation03 disabled enabled - - disabled trigger operation on/off triglevel03 trig on 0 trig on 1 - - trig on 1 trig on positiv (1) or negative (0) slope for binary inp 3 indicationma03 hide show - - hide indication mask for binary channel 3 setled0...

  • Page 801

    Name values (range) unit step default description indicationma08 hide show - - hide indication mask for binary channel 8 setled08 disabled enabled - - disabled set red-led on hmi for binary channel 8 operation09 disabled enabled - - disabled trigger operation on/off triglevel09 trig on 0 trig on 1 -...

  • Page 802

    Name values (range) unit step default description operation14 disabled enabled - - disabled trigger operation on/off triglevel14 trig on 0 trig on 1 - - trig on 1 trig on positiv (1) or negative (0) slope for binary inp 14 indicationma14 hide show - - hide indication mask for binary channel 14 setle...

  • Page 803

    Name values (range) unit step default description funt11 0 - 255 funt 1 0 function type for binary channel 11 (iec -60870-5-103) funt12 0 - 255 funt 1 0 function type for binary channel 12 (iec -60870-5-103) funt13 0 - 255 funt 1 0 function type for binary channel 13 (iec -60870-5-103) funt14 0 - 25...

  • Page 804

    3.15.7 sequential of events 3.15.7.1 application from an overview perspective, continuous event-logging is a useful system monitoring instrument and is a complement to specific disturbance recorder functions. The event list (el), always included in the ied, logs all selected binary input signals con...

  • Page 805

    During a disturbance. The status changes are logged during the entire recording time, which depends on the set of recording times (pre-, post-fault and limit time) and the actual fault time. The indications are not time-tagged. The indication information is available for each of the recorded disturb...

  • Page 806

    The event recorder information is available for each of the recorded disturbances in the ied and the user may use the local hmi to get the information. The information is included in the disturbance recorder file, which may be uploaded to pcm600 and further analyzed using the disturbance handling to...

  • Page 807

    3.15.10.2 setting guidelines the trip value recorder (tvr) setting parameters are a part of the disturbance report settings. For the trip value recorder (tvr) there is one dedicated setting: zeroangleref: the parameter defines which analog signal to use as phase-angle reference for all other input s...

  • Page 808

    Recordings. The disturbance recording information is included in the disturbance recorder files, which may be uploaded to pcm600 for further analysis using the disturbance handling tool. The information is also available on a station bus according to iec 61850 and according to iec 60870-5-103. 3.15....

  • Page 809

    System as a service value. When using iec 61850–8–1, a scaled service value is available over the station bus. The normal use for this function is the counting of energy pulses from external energy meters. An optional number of inputs from an arbitrary input module in ied can be used for this purpos...

  • Page 810

    Name values (range) unit step default description scale 1.000 - 90000.000 - 0.001 1.000 scaling value for scal_val output to unit per counted value quantity count activepower apparentpower reactivepower activeenergy apparentenergy reactiveenergy - - count measured quantity for scal_val output trepor...

  • Page 811

    Display editor tool (gde) with a measuring value which is selected to the active and reactive component as preferred. All four values can also be presented. Maximum demand values are presented in mwh or mvarh in the same way. Alternatively, the values can be presented with use of the pulse counters ...

  • Page 812

    Erfaccplsqty and ervaccplsqty : gives the mvarh value in each pulse. It should be selected together with the setting of the pulse counter (pcggio) settings to give the correct total pulse value. For the advanced user there are a number of settings for direction, zero clamping, max limit, and so on. ...

  • Page 813

    Name values (range) unit step default description levzeroclampp 0.001 - 10000.000 mw 0.001 10.000 zero point clamping level at active power levzeroclampq 0.001 - 10000.000 mvar 0.001 10.000 zero point clamping level at reactive power eafprestval 0.000 - 10000.000 mwh 0.001 0.000 preset initial value...

  • Page 814

    808.

  • Page 815

    Section 4 station communication about this chapter this chapter describes the communication possibilities in a sa-system. 4.1 overview each ied is provided with a communication interface, enabling it to connect to one or many substation level systems or equipment, either on the substation automation...

  • Page 816

    Figure 312 shows the topology of an iec 61850–8–1 configuration. Iec 61850–8–1 specifies only the interface to the substation lan. The lan itself is left to the system integrator. Kiosk 2 kiosk 3 station hsi base system engineering workstation sms gateway printer cc iec09000135_en.V sd kiosk 1 ied 1...

