Performance Analysis of the Distance Relay Characteristics in a Compensated Transmission Line

Performance Analysis of the Distance Relay Characteristics in a Compensated Transmission
Line
Mohammad M. Al-Momani1*
, Asmaa S.M. Hatmi2
, Seba F. Al-Gharaibeh1
1
The Department of Electrical Engineering, College of Engineering, Mutah University, Karak 61621, Jordan
2
Electrical Power Engineering Department, Hijjawi Faculty for Engineering, Yarmouk University, Irbid 21163, Jordan
Corresponding Author Email: monqedmohammad@gmail.com
https://doi.org/10.18280/ejee.230304 ABSTRACT
Received: 2 November 2020
Accepted: 18 April 2021
The present work investigates the effect of the FACTS devices on distance relay operation.
FACTS devices have different advantages in power system performance, stability, and
load ability. In this paper, FACTS technologies' effect on the distance protective relay is
presented using the measured impedance between the fault location and the relaying point.
Different factors and parameters are changed to see their impacts on the studied system. It
is shown that the measured impedance is affected by the presence of the FACTS devices
depending on its type (series, parallel, and hybrid), fault location, and the operation point
of the FACTS device. The analyses present that the shunt FACTS devices' effect may
cause overreach problem to the relay; however, series FACTS devices may cause under
reach problems in distance characteristics. MATLAB 2019b does the simulation test; the
results of the simulation proved the mathematical analysis. The numerical analysis in this
paper may be used for researchers in fault analysis and protection coordinators.
Keywords:
distance protection, FACTS devices,
MATLAB, measured impedance
1. INTRODUCTION
Fixable AC transmission system (FACTS) devices are
widely used in high voltage transmission systems. The benefits
of using FACTS, such as load flow, economic benefits and
stability enhancement, make it very powerful and desirable in
the system. FACTS devices as a power flow controller based
on power electronics technologies divide into two main
categories; thyristor-based technology such as thyristor-
controlled series capacitor (TCSC), static var compensator
(SVC), thyristor-controlled voltage regulator (TCVR), and
thyristor-controlled phase angle regulator (TCPAR); and
voltage source converter-based technologies such as static
synchronous series compensator (SSSC), static VAR system
(SVS), static synchronous compensator (STATCOM), unified
power flow controller (UPFC). Each device should be
connected in series or parallel with the transmission line to
inject voltage or current to the system. So, the protective relay
will see the device as impedance during the fault. Series
compensating dives, where the capacitors are connected in
series with the transmission line, are used mainly to increase
transfer capability. In contrast, the shunt devices are installed
to improve the voltage profile and reduce line losses.
Different researchers analyze the performance of the
distance relay in compensated transmission lines. In Ref. [1],
detailed discussions on the distance relay principle and
compare the performance of distance relay with and without
FACTS devices are presented. The simulation of SSSC,
STATCOM, and UPFC effect on measured impedance is
shown. As a result, the measured resistance for both UPFC and
STATCOM starts from a high value. However, a single-phase
to ground fault is mentioned without detailed analysis based
on the sequence component. Other researchers [2] present the
effect of STATCOM on the performance of the distance relay.
A real-time digital simulator-based hardware in the loop is
established in this research. Other studies [3-7] show the effect
of STATCOM on distance relay under different system
configurations, fault locations, and fault conditions. The
impacts of SSSC on measured impedance at the relay point for
various fault locations are discussed in Refs. [8-10]. New
techniques are presented in the literature to protect the
transmission line may be affected in the compensated lines [11,
12]. The performance of digital relay in UPFC compensated
transmission line is presented in literatures [13-15]. In these
researches the effect of UPFC on measured impedance, which
results in tripping boundaries of distance relay, is shown.
This paper provides a comprehensive analysis of the
measured impedance on compensated transmission lines for
different fault types, fault locations, system operations, and
various FACTS devices. The rest of this paper is presented as
follows: section (II) shows a summary of the FACTS devices
types and their process. Different types of FACTS devices are
presented. In section (III), the mathematical analysis of
measured impedance at different fault types and different
FACTS devices is presented. The characteristic of the distance
relay and proposed pilot scheme to compensated transmission
lines are presented in section (IV). The simulation results of
the proposed model built on MATLAB 2019b /SIMULINK is
shown in the Vth section, and the conclusion is shown in
section (VI).
2. FACTS DEVICES MODEL
There are mainly three types of FACTS devices from the
view of its connection; series, parallel, and hybrid device.
