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Introduction 10.1
Convention of direction 10.2
Conditions for direction comparison 10.3
Circulating current system 10.4
Balanced voltage system 10.5
Summation arrangements 10.6
Examples of electromechanicaland static unit protection systems 10.7
Digital/Numerical current differentialprotection systems 10.8
Carrier unit protection schemes 10.9
Current differential scheme– analogue techniques 10.10
Phase comparison protectionscheme considerations 10.11
Examples 10.12
References 10.13
• 1 0 • U n i t P r o t e c t i o n o f F e e d e r s
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e • 1 5 3 •
10.1 INTRODUCTION
The graded overcurrent systems described in Chapter 9,though attractively simple in principle, do not meet allthe protection requirements of a power system.Application difficulties are encountered for two reasons:firstly, satisfactory grading cannot always be arrangedfor a complex network, and secondly, the settings maylead to maximum tripping times at points in the systemthat are too long to prevent excessive disturbancesoccurring.
These problems led to the concept of 'Unit Protection',whereby sections of the power system are protectedindividually as a complete unit without reference toother sections. One form of ‘Unit Protection’ is alsoknown as ‘Differential Protection’, as the principle is tosense the difference in currents between the incomingand outgoing terminals of the unit being protected.Other forms can be based on directional comparison, ordistance teleprotection schemes, which are covered inChapter 12, or phase comparison protection, which isdiscussed later in this chapter. The configuration of thepower system may lend itself to unit protection; forinstance, a simple earth fault relay applied at the sourceend of a transformer-feeder can be regarded as unitprotection provided that the transformer windingassociated with the feeder is not earthed. In this casethe protection coverage is restricted to the feeder andtransformer winding because the transformer cannottransmit zero sequence current to an out-of-zone fault.
In most cases, however, a unit protection systeminvolves the measurement of fault currents (and possiblyvoltages) at each end of the zone, and the transmissionof information between the equipment at zoneboundaries. It should be noted that a stand-alonedistance relay, although nominally responding only tofaults within their setting zone, does not satisfy theconditions for a unit system because the zone is notclearly defined; it is defined only within the accuracylimits of the measurement. Also, to cater for someconditions, the setting of a stand-alone distance relaymay also extend outside of the protected zone to caterfor some conditions.
Merz and Price [10.1] first established the principle ofcurrent differential unit systems; their fundamentaldifferential systems have formed the basis of many
• 10 • Un it P rote ct ion of Fe e de rs
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
highly developed protection arrangements for feedersand numerous other items of plant. In one arrangement,an auxiliary ‘pilot’ circuit interconnects similar currenttransformers at each end of the protected zone, asshown in Figure 10.1. Current transmitted through thezone causes secondary current to circulate round thepilot circuit without producing any current in the relay.For a fault within the protected zone the CT secondarycurrents will not balance, compared with the through-fault condition, and the difference between the currentswill flow in the relay.
An alternative arrangement is shown in Figure 10.2, inwhich the CT secondary windings are opposed forthrough-fault conditions so that no current flows in theseries connected relays. The former system is known asa ‘Circulating Current’ system, while the latter is knownas a ‘Balanced Voltage’ system.
Most systems of unit protection function through thedetermination of the relative direction of the faultcurrent. This direction can only be expressed on acomparative basis, and such a comparative measurementis the common factor of many systems, includingdirectional comparison protection and distanceteleprotection schemes with directional impedancemeasurement.
A major factor in consideration of unit protection is themethod of communication between the relays. This iscovered in detail in Chapter 8 in respect of the latestfibre-optic based digital techniques. For older ‘pilot wire’systems, only brief mention is made. For more detaileddescriptions of ‘pilot wire’ techniques, see reference[10.2] in Section 10.13.
10.2 CONVENTION OF DIRECTION
It is useful to establish a convention of direction ofcurrent flow; for this purpose, the direction measuredfrom a busbar outwards along a feeder is taken aspositive. Hence the notation of current flow shown inFigure 10.3; the section GH carries a through currentwhich is counted positive at G but negative at H, whilethe infeeds to the faulted section HJ are both positive.
Neglect of this rule has often led to anomalousarrangements of equipment or difficulty in describingthe action of a complex system. When applied, the rulewill normally lead to the use of identical equipments atthe zone boundaries, and is equally suitable for extensionto multi-ended systems. It also conforms to the standardmethods of network analysis.
10.3 CONDIT IONSFOR DIRECTION COMPARISON
The circulating current and balanced voltage systems ofFigures 10.1 and 10.2 perform full vectorial comparisonof the zone boundary currents. Such systems can betreated as analogues of the protected zone of the powersystem, in which CT secondary quantities representprimary currents and the relay operating currentcorresponds to an in-zone fault current.
These systems are simple in concept; they arenevertheless applicable to zones having any number ofboundary connections and for any pattern of terminalcurrents.
To define a current requires that both magnitude andphase be stated. Comparison in terms of both of thesequantities is performed in the Merz-Price systems, but itis not always easy to transmit all this informationover some pilot channels. Chapter 8 provides a detaileddescription of modern methods that may be used.
10.4 CIRCULATING CURRENT SYSTEM
The principle of this system is shown in outline inFigure 10.1. If the current transformers are ideal, thefunctioning of the system is straightforward. The
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End HEnd G
RelayIdIdI >
Figure 10.1: Circulating current system
FaultHG J
Source+ _ + +
Source
Figure 10.3: Convention of current direction
Figure 10.2: Balanced voltage system
End G
Relay G Relay H
End H
IdI > IdI >
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transformers will, however, have errors arising from bothWattmetric and magnetising current losses that causedeviation from the ideal, and the interconnectionsbetween them may have unequal impedances. This cangive rise to a ‘spill’ current through the relay evenwithout a fault being present, thus limiting thesensitivity that can be obtained. Figure 10.4 illustratesthe equivalent circuit of the circulating current scheme.If a high impedance relay is used, then unless the relay islocated at point J in the circuit, a current will flowthrough the relay even with currents IPg and IPh beingidentical. If a low impedance relay is used, voltage FF ’will be very small, but the CT exciting currents will beunequal due to the unequal burdens and relay current IRwill still be non-zero.
10.4.1 Transient Instability
It is shown in Section 6.4.10 that an asymmetricalcurrent applied to a current transformer will induce aflux that is greater than the peak flux corresponding tothe steady state alternating component of the current. Itmay take the CT into saturation, with the result that thedynamic exciting impedance is reduced and the excitingcurrent greatly increased.
