Online Optimal Transmission Line Parameter
Estimation For Relaying Applications
Yuan Liao1, Senior Member, IEEE Mladen Kezunovic2, Fellow, IEEE
actual values of these factors may differ from those employed
in the estimation process, considerable discrepancies between
Abstract Transmission line protective relaying algorithms
actual line parameters and estimated values could occur.
usually require transmission line parameters as inputs and thus
accuracy of line parameters plays a pivotal role in ensuring the An alternative approach for line parameter estimation is
reliable performance of relaying algorithms. Online estimation of discussed in [10], where the line parameters are derived based
line parameters is highly desirable and various methods have on impedances calculated at one terminal using acquired
been proposed in the past. These methods perform well when the voltage and current phasors assuming the other end of the line
measurements utilized are accurate; they may yield erroneous
is open or short-circuited. Such required measurements may
results when the measurements contain considerable errors.
be difficult to obtain. Moreover, inaccuracies in the
Based on non-linear optimal estimation theory, this paper puts
measurements may lead to appreciable errors in parameter
forward an optimal estimator for deriving the positive sequence
estimation.
line parameters, capable of detecting and identifying the bad
To obtain the most prevailing line parameters, online
measurement data, minimizing the impacts of the measurement
errors and thus significantly improving the estimation accuracy. estimation approaches would be highly desirable and
The solution is based on the distributed parameter line model especially beneficial to protection applications. This type of
and thus fully considers the effects of shunt capacitances of the techniques take advantage of online voltage and current
line. Case studies based on simulated data are presented for measurements [11-15]. In [11], two sets of synchronized
demonstrating the effectiveness of the new approach.
voltage and current phasors from the two terminals of the line
are utilized to obtain the ABCD parameters of the line. How
Index Terms Transmission line parameter estimation, Non-
distributed parameter per unit length can be obtained is not
linear estimation theory, Bad measurement detection and
covered. The estimation accuracy highly relies on
identification, Distributed parameter line model.
synchronization precision [12]. The authors of [13] suggest a
method for deriving the line characteristic impedance and
I. INTRODUCTION
propagation constant by making use of online voltage and
current phasors captured at sending-end and receiving-end of
T the line. Reference [14] solves for the line parameters based
ransmission line parameters including series resistance,
on Laplace transform technique by utilizing three sets of
series reactance and shunt susceptance are critical inputs
synchronized voltage and current phasors. Another approach
to diverse power system analysis programs. Precision of line
based on synchronized voltage and current phasors obtained
parameters is thus essential in ensuring the accuracy of the
from both ends of the line is introduced in a recent paper,
obtained analysis results. Especially in areas of power system
which emphasizes the benefits of online parameter estimation
protection, many distance relaying algorithms entail line
to distance relaying [15]. All these algorithms assume that
parameters for determining appropriate relay settings,
highly precise synchronization is available and may yield
calculating fault distance, and making a sound tripping
significant errors if this does not hold.
decision [1-3]. It has been established that the value of line
Generally speaking, the existing online estimation
resistance, inductance and capacitance is frequency dependent
algorithms perform well when the measurements utilized are
[4-6]. This paper is concerned only with estimating line accurate. In practice sometimes the measurements may
parameters at the fundamental frequency, which are usually contain errors due to various reasons like the current
required by relaying applications.
transformer saturation, data conversion errors or
Various algorithms for computing transmission line
communication device abnormalities [16-17]. Such
parameters have been presented in the past literature. Classical
measurement errors as well as possible synchronization errors
approaches as described in [7-9] utilize factors such as tower
could result in substantial inaccuracy in estimates.
and conductor geometric parameters, conductor type, assumed
Therefore, as pointed out in [18], it will be very desirable if
ambient conditions, etc. for estimating line parameters. Since
an online parameter estimation approach can be designed
capable of detecting and identifying measurement errors and
synchronization inaccuracy. In this way, the bad
1
Yuan Liao (abphjl@r.postjobfree.com) is with the Department of electrical and
measurements would be removed and only the sound
computer engineering, University of Kentucky, Lexington, KY 40506, USA.