SSSC, SVC, and UPFC are examples of series, parallel and
hybrid type FACTS devices, respectively. These devices are
European Journal of Electrical Engineering
Vol. 23, No. 3, June, 2021, pp. 197-205
Journal homepage: http://iieta.org/journals/ejee
197

installed at the transmission line in order to enhance voltage
profile, economic dispatch, maximize load ability, minimize
total error etc. Moreover, the power flow of any transmission
line is given by:
𝑆 = 𝑉
𝑠 (
𝑉
𝑠 − 𝑉
𝑟
𝑍𝑙
)
∗
(1)
where, 𝑉
𝑠 , 𝑉
𝑟 : sending and receiving end complex voltages
respectively, 𝑍𝑙 : line impedance. * indicates the conjugate
operator. From this equation, the real and reactive power can
be written as:
𝑃 =
𝑣𝑠𝑣𝑟
𝑋𝑙
sin 𝛿 (1a)
𝑄 =
𝑣𝑠(𝑣𝑠 − 𝑣𝑟 cos 𝛿)
𝑋𝑙
(1b)
where, 𝑣𝑠, 𝑣𝑟: voltage magnitude of sending and receiving end
of the transmission lines. 𝛿: power angle the difference angle
between the voltages at the terms of the line. Based on these
equations, FACTS devices can be categorized as follows [16]:
• Voltage regulators: change the magnitude of the
voltage at the sending end to control both real and
reactive power flow. e.g., STATCOM, SVC, TCVR,
SVS-based voltage regulator. These controllers should
have a shunt part to inject current (so reactive power)
to the system.
• Line impedance compensators: induce a controlled
capacitance or inductance in series with the line
inductance. e.g., TCSC, SSSC. These devices should
have a series part to inject voltage out of phase to the
line current by ±
90°
.
• Phase angle regulation (Phase shift): these FACTS
devices change the voltage's angle, but the magnitude
does not change.
• Unified power flow controller (UPFC): this particular
configuration may change all line parameters to
independently control both real and reactive power.
This configuration has series and shunts VSC
connected via a DC link (capacitor).
3. MATHEMATICAL ANALYSIS
3.1 Three phase faults
For the analysis purposes, the system in Figure 1 is used.
The test system consists of two strong sources (source A and
source B) connected via a transmission line and two stations.
In the case of UPFC disconnected, simply the balance
impedance seen by relay R is given by Eq. (2) and Eq. (2a).
ZR = m ZL (2)
𝑍 =
𝑉
𝑎
𝐼𝑎
𝑜𝑟
𝑉𝑏
𝐼𝑏
𝑜𝑟
𝑉
𝑐
𝐼𝑐
(2a)
where, ZR : impedance seen by the relay R from its Current
transformer (CT) position to the fault location without the
FACTS device (actual value). m: a factor of the line which
represent the location of the fault to the relay. From Figure 1,
the index m could be written as:
𝑚 =
𝑍𝐿𝐴
𝑍𝐿𝐴 + 𝑍𝐿𝐵
(2b)
where, 𝑍𝐿𝐴 : impedance between the relay position and the
fault location. The series ( 𝑍𝑆𝐸 ) and shunt ( 𝑍𝑠ℎ) FACTS
impedances refer to the line impedance can represent as
following relations:
R FACTS
Source A Source B
ZsB
ZLB
ZLA
RF
F
ZsA
Station A Station B
Figure 1. Two machines test system with FACTS located at
station A
𝑘𝑠 =
𝑍𝑆𝐸
𝑍𝐿
(3a)
𝑘ℎ =
𝑍𝑆ℎ
𝑍𝐿
(3b)
The measured impedance by the relay ( 𝑍𝑅′ ) for the
compensated transmission line is affected by 𝐾𝑠 and 𝐾ℎ. The
relation between measured impedance in the present of
FACTS device and without FACTS device in term of 𝐾𝑠 and
𝐾ℎ can be found as follows:
𝐸𝐹 =
𝑍𝑅
′
𝑍𝑅
=
(𝑚 + 𝐾𝑠)(
𝐾ℎ
𝑚
)
𝑚 + 𝐾𝑆 + 𝐾ℎ
(4)
EF is called Error Factor. Eq. (4) presents the impact of
𝐾𝑠 and 𝐾ℎ on measured impedance by distance relay when a
fault occurred behind the FACTS device. If the fault occurs
between the FACTS device and relay, the relay will work
correctly.