  • Page 817

    Control protection control protection control and protection goose en05000734.Vsd station hsi microscada gateway ied a ied a ied a ied a ied a iec05000734 v1 en figure 313: example of a broadcasted goose message 4.2.2 setting guidelines there are two settings related to the iec 61850–8–1 protocol: o...

  • Page 818

    4.2.4 iec 61850 generic communication i/o functions spggio, sp16ggio 4.2.4.1 application iec 61850–8–1 generic communication i/o functions (spggio) function is used to send one single logical output to other systems or equipment in the substation. It has one visible input, that should be connected i...

  • Page 819

    4.2.5.3 setting parameters table 238: mvggio non group settings (basic) name values (range) unit step default description mv db 1 - 300 type 1 10 cycl: report interval (s), db: in % of range, int db: in %s mv zerodb 0 - 100000 m% 1 500 zero point clamping in 0.001% of range mv hhlim -10000000000.000...

  • Page 820

    Duo switch a switch b 1 2 redundancy supervision station control system data data data data iec09000758-2-en.Vsd ied configuration duodrv prpstatus 1 2 oem ab cd iec09000758 v2 en figure 314: redundant station bus section 4 1mrk504116-uus c station communication 814 application manual.

  • Page 821

    4.2.6.2 setting guidelines redundant communication (duodrv) is configured in the local hmi under main menu/settings/general settings/communication/ethernet configuration/rear oem - redundant prp the settings can then be viewed, but not set, in the parameter setting tool in pcm600 under main menu/ied...

  • Page 822

    Iec10000057-1-en.Vsd iec10000057 v1 en figure 315: pst screen: duodrv operation is set to on, which affect rear oem - port ab and cd which are both set to duo 4.2.6.3 setting parameters table 239: duodrv non group settings (basic) name values (range) unit step default description operation disabled ...

  • Page 823

    4.3 iec 61850-9-2le communication protocol 4.3.1 introduction every ied can be provided with a communication interface enabling it to connect to a process bus, in order to get data from analog data acquisition units close to the process (primary apparatus), commonly known as merging units (mu). The ...

  • Page 824

    Iec06000537 v1 en figure 316: example of a station configuration with separated process bus and station bus the ied can get analog values simultaneously from a classical ct or vt and from a merging unit, like in this example: the merging units (mu) are called so because they can gather analog values...

  • Page 825

    Ct ct abb merging unit ethernet switch ied combi sensor conventional vt iec61850-9-2le iec61850-9-2le splitter electrical-to- optical converter 1pps 1pps 110 v 1 a 1 a iec61850-8-1 station wide scada system station wide gps clock other relays iec61850-8-1 en08000069-3.Vsd iec08000069 v2 en figure 31...

  • Page 826

    4.3.2 setting guidelines there are several settings related to the merging units in local hmi under: main menu\settings\general settings\analog modules\merging unit x where x can take the value 1,2 or 3. 4.3.2.1 specific settings related to the iec 61850-9-2le communication the process bus communica...

  • Page 827

    4.3.2.2 consequence on accuracy for power measurement functions when using signals from iec 61850-9-2le communication the power measurement functions (cvmmxn, cmmxu, vmmxu and vnmmxu) contains correction factors to account for the non-linearity in the input circuits, mainly in the input transformers...

  • Page 828

    Function description iec 61850 identification function description iec 61850 identification current reversal and weakend infeed logic for residual overcurrent protection ecrwpsch fuse failure supervision sddrfuf four step residual overcurrent protection ef4ptoc sensitive directional residual over cu...

  • Page 829

    Function description iec 61850 identification function description iec 61850 identification zero sequence overcurrent protection lczsptoc directional impedance element for mho characteristic zdmrdir zero sequence overvoltage protection lczsptov directional impedance quadrilateral zdrdir ldlpdif dire...

  • Page 830

    4.3.2.4 setting examples for iec 61850-9-2le and time synchronization it is important that the ied and the merging units (mu) uses the same time reference. This is especially true if analog data is used from several sources, for example an internal trm and a mu. Or if several physical mu is used. Th...