When the balancing current transformers of a unitprotection system differ in excitation characteristics, orhave unequal burdens, the transient flux build-ups willdiffer and an increased 'spill' current will result. There isa consequent risk of relay operation on a healthy circuitunder transient conditions, which is clearly
unacceptable. One solution is to include a stabilisingresistance in series with the relay. Details of how tocalculate the value of the stabilising resistor are usuallyincluded in the instruction manuals of all relays thatrequire one.
When a stabilising resistor is used, the relay currentsetting can be reduced to any practical value, the relaynow being a voltage-measuring device. There isobviously a lower limit, below which the relay elementdoes not have the sensitivity to pick up. Relaycalibration can in fact be in terms of voltage. For moredetails, see reference [10.2].
10.4.2 Bias
The 'spill' current in the relay arising from these varioussources of error is dependent on the magnitude of thethrough current, being negligible at low values ofthrough-fault current but sometimes reaching adisproportionately large value for more severe faults.Setting the operating threshold of the protection abovethe maximum level of spill current produces poorsensitivity. By making the differential settingapproximately proportional to the fault current, the low-level fault sensitivity is greatly improved. Figure 10.5illustrates a typical bias characteristic for a modern relaythat overcomes the problem. At low currents, the bias issmall, thus enabling the relay to be made sensitive. Athigher currents, such as would be obtained from inrush orthrough fault conditions, the bias used is higher, and thusthe spill current required to cause operation is higher. Therelay is therefore more tolerant of spill current at higherfault currents and therefore less likely to maloperate,while still being sensitive at lower current levels.
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I1
Idiff
Is1
Is2
I2I
I3I
Percentagebias k2
Percentagebias k1
Operate
I1Ibias+ I2 I3+
2=
= I1+I2+I3
Figure 10.5: Typical bias characteristic of relay
Figure 10.4: Equivalent circuitof circulating current scheme
RelayIdI
RSh RSh
IPhIIPgI
iehieg
R
RR
ZehZeg
ShiSg
RLgR RLhR
(a)
H
G''
G
G '
F '
FJ
H '
H''H''H
Electro-motive forces with low impedance relayGG' 'GG'' ''
(b)
End G End H
Subscripts:scripts
S - CT Secondary
LG
hh - end H
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
10.5 BALANCED VOLTAGE SYSTEM
This section is included for historical reasons, mainlybecause of the number of such schemes still to be foundin service – for new installations it has been almostcompletely superseded by circulating current schemes. Itis the dual of the circulating current protection, and issummarised in Figure 10.2 as used in the ‘Translay H04’scheme.
With primary through current, the secondary e.m.f.’s ofthe current transformers are opposed, and provide nocurrent in the interconnecting pilot leads or the seriesconnected relays. An in-zone fault leads to a circulatingcurrent condition in the CT secondaries and hence torelay operation.
An immediate consequence of the arrangement is thatthe current transformers are in effect open-circuited, asno secondary current flows for any primary through-current conditions. To avoid excessive saturation of thecore and secondary waveform distortion, the core isprovided with non-magnetic gaps sufficient to absorbthe whole primary m.m.f. at the maximum current level,the flux density remaining within the linear range. Thesecondary winding therefore develops an e.m.f. and canbe regarded as a voltage source. The shunt reactance ofthe transformer is relatively low, so the device acts as atransformer loaded with a reactive shunt; hence theAmerican name of transactor. The equivalent circuit ofthe system is as shown in Figure 10.6.
The series connected relays are of relatively highimpedance; because of this the CT secondary windingresistances are not of great significance and the pilotresistance can be moderately large without significantlyaffecting the operation of the system. This is why thescheme was developed for feeder protection.
10.5.1 Stability Limit of the Voltage Balance System
Unlike normal current transformers, transactors are notsubject to errors caused by the progressive build-up of
exciting current, because the whole of the primarycurrent is expended as exciting current. In consequence,the secondary e.m.f. is an accurate measure of theprimary current within the linear range of thetransformer. Provided the transformers are designed tobe linear up to the maximum value of fault current,balance is limited only by the inherent limit of accuracyof the transformers, and as a result of capacitancebetween the pilot cores. A broken line in the equivalentcircuit shown in Figure 10.6 indicates such capacitance.Under through-fault conditions the pilots are energisedto a proportionate voltage, the charging current flowingthrough the relays. The stability ratio that can beachieved with this system is only moderate and a biastechnique is used to overcome the problem.
10.6 SUMMATION ARRANGEMENTS
Schemes have so far been discussed as though they wereapplied to single-phase systems. A polyphase systemcould be provided with independent protection for eachphase. Modern digital or numerical relayscommunicating via fibre-optic links operate on thisbasis, since the amount of data to be communicated isnot a major constraint. For older relays, use of thistechnique over pilot wires may be possible for relativelyshort distances, such as would be found with industrialand urban power distribution systems. Clearly, eachphase would require a separate set of pilot wires if theprotection was applied on a per phase basis. The cost ofproviding separate pilot-pairs and also separate relayelements per phase is generally prohibitive. Summationtechniques can be used to combine the separate phasecurrents into a single relaying quantity for comparisonover a single pair of pilot wires. For details of suchtechniques, see reference [10.2].
10.7 EXAMPLES OF ELECTROMECHANICAL AND STATIC UNIT PROTECTION SYSTEMS
As mentioned above, the basic balanced voltage principleof protection evolved to biased protection systems.Several of these have been designed, some of whichappear to be quite different from others. Thesedissimilarities are, however, superficial. A number ofthese systems that are still in common use are describedbelow.
10.7.1 ‘Translay’ Balanced VoltageElectromechanical System
A typical biased, electromechanical balanced voltagesystem, trade name ‘Translay’, still giving useful serviceon distribution systems is shown in Figure 10.7.
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Figure 10.6: Equivalent circuitfor balanced voltage system
Zeg
RSg RLgR RLhR RSh
Zeh
IdI >IdI >
Relay G
PilotParameters
End G
Relay H
End H
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The electromechanical design derives its balancing voltagesfrom the transactor incorporated in the measuring relay ateach line end. The latter are based on the induction-typemeter electromagnet as shown in Figure 10.7.
The upper magnet carries a summation winding toreceive the output of the current transformers, and asecondary winding which delivers the reference e.m.f.The secondary windings of the conjugate relays areinterconnected as a balanced voltage system over thepilot channel, the lower electromagnets of both relaysbeing included in this circuit.