3.1.1 Series FACTS device
The series FACTS device may consider as a particular
operation point of UPFC when 𝐾ℎ → ∞. The error factor of
the series FACTS device (𝐸𝐹𝑠) is given as folow:
𝐸𝐹𝑠 = (1 +
𝑘𝑠
𝑚
) (5)
|𝐸𝐹𝑠| = √1 +
|𝑘𝑠|2
𝑚2
+
2|𝑘𝑠|
𝑚
cos 𝜃𝑠
(5a)
θEF.s
= tan−1
[
|𝑘𝑠| sin 𝜃𝑠
𝑚 + |𝑘𝑠| 𝑐𝑜𝑠𝜃𝑠
] (5b)
where, 𝜃𝑠: the angle of the series factor (𝑘𝑠). θEF.s
: the angle
of the error factor (EF). From this relation, the effect of series
FACTS devices on distance relay can be determined. Three
parameters play significant impacts on this relation; 𝐾𝑠 , 𝜃𝑠 ,
and m.
198

Figure 2. The impact of the factor Ks on the magnitude of
the measured impedance
Figure 3. The impact of the factor Ks on the angle of the
measured impedance
The first zone of the distance relay is the most critical issue
because the FACTS device protection will isolate the device
before the set time of the second zone is gone. So, m = 0.75,
which refers to the first zone fault, will be considered here.
Figures 2 and 3 show the impact of series FACTS parameters
on the measured impedance's magnitude and angle,
respectively.
To avoid the effect of the series FACTS device on the
distance operation, the controller should send the operation
point (𝐾𝑠) to the relay then the relay should make the proper
correction to find the actual impedance. Some of the series of
FACTS devices inject reactance to the line without resistance.
In this case, the angle between line impedance (~70°
) and the
injected reactance is in the range of (~20°
) in case of an
inductive operation case and about (-160°
) in case of a
capacitive operation case.
The effect of this type of FACTS device (which inject
inductance in series) can be ignored if the magnitude of 𝐾𝑠
greater than one by adding about 15° to the measured
impedance. Otherwise, the relay should know the device's
operation point to make a proper correction on the measured
impedance.
From Figure 2, it can be noted that EF's value is higher than
one in most cases. That means the series of FACTS devices
make a problem of underreach in most operation cases, but this
note depends on the operation case of the device. From Figure
2, it can say that the measured impedance is less than actual
when 𝐾𝑠 < 1.5 and 𝜃𝑠 around 180°or -180°
, capacitance case;
otherwise, the measured impedance is higher than the actual.
Based on these notes, we can generalize the following
comments. If the FACTS device consumes reactive power
(inductance case), the relay may see the fault impedance
higher than the actual (under reach). If the FACTS device
operation is leading (capacitive case) the relay may see the
fault impedance lower than the real (overreach). From this
observation, if the relay knows the FACTS device's setting
point, it will be able to see when the device will operate
lagging or leading based on measured power at the relay point.
For the MHO characteristic or impedance-direction
characteristic relay, the small deviation in measured angle may
not impact the relay operation. Based on this comment, the
magnitude of impedance may be corrected with ignored the
variation in the angle based on measured power and predefined
setting point of the FACTS device. Some suitable operation
cases can be mentioned here; as an example, the effect of the
series part of UPFC can neglect if Kse = 0.5 and θs around
100°or 260°
, as shown in Figure 2. These operation points
may be found from Eq. (5a) as follow:
𝑚 =
𝑍𝐿𝐴
𝑍𝐿𝐴 + 𝑍𝐿𝐵
(5c)
At the summary of this section, some recommended notes
for operators or protection coordinators can be summarized as
follow:
⚫ If |𝐾𝑠| controlled and θs select to be constant, the
magnitude of EF will be very sensitive to Ks, and the
angle of 𝜃𝐸𝐹 is almost lag θs by (0-30°
) if Ks less than
0.5 (Figure 3). This note regards line impedance
compensators and some particular operations of the
UPFC.
⚫ If θs controlled and Ks select to be constant, the
magnitude of EF will be very sensitive to θs, the angle
of 𝜃𝐸𝐹 is almost lag θs by around 15°
. This note
regards phase angle regulators and particular
operation points of the UPFC.
3.1.2 Shunt FACTS device
From Eq. (4), if we ignore the series part of the FACTS
device (𝐾𝑠 = 0) the error factor of the shunt FACTS device
can be written as:
𝐸𝐹ℎ =
𝐾ℎ
𝑚 + 𝐾ℎ
(6)
|𝐸𝐹ℎ| = √
|𝑘ℎ
2|
𝑚2 + 2𝑚|𝑘ℎ| cos 𝜃ℎ + |𝑘ℎ|2
(6a)
θEF.h
= θh − tan−1
[
|𝑘ℎ| sin 𝜃ℎ
𝑚 + |𝑘ℎ|𝑐𝑜𝑠𝜃ℎ
] (6b)
where, 𝜃ℎ: the angle of the shunt factor. Eq. (6a) shows the
effect of |𝐾ℎ|, 𝜃ℎ, and m on the magnitude of 𝐸𝐹ℎ. Figures 4-
5 show the shunt FACTS device's effect on the magnitude and
the angle of the measured impedance at m=0.75, respectively.