  • Page 831

    • hwsyncsrc: set to pps since this is what is generated by the mu (abb mu) • appsynch : set to synch, since protection functions should be blocked in case of loss of timesynchronization • syncacclevel: could be set to 4us since this corresponds to a maximum phase- angle error of 0.072 degrees at 50h...

  • Page 832

    Ied mu data pps iec 61850-9-2le pps / irig-b station clock iec10000074-1-en.Vsd iec10000074 v1 en figure 320: setting example with external synchronization settings in local hmi under settings/time/synchronization/timesynchgen/ iec 61850-9-2: • hwsyncsrc : set to pps/irig-b depending on available ou...

  • Page 833

    Will block the protection functions after maximum 4 seconds after an interruption in the pps fiber communication from the mu. • synch signal on the mu_4i_4u function block indicate that protection functions are blocked by loss of internal time synchronization to the ied (that is loss of the hw-synch...

  • Page 834

    • syncmode: set to nosynch. This means that the ied do not care if the mu indicates loss of time synchronization. • tsyncerr signal will not be set since there is no configured time synchronization source • synch signal on the mu_4i_4u function block indicates when protection functions are blocked d...

  • Page 835

    4.4 lon communication protocol 4.4.1 application control center ied ied ied gateway star coupler rer 111 station hsi microscada iec05000663-1-en.Vsd iec05000663 v2 en figure 322: example of lon communication structure for a substation automation system an optical network can be used within the subst...

  • Page 836

    The lon protocol the lon protocol is specified in the lontalkprotocol specification version 3 from echelon corporation. This protocol is designed for communication in control networks and is a peer-to-peer protocol where all the devices connected to the network can communicate with each other direct...

  • Page 837

    Table 245: ade non group settings (basic) name values (range) unit step default description operation disabled enabled - - disabled operation timerclass slow normal fast - - slow timer class 4.5 spa communication protocol 4.5.1 application spa communication protocol as an alternative to iec 60870-5-...

  • Page 838

    En 05000672_ansi.Vsd local monitoring system with pcm600 ied ied ied converter, e.G . Spa- zc 22 optical to electrical or fiberdata modem telephone modem telephone modem remote monitoring system with pcm600 ansi05000672 v2 en figure 323: spa communication structure for a monitoring system. The monit...

  • Page 839

    The spa communication is mainly used for the station monitoring system. It can include different ieds with remote communication possibilities. Connection to a computer (pc) can be made directly (if the pc is located in the substation) or by telephone modem through a telephone network with itu (forme...

  • Page 840

    Station, although different baud rates in a loop are possible. If different baud rates in the same fibre optical loop or rs485 network are used, consider this when making the communication setup in the communication master, the pc. For local fibre optic communication, 19200 or 38400 baud is the norm...

  • Page 841

    4.6 iec 60870-5-103 communication protocol 4.6.1 application en 05000660_ansi.Vsd tcp/ip control center ied ied ied gateway star coupler rer 125 station hsi ansi05000660 v3 en figure 325: example of iec 60870-5-103 communication structure for a substation automation system iec 60870-5-103 communicat...

  • Page 842

    • event handling • report of analog service values (measurands) • fault location • command handling • autorecloser on/off • teleprotection on/off • protection on/off • led reset • characteristics 1 - 4 (setting groups) • file transfer (disturbance files) • time synchronization hardware when communic...

  • Page 843

    • ied status indication in monitor direction function block with defined ied functions in monitor direction, i103ied. This block use parameter as function type, and information number parameter is defined for each input signal. • function status indication in monitor direction, user-defined function...

  • Page 844

    Function block with defined functions for autorecloser indications in monitor direction, i103ar. This block includes the function type parameter, and the information number parameter is defined for each output signal. Measurands the measurands can be included as type 3.1, 3.2, 3.3, 3.4 and type 9 ac...

  • Page 845

    Slm configuration /rear optical spa-iec-dnp port /protocol selection to the selected protocol. When the communication protocols have been selected, the ied is automatically restarted. The general settings for iec 60870-5-103 communication are the following: • slaveaddress and baudrate: settings for ...

  • Page 846

    For each input of the disturbance recorder function there is a setting for the information number of the connected signal. The information number can be set to any value between 0 and 255. Furthermore, there is a setting on each input of the disturbance recorder function for the function type. Refer...

