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16th International Conference on Electrical Engineering, July 11-14, 2010 Busan Korea
1
Application of Phasor Measurement Unit (PMU)
Data for Out-of-Step Detection
Dikpride Despa*,**
, Yasunori Mitani *, Masayuki Watanabe* ,
Changson Li,* Bessie Monchusi*
Abstract The algorithm based on equal area criterion is developed and the stability of generators after a fault is assessed. The power swing equation is integrated to calculate the accelerating and decelerating area under the power
delta curve. Phasor Measurement Unit (PMU) data from a four generators power system is utilized in detecting
out-of-step condition. A three phase to ground fault on the power system is simulated by MATLAB and Dymola with
ObjectStab. The algorithm developed is tested by simulations on the four generator power system.
Keywords: Phasor Measurement Unit (PMU), Out of Step Detection, Equal Area Criterion, Transient Stability.
1. Introduction
The stability of an interconnected power system is its
ability to return to normal or stable operation after having
been subjected to some form of disturbance [1]. Certain
disturbances may cause the interconnected power systems
to lose synchronism, which may lead to cascading
blackouts and equipment damage. In order to avoid these
severe results, controlled separation of the system using out-of-step protection is an effective way to preserve stability in several smaller islands. Traditional out-of-step
protection uses distance relays and timers to detect the out-
of-step condition by assessing that the voltage and current
during a power swing is gradual instead of a step change.
Faults and out-of-step condition lead to a change of measured apparent impedance, but the change is much
slower during out-of-step conditions. After the out-of-step
condition is detected, out-of-step protection must block
other fault relays prone to malfunction during out of-step
conditions. Meanwhile, the controlled separation at the pre-
selected points provides load-generation balance in each
separated area with the help of a load-shedding program.
However, the disadvantage of the traditional out of step
protection scheme is that it only uses local measurements to
estimate the condition of the entire power system network,
which inevitably affects its ability to detect the out-of-step
conditions in certain circumstances. Phasor Measurement
Unit (PMU) is widely applied for detecting out of step
condition. A PMU is a device that can measure voltage and
current phasors, i.e. as complex quantities, with a common time reference for all the PMUs in the system. Line parameters such as; resistance, inductance and
capacitance can be calculated, even corona and zero sequence parameters can be determined with the PMU.
PMU provides more precise data at a much faster rate. It is
possible to receive accuracy of synchronization of 1
microsecond or 0.021 for 60 Hz signal [2]. This offers new
opportunities in power system control. The research
focused on a method to detect out of step condition using
phasor measurement, voltage phase angle difference
between different buses and simulate the out of step
scenarios on a four generators power system.
The rest of the paper discusses; 2. Equal Area Criterion, 3.
Phasor Measurements Units, 4. Out-of-step algorithm, 5.
Simulations and 6. Conclusion.
2. Equal Area Criterion
The power-angle relationship and the swing equation are
essential in understanding transient stability and can be
* Dept. of Electrical and Electronic Engineering, Kyushu Institute of
Technology, Japan ([email protected])
** Dept. of Electrical Engineering, Lampung University, Indonesia
2
utilized to describe the Equal-Area Criterion (EAC).The
swing equation describes the swings of the rotor angle () during a disturbance. EAC on the other hand, describes the
movement of the rotor angle using three graphs
representing the pre-fault, fault and post-fault conditions.
Based on the accelerating and decelerating areas of the
rotor angle, under these graphs, EAC assesses transient
stability. The swing equation is given by [3]:
aei PPPdt
dM ==
2
2 (1)
dt
d = (2)
where M = the inertia constant, = the rotor angle of the synchronous machine, Pm = mechanical power, Pe =
electrical power and = rotor speed. The inter-area oscillation component in the voltage variables resulting
from disturbances is utilized for extrapolating system
impedances beyond the measured buses by:
( )P
SinVVxT
21= (3)
where |V1|, |V2|are phasor voltages, is the phase rotor angle and P is the output power. The maximum power transferred between the generators and the mechanical power are estimated using these formulas:
TX
VVP
21
max = (4)
)( 0max SinPPm = (5)
where XT= the total impedance, |V1|and |V2|= the synchronized phasor voltages, maxP = the maximum power,
mP = the mechanical power and 0 = the initial power
angle.