Figure 4 shows that the measured impedance is lower than the
actual for both lag and lead operation points. Increasing the
value of the magnitude of the shunt factor decreases the effect
on the measured impedance.
199

Figure 4. The effect of the factor Kh on the magnitude of the
measured impedance
Figure 5. The effect of the factor Kh on the angle of the
measured impedance
The effect of the Shunt device on the angle of the measured
impedance is shown in Figure 5. From the figure, it can be
observed that the impact of the shunt device on the measured
impedance's angle may be neglected if the 𝜃ℎ around zero or
Kh greater than 5. On the other hand, the effect of the shunt
FACTS devices on the magnitude of the measured impedance
can be neglected if Kh > 5 (Figure 4).
For the UPFC, shunt and series parts are operated
independently, from the controller viewpoint; therefore, the
shunt part can make a control on the reactive power flow (so
voltage magnitude), and the series part can make a control on
the real power flow. Thus, the voltage magnitude, the voltage
angle, and the line's impedance can be changed independently
by the UPFC. Two of them are enough to regulate the real and
the reactive power flow in the line based on Eq. (1a) and Eq.
(1b). So, if the UPFC is used only to hold the power flow (real
and imaginary), it will have one free parameter. Based on this
additional freedom in the control axis, it is possible to operate
the UPFC in a lower impact on the distance relay. If the factor
EF=1∠0, the relay will not be affected by the existence of the
UPFC. So, from Eq. (4), this condition can achieve when:
|𝑘ℎ| =
𝑚
𝑘𝑠
∗ √𝑚2 + 2𝑚 |𝐾𝑠| cos(𝜃𝑆) + |𝐾𝑠|2
(7a)
θh = tan−1
[
ks sin θs
m + ks cos θs
] − θs (7b)
From Eq. (7a) and Eq. (7b), either the value of the shunt
factor's magnitude or angle can be controlled based on the
series factor. From the solution of the set of equations
viewpoint, the UPFC problem has four parameters
(𝐾ℎ, 𝐾𝑠, 𝜃𝑠, 𝜃ℎ): two of them are used to control the power flow
(real and imaginary); third one is necessary to achieve the law
of power conservation in the DC coupling. So, if the voltage
regulation is not needed, then there is one free parameter and
can be made by one of the Eq. (7a) and (7b). The selection of
the adjusted settings by Eq. (7) should depend on the operation
point to decrease the device's impact on the relay. For two
separate voltage source converters, without DC coupling, both
equations can be applied.
For adaptive distance relay, a correct solution may be
implemented inside the relay. Based on Eq. (4), the actual
impedance based on measured parameters must be calculated
before used in distance relay to overcome any relay's mis
operation. The actual impedance can be calculated as follow:
𝑍𝑅 =
𝑍𝑅
′
1 − 𝛼𝑍𝑅
′ − 𝛽 (8)
where, α, β, and γ correction factors are depending on the type
of FACTS device as follow:
Series FACTS: 𝛼 = 0 𝑎𝑛𝑑 𝛽 = 𝑍𝑠𝑒
Shunt FACTS: 𝛼 =
1
𝑍𝑠ℎ
𝑎𝑛𝑑 𝛽 = 0
UPFC: 𝛼 =
1
𝑍𝑠ℎ
𝑎𝑛𝑑 𝛽 = 𝑍𝑠𝑒
where, 𝑍𝑅 : actual impedance and𝑍𝑅
′
: measured impedance.
This equation may be used to correct the operation zones
adaptively based on communication between the relay and the
FACTS device.
3.2 Single phase-to-ground fault
In the case of a single-phase to ground fault (R-G), the
measured impedance without the FACTS device is written in
Eq. (9) [17].