Through current in the power circuit produces a state ofbalance in the pilot circuit and zero current in the lowerelectromagnet coils. In this condition, no operatingtorque is produced.
An in-zone fault causing an inflow of current from eachend of the line produces circulating current in the pilotcircuit and the energisation of the lower electromagnets.These co-operate with the flux of the upperelectromagnets to produce an operating torque in thediscs of both relays. An infeed from one end only willresult in relay operation at the feeding end, but nooperation at the other, because of the absence of uppermagnet flux.
Bias is produced by a copper shading loop fitted to thepole of the upper magnet, thereby establishing a Ferrarismotor action that gives a reverse or restraining torqueproportional to the square of the upper magnet flux value.
Typical settings achievable with such a relay are:Least sensitive earth fault - 40% of ratingLeast sensitive phase-phase fault - 90% of ratingThree-phase fault - 52% of rating
10.7.2 Static Circulating CurrentUnit Protection System – ‘Translay ‘S’ ’
A typical static modular pilot wire unit protection systemoperating on the circulating current principle is shown inFigure 10.8. This uses summation transformers with aneutral section that is tapped, to provide alternativeearth fault sensitivities. Phase comparators tuned to thepower frequency are used for measurement and arestraint circuit gives a high level of stability for throughfaults and transient charging currents. High-speedoperation is obtained with moderately sized currenttransformers and where space for current transformers islimited and where the lowest possible operating time isnot essential, smaller current transformers may be used.This is made possible by a special adjustment (Kt) bywhich the operating time of the differential protectioncan be selectively increased if necessary, therebyenabling the use of current transformers having acorrespondingly decreased knee-point voltage, whilstensuring that through-fault stability is maintained togreater than 50 times the rated current.
Internal faults give simultaneous tripping of relays atboth ends of the line, providing rapid fault clearanceirrespective of whether the fault current is fed from bothline ends or from only one line end.
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Figure 10.8: Typical static circulating current feeder unit protection circuit diagram
A
C
BT1 - Summation transformer
T2 - Auxiliary transformer
RVO - Non linear resistor
Trip Trip
V
T2T T2T
T1T1
Pr Pr
TrTrT
TOTOTO
TrTrT RsRs
RoRo RVORVOV
Pilot wires
To - Operating winding
Tr - Restraining winding
Ro - Linear resistor
Pr - Pilots padding resistor
c - Phase comparator
cc
End G End H
Summationwinding
Pilot
ABC
Secondarywinding
Bias loop
ry
Figure 10.7: Typical biasedelectromechanical differential protection system.
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
10.8 DIGITAL/NUMERICAL CURRENT DIFFERENTIAL PROTECTION SYSTEMS
A digital or numerical unit protection relay may typicallyprovide phase-segregated current differential protection.This means that the comparison of the currents at eachrelay is done on a per phase basis. For digital datacommunication between relays, it is usual that a directoptical connection is used (for short distances) or amultiplexed link. Link speeds of up to 64kbit/s (56kbit/sin N. America) are normal. Through current bias istypically applied to provide through fault stability in theevent of CT saturation. A dual slope bias technique(Figure 10.5) is used to enhance stability for throughfaults. A typical trip criterion is as follows:
For |Ibias| < Is2
|Idiff | < k1 |Ibias| + Is1
For |Ibias| < Is2
|Idiff | < k2 |Ibias| - (k2 - k1) Is2 + Is1
Once the relay at one end of the protected section hasdetermined that a trip condition exists, an intertripsignal is transmitted to the relay at the other end. Relaysthat are supplied with information on line currents at allends of the line may not need to implement intertrippingfacilities. However, it is usual to provide intertripping inany case to ensure the protection operates in the eventof any of the relays detecting a fault.
A facility for vector/ratio compensation of the measuredcurrents, so that transformer feeders can be included inthe unit protection scheme without the use ofinterposing CT’s or defining the transformer as a separatezone increases versatility. Any interposing CT’s requiredare implemented in software. Maloperation ontransformer inrush is prevented by second harmonicdetection. Care must be taken if the transformer has awide-ratio on-load tap changer, as this results in thecurrent ratio departing from nominal and may causemaloperation, depending on the sensitivity of the relays.The initial bias slope should be set taking this intoconsideration.
Tuned measurement of power frequency currentsprovides a high level of stability with capacitance inrushcurrents during line energisation. The normal steady-state capacitive charging current can be allowed for if avoltage signal can be made available and thesusceptance of the protected zone is known.
Where an earthed transformer winding or earthingtransformer is included within the zone of protection,some form of zero sequence current filtering is required.This is because there will be an in-zone source of zerosequence current for an external earth fault. Thedifferential protection will see zero sequence differentialcurrent for an external fault and it could incorrectly
operate as a result. In older protection schemes, theproblem was eliminated by delta connection of the CTsecondary windings. For a digital or numerical relay, aselectable software zero sequence filter is typicallyemployed.
The problem remains of compensating for the timedifference between the current measurements made atthe ends of the feeder, since small differences can upsetthe stability of the scheme, even when using fast directfibre-optic links. The problem is overcome by either timesynchronisation of the measurements taken by therelays, or calculation of the propagation delay of the linkcontinuously.
10.8.1 Time Synchronisation of Relays
Fibre-optic media allow direct transmission of thesignals between relays for distances of up to several kmwithout the need for repeaters. For longer distancesrepeaters will be required. Where a dedicated fibre pairis not available, multiplexing techniques can be used. Asphase comparison techniques are used on a per phasebasis, time synchronisation of the measurements isvitally important. This requires knowledge of thetransmission delay between the relays. Four techniquesare possible for this:
a. assume a valueb. measurement during commissioning onlyc. continuous online measurementd. GPS time signal
Method (a) is not used, as the error between the assumedand actual value will be too great.
Method (b) provides reliable data if directcommunication between relays is used. As signalpropagation delays may change over a period of years,repeat measurements may be required at intervals andrelays re-programmed accordingly. There is some risk ofmaloperation due to changes in signal propagation timecausing incorrect time synchronisation betweenmeasurement intervals. The technique is less suitable ifrented fibre-optic pilots are used, since the owner mayperform circuit re-routing for operational reasonswithout warning, resulting in the propagation delaybeing outside of limits and leading to schememaloperation. Where re-routing is limited to a fewroutes, it may be possible to measure the delay on allroutes and pre-program the relays accordingly, with therelay digital inputs and ladder logic being used to detectchanges in route and select the appropriate delayaccordingly.