2
Mladen Kezunovic (abphjl@r.postjobfree.com) is with the Department of measurements exploited to achieve a more precise estimate of
electrical and computer engineering, Texas A&M University, College Station,
the line parameters. Detection of synchronization inaccuracy
TX 77843-3128, USA.
can alert us to avoid synchronization assumption in parameter
2
estimation and meanwhile take timely actions to remedy the improve the estimation accuracy and increase the robustness
problems leading to synchronization inaccuracy. of the algorithm by minimizing the impacts of possible
This paper proposes an online algorithm for estimating the measurement errors. More accurate estimates of the line
positive sequence line parameters able to make the most of all parameters can lead to more accurate calculation of relay
the measurements available and minimize the impacts of settings and more reliable operation of relaying algorithms.
measurement and synchronization errors. The proposed Note that zero sequence components in the circuit during
solution is based on the fundamental frequency voltage and normal operations are usually negligible, thus the proposed
current phasors, which can be calculated from recorded algorithm mainly aims at estimating positive sequence line
waveforms or directly obtained from measuring devices such parameters instead of zero sequence parameters. Nonetheless,
as phasor measurement units. We employ a two terminal if significant zero sequence components arise due to various
transmission line model for illustrating the solution. reasons such as unbalanced load conditions, existence of faults
The equivalent circuit based on distributed parameter external to the studied line, etc., the proposed algorithm will
be equally applicable for estimating zero sequence parameters
line model is harnessed to automatically and fully consider
of the line.
shunt capacitances and distributed parameter effects of long
The proposed approach for estimating positive sequence
lines.
parameters is delineated in the following sections.
Section II illustrates the proposed method. The evaluation
studies are reported in Section III, followed by the conclusion.
B. Proposed optimal estimator
II. PROPOSED OPTIMAL ESTIMATOR FOR LINE PARAMETER
The following discussion assumes that synchronized voltage
ESTIMATION
and current measurements at P and Q during normal operation
are available. Figure 2 depicts the positive sequence network
Section A presents the overall description of the proposed of the system during normal operation.
method, with elaborations given in Sections B. Section C
explains the procedure for detecting and identifying possible
I qi
I pi
bad measurements. P Q
Z c sinh( l )
A. Overall description of the method
V qi
V pi
Q tanh( l / 2) tanh( l / 2)
P
Zc Zc
EG EH
Figure 1. Transmission line considered for analysis
Figure 2. Positive sequence network of the system during normal operation
Consider the line, assumed to be a transposed line, between
terminals P and Q as shown in Figure 1, where EG and E H In the figure, the following notations are adopted.
represent the Thevenin equivalent sources. i th phasor measurement of positive sequence
V pi, I pi
The proposed algorithm draws on the steady state voltage
voltage and current at P;
and current phasors at terminal P and Q that are measured at
Vqi, I qi i th phasor measurement of positive sequence voltage
different moments such as every hour during normal
operations. The aim is to estimate the positive sequence series and current at Q; i = 1,2 N, N being the total number of
resistance and reactance and shunt susceptance of the line per
measurement sets, with each set consisting of V pi, I pi, Vqi
unit length.
Based on one set of voltage and current phasors at P and Q, and I qi ;
two complex equations can be obtained based on the positive
Zc characteristic impedance of the line;
sequence equivalent circuit, which link the phasors with the
unknown line parameters. Separating the two complex propagation constant of the line;
equations into four real equations and solving these equations l length of the line in mile or km.
gives rise to the solution of unknown variables.