  • Page 847

    Table 249: i103iedcmd non group settings (basic) name values (range) unit step default description funtype 1 - 255 funt 1 255 function type (1-255) table 250: i103cmd non group settings (basic) name values (range) unit step default description funtype 1 - 255 funt 1 1 function type (1-255) table 251...

  • Page 848

    Name values (range) unit step default description infno_6 1 - 255 infno 1 6 information number for binary input 6 (1-255) infno_7 1 - 255 infno 1 7 information number for binary input 7 (1-255) infno_8 1 - 255 infno 1 8 information number for binary input 8 (1-255) table 254: i103superv non group se...

  • Page 849

    Name values (range) unit step default description ratedv_ab 0.05 - 2000.00 kv 0.05 400.00 rated voltage for phase-phase a-b ratedv_n 0.05 - 2000.00 kv 0.05 230.00 rated residual voltage vn ratedp 0.00 - 2000.00 mw 0.05 1200.00 rated value for active power ratedq 0.00 - 2000.00 mva 0.05 1200.00 rated...

  • Page 850

    4.7.1 application the ied can be provided with a function to send and receive signals to and from other ieds via the interbay bus. The send and receive function blocks has 16 outputs/inputs that can be used, together with the configuration logic circuits, for control purposes within the ied or via b...

  • Page 851

    Section 5 remote communication about this chapter this chapter describes the remote end data communication possibilities through binary signal transferring. 5.1 binary signal transfer function description iec 61850 identification iec 60617 identification ansi/ieee c37.2 device number binary signal t...

  • Page 852

    The protocol used is ieee/ansi c37.94. The distance with this solution is typical 110 km/68 miles. Ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm ld cm en06000519-2.Vsd iec06000519 v2 en figure 326: direct fibre optical connection between two ieds with ldcm...

  • Page 853

    5.1.2 setting guidelines channelmode: this parameter can be set enabled or disabled. Besides this, it can be set outofservice which signifies that the local ldcm is out of service. Thus, with this setting, the communication channel is active and a message is sent to the remote ied that the local ied...

  • Page 854

    Gpssyncerr: if gps synchronization is lost, the synchronization of the line differential function will continue during 16 s. Based on the stability in the local ied clocks. Thereafter the setting block will block the line differential function or the setting echo will make it continue by using the e...

  • Page 855

    Local communication module, ldcm. The parameter shall be set to 2 when transmitting analog data from the local transformer module, trm. When a merging unit according to iec 61850-9-2 is used instead of the trm this parameter shall be set to 5. Remainlatency: remote analog latency; this parameter cor...

  • Page 856

    Table 264: ldcmrecbinstat2 non group settings (basic) name values (range) unit step default description channelmode disabled enabled outofservice - - enabled channel mode of ldcm, 0=off, 1=on, 2=outofservice namech1 0 - 13 - 1 ldcm#-ch1 user defined string for analog input 1 terminalno 0 - 255 - 1 0...

  • Page 857

    Name values (range) unit step default description maxtdifflevel 200 - 2000 us 1 600 maximum time diff for echo back-up deadbandtdiff 200 - 1000 us 1 300 deadband for t diff invertpolx21 disabled enabled - - disabled invert polarization for x21 communication table 265: ldcmrecbinstat3 non group setti...

  • Page 858

    Name values (range) unit step default description remainlatency 2 - 20 - 1 2 analog latency of remote terminal maxtransmdelay 0 - 40 ms 1 20 max allowed transmission delay comprange 0-10ka 0-25ka 0-50ka 0-150ka - - 0-25ka compression range maxtdifflevel 200 - 2000 us 1 600 maximum time diff for echo...

  • Page 859

    Section 6 configuration about this chapter this chapter describes the ied configurations. 6.1 introduction there are six different software alternatives with which the ied can be ordered. The intention is that these configurations shall suit most applications with minor or no changes. The few change...

  • Page 860

    And only the key functions such as tripping are connected to the outputs. The required total io must be calculated and specified at ordering. Hardware modules are configured with the hardware configuration tool in the pcm600 engineering platform. The application configuration tool, which is part of ...

  • Page 861

    The differential protection is the main function. It provides fast and sensitive tripping for internal faults. Stabilization against through faults, inrush and overexcitation are standard features. Restricted earth fault protection of low impedance types are provided for each winding. The low impeda...

