r transmission line impedance estimation winter using ...apic/uploads/forum/poster_2014_155.pdf ·...
TRANSCRIPT
Introduction
Transmission Line Impedance Estimation
Using SCADA Data
Project Background
Application to Real SCADA Data
University of Alberta researchers: Yang (Frank) Wang
Industry collaborators: James Shen
Line parameters, i.e. the series resistance, series reactance, and shunt
admittance of a line, are critical input data for a wide variety of power system
analysis programs. Accuracy of line parameters is essential to ensure
adequate analysis and prediction of power system responses. These
parameters can also be used to find abnormal operating conditions of
conductors. In Alberta, the parameters of a transmission line are calculated
based on the structure and material information of the line. It is important to
actually measure the line parameters to verify if the calculated parameters
have acceptable accuracy.
RX
G/2 B/2 G/2 B/2
Sending End:
Vs,rms , Ps, Qs Irms
Receiving End:
Vr,rms , Pr, Qr
S2, P2, Q2S1, P1, Q1
Transmission Line Model:
Objective: To measure line parameter, i.e. R - line resistance and X – Line reactance,
B – shunt capacitance and G – shunt conductance (corona).
Available Information: SCADA data, i.e. voltage magnitude (Vrms), active power (P) and reactive
power (Q) of two ends.
Potential Applications: The proposed method is an online tracking of line impedance, many
potential applications can be expected. For example, 1) online condition
monitoring of the transmission line, 2) Update the inputs to diverse
power system analysis programs and algorithms, such as protective
relaying algorithms and power flow analysis, …….
Proposed Algorithm
① The total active power loss of the line equals to the loss on R,
which is a function of the current and the loss on G, which is a
function of the voltage.
(1)
② The total reactive power change of the line equals to the loss on X,
which is a function of current and the compensation from B, which is
a function of voltage.
(2)
③ The current magnitude of "R & X branch" (Irms) can be calculated by
either sending end data or receiving end data
(3)
Using Equation (1)~(3), transmission line parameter can be solved !
Additionally, a data selection method is further proposed based on to
minimize the impact of error in SCADA data. In Equation (1) and (2),
s is the coefficient of R and X, which means that the impact of error in
SCADA data (V, P, Q) decreases with the increase of . Therefore, we
only trust 5% estimation results calculated with largest .
2 22( )
2 2
s rrms s r
V G V GI R P P
2 22( )
2 2
s rrms s r
V B V BI X Q Q
2 2 2 2 2 2 2 2
2 2
( / 2) ( / 2) ( / 2) ( / 2)s s s s r r r rrms
s r
P V G Q V B P V G Q V BI
V V
0 2000 4000 6000 8000 10000 12000 14000 16000 180000
100
200
MW
summer
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-50
0
50
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 18000240
250
260
kV
sending end
receiving end
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-150
-100
-50
MW
winter
0 2000 4000 6000 8000 10000 12000 14000 16000 1800020
40
60
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 18000250
255
260
kV
sending end
receiving end
0 2000 4000 6000 8000 10000 12000 14000 16000 180000
100
200
MW
fault date
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-50
0
50
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 18000245
250
255
kV
sending end
receiving end
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8
2
4
6
8
10
12
14
Irms
(kA)
p.u
.
summer
R-est
X-est
R-ref
X-ref
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.80
5
10
15
Irms
(kA)
p.u
.
winter
R-est
X-est
R-ref
X-ref
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8
2
4
6
8
10
12
14
Irms
(kA)
p.u
.
faultdate
R-est
X-est
R-ref
X-ref
925L R X
Given value 1.68 9.70 Summer peak 2.14 ±0.27 9.61 ±0.38 Winter peak 1.74 ±0.14 9.78 ±0.31
Fault day
Proposed method 1.63 ±0.17 9.57 ±0.30 Relay data using
phasor based method 1.70 9.68
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-300
-200
-100
MW
summer
0 2000 4000 6000 8000 10000 12000 14000 16000 180000
20
40
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 18000250
255
260
kV
sending end
receiving end
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-400
-300
-200
MW
winter
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-100
0
100
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 180000
200
400
kV
sending end
receiving end
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-200
-100
0
MW
fault date
0 2000 4000 6000 8000 10000 12000 14000 16000 18000-50
0
50
MV
ar
0 2000 4000 6000 8000 10000 12000 14000 16000 18000250
255
260
kV
sending end
receiving end
0.5 1 1.50
5
10
15
Irms
(kA)
p.u
.
summer
R-est
X-est
R-ref
X-ref
0.5 1 1.50
5
10
15
Irms
(kA)
p.u
.
winter
R-est
X-est
R-ref
X-ref
0.5 1 1.50
5
10
15
Irms
(kA)
p.u
.
faultdate
R-est
X-est
R-ref
X-ref
rmsI
rmsI
rmsI
rmsI
Two real transmission lines are tested by the proposed algorithm. For each of line, three different
days’ SCADA data are employed for calculation, which are winter peak, summer peak and fault day.
Fault day means that there was a line fault happened at that day and we have obtained the
corresponding fault recorder data from relays. The fault recorder data can be used to estimate line
parameters by using phasor based method. Thus, results obtained from two different methods can be
used to crosscheck.
Line 1 - 925L
Raw SCADA Data Measured Line Impedance
Line 2 - 903L
Raw SCADA Data Measured Line Impedance
Summary 903L
R X Given value 1.45 9.08
Summer peak 1.48 ±0.05 9.03 ±0.08 Winter peak 1.17 ±0.05 9.09 ±0.10
Fault day
Proposed method 1.45 ±0.06 9.03 ±0.21 Relay data using
phasor based method 1.41 8.94