However, since the phasor estimates may contain errors,
Based on Figure 2, we can derive the following equations
estimation of line parameters based on a single set of
[3, 7]:
equations could be unreliable. Fortunately, a set of redundant
equations may be derived by utilizing voltage and current
V pi Z c sinh( l ) I pi + sinh( l ) tanh( l / 2)V pi Vqi e j = 0 (1)
measurements taken at different moments such as each hour
[14]. Then, the non-linear estimation theory may be utilized to
obtain an optimal estimate of the line parameters and each of
the phasors. Statistical approaches can also be adopted to
detect, identify and remove any possible bad data, and thus
3
I pi tanh( l / 2)V pi / Z c + I qi e j = ( x8 N + 2 + jx8 N +3 )( jx8 N + 4 ) (12)
(2)
j
tanh( l / 2)Vqi e / Zc = 0
Introduce S and F ( X ) as the measurement vector and
function vector, respectively, with their elements shown in the
Z c = z1 / y1 (3) Appendix. The measurement vector and function vector are
related by:
= z1 y1 (4)
Where,
S = F(X ) + (13)
the synchronization angle between measurements at
P and Q, representing any possible synchronization
Where, is determined according to meter characteristics.
error..
The optimal estimate of X is obtained by minimizing the
z1, y1 positive-sequence series impedance and shunt
cost function defined as:
admittance of the line per mile or km, respectively.
The phasors in (1-2) and synchronization angle are
J = [S F ( X )]T R 1[S F ( X )] (14)
considered as known measurements. Define
M = [V p1, I p1, V q1, I q1 V pN, I pN, VqN, I qN, ] (5)
The solution to (14) can be derived following the Newton-
will be assigned a value of zero since synchronized Raphson method [3]. After X is obtained, (6) can be applied
measurements are utilized. Modeling in the system to compute the estimated values of the measurement phasors.
equations could detect potential synchronization error due to For estimating positive-sequence line parameters, the
synchronizing device failures, as shown in Section III. M i, proposed method is also applicable to complex topology such
as parallel lines as long as the voltage and current
i = 1 (4 N + 1), designates the i th element of M .
measurements at two ends of the line are available, since there
We define the measurement functions for each measurement is no mutual coupling between positive-sequence circuits.
as
C. Detection and identification of bad measurements
jx 2 i
Yi ( X ) = x 2i 1e, i = 1 4 N (6)
To detect the presence of bad measurement data, the method
Y4 N +1 ( X ) = x8 N +1 (7)
based on chi-square test as illustrated in [7, 19] can be utilized.
In this method, the expected value of the cost function is
Where X denotes the unknown variable vector, defined as calculated first, which is equal to the number of degrees of
freedom designated as k . Then the estimated value of the cost
X = [ x1, x 2 x8 N, x8 N +1, x8 N +2, x8 N +3, x8 N + 4 ]T (8) 2
function C J is obtained. If C J k,, then the presence of
2
bad data is suspected with probability (1 - ). Value of k,
Where,
vector or matrix transpose operator;
T can be calculated for a specific k and based on chi-square
x1, x2 x8 N variables required to represent the distribution. If bad data exists, the measurement corresponding
to the largest standardized error will be identified as the bad
4 N complex measurements;
data. In our study, we choose to be 0.01, indicating a 99%
synchronization angle;
x8 N +1
confidence level on the detection. More details are referred to
x8 N +2, x8 N +3 and x8 N +4 positive-sequence transmission line pages 655-664 of [7].
series resistance, series reactance and shunt
susceptance per unit length, respectively. III. CASE STUDIES
By employing the defined variables, (1-2) can be written
as f 2i 1 ( X ) = 0 and f 2i ( X ) = 0, respectively as shown below.
This section presents the case studies demonstrating the
procedure and effectiveness of the proposed solution for
f 2i 1 ( X ) = x8i 7 e jx 8i 6 Z c sinh( l ) x8i 5e jx 8i 4 + detecting and identifying possible bad measurements and thus
(9) deriving a more accurate estimate of the line parameters.