  • Page 862

    Trip bkr3 trip bkr1 50bf 87n 51p 51g 87n 87t 50bf 51g 51p/67p 94 49 bkr 3 bkr 1 ct1 ct3 ct6 ct7 wdg1 wdg2 vt’s from wdg 2 side of xfrm ret 670 51n 51n/67n 59p 27p 59n 60f ansi10000087-2-en.Vsd 24 94 ansi10000087 v2 en figure 328: protection functions configured in 2 wdg transformer with single break...

  • Page 863

    6.2.1.2 description of configuration b30 this configuration is used in applications with two winding transformers in multi- breaker arrangement on one or both sides. The tripping is three poles and includes also a synchronism check function for manual closing of the low voltage side breaker. The hig...

  • Page 864

    Trip bkr3 94/86 87n 50/51p 87n 27p 59p 50/51g 50/51p bkr1 60 49 50bf2 50bf1 50bf4 50bf3 vt’s from mv side of xfrm trip bkr1 94/86 trip bkr2 94/86 trip bkr4 94/86 trip from 50-bf1, 50-bf2 trip from 50-bf3, 50-bf4 50/51n 50/51n bkr2 bkr3 bkr4 ct1 ct2 ct3 ct4 ct6 ct7 wdg1 wdg2 59n 81u 81o 81r 24 87t 50...

  • Page 865

    Instantaneous, and time delayed overcurrent protection for phase and ground are provided for each winding. The following protection is also included: • undervoltage • overvoltage • overexcitation • 4 step over frequency • 4 step under frequency • breaker failure protection for each breaker • provisi...

  • Page 866

    87n 50/51p 27p 59p 50/51g 50/51p bkr1 60 49 50bf2 50bf1 50bf4 50bf3 vt’s from mv side of xfrm 94/86 trip from 50-bf1, 50-bf2 trip from 50-bf3, 50-bf4 50/51n 50/51n bkr2 bkr4 ct1 ct2 ct7 wdg1 wdg2 59n 50bf5 50/51p 94/86 trip bkr5 bkr3 ct3 ct4 wdg3 ct5 67p 24 94/86 trip bkr3 trip bkr4 94/86 trip bkr1 ...

  • Page 867

    Aim # term # p ret670-b30 ret670-a40 ret670-b40 4 7 i+ hv wdg – i n hv bkr 2 - i a hv bkr 2 - i a 8 - 5 9 i+ lv bkr 3 - i a hv bkr 2 - i b hv bkr 2 - i b 10 - 6 11 i+ lv bkr 3 - i b hv bkr 2 - i c hv bkr 2 - i c 12 - 7 13 i+ lv bkr 3 - i c hv wdg – i n lv bkr 5 - i a 14 - 8 15 i+ lv wdg – in not use...

  • Page 868

    Aim # term # p ret670-b30 ret670-a40 ret670-b40 5 9 i+ lv bkr 4 - i b not used mv bkr 4 - i b 10 - 6 11 i+ lv bkr 4 - i c not used mv bkr 4 - i c 12 - 7 13 i+ lv wdg - i n not used mv wdg - i n 14 - 8 15 i+ not used not used hv wdg - i n 16 - 9 17 i+ not used not used not used 18 - 10 19 v + not use...

  • Page 869

    Bim # term # p ret670-a30 ret670-b30 ret670-b40 5 9 + bkr3-52b bkr2-52b bkr2-52b 10 - 6 11 + bkr3 alarm bkr2 alarm bkr2 alarm 12 - 7 13 + 43a l_r bkr3-52a bkr3-52a 14 - 8 15 + bkr1 close cmd bkr3-52b bkr3-52b 16 - 1) if 52a contact is used, setting needs to be enabled under settings/setting group/n1...

  • Page 870

    Bim # term # p ret670-a30 ret670-b30 ret670-b40 14 11 + external dfr trig bkr1 close cmd bkr5-52b 12 - 15 13 + external trip block bkr1 open cmd bkr5 alarm 14 - 16 15 + not used bkr2 close cmd 43a l_r 16 - energized input will enable remote (scada) open or close command table 270: binary input modul...

  • Page 871

    Bim # term # p ret670-a30 ret670-b30 ret670-b40 7 13 + not used ltc sudden pressure trip bkr4 close cmd 14 - 8 15 + not used external dfr trig bkr4 open cmd 16 - table 271: binary input module, slot p5, connector x52 bim # term # p ret670-a30 ret670-b30 ret670-b40 9 1 + not used external trip block ...