𝑍𝑅 = 𝑍1𝐿𝐴 +
3𝑅𝐹
2𝐶1 + 𝐶0(1 + 3𝐾0)
(9)
where:
𝐶0 =
𝑍0𝐵
𝑍0𝐵+𝑍0𝐴
, 𝐶1 =
𝑍1𝐵
𝑍1𝐵+𝑍1𝐴
, 𝐾𝑜 =
𝑍𝑜𝐿−𝑍1𝐿
3 𝑍1𝐿
The apparent impedance with FACTS is given by Eq. (10),
and the derivative of this formula is attached in the appendix:
𝑍𝐴
′
≈
3𝑅𝐹
2𝐶1
′
+ 𝐶0
′(1 + 3𝐾0)
+ (𝑍1𝐿𝐴
+ 𝑍1𝑆𝐸)
𝑍1𝑠ℎ + 𝑍1𝑆𝐴
𝑍1𝑠ℎ
(10)
The relation between measured impedance with FACTS (𝑍𝑅
′
)
and the measured impedance without FATCS (𝑍𝑅 ) can be
written as follow:
𝑍𝑅
≈
𝑍𝑅
′
𝑍1𝑠ℎ
𝑍1𝑠ℎ + 𝑍1𝑠𝐴
− 𝑍1𝑆𝐸
+ 3𝑅𝑓
2𝐶1
′
+ 𝐶0
′(1 + 3𝐾0
′) − 2𝐶1 + 𝐶0(1 + 3𝐾0)
(2𝐶1 + 𝐶0(1 + 3𝐾0))(2𝐶1
′
+ 𝐶0
′(1 + 3𝐾0
′))
(11)
200

𝑍𝑅 should be calculated before it is used in distance
characteristics. Different algorithms are used in literature to
estimate the value of the fault resistance (Rf) such a technique
in Ref. [18]. Another research [19] presents typical values of
the fault resistance in the power system. The analyses in the
previous section are repeated to the single-phase and double-
phase fault with different fault resistance values. The same
general comments are observed. The actual impedance for
shunt ( 𝑍𝑅ℎ ) and series ( 𝑍𝑅𝑠 ) FACTS devices based on
measured impedances are written in Eq. (12) and Eq. (13),
respectively, Rf supposed to be zero.
𝑍𝑅 ≈
𝑍𝑅
′
𝑍1𝑠ℎ
𝑍1𝑠ℎ + 𝑍1𝑠𝐴
(12)
𝑍𝑅 ≈ 𝑍𝑅
′
− 𝑍𝑆𝐸 (13)
4. DISTANCE CHARACTERISTICS BEHAVIOR
In this section, FACT's effect on the distance relay
characteristic (MHO) is discussed depending on the measured
impedance. The meaning of over/under reach and mal-
operation is also explained. Figures 6(a) and 6(b) show the
impact of MHO distance relay by FACTS.
(a) Underreach case
(b) Negative deviation of the θf
Figure 6. MHO-characteristic, actual (red) and measured
(green) impedances
Figure 6(a) shows under reach case where the measured
impedance higher than an actual impedance EF>1. The typical
setting for distance relay is 80% for zone 1 and 120% for the
second zone. EF gives the ratio of measured impedance to the
actual. If (EF < 1.5), the worst case of a fault at the first zone's
reach will move to the second zone. Otherwise, the fault may
move to Z3 or may not be covered if (EF>2.25).
In another case, if EF<1, fault in zone 2 may move to zone
1, the worst case here when (F>0.67). If F is lower than 0.67,
a fault in zone 3 may transfer to the first region, or the relay
may trigger a fault out of its zones (F<0.44). In this case, the
overreach problem may cause improper line cascaded tripping.
Figure 6(b) shows the effect of θh on relay behaviour. In
MHO characteristics, a small deviation on the angle may not
impact the relay decision. For this purpose, the MHO
characteristic is better than others like the lenticular
characteristic for the compensated transmission lines. Another
important note is that the acceptable negative deviation range
is higher than the positive coverage in the MHO characteristic.
Where the negative deviation in 𝜃𝑓 move the operation point
clockwise, and positive deviation move it counter clockwise.
The FACTS device's effect at one side of the protected line
will impact the operation of the local distance relay (the relay
at the FACTS side). The FACTS device will not impact on the
remote distance relay (relay at the end). Two proposed
solutions are suggested here:
⚫ Pilot scheme between two end relays is proposed to protect
the first zone as follow:
o Directional comparison blocking scheme (DCB): If the
remote relay discovers a fault in its reverse direction, it
should send a block signal to the first zone in the local
relay, and vice versa.
o Permissive under/over reach scheme (PUTT/ POTT): This
scheme is recommended in the series FACTS device is
used. For the short lines, POTT is better than PUTT at the
two ends of the line. For the medium transmission lines,
if the local relay sends (POTT) and the remote relay send
(PUTT), the scheme may provide the optimal
coordination to solve the problems of the FACTS devices'
presents. For long lines, PUTT is used at the two ends of
the line.
⚫ Create adaptive zones characteristic based on measured
each of FACTS device impedances and transmission line
impedance. Eqns. (8), (13), and (14) can be used to correct the
measured impedance before the distance relay operated.
The first solution can be applied easily using five-zone
distance relay [20].