sinh( l ) tanh( l / 2) x8i 7e jx 8i 6 x8i 3e jx 8i 2 e jx 8 N +1 = 0 A steady state analysis program has been developed to
generate steady state phasors during normal operations. A 500
f 2i ( X ) = x8i 5 e jx8i 4 tanh( l / 2) x8i 7 e jx8i 6 / Z c + kV, 200 mile transmission line system with configuration as
(10) shown in Figure 1 is modeled, with line parameters and source
x8i 1e jx8i e jx8 N +1 tanh( l / 2) x8i 3e jx8i 2 e jx8 N +1 / Z c = 0 impedances being referred to [3]. The distributed parameter
line model is used to calculate the equivalent series impedance
and shunt admittance of the line, which is used in the steady
Where,
state analysis program. Varying the angle difference between
i = 1,2 N, representing the index of the measurement set;
the voltage sources EG and E H will change the power flow
Z c = ( x8N + 2 + jx8N +3 ) /( jx8N + 4 ) (11)
transferred from terminal P to Q, and accordingly different
4
sets of voltage and current phasors at P and Q can be 2
less than 9,0.01, it is concluded based on Section II-C that no
produced. These phasors are then distorted with Gaussian
bad data exists.
noises with specified variances and then utilized as inputs to
It can be seen that quite accurate estimates have been
the developed algorithm for estimating the line parameters.
achieved by the proposed method.
The algorithm has been implemented in Matlab.
Representative results are reported in this section. The per unit
system is utilized in the following discussions, with a base B. Cases with bad synchronization
voltage of 500 KV and base voltampere of 1000 MVA. All the Although synchronization based on global positioning
cases utilize 3 sets of measurements ( N = 3 ) and the system is normally highly precise, synchronization errors still
following starting values: one for phasor magnitude, zero for may arise due to various reasons such as improper hardware
phasor angle, zero for synchronization angle, 1E-3 for line wiring, unavailability of the GPS time reference and
resistance per unit length, 1E-3 for line reactance per unit communication problems. This subsection illustrates how such
length, and 1E-3 for line shunt susceptance per unit length. errors may be pinpointed by the proposed method.
The estimator achieves the optimal estimate of line parameters We first generate the measurement phasors. Next a
quickly, around five iterations for all the cases. For the chi- synchronization error is applied to the measurements at
square test, we choose to be 0.01. terminal Q to emulate the synchronization error. Then the
estimator is applied to obtain the results and compute the
value of the cost function C J . Figure 3 depicts the calculated
A. Cases without bad measurements
value of the cost function versus the synchronization error.
One curve is obtained by using a value of 1E-6 for
This subsection studies the behavior of the algorithm when
synchronization variance, and the other curve using 1E-4.
there are no bad measurements.
Variances for other measurements are set to 1E-4. It can be
seen that the cost function becomes considerably larger when
Table I. Optimal estimates of line parameters and phasors without bad
the synchronization error reaches 6 degrees, which can be
measurements
Quantity Measured values Optimal estimates utilized to detect the presence of bad measurement data. As
0.82189 + j0.53537 0.82057 + j0.53457
V (p.u.) expected, Figure 3 also reveals that a smaller variance value of
p1
the synchronization angle makes the estimator more sensitive
0.51781 + j0.7094 0.52166 + j0.71375
I p1 (p.u.)
to synchronization errors. A more detailed analysis is shown
0.97005 + j0.1433 0.96981 + j0.14534
Vq1 (p.u.) below.
-0.65313 - j0.38769 -0.64951 - j0.38421
I q1 (p.u.) 40
Syn. var.=1e-4
0.85496 + j0.48538 0.85912 + j0.48732
V p 2 (p.u.) Syn. var.=1e-6
35
0.49938 + j0.65946 0.49677 + j0.65723
I p 2 (p.u.)
30
Value of the cost function
0.99233 + j0.13169 0.98917 + j0.12903
Vq 2 (p.u.)
25
-0.60678 - j0.30728 -0.60846 - j0.30943
I q 2 (p.u.)
20
0.92162 + j0.41448 0.91792 + j0.41406
V p3 (p.u.)
15
0.43283 + j0.55017 0.4338 + j0.54963
I p3 (p.u.)
10
0.9951 + j0.10816 0.99895 + j0.1091
Vq3 (p.u.)
-0.53077 - j0.19337 -0.52993 - j0.19302 5
I q3 (p.u.)