  • Page 872

    Table 272: binary output module, slot p7, connector x71 bo m # term # p ret670-a30 ret670-b30 ret670-b40 1 1 trip bkr1 trip bkr1 trip bkr1 2 + 2 close bkr1 close bkr1 close bkr1 3 3 4 trip bkr3 trip bkr2 trip bkr2 5 + 4 close bkr3 close bkr2 close bkr2 6 5 7 lor trip trip bkr3 trip bkr3 8 + 6 not us...

  • Page 873

    Bo m # term # p ret670-a30 ret670-b30 ret670-b40 21 13 not used not used not used 14 + 22 not used not used not used 15 23 16 not used not used not used 17 + 24 not used not used not used 18 the following is the default led mapping: table 274: led mapping led # ret670-a30 ret670-b30 ret670-b40 1 ph ...

  • Page 874

    Function name ansi number description ioc2 50p wdg2 instantaneous overcurrent protection ioc3 50p wdg3 instantaneous overcurrent protection toc1 51p wdg1 time delayed overcurrent protection toc2 51p wdg2 time delayed overcurrent protection toc3 51p wdg3 time delayed overcurrent protection ief1 50n w...

  • Page 875

    Function name type description gt02 logic gate enable the gate if the transformer is not an autotransformer gt22 logic gate enable the gate if wdg1 circuit breaker position input is 52a gt24 logic gate enable the gate if wdg2 circuit breaker position input is 52a gt18 logic gate enable the gate if w...

  • Page 876

    870

  • Page 877

    Section 7 glossary about this chapter this chapter contains a glossary with terms, acronyms and abbreviations used in abb technical documentation. Ac alternating current act application configuration tool within pcm600 a/d converter analog-to-digital converter adbs amplitude deadband supervision adm...

  • Page 878

    Can controller area network. Iso standard (iso 11898) for serial communication cb circuit breaker cbm combined backplane module ccitt consultative committee for international telegraph and telephony. A united nations-sponsored standards body within the international telecommunications union. Ccm can...

  • Page 879

    Dfc data flow control dft discrete fourier transform dhcp dynamic host configuration protocol dip-switch small switch mounted on a printed circuit board di digital input dllb dead line live bus dnp distributed network protocol as per ieee std 1815-2012 dr disturbance recorder dram dynamic random acc...

  • Page 880

    Gis gas-insulated switchgear goose generic object-oriented substation event gps global positioning system gsal generic security application gtm gps time module hdlc protocol high-level data link control, protocol based on the hdlc standard hfbr connector type plastic fiber connector hmi human-machin...

  • Page 881

    One instance of a function is identical to another of the same kind but has a different number in the ied user interfaces. The word "instance" is sometimes defined as an item of information that is representative of a type. In the same way an instance of a function in the ied is representative of a ...

  • Page 882

    Mvb multifunction vehicle bus. Standardized serial bus originally developed for use in trains. Ncc national control centre num numerical module oco cycle open-close-open cycle ocp overcurrent protection oem optical ethernet module oltc on-load tap changer ov over-voltage overreach a term used to des...

  • Page 883

    Rs422 a balanced serial interface for the transmission of digital data in point-to-point connections rs485 serial link according to eia standard rs485 rtc real-time clock rtu remote terminal unit sa substation automation sbo select-before-operate sc switch or push button to close scs station control...

  • Page 884

    Tcp/ip transmission control protocol over internet protocol. The de facto standard ethernet protocols incorporated into 4.2bsd unix. Tcp/ip was developed by darpa for internet working and encompasses both network layer and transport layer protocols. While tcp and ip specify two protocols at specific...

  • Page 885

    3i o three times zero-sequence current. Often referred to as the residual or the -fault current 3v o three times the zero sequence voltage. Often referred to as the residual voltage or the neutral point voltage 1mrk504116-uus c section 7 glossary 879 application manual.

  • Page 886

    880

  • Page 887

    881.

  • Page 888

    Contact us abb inc. 1021 main campus drive raleigh, nc 27606, usa phone toll free: 1-800-help-365, menu option #8 abb inc. 3450 harvester road burlington, on l7n 3w5, canada phone toll free: 1-800-help-365, menu option #8 abb mexico s.A. De c.V. Paseo de las americas no. 31 lomas verdes 3a secc. 531...