5. SIMULATION RESULTS
The system under study consists of a two-bus system of 400
kV similar to the system in Figure 1. In this simulation, the
UPFC is installed as seen in Figure 7. This section is presented
to make a general view of shunt and series FACTS devices'
impact on the relay. System parameters, operation points, and
FACTS setting points are attached in the appendix.
In this section, two operation cases with two setting points
(in the appendix) to the UPFC are considered to plot the error
factor of three-phase fault, double-phase (phase B, and C) fault,
and single-phase (phase 1) fault. The fault is occurred at t=0.4
sec and removed at t=0.45 sec.
5.1 Increase load ability, inductive mode
In this section, the UPFC is used to increase the
transmission line real power from 1 Pu to 1.5 Pu and consume
201

0.5 Pu reactive power. Figure 8 shows the error factor's
magnitude and angle for three fault cases at m=0.75 for
operation point (1) and set point (1).
Figure 8(a) shows the error factor (magnitude and angle) in
a three-phase fault. The figure shows that the magnitude of the
error factor greater than one (under reach problem), so the
effect of the series part (Figure 2) is greater than the effect of
shunt part (Figure 4) during the fault. Moreover, the series part
is higher effect than the shunt on the measured impedance at
the same operation condition (Figures 2 and 4).
Figure 8(b) shows the error factor at the three phases when
a double-phase (phase Y and phase B) fault occurred at 0.75
of the line. From Figure 8(b), EF's magnitude on the faulty-
phases (B, C) is greater than 1, so the same comment on the
three-phase fault. From Figure 8(c), the single-phase (phase A)
to ground fault observed same comments. Note that all angles
are given in radius.
From Figures 8(b) and 8(c), the impact of the UPFC on the
phase angle of the faulty phases can be ignored, this comment
means that the series part angle of the UPFC is moved to zero
during the fault (Figure 3).
5.2 Decrease load ability, inductive mode
In this section, the UPFC is used to decrease the
transmission line real power from 1 Pu to 0.5 Pu and consume
0.5 Pu reactive power. Figure 9 shows the error factor's
magnitude and angle for three fault cases at m=0.75 for
operation point (1) and set point (2).
It’s clear from Figure 9 that the error in the measured angle
can be neglected for all fault cases, and the magnitude of the
error factor is greater than 1 for the faulty phases (under reach
problem). These comments are similar to the previous case in
general, but the error factor magnitude is decrease during the
fault in this scenario and increase in the previous.
Another difference between this scenario (decrease load
ability) and the previse (increase load ability) is in the pre-fault
condition. The measured impedance is greater than the actual
in this scenario and less than the actual when the UPFC is used
to increase the real power flow in the transmission line.
The under-reach problem in the relay due to the UPFC in
the second scenario (when UPFC decrease load ability) is less
than that in the first scenario.
Figure 7. A studied system using MATLAB
(a) Three-phase fault
(b) Double phase (Y-B) fault
(c) Single-phase (R-G) to ground fault
Figure 8. The error factor EF when the UPFC changes the
power flow from operation point 1 to setpoint 1
(b) Double-phase fault
(c) Single-phase-ground fault
202

5.3 Increase load ability, capacitive mode
In this section, the UPFC is used to increase the
transmission line real power from 1 Pu to 1.5 Pu and provide
the system with 0.5 Pu reactive power. Figure 10 shows the
error factor's magnitude and angle for three fault cases at
m=0.75 for operation point (2) and set point (1).
This operation point is very similar to the first scenario (sec.
5.1), but the pre-fault error factor angle is negative in this
scenario and positive in the first scenario. This comment is
clearly justified in Figures 3 and 5.
(b) Double- phase fault
5.4 Decrease load ability, capacitive mode
In this section, the UPFC is used to decrease the
transmission line real power from 1 Pu to 0.5 Pu and provide
the system with 0.5 Pu reactive power. Figure 11 shows the
error factor's magnitude and angle for three fault cases at
m=0.75 for operation point (2) and set point (2).
(b) Double-phase fault
Figure 11. EF's magnitude and angle when UPFC changes
the power flow from operation point 2 to setting point 2
This operation point is very similar to the second scenario
(sec. 5.2), but the pre-fault error factor angle is negative in this
scenario and positive in the second scenario. This comment is
clearly justified in Figures 3 and 5.
In this section, all the operation conditions of the UPFC are
simulated for different faults occurred in the zone one of the
compensated transmission lines. From the whole results, it is
observed that the error factor before the fault is similar to the
previous analysis (shunt and series devices separately). On the
other hand, all the cases' error factor is higher than one during
the fault. So, it can be generalized that the UPFC compensated
transmission line's main problem is the underreach in the
distance relay.
