9-11 September 2018 - 50th North American Power Symposium
Mixed Integer Programing(MIP)-Based Fault LocationIdentification