Method (c), continuous sensing of the signal propagationdelay, is a robust technique. One method of achievingthis is shown in Figure 10.9.
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Relays A and B sample signals at time TA1,TA2 …andTB1,TB2 …respectively. The times will not be coincident,even if they start coincidentally, due to slight differencesin sampling frequencies. At time TA1 relay A transmitsits data to relay B, containing a time tag and other data.Relay B receives it at time TA1+Tp1 where Tp1 is thepropagation time from relay A to relay B. Relay Brecords this time as time TB*. Relay B also sendsmessages of identical format to relay A. It transmits sucha message at time TB3, received by relay A at timeTB3+Tp2 (say time TA*), where Tp2 is the propagationtime from relay B to relay A. The message from relay Bto relay A includes the time TB3, the last received timetag from relay A (TA1) and the delay time between thearrival time of the message from A (TB*) and TB3 – callthis the delay time Td. The total elapsed time istherefore:
(TA* - TA1) = (Td + Tp1 + Tp2)
If it is assumed that Tp1 = Tp2, then the value of Tp1 andTp2 can be calculated, and hence also TB3. The relay Bmeasured data as received at relay A can then beadjusted to enable data comparison to be performed.Relay B performs similar computations in respect of thedata received from relay A (which also contains similartime information). Therefore, continuous measurementof the propagation delay is made, thus reducing thepossibility of maloperation due to this cause to aminimum. Comparison is carried out on a per-phase basis,so signal transmission and the calculations are requiredfor each phase. A variation of this technique is availablethat can cope with unequal propagation delays in the two
communication channels under well-defined conditions.
The technique can also be used with all types of pilots,subject to provision of appropriate interfacing devices.
Method (d) is also a robust technique. It involves bothrelays being capable of receiving a time signal froma GPS satellite. The propagation delay on eachcommunication channel is no longer required to beknown or calculated as both relays are synchronised to acommon time signal. For the protection scheme to meetthe required performance in respect of availability andmaloperation, the GPS signal must be capable of reliablereceipt under all atmospheric conditions. There is extrasatellite signal receiving equipment required at bothends of the line, which implies extra cost.
The minimum setting that can be achieved with suchtechniques while ensuring good stability is 20% of CTprimary current.
10.8.2 Application to Mesh Cornerand 1 1/2 Breaker Switched Substations
These substation arrangements are quite common, andthe arrangement for the latter is shown in Figure 10.10.Problems exist in protecting the feeders due to thelocation of the line CT’s, as either Bus 1 or Bus 2 or bothcan supply the feeder. Two alternatives are used toovercome the problem, and they are illustrated in theFigure. The first is to common the line CT inputs (asshown for Feeder A) and the alternative is to use a secondset of CT inputs to the relay (as shown for Feeder B).
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End A
Digital communications linkA B
End B
Current vectors
Current vectors
Measured sampling time Propagation delay timeTB3*=(TA*-Tp2) Tp1=Tp2=1/2(TA*-TA1-Td)
TB*
TA*
TA1'TA2'
TB1'TB2'
Tp1
Tp2
Td
TA1*
TB*
TB3*
TB3*
TB2
TB3
TB3Td
Td
TB4
TB5
TB1
TA2
TA3
TA4
TA5
TA1
TA1
TA1
Tp1
Tp2
- sampling instants of relay A- sampling instants of relay B- propagation delay time
from relay A to B- propagation delay time
from relay B to A- time between the arrival of message TA1 at relay B and despatch of message TB3
- arrival time of message TB3
and relay A- arrival time of message TA1
and relay B- the measured sampling time of TB3 by relay A
Figure 10.9: Signal propagation delay measurement
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
In the case of a through fault as shown, the relayconnected to Feeder A theoretically sees no unbalancecurrent, and hence will be stable. However, with the linedisconnect switch open, no bias is produced in the relay,so CT’s need to be well matched and equally loaded ifmaloperation is to be avoided.
For Feeder B, the relay also theoretically sees nodifferential current, but it will see a large bias current evenwith the line disconnect switch open. This provides a highdegree of stability, in the event of transient asymmetric CTsaturation. Therefore, this technique is preferred.
Sensing of the state of the line isolator through auxiliarycontacts enables the current values transmitted to andreceived from remote relays to be set to zero when theisolator is open. Hence, stub-bus protection for theenergised part of the bus is then possible, with any faultresulting in tripping of the relevant CB.
10.9 CARRIER UNIT PROTECTION SCHEMES
In earlier sections, the pilot links between relays havebeen treated as an auxiliary wire circuit thatinterconnects relays at the boundaries of the protectedzone. In many circumstances, such as the protection oflonger line sections or where the route involvesinstallation difficulties, it is too expensive to provide anauxiliary cable circuit for this purpose, and other meansare sought.
In all cases (apart from private pilots and some shortrented pilots) power system frequencies cannot betransmitted directly on the communication medium.Instead a relaying quantity may be used to vary thehigher frequency associated with each medium (or thelight intensity for fibre-optic systems), and this processis normally referred to as modulation of a carrier wave.Demodulation or detection of the variation at a remotereceiver permits the relaying quantity to be reconstitutedfor use in conjunction with the relaying quantitiesderived locally, and forms the basis for all carrier systemsof unit protection.
Carrier systems are generally insensitive to induced
power system currents since the systems are designed tooperate at much higher frequencies, but each mediummay be subjected to noise at the carrier frequencies thatmay interfere with its correct operation. Variations ofsignal level, restrictions of the bandwidth available forrelaying and other characteristics unique to eachmedium influence the choice of the most appropriatetype of scheme. Methods and media for communicationare discussed in Chapter 8.
10.10 CURRENT DIFFERENTIAL SCHEME – ANALOGUE TECHNIQUES
The carrier channel is used in this type of scheme toconvey both the phase and magnitude of the current atone relaying point to another for comparison with thephase and magnitude of the current at that point.Transmission techniques may use either voice frequencychannels using FM modulation or A/D converters anddigital transmission. Signal propagation delays still needto be taken into consideration by introducing adeliberate delay in the locally derived signal before acomparison with the remote signal is made.
A further problem that may occur concerns the dynamicrange of the scheme. As the fault current may be up to30 times the rated current, a scheme with linearcharacteristics requires a wide dynamic range, whichimplies a wide signal transmission bandwidth. Inpractice, bandwidth is limited, so either a non-linearmodulation characteristic must be used or detection offault currents close to the setpoint will be difficult.