Fig. 1 P- Curve
The EAC integrates the energy gained when the turbine-generator is accelerating, during the fault (area A, in Fig. 1 )
and compares that area with the decelerating area, (area B, in Fig. 1). When the generator exports the energy stored
during the fault. The accelerating and decelerating area at
the different generator conditions are calculated by integration of the power swing equation between the
boundary angles. In Fig. 1 the simplest condition is shown,
i.e. immediately at the occurrence of a fault, the electric
power output drops to zero and as soon as the fault is
cleared the electric power output returns to its initial curve.
Equation (6) and (7) describes area A and area B. Transient stability assessment can be explained using Equal-Area
Criterion by Fig. 1. Area A is the accelerating or positive
area and B is the decelerating or negative area
dPPAcl
faultem )sin(0 , =
(6)
=f
cldPPB m
)sinmax (7)
Where cl stands for clearing time, f is the fault time.
Transient stability of the system is guaranteed if A
16th International Conference on Electrical Engineering, July 11-14, 2010 Busan Korea
3
When A and B are equal, the stability limit of the system is
reached and the accelerating power (Pa) is equal to zero.
The unstable case is reached when A>B, the angle keeps
increasing and goes out-of-step, or becomes unstable.
3. Phasor Measurement Units
PMUs are also known as synchronized phasor units for they
allow more finely calibrated observation power flows on
the power system. PMU data from different utilities is time-
synchronized and combined to create a detailed and
comprehensive view of the broader system. Conventional
methods measure voltage, current, real and reactive power
for determining the operating condition of the electric
network. These technologies cannot measure voltage phase
angles while PMU provide the phasors of voltage and
currents measured at a given substation. PMU is able to
measure phase difference at different locations. Instead of
the indirect measurements or estimation used in traditional
out-of-step protection, the voltage frequency and angle
measurement from different buses can provide the ability to
directly monitor system transient stability conditions.
4. Out-of-Step Algorithm
An out-of-step condition in a network occurs when a
generator or a group of generators lose synchronism with
the rest of the network. The event forces generators to
shutdown and sometimes large parts of the network are
forced out of service. Before losing synchronism the
network normally experiences power oscillations between
neighboring generator groups. The oscillations cause
voltage and current variations throughout the power system
and there will be a variation in power flow between two
areas, this phenomenon is called a power swing. The out-
of-step algorithm creates vectors of complex current,
voltage and impedance from phasor measurements. For the
construction the P- curve, the equivalent phase angle for
the system is calculated using the COA algorithm [4].
=
==
N
ii
i
N
ii
COA
1
1
(8)
The total Impedance of the power system is calculated
using the equivalent phase angle.
I
VeVX
i
ref
T
= (9)
And applied to determine the equivalent rotor angle is
calculated by :
=
T
T
jX
X1tan (10)
The total power of the system is calculated by :
( ) ( ) += sinsin2
T
xref
T X
VV
X
VP (11)
Utilizing (11) the total mechanical power can be calculated
using the initial values of voltage, impedance, and delta. The phase angle and power value of generator 3 the steady
state condition are used as a reference and compared to the
phase angle and power of the other generator at different
time step. Using time phase angle and power vector at each
time step the P- curve is constructed. The area under the
curves is calculated using the Riemann Integration. To
estimate the power output for the fault and post fault at
different time steps, a constant is calculated by:
SinP
tCons =tan (12)
The new value of outP for fault and post fault at
different steps are given by:
2sintancos
XtP new = (13)
4
0 20 40 60 80 100 120 140 160 1800
0.5
1
1.5
2
2.5
Angle [degrees]
Power [p.u.]