6. CONCLUSION
FACTS devices have tremendous advantages of improving
power system stability and regulating the power flow of active
and reactive power along the transmission line. Along with
this, they can harm the operating characteristics of the
protective devices, especially distance protection.
The present paper introduces the effect of the different
FACTS devices on the distance relay's performance using the
measured impedance between the fault and the distance relay.
The impact of FACTS devices on MHO characteristics is
presented. The work is evidenced by mathematical analysis
and carried out on the two-source test system using MATLAB
2019b Simulink.
This paper provides a comprehensive analysis of the
measured impedance in the compensated transmission line.
For protection coordinators, UPFC/FACTS controllers, and
protection/FACTS researchers, this analysis may be needed.
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APPENDIX
Appendix A: Single Phase fault
Firstly, pre-fault load current (𝐼𝐴𝐿
′
) from station A to B (from
Figure 2) and voltage (𝑈𝐴𝐿
′
) at fault position in phase A can be
expressed as:
𝐼𝐴𝐿
′
=
𝐸𝐴(
𝑧1𝑠ℎ
) − 𝐸𝐵
𝑍1𝐴
′
+ 𝑍1𝐵
=
(
𝑧1𝑠ℎ
− ℎ𝑒−𝑗𝛿
) 𝐸𝐴
𝑍1𝐴
′
+ 𝑍1𝐵
(A1)
𝑈𝐴𝐿
′
= 𝐸𝐴
𝑧1𝑠ℎ
− 𝐼𝐴𝐿
′
𝑍1𝐴
′
(A2)
where: 𝑍1𝐴
′
= 𝑍1𝐿𝐴 + 𝑍1𝑆𝐸 +
𝑍1𝑆𝐴𝑍1𝑆ℎ
𝑍1𝑆𝐴+𝑍1𝑆ℎ
, 𝑎𝑛𝑑 𝑍1𝐵 = 𝑍1𝐿𝐵 +
𝑍1𝑆𝐵 are the positive sequence impedances.
When a fault occurs, the impedance of phase A measured at
F is:
𝑍𝑅
′
=
𝑈𝐴𝐹
𝐼𝐴𝐹 + 3𝐾0𝐼0𝐴
(A3)
where: 𝑈𝐴𝐹 faulted phase voltage at A during the fault, 𝐼𝐴𝐹
fault current measured at A. 𝐾0 Zero-sequence compensation
factor due to remote generators' contribution. 𝐼0𝐴 Zero-
sequence fault current measured at A.
𝐾𝑜
′
=
𝑍𝑜𝐿 − 𝑍1𝐿
3 𝑍1𝐿
(A4)
where, 𝑍𝑜𝐿, 𝑍1𝐿 zero and negative sequence impedance of the
faulted line. To calculate 𝐼𝐴𝐹 , the sequence components are
used. The sequence impedances are computed as the Figure
A1 below.
204

Figure A1. Sequence component of a single-phase fault
where, positive, negative, and zero equivalent impedances are
connected in series in case of single-phase to ground fault. In
Transmission lines and generators Z1=Z2. So, the equivalent
impedance can be found as flow:
𝑍∆
′
=
2 𝑍1𝐴
′
𝑍1𝐵
𝑍1𝐴
′
+ 𝑍1𝐵
+
𝑍0𝐴
′
𝑍0𝐵
𝑍0𝐴
′
+ 𝑍0𝐵
(A5)
where,𝑍0𝐴
′
, 𝑍1𝐴
′