10.10.1 Phase Comparison Scheme
The carrier channel is used to convey the phase angle of thecurrent at one relaying point to another for comparisonwith the phase angle of the current at that point.
The principles of phase comparison are illustrated inFigure 10.11. The carrier channel transfers a logic or'on/off' signal that switches at the zero crossing pointsof the power frequency waveform. Comparison of a locallogic signal with the corresponding signal from theremote end provides the basis for the measurement ofphase shift between power system currents at the twoends and hence discrimination between internal andthrough faults.
Current flowing above the set threshold results in turn-off of the carrier signal. The protection operates if gapsin the carrier signal are greater than a set duration – thephase angle setting of the protection.
Load or through fault currents at the two ends of aprotected feeder are in antiphase (using the normal relayconvention for direction), whilst during an internal faultthe (conventional) currents tend towards the in-phase
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Figure 10.10: Breaker anda half switched substation
Bus 1
A B
Stubbusinputs
F
Bus 2B1IF
Id>Id>
B2
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condition. Hence, if the phase relationship of throughfault currents is taken as a reference condition, internalfaults cause a phase shift of approximately 180° withrespect to the reference condition.
Phase comparison schemes respond to any phase shiftfrom the reference conditions, but tripping is usuallypermitted only when the phase shift exceeds an angle oftypically 30 to 90 degrees, determined by the time delaysetting of the measurement circuit, and this angle isusually referred to as the Stability Angle. Figure 10.12 isa polar diagram that illustrates the discriminationcharacteristics that result from the measurementtechniques used in phase comparison schemes.
Since the carrier channel is required to transfer only
binary information, the techniques associated withsending teleprotection commands. Blocking orpermissive trip modes of operation are possible, howeverFigure 10.11 illustrates the more usual blocking mode,since the comparator provides an output when neithersquarer is at logic '1'. A permissive trip scheme can berealised if the comparator is arranged to give an outputwhen both squarers are at logic '1'. Performance of thescheme during failure or disturbance of the carrierchannel and its ability to clear single-end-fed faultsdepends on the mode of operation, the type and functionof fault detectors or starting units, and the use of anyadditional signals or codes for channel monitoring andtransfer tripping.
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Receiver
GF
E
SquarerSummation
network
ATransmitter
D'
B
H
DC
Load or through fault Internal faultIG IHIG IH HG
01
01
01
01
01
01
01
01
E=B+D'
Stability setting
D. Squarer output at end H(Received at end G viaideal carrier system as D'
C. Summation voltage at end H
E. Comparator output at end G
F. Discriminator output at end G
B. Squarer output at end G
A. Summation voltage at end G
End HEnd G
Phase comparator
Pulse lengthdiscrimination
Figure 10.11: Principles of phase comparison protection.
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
Signal transmission is usually performed by voicefrequency channels using frequency shift keying (FSK) orPLC techniques.
Voice frequency channels involving FSK use two discretefrequencies either side of the middle of the voice band.This arrangement is less sensitive to variations in delay orfrequency response than if the full bandwidth was used.Blocking or permissive trip modes of operation may beimplemented. In addition to the two frequencies usedfor conveying the squarer information, a third tone isoften used, either for channel monitoring or transfertripping dependent on the scheme.
For a sensitive phase comparison scheme, accuratecompensation for channel delay is required. However,since both the local and remote signals are logic pulses,simple time delay circuits can be used, in contrast to theanalogue delay circuitry usually required for currentdifferential schemes.
The principles of the Power Line Carrier channeltechnique are illustrated in Figure 10.13. The schemeoperates in the blocking mode. The 'squarer' logic is useddirectly to turn a transmitter 'on' or 'off' at one end, andthe resultant burst (or block) of carrier is coupled to andpropagates along the power line which is being protectedto a receiver at the other end. Carrier signals above athreshold are detected by the receiver, and hence producea logic signal corresponding to the block of carrier. Incontrast to Figure 10.11, the signalling system is a 2-wirerather than 4-wire arrangement, in which the localtransmission is fed directly to the local receiver alongwith any received signal. The transmitter frequencies at
both ends are nominally equal, so the receiver respondsequally to blocks of carrier from either end. Through-fault current results in transmission of blocks of carrierfrom both ends, each lasting for half a cycle, but with aphase displacement of half a cycle, so that the compositesignal is continuously above the threshold level and thedetector output logic is continuously '1'. Any phase shiftrelative to the through fault condition produces a gap inthe composite carrier signal and hence a corresponding'0' logic level from the detector. The duration of the logic'0' provides the basis for discrimination between internaland external faults, tripping being permitted only when atime delay setting is exceeded. This delay is usuallyexpressed in terms of the corresponding phase shift indegrees at system frequency ϕs in Figure 10.12.
The advantages generally associated with the use of thepower line as the communication medium apply namely,that a power line provides a robust, reliable, and low-lossinterconnection between the relaying points. In additiondedicated 'on/off' signalling is particularly suited for usein phase comparison blocking mode schemes, as signalattenuation is not a problem. This is in contrast topermissive or direct tripping schemes, where high poweroutput or boosting is required to overcome the extraattenuation due to the fault.
The noise immunity is also very good, making the schemevery reliable. Signal propagation delay is easily allowedfor in the stability angle setting, making the scheme verysensitive as well.
10.11 PHASE COMPARISION PROTECTION SCHEME CONSIDERATIONS
One type of unit protection that uses carrier techniquesfor communication between relays is phase comparisonprotection. Communication between relays commonlyuses PLCC or frequency modulated carrier modemtechniques. There are a number of considerations thatapply only to phase comparison protection systems,which are discussed in this section.
10.11.1 Lines with Shunt Capacitance
A problem can occur with the shunt capacitance currentthat flows from an energising source. Since this current isin addition to the load current that flows out of the line,and typically leads it by more than 90°, significantdifferential phase shifts between the currents at the endsof the line can occur, particularly when load current is low.
The system differential phase shift may encroach into thetripping region of the simple discriminator characteristic,regardless of how large the stability angle setting maybe. Figure 10.14 illustrates the effect and indicatestechniques that are commonly used to ensure stability.
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Discriminator stability angle setting.