Fig. 2 Shows the power-output and the mechanical
power for the power system in steady state
operation.
0 20 40 60 80 100 120 140 160 1800
0.5
1
1.5
2
2.5
Angle [degrees]
Power [p.u.]
Fig. 3 Shows the power output and mechanical
power under fault and post fault conditions
Its applied in calculating the output power and mechanical
power. The new vectors of phase angle and power for all
time steps are calculated from the above complex values.
To detect angle change the difference between the reference
value and a value at a specific time-step is calculated. If the
difference is too much, the algorithm to detect the power
swing will start. The reference value is taken from studying
the graphs of the change of phase angle. If the phase angle
has changed too much and the electric power output has
decreased to a level below the mechanical power input, it is
for sure that the system will experience a power swing. If
the accelerating area is greater than decelerating area, the
system will go out of step.
5. Simulation
The Algorithm developed is tested on the four generators,
two areas power system (shown in Fig. 4) on MATLAB.
The system is designed by Dymola with ObjectStab. The
generators have an exciter and a turbine governor.
Simulations are performed with a three phase to ground
fault on the transmission line as shown in Fig. 4 PMUs are
placed on the generators bus bars (1, 2, 11 and 12)
Fig. 4 Four Generators Two Areas Power System
Fig. 5 P- Curve for Generator 1
In Fig. 5 the power at the state and change of power around
the time of the instant fault are shown for Generator 1 by
the solid graph. Generator 3 is chosen as a reference
generator. The impedance of the equivalent power system is
utilized in the calculation of the maximum power and
mechanical power. The output power for the fault and after
fault condition is shown by graphs with dashes. The
generator is not out of step with the other generators in the
power system.
16th International Conference on Electrical Engineering, July 11-14, 2010 Busan Korea
5
Fig. 6 P-Curve for Generator 2
In Fig. 6 the solid curve shows the stable electric power
output before the fault. The dashed curves represent the
electric power output during and after the fault. The
mechanical power input is represented by the dotted line. In
this case, the generator is far from losing synchronism. The
power will oscillate back to its stable equilibrium point.
A fault has occurred but the system remains stable.
Fig. 7 P- Curve for Generator 4 Generator 4 does not loose synchronism even if there is a
fault in the power system. The power at the stable point and
the change of power around the time of the instant fault for
generator 4 are shown in Fig. 7. From the results of the
simulations, it can be concluded that the fault in the system
is not severe enough to cause all the generators to loose
synchronism.
Fig. 8 P-Curve for Generator 1 out-of-step
Fig. 9 P-Curve for Generator 2 out-of-step
6
Fig 10. P-Curve for Generator 4 out-of-step Figures 8-10 show the P-curves for out-of-step condition, for generators 2, 3 and 4. The out-of-step message is issued
to warn that the generators 1 and 2 are out- of- step while
generator 3 remains in synchronism with generator 4.
5. Conclusion
Phasor measurements are utilized to calculate the vectors of
complex current, voltage and impedance which are applied
to determine the new vectors with phase angle and power
for all time steps. The angle change is determined by the
difference between the reverence value and a value at a
specific time-step is calculated. The Equal Area Criterion is
utilized to detect if the generators are going out of step or
not. A three phase to ground fault is simulated on the four
generators power system.
Acknowledgements
This work was supported by in part by Grant-in-Aid for
Science Research (A) 18206028 of JSPS.
References [1] I J Nagrath, DP Kothari, Modern Power System
Analisys, McGraw Hill, 1980.
[2] Mark R Gerald T.H. Phasor Measurement Unit
Data in Power System State EstimationJanuary
2005.
[3] Prabha Kundur Power System Stability and
Control,McGraw Hill, 1993.
[4] B. B. Monchusi Optimal Approach Towards Using
Phasor Measurement (PMU) Data in Equal-Area
Criterion Based Systems for Power System Transient
Stability Assessment, PhD Thesis, Graduate School
of Engineering, Kyushu Institute of Technology,
Japan, February 2010.