, 𝑍0𝐵 = 𝑍0𝐿𝐵 + 𝑍0𝑆𝐵𝑎𝑛𝑑 𝑍1𝐵 = 𝑍1𝐿𝐵 + 𝑍1𝑆𝐵 : The
zero and positive sequence impedances. During a single line
to ground fault in phase-A, the positive, negative, and zero
sequence currents through the fault resistance RF equal:
𝐼1𝐹
′
= 𝐼2𝐹
′
= 𝐼0𝐹
′
=
𝑈𝐴𝐿
′
𝑍∆
′
+ 3𝑅𝐹
(A6)
Based on the concept of the current divider, the positive,
negative, and zero sequence currents through the relay point
(A) equal:
𝐼1𝐴
′
= 𝐼2𝐴
′
= 𝐶1
′
𝐼1𝐹
′
=
𝐶1
′
𝑈𝐴𝐿
′
𝑍∆
′
+ 3𝑅𝐹
(A7)
𝐼0𝐴
′
= 𝐶0
′
𝐼1𝐹
′
=
𝐶0
′
𝑈𝐴𝐿
′
𝑍∆
′
+ 3𝑅𝐹
(A8)
where, 𝐶1
′
, 𝐶0
′
are distribution factors and given by:
𝐶1
′
=
𝑍1𝐵
𝑍1𝐵 + 𝑍1𝐴
′ ∗
𝑍1𝑠ℎ
= 𝐶1
′′
∗
𝑍1𝑠ℎ
𝑎𝑛𝑑 𝐶0
′
=
𝑍0𝐵
𝑍0𝐵 + 𝑍0𝐴
′ ∗
𝑍0𝑠ℎ
= 𝐶0
′′
∗
𝑍0𝑠ℎ
Now, the total fault current throw relay at terminal A and
fault voltage are given by:
𝐼𝐴𝐹 = 𝐼𝐴𝐿
′
+ 𝐼1𝐴
′
+ 𝐼2𝐴
′
+ 𝐼0𝐴
′
= 𝐼𝐴𝐿
′
+ 2𝐶1
′
𝐼1𝐹
′
+ 𝐶0
′
𝐼0𝐹
′
(A9)
𝑈𝐴𝐹 = (𝐼1𝐹
′
+ 𝐼2𝐹
′
+ 𝐼0𝐹
′ )𝑅𝐹 + (𝐼1𝐹
′
∗ 𝐶1
′′
+ 𝐼𝐿𝐴
′ )(𝑍1𝐿𝐴
+ 𝑍1𝑆𝐸) + 𝐼2𝐹
′
∗ 𝐶1
′′
(𝑍2𝐿𝐴 + 𝑍2𝑆𝐸)
+ 𝐼0𝐹
′
∗ 𝐶0
′′
(A10)
𝑍𝐴 =
𝑈𝐴𝐹
𝐼𝐴𝐹
′
+ 3𝐾0𝐼0𝐴
′ (A11)
𝑍𝐴
′
=
3𝐼1𝐹
′
𝑅𝐹 + (𝐼1𝐹
′
∗ 𝐶1
′′
+ 𝐼𝐿𝐴
′ )(𝑍1𝐿𝐴 + 𝑍1𝑆𝐸) + 𝐼2𝐹
′
∗ 𝐶1
′′
(𝑍2𝐿𝐴 + 𝑍2𝑆𝐸) + 𝐼0𝐹
′
∗ 𝐶0
′′
𝐼𝐴𝐿
′
+ 2𝐶1
′
𝐼1𝐹
′
+ 𝐶0
′
𝐼0𝐹
′
+ 3𝐾0𝐶0
′
𝐼0𝐹
(A12)
If we ignore the contribution of load current in fault current:
𝑍𝐴
′
=
3𝑅𝐹 + (2𝐶1
′′
+ 𝐶0
′′
(1 + 3𝐾0))(𝑍1𝐿𝐴 + 𝑍1𝑆𝐸)
2𝐶1
′′
∗
𝑍1𝑠ℎ
+ (1 + 3𝐾)0𝐶0
′′
∗
𝑍0𝑠ℎ
(A13)
𝑍𝐴
′
≈
3𝑅𝐹
2𝐶1
′
+ 𝐶0
′(1 + 3𝐾0)
+ (𝑍1𝐿𝐴
+ 𝑍1𝑆𝐸)
𝑍1𝑠ℎ
(A14)
Appendix B: Case study parameters
Voltage base: 400 Kv, Power base=100 MW. F=50 Hz.
✓ Operation point (1):
Source (A): V=1.085 Pu, 𝜃 = −19.75𝑜
, swing. R=8.03,
L=0.07875H.
Source (B): V=1.0 Pu, 𝜃 = −30.8𝑜
, swing. R=8.03,
L=0.7875 H.
Transmission line (power flow): PL=1 Pu, QL=-0.5 Pu.
✓ Operation point (2):
Source (A): V=1.17 Pu, 𝜃 = −20.25𝑜
, swing. R=8.03,
L=0.07875H.
Source (B): V=0.88 Pu, 𝜃 = −30.8𝑜
, swing. R=8.03,
L=0.7875 H.
Transmission line (power flow): PL=1 Pu, QL=0.5 Pu.
✓ System Parameters:
Transmission line: 150Km, R=0.117 Pu/Km, X=1.547e-3
Pu/Km.
UPFC: Shunt converter parameters: R=0.22/30 Pu, L=0.22
Pu.
UPFC: Series converter parameters: R=0.13/30 Pu, L=0.16
Pu.
UPFC: DC-link: V=40 KV, C=750micro F.
UPFC: Setting point (1) of the UPFC: P=1.5Pu, Q=0,
UPFC: Setting point (2) of the UPFC: P=0.5 Pu, Q=0.
205

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