(degrees) 0 0.027705 0
0 1 2 3 4 5 6 7 8 9 10
line resistance 0.00099667 0.00094316 Synchronization error (degrees)
(p.u./mile)
Figure 3. Cost function versus the synchronization errors
line reactance 0.0023566 0.0023762
(p.u./mile)
Table II lists the optimal estimates when the
line susceptance 0.0018349 0.0018315
(p.u./mile) synchronization has an error of 10 degrees using a value of
1E-6 for synchronization variance.
Assuming that all the measurements have the same error The estimated value of the cost function C J is computed as
variance value of 1E-4, the optimal estimates of the line 2
38.6139. Since C J exceeds 9,0.01, presence of bad data is
parameters and phasors are shown in Table I. The measured
values and the optimal estimates are shown in the 2nd and 3rd suspected, based on Section II-C.
column respectively. The line parameters in the 2nd column
indicate the actual line parameters.
2
We have k = 9, 9,0.01 = 21.666, and the estimated value
of the cost function C J is calculated as 2.3955. Since C J is
5
After removing from the measurement set, a new optimal
Table II. Optimal estimates of line parameters and phasors with bad
synchronization
estimate can be obtained as shown in Table III, which
indicates that a more accurate estimate of the parameters has
Quantity Measured values Optimal estimates
been reached. N/A means the corresponding measurement is
0.82189 + j0.53537 0.81899 + j0.54556
V p1 (p.u.) 2
not available. In this case, k is 8.0, 8,0.01 = 20.09, and the
0.51781 + j0.7094 0.53716 + j0.71177
I p1 (p.u.)
estimated value of the cost function C J is 2.372. Since C J is
0.9802 - j0.027324 0.98241 - j0.026031
Vq1 (p.u.) 2
less than 8,0.01, all the data are considered fairly accurate,
-0.71053 - j0.26839 -0.68662 - j0.26274
I q1 (p.u.) and the estimates are regarded as acceptable.
Therefore, the optimal estimator is able to successfully
0.85496 + j0.48538 0.85777 + j0.49139
V p 2 (p.u.)
detect and identify the possible synchronization errors, and
0.49938 + j0.65946 0.51108 + j0.6618
I p 2 (p.u.) obtain a more accurate estimate by employing only the reliable
measurements.
1.0001 - j0.042627 0.99751 - j0.040914
Vq 2 (p.u.)
-0.65092 - j0.19724 -0.63507 - j0.19519
I q 2 (p.u.)
C. Cases with bad voltage or current measurements
0.92162 + j0.41448 0.91694 + j0.40859
V p3 (p.u.)
Large errors in voltage or current measurements can lead to
0.43283 + j0.55017 0.4489 + j0.56397 considerable inaccuracy in parameter estimates. This
I p3 (p.u.)
subsection illustrates how such bad measurements can be
0.99877 - j0.066278 0.99817 - j0.052813
Vq3 (p.u.)
detected by the optimal estimator. A value of 1E-6 for
-0.55628 - j0.098266 -0.54378 - j0.093658 synchronization variance and 1E-4 for other measurements are
I q3 (p.u.)
utilized.
(degrees) 0 0.011675
line resistance 0.00099667 0.0014293
(p.u./mile)
Table IV. Optimal estimates of line parameters and phasors with bad
line reactance 0.0023566 0.0034997
voltage measurement
(p.u./mile)
line susceptance 0.0018349 0.0024303
Quantity Measured values Optimal estimates
(p.u./mile)
0.98627 + j0.64245 0.95422 + j0.62266
V p1 (p.u.)
Table III. Optimal estimates of line parameters and phasors after 0.51781 + j0.7094 0.52723 + j0.71686
I p1 (p.u.)
synchronization angle data is removed
0.97005 + j0.1433 0.99817 + j0.16352
Vq1 (p.u.)
Quantity Measured values Optimal estimates
0.82189 + j0.53537 0.82063 + j0.53433 -0.65313 - j0.38769 -0.65767 - j0.379
V p1 (p.u.) I q1 (p.u.)