θ System differential phase shift referred to through fault referenceconditionOR Through faultreference condition H
IG=-IHIG IH
G
RStabilityθ=0°
θ=270°
θ=180°-Tripping
θ=90°
(IG' IH conventional relay currents at ends of protected feeder)
O
Figure 10.12: Polar diagram for phasecomparison scheme
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Operation of the discriminator can be permitted onlywhen current is above some threshold, so thatmeasurement of the large differential phase shifts whichoccur near the origin of the polar diagram is avoided. Bychoice of a suitable threshold and stability angle, a'keyhole' characteristic can be provided such that thecapacitive current characteristic falls within theresultant stability region. Fast resetting of the faultdetector is required to ensure stability following theclearance of a through fault when the currents tend tofall towards the origin of the polar diagram.
The mark-space ratio of the squarer (or modulating)waveform can be made dependent on the currentamplitude. Any decrease in the mark-space ratio willpermit a corresponding differential phase shift to occurbetween the currents before any output is given from thecomparator for measurement in the discriminator. Asquarer circuit with an offset or bias can provide a
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D. Discriminator output
C. Carrier detector output
B. Composite carrier signal at end G
1
1
0
0
10
0
1
Receiver
Transmitter
Trip
A. Squarer output at end G
Pulse lengthdiscriminator
Squarer
D
A
C
End G
Summationnetwork
B
Couplingfilter
Line trap
Line trap trap
Stability setting
End H
Identicalrelay
to end G
Blocks of carrier transmitted from end G
Squarer output at end H
Blocks of carrier transmitted from end H
Load or through fault Internal fault
0
1
0
1
0
1
1
0
Trip
Figure 10.13: Principles of power line carrier phase comparison
Figure 10.14: Capacitive current in phase comparisonschemes and techniques used to avoid instability
Limits of differential phase shift due to capacitive current ICEncroachment into tripping region for discriminatorwith stability angle setting ϕs
Through FaultReference
A
Squarer ThresholdStarter Threshold
`Keyhole' characteristicMinimum starter threshold =
Characteristic of system with amplitude dependentcompensation ϕs = angular compensation for current of magnitude OA
O
sin ϕs
capacitive current
θc
where ϕs = tan-1 ICIL
OA2sin-1 for squarer threshold IC
IC
IL = load current
ICϕsIL
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decreasing mark-space ratio at low currents, and with asuitable threshold level the extra phase shift θc which ispermitted can be arranged to equal or exceed the phaseshift due to capacitive current. At high current levels thecapacitive current compensation falls towards zero andthe resultant stability region on the polar diagram isusually smaller than on the keyhole characteristic, givingimprovements in sensitivity and/or dependability of thescheme. Since the stability region encompasses allthrough-fault currents, the resetting speed of any faultdetectors or starter (which may still be required for otherpurposes, such as the control of a normally quiescentscheme) is much less critical than with the keyholecharacteristic.
10.11.2 System Tripping Angles
For the protection scheme to trip correctly on internalfaults the change in differential phase shift, θ0, from thethrough-fault condition taken as reference, must exceedthe effective stability angle of the scheme. Hence:
θ0 = ϕs + θc …Equation 10.1
where
ϕs = stability angle setting
θc = capacitive current compensation
(when applicable)
The currents at the ends of a transmission line IG and IHmay be expressed in terms of magnitude and phaseshift θ with respect a common system voltage.
IG = |IG| ∠ θG
IH = |IH| ∠ θH
Using the relay convention described in Section 10.2, thereference through-fault condition is
IG = -IH
∴ IG ∠ θG = -IH ∠ θH = IH ∠ θH ± 180°
∴ |θG - θH| =180°
During internal faults, the system tripping angle θ0 is thedifferential phase shift relative to the referencecondition.
∴ θ0 =180° - |θG - θH|
Substituting θ0 in Equation 10.1, the conditions fortripping are:
180 - |θG - θH| ≥ ϕS + θc
∴ |θG - θH| ≤ 180 - (ϕS + θc) …Equation 10.2
The term (ϕs + θc) is the effective stability angle settingof the scheme. Substituting a typical value of 60° inEquation 10.2. gives the tripping condition as
|θG - θH| ≤ 120° …Equation 10.3
In the absence of pre-fault load current, the voltages atthe two ends of a line are in phase. Internal faults arefed from both ends with fault contributions whosemagnitudes and angles are determined by the position ofthe fault and the system source impedances. Althoughthe magnitudes may be markedly different, the angles(line plus source) are similar and seldom differ by morethan about 20°.
Hence |θG - θH| ≤ 20° and the requirements of Equation10.3 are very easily satisfied. The addition of arc or faultresistance makes no difference to the reasoning above, sothe scheme is inherently capable of clearing such faults.
10.11.3 Effect of Load Current
When a line is heavily loaded prior to a fault the e.m.f.'sof the sources which cause the fault current to flow maybe displaced by up to about 50°, that is, the power systemstability limit. To this the differential line and sourceangles of up to 20° mentioned above need to be added.
So |θG - θH| ≤ 70° and the requirements of Equation 10.3are still easily satisfied.
For three phase faults, or solid earth faults on phase-by-phase comparison schemes, through load current falls tozero during the fault and so need not be considered. Forall other faults, load current continues to flow in thehealthy phases and may therefore tend to increase|θG - θH| towards the through fault reference value. Forlow resistance faults the fault current usually far exceedsthe load current and so has little effect. High resistancefaults or the presence of a weak source at one end canprove more difficult, but high performance is stillpossible if the modulating quantity is chosen with careand/or fault detectors are added.
10.11.4 Modulating Quantity
Phase-by-phase comparison schemes usually use phasecurrent for modulation of the carrier. Load and faultcurrents are almost in antiphase at an end with a weaksource. Correct performance is possible only when faultcurrent exceeds load current, or
for IF < IL’ |θG - θH| ≈ 180°for IF > IL’ |θG - θH| ≈ 180° …Equation 10.4
where IF = fault current contribution from weak sourceIL = load current flowing towards weak source
To avoid any risk of failure to operate, fault detectorswith a setting greater than the maximum load currentmay be applied, but they may limit the sensitivity ofscheme. When the fault detector is not operated at oneend, fault clearance invariably involves sequentialtripping of the circuit breakers.
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Most phase comparison schemes use summationtechniques to produce a single modulating quantity,responsive to faults on any of the three phases. Phasesequence components are often used and a typicalmodulating quantity is:
IM = MI2 + NI1 …Equation 10.5
where
I1 = Positive phase sequence componentI2 = Negative phase sequence componentM,N = constants
With the exception of three phase faults all internalfaults give rise to negative phase sequence (NPS)currents, I2, which are approximately in phase at theends of the line and therefore could form an idealmodulating quantity. In order to provide a modulatingsignal during three phase faults, which give rise topositive phase sequence (PPS) currents, I1, only, apractical modulating quantity must include someresponse to I1 in addition to I2.