0.51781 + j0.7094 0.52125 + j0.71374 0.85496 + j0.48538 0.87891 + j0.49956
I p1 (p.u.) V p 2 (p.u.)
0.9802 - j0.027324 0.98027 - j0.02521 0.49938 + j0.65946 0.4919 + j0.65531
Vq1 (p.u.) I p 2 (p.u.)
-0.71053 - j0.26839 -0.70684 - j0.26561 0.99233 + j0.13169 0.97071 + j0.11704
I q1 (p.u.) Vq 2 (p.u.)
0.85496 + j0.48538 0.85915 + j0.48725 -0.60678 - j0.30728 -0.60473 - j0.31174
V p 2 (p.u.) I q 2 (p.u.)
0.49938 + j0.65946 0.49642 + j0.65708 0.92162 + j0.41448 0.93511 + j0.42323
I p 2 (p.u.) V p3 (p.u.)
1.0001 - j0.042627 0.99652 - j0.044755 0.43283 + j0.55017 0.43057 + j0.54731
Vq 2 (p.u.) I p3 (p.u.)
-0.65092 - j0.19724 -0.65339 - j0.19914 0.9951 + j0.10816 0.98324 + j0.10014
I q 2 (p.u.) Vq3 (p.u.)
0.92162 + j0.41448 0.9179 + j0.41423 -0.53077 - j0.19337 -0.52722 - j0.1947
V p3 (p.u.) I q3 (p.u.)
0.43283 + j0.55017 0.43348 + j0.54927 (degrees) 0 -0.0024721
I p3 (p.u.)
line resistance 0.00099667 0.0014317
0.99877 - j0.066278 1.0028 - j0.066347
Vq3 (p.u.) (p.u./mile)
line reactance 0.0023566 0.0023126
-0.55628 - j0.098266 -0.55571 - j0.098164
I q3 (p.u.) (p.u./mile)
line susceptance 0.0018349 0.0017765
(degrees) N/A 10.2775
(p.u./mile)
line resistance 0.00099667 0.00093137
(p.u./mile)
Suppose that there is an error of 20% in the magnitude of
line reactance 0.0023566 0.0023485
(p.u./mile) V p1, then the optimal estimates will be obtained as shown in
line susceptance 0.0018349 0.0018164
Table IV.
(p.u./mile)
The estimated value of the cost function C J is calculated as
To identify the possible bad data, the standardized errors are 2
79.6378, which is larger than 9,0.01 = 21.666 . Therefore,
calculated and the largest standardized error is 6.0173, which
corresponds to . Hence, is identified as the bad data.
6
Table VI. Optimal estimates of line parameters and phasors with bad
presence of bad measurements is suspected and V p1 is
current measurement
successfully identified as the bad data.
After the bad measurement is removed, a new set of optimal Quantity Measured values Optimal estimates
0.82189 + j0.53537 0.82374 + j0.53603
estimates are calculated as shown in Table V. In this case, V p1 (p.u.)
2
k = 7, 7,0.01 = 18.475, and the estimated value of the cost 0.62137 + j0.85128 0.58756 + j0.81357
I p1 (p.u.)
2
7,0.01,
function C J is 2.2706. Since C J is less than all the 0.97005 + j0.1433 0.98272 + j0.1302
Vq1 (p.u.)
data are considered fairly accurate and the estimates are -0.65313 - j0.38769 -0.68713 - j0.41756
I q1 (p.u.)
regarded as satisfactory. Comparison between Tables IV and
0.85496 + j0.48538 0.86043 + j0.48057
V manifests that the line parameter estimation accuracy is V p 2 (p.u.)
considerably enhanced. 0.49938 + j0.65946 0.49637 + j0.66786
I p 2 (p.u.)
Table V. Optimal estimates of line parameter and phasors with bad voltage 0.99233 + j0.13169 0.98345 + j0.13429
Vq 2 (p.u.)
measurement being removed
-0.60678 - j0.30728 -0.61089 - j0.30494
I q 2 (p.u.)
Quantity Measured values Optimal estimates
0.92162 + j0.41448 0.91818 + j0.4081
V p3 (p.u.)