Typical values of the ratio M: N exceed 5:1, so that themodulating quantity is weighted heavily in favour ofNPS, and any PPS associated with load current tends tobe swamped out on all but the highest resistance faults.
For a high resistance phase-earth fault, the systemremains well balanced so that load current IL is entirelypositive sequence. The fault contribution IF providesequal parts of positive, negative and zero sequencecomponents IF /3. Assuming the fault is on 'A' phase andthe load is resistive, all sequence components are inphase at the infeed end G:
At the outfeed end load current is negative,
Now, forImH > 0,θH = 0, and |θG - θH| = 0°
and forImH < 0,θH = 180°, and |θG - θH| = 180°
Hence for correct operation ImH ≥ 0Let ImH = 0
Then
…Equation 10.6
I IMN
IFHL
E=+
=3
1
∴ =− + + I NI MI NImH L
FH FH
3 3
∴ = + +
≈
and
I NI MI NImG L
FG FG
G
3 3
0θ
The fault current in Equation 10.6 is the effective earthfault sensitivity IE of the scheme. For the typical values of
M = 6 and N = -1
Comparing this with Equation 10.4, a scheme usingsummation is potentially 1.667 times more sensitivethan one using phase current for modulation.
Even though the use of a negative value of M gives alower value of IE than if it were positive, it is usuallypreferred since the limiting condition of Im = 0 thenapplies at the load infeed end. Load and faultcomponents are additive at the outfeed end so that acorrect modulating quantity occurs there, even with thelowest fault levels. For operation of the scheme it issufficient therefore that the fault current contributionfrom the load infeed end exceeds the effective setting.
For faults on B or C phases, the NPS components aredisplaced by 120° or 240° with respect to the PPScomponents. No simple cancellation can occur, butinstead a phase displacement is introduced. For trippingto occur, Equation 10.2 must be satisfied, and to achievehigh dependability under these marginal conditions, asmall effective stability angle is essential. Figure 10.15illustrates operation near to the limits of earth faultsensitivity.
Very sensitive schemes may be implemented by usinghigh values of M_N but the scheme then becomes moresensitive to differential errors in NPS currents such asthe unbalanced components of capacitive current or spillfrom partially saturated CT's.
Techniques such as capacitive current compensation andreduction of M_N at high fault levels may be required toensure stability of the scheme.
10.11.5 Fault Detection and Starting
For a scheme using a carrier system that continuouslytransmits the modulating quantity, protecting an idealline (capacitive current=0) in an interconnectedtransmission system, measurement of current magnitudemight be unnecessary. In practice, fault detector orstarting elements are invariably provided and the schemethen becomes a permissive tripping scheme in whichboth the fault detector and the discriminator mustoperate to provide a trip output, and the fault detectormay limit the sensitivity of the scheme. Requirementsfor the fault detectors vary according to the type ofcarrier channel used, mode of operation used in the
∴ =− I IE L35
MN
=−6
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phase angle measurement, that is, blocking orpermissive, and the features used to provide tolerance tocapacitive current.
10.11.6 Normally Quiescent Power Line Carrier (Blocking Mode)
To ensure stability of through faults, it is essential thatcarrier transmission starts before any measurement ofthe width of the gap is permitted. To allow forequipment tolerances and the difference in magnitude ofthe two currents due to capacitive current, two startingelements are used, usually referred to as 'Low Set' and'High Set' respectively. Low Set controls the start-up oftransmission whilst High Set, having a setting typically1.5 to 2 times that of the Low Set element, permits thephase angle measurement to proceed.
The use of impulse starters that respond to the change incurrent level enables sensitivities of less than ratedcurrent to be achieved. Resetting of the starters occursnaturally after a swell time or at the clearance of thefault. Dwell times and resetting characteristics must
ensure that during through faults, a High Set is neveroperated when a Low Set has reset and potential raceconditions are often avoided by the transmitting of anunmodulated (and therefore blocking) carrier for a shorttime following the reset of low set; this feature is oftenreferred to as 'Marginal Guard.'
10.11.7 Scheme without CapacitiveCurrent Compensation
The 'keyhole' discrimination characteristic of depends onthe inclusion of a fault detector to ensure that nomeasurements of phase angle can occur at low currentlevels, when the capacitive current might cause largephase shifts. Resetting must be very fast to ensurestability following the shedding of through load.
10.11.8 Scheme with CapacitiveCurrent Compensation (Blocking Mode)
When the magnitude of the modulating quantity is lessthan the threshold of the squarer, transmission if itoccurred, would be a continuous blocking signal. Thismight occur at an end with a weak source, remote froma fault close to a strong source. A fault detector isrequired to permit transmission only when the currentexceeds the modulator threshold by some multiple(typically about 2 times) so that the effective stabilityangle is not excessive. For PLCC schemes, the low setelement referred to in Section 10.11.6 is usually used forthis purpose. If the fault current is insufficient tooperate the fault detector, circuit breaker tripping willnormally occur sequentially.
10.11.9 Fault Detector Operating Quantities
Most faults cause an increase in the corresponding phasecurrent(s) so measurement of current increase could formthe basis for fault detection. However, when a line isheavily loaded and has a low fault level at the outfeedend, some faults can be accompanied by a fall in current,which would lead to failure of such fault detection,resulting in sequential tripping (for blocking modeschemes) or no tripping (for permissive schemes).Although fault detectors can be designed to respond toany disturbance (increase or decrease of current), it ismore usual to use phase sequence components. Allunbalanced faults produce a rise in the NPS componentsfrom the zero level associated with balanced load current,whilst balanced faults produce an increase in the PPScomponents from the load level (except at ends with verylow fault level) so that the use of NPS and PPS faultdetectors make the scheme sensitive to all faults. Forschemes using summation of NPS and PPS componentsfor the modulating quantity, the use of NPS and PPS fault
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Assumptions for examples:Infeed of load IL at end GOutfeed of load IL at end G
System voltage reference
(a) A phase to earth fault IF = 0.9IE
(c) B phase to earth fault IF = IE (d) C phase to earth fault IF = IE
(b) A phase to earth fault IF = 1.1 IE
NM =-6 therefore Im = 6I2 - I2 and from Equation 10.6
NILH
NILG NILG
NILGNILG
NILH NILH
ImH
θH=0
ImG
ImG
θG=180°θG=0
|θG- θH |=180°
|θG- θH |=70°
|θG- θH |=0°
θGθGθH
θH
NILH
3NIE0.9
3NIE0.9
3MIE0.9
3NIE1.1
3NIE1.1
3NIE
3NIE
3NIE
3NIE
3MIE
3MIE
3MIE
3MIE
ImHImH
ImGImG
3MIE
0.93
MIE1.1
3MIE1.1
effective earth fault sensitivity IE =- 35
ILalso IF1 =
IF3
120° 120°
Figure 10.15: Effect of load current on differentialphase shift |θg - θH| for resistive earth faultsat the effective earth fault sensitivity IE
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e • 1 6 7 •
detectors is particularly appropriate since, in addition toany reductions in hardware, the scheme may becharacterized entirely in terms of sequence components.Fault sensitivities IF for PPS and NPS impulse startersettings I1S and I2S respectively are as follows:
Three phase fault IF = I1SPhase-phase fault IF = √3I2SPhase-earth fault IF = 3I2S
10.12 EXAMPLES
This section gives examples of setting calculations forsimple unit protection schemes. It cannot and is notintended to replace a proper setting calculation for aparticular application. It is intended to illustrate theprinciples of the calculations required. The examples usethe AREVA MiCOM P541 Current Differential relay, whichhas the setting ranges given in Table 10.1 for differentialprotection. The relay also has backup distance, high-setinstantaneous, and earth-fault protection included in thebasic model to provide a complete ‘one-box’ solution ofmain and backup protection.
10.12.1 Unit Protection of a Plain Feeder
The circuit to be protected is shown in Figure 10.16. Itconsists of a plain feeder circuit formed of an overheadline 25km long. The relevant properties of the line are:Line voltage: 33kV
Z = 0.157 + j0.337Ω/km
Shunt charging current = 0.065A/km
To arrive at the correct settings, the characteristics of therelays to be applied must be considered.
The recommended settings for three of the adjustablevalues (taken from the relay manual) are:
Is2 = 2.0pu
k1 = 30%k2 = 150%
To provide immunity from the effects of line chargingcurrent, the setting of IS1 must be at least 2.5 times thesteady-state charging current, i.e. 4.1A or 0.01p.u., aftertaking into consideration the CT ratio of 400/1. The nearestavailable setting above this is 0.20p.u. This gives the pointson the relay characteristic as shown in Figure 10.17.The minimum operating current Idmin is related to thevalue of Is1 by the formula
Idmin = (k1IL + Is1)/(1-0.5k1)
for Ibias <Is2and
Idmin = (k2IL -(k2-k1)Is2 + Is1)/(1-0.5k2)for Ibias >Is2
where IL = load currentand hence the minimum operating current at no load is0.235p.u. or 94A.
In cases where the capacitive charging current is verylarge and hence the minimum tripping current needs tobe set to an unacceptably high value, some relays offerthe facility of subtracting the charging current from themeasured value. Use of this facility depends on having asuitable VT input and knowledge of the shuntcapacitance of the circuit.
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Figure 10.16: Typical plain feeder circuit
33kV
Digital communications link
33kV400/1400/1
25km
Steady state charging current = 0.065A/km
Id> Id>
Parameter Setting Range
Differential Current Setting, Is1 0.2 -2.0 InBias Current Threshold Setting, Is2 1-30 InLower Percentage Bias Setting, k1 0.3-1.5
Higher Precentage Bias Setting, k2 0.3-1.5
In - CT rated secondary current
Table 10.1: Relay Setting Ranges
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e
10.12.2 Unit Protection of a Transformer Feeder
Figure 10.18 shows unit protection applied to atransformer feeder. The feeder is assumed to be a 100mlength of cable, such as might be found in someindustrial plants or where a short distance separates the33kV and 11kV substations. While 11kV cablecapacitance will exist, it can be regarded as negligible forthe purposes of this example.
The delta/star transformer connection requires phaseshift correction of CT secondary currents across thetransformer, and in this case software equivalents ofinterposing CT’s are used.
Since the LV side quantities lag the HV side quantities by30°, it is necessary to correct this phase shift by usingsoftware CT settings that produce a 30° phase shift.There are two obvious possibilities:
a. HV side: Yd1LV side: Yy0
b. HV side: Yy0LV side: Yd11
Only the second combination is satisfactory, since onlythis one provides the necessary zero-sequence currenttrap to avoid maloperation of the protection scheme forearth faults on the LV side of the transformer outside ofthe protected zone.
Ratio correction must also be applied, in order to ensurethat the relays see currents from the primary andsecondary sides of the transformer feeder that are wellbalanced under full load conditions. This is not alwaysinherently the case, due to selection of the main CTratios. For the example of Figure 10.18,
Transformer turns ratio at nominal tap
Required turns ratio according to the CT ratios used
= = 400
11250
10 32.
= =1133
0 3333 .
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I diff
I diff
I
IbiasII
00
1
2
3
4
5
6
7
8
1 2 3 4 5 6
Figure 10.17: Relay characteristic;plain feeder example
Figure 10.18: Unit protection of a transformer feeder
20 MVA33/11kV
Dyn133kV 11kV
IdI > IdI >
Digital communicationchannel
1250/1400/1
350A 1050A
0.875A 0.84A
Ratio correction: 1.14software CT: Yy0
Ratio correction: 1.19software CT: Yd11
0° -30°
Cable100m
N e t w o r k P r o t e c t i o n & A u t o m a t i o n G u i d e • 1 6 9 •
Spill current that will arise due to the incompatibility ofthe CT ratios used with the power transformer turns ratiomay cause relay maloperation. This has to be eliminatedby using the facility in the relay for CT ratio correctionfactors. For this particular relay, the correction factorsare chosen such that the full load current seen by therelay software is equal to 1A.
The appropriate correction factors are:
HV: 400/350 = 1.14
LV: 1250/1050 = 1.19
where:
transformer rated primary current = 350A
transformer rated secondary current = 1050A
With the line charging current being negligible, thefollowing relay settings are then suitable, and allow fortransformer efficiency and mismatch due to tap-changing:
IS1 = 20% (minimum possible)
IS1 = 20%
k1 = 30%
k2 = 150%
10.13 REFERENCES
10.1 Merz-Price Protective Gear. K. Faye-Hansen andG. Harlow. IEE Proceedings, 1911.
10.2 Protective Relays Application Guide – 3rdEdition. AREVA Transmission and DistributionProtection and Control, 1987.
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