N/A 0.81473 + j0.53124
V p1 (p.u.)
0.43283 + j0.55017 0.43481 + j0.56013
I p3 (p.u.)
0.51781 + j0.7094 0.52155 + j0.71368
I p1 (p.u.)
0.9951 + j0.10816 0.99361 + j0.11324
Vq3 (p.u.)
0.97005 + j0.1433 0.96858 + j0.14463
Vq1 (p.u.)
-0.53077 - j0.19337 -0.53226 - j0.18952
I q3 (p.u.)
-0.65313 - j0.38769 -0.64918 - j0.38447
I q1 (p.u.)
(degrees) 0 -0.0049759
0.85496 + j0.48538 0.85825 + j0.48687
V p 2 (p.u.)
line resistance 0.00099667 0.00090433
0.49938 + j0.65946 0.49695 + j0.65726 (p.u./mile)
I p 2 (p.u.)
line reactance 0.0023566 0.002237
0.99233 + j0.13169 0.98999 + j0.12948
Vq 2 (p.u.) (p.u./mile)
line susceptance 0.0018349 0.0019697
-0.60678 - j0.30728 -0.60854 - j0.30929
I q 2 (p.u.) (p.u./mile)
0.92162 + j0.41448 0.91717 + j0.4137
V p3 (p.u.)
Table VII. Optimal estimates of line parameter and phasors with bad
current measurement being removed
0.43283 + j0.55017 0.43393 + j0.54972
I p3 (p.u.)
0.9951 + j0.10816 0.99962 + j0.10946
Vq3 (p.u.) Quantity Measured values Optimal estimates
0.82189 + j0.53537 0.82081 + j0.53486
V p1 (p.u.)
-0.53077 - j0.19337 -0.52998 - j0.19291
I q3 (p.u.)
N/A 0.52873 + j0.72348
I p1 (p.u.)
0 0.00038015
(degrees)
line resistance 0.00099667 0.00092429 0.97005 + j0.1433 0.97106 + j0.14371
Vq1 (p.u.)
(p.u./mile)
-0.65313 - j0.38769 -0.65343 - j0.38749
line reactance 0.0023566 0.0023836 I q1 (p.u.)
(p.u./mile)
0.85496 + j0.48538 0.85926 + j0.48665
V p 2 (p.u.)
line susceptance 0.0018349 0.0018355
(p.u./mile)
0.49938 + j0.65946 0.49679 + j0.65825
I p 2 (p.u.)
Similarly, bad current measurements may also be 0.99233 + j0.13169 0.98863 + j0.12958
Vq 2 (p.u.)
successfully detected and identified. Suppose that there is an
-0.60678 - j0.30728 -0.60866 - j0.309
I q 2 (p.u.)
error of 20% in the magnitude of I p1, then the estimates will
0.92162 + j0.41448 0.91796 + j0.41344
be derived as shown in Table VI. The estimated value of the V p3 (p.u.)
cost function C J is calculated as 81.312, which is greater than 0.43283 + j0.55017 0.43395 + j0.55067
I p3 (p.u.)
2
9,0.01 = 21.666 . Therefore, presence of bad measurements is 0.9951 + j0.10816 0.99844 + j0.10957
Vq3 (p.u.)
suspected and I p1 is identified as bad data. -0.53077 - j0.19337 -0.53012 - j0.19268
I q3 (p.u.)
After the bad current measurement is removed, a new set of
0 -0.00028832
(degrees)
optimal estimates are calculated as shown in Table VII. In this
line resistance 0.00099667 0.00094006
2
case, k = 7, 7,0.01 = 18.475, and the estimated value of the (p.u./mile)
line reactance 0.0023566 0.0023649
2
cost function C J is 1.3604. Since C J is less than 7,0.01, all (p.u./mile)
line susceptance 0.0018349 0.001846
the data are considered fairly accurate and the estimates are
(p.u./mile)
regarded as satisfactory. Comparing Tables VI and VII
evinces that the line parameter estimation accuracy is
significantly improved.
7
[17] J. R. Linders, C. W. Barnett, J. W. Chadwick, et al, Relay performance
IV. CONCLUSION
considerations with low-ratio CTs and high-fault currents, IEEE
This paper presents an algorithm for estimating the positive Transactions on Industry Applications, Vol. 31, No. 2, March-April
sequence parameters of a transmission line by utilizing online 1995, pp. 392-404.
[18] Yuan Liao, Algorithms for power system fault location and line
voltage and current phasors measured at different moments
parameter estimation, the 39th Southeastern Symposium on System
from two terminals of the line during normal operations. This Theory, Mercer University, Macon, Georgia, March 4-6, 2007.
paper demonstrates that it may be feasible to design an [19] A. Abur and A. G. Exposito, Power System State Estimation Theory
approach for detecting, identifying and removing possible bad and Implementation, Marcel Dekker, Inc., New York, USA, 2004.
measurements and thus improving the estimation accuracy.
When synchronized measurements are employed, possible
VI. APPENDIX
synchronization errors can also be detected, thus enhancing
the line parameter estimation accuracy. The developed Elements of vector S are:
algorithm is based on distributed parameter line model and
thus fully considers the effects of shunt capacitance and S i = 0, i = 1 4 N (A.1)
distributed parameter effects of long lines. Quite encouraging
S 2i + 4 N 1 = abs( M i ), i = 1,2 4 N (A.2)
results have been obtained by simulation studies.
S 2i + 4 N = angle( M i ), i = 1,2 4 N (A.3)
V. REFERENCES S12 N +1 = M 4 N +1 (A.4)
Where abs and angle yield the magnitude and angle of
[1] J. L. Blackburn, Protective Relaying Principles and Applications,
the input argument, respectively.
Marcel Dekker, Inc., New York, USA, 1998.
[2] S.H. Horowitz and A. G. Phadke, Power System Relaying, Research
Studies Press Ltd., Taunton, Somerset, England, 1995.
Elements of function vector F ( X ) are:
[3] Y. Liao, Fault location utilizing unsynchronized voltage measurements
during fault, Electric Power Components & Systems, vol. 34, no. 12,
December 2006, pp. 1283 1293. F2i 1 ( X ) = Re( f i ( X )), i = 1 2 N (A.5)
[4] H.W. Dommel, EMTP Theory Book, Vancouver, BC, Microtran Power
F2i ( X ) = Im( f i ( X )), i = 1 2 N (A.6)
System Analysis Corporation, May 1992.
[5] J. R. Marti, Accurate modeling of frequency-dependent transmission
F2i + 4 N 1 ( X ) = abs(Yi ( X )) = x2i 1, i = 1 4 N (A.7)
line in electromagnetic transient simulations, IEEE Transactions on
Power Apparatus and Systems, Vol. PAS-101, No. 1, January 1982, pp. F2i + 4 N ( X ) = angle(Yi ( X ) = x 2i, i = 1 4 N (A.8)
147 155.
F12 N +1 ( X ) = Y4 N +1 ( X ) = x8 N +1 (A.9)
[6] M. C. Tavares, J. Pissolato, and C. M. Portela, Mode domain
multiphase transmission line model Use in transient studies, IEEE
Transactions on Power Delivery, Vol. 14, No. 4, October 1999, pp.
1533 1544.
VII. BIOGRAPHY
[7] John Grainger and William Stevenson, Power System Analysis,
McGraw-Hill, Inc., New York, USA, 1994.
[8] S. M. Chan, Computing overhead line parameters, Computer Yuan Liao (S 98-M 00-SM 05) is an Assistant
Applications in Power, Vol. 6, No. 1, 1993, pp. 43 45. Professor with the Department of electrical and
[9] H. Dommel, Overhead line parameters from handbook formulas and computer engineering at the University of Kentucky,
computer programs, IEEE Transactions on PAS, Vol. PAS-104, No. 4, Lexington, KY, USA. He was a R&D Consulting
February 1985, pp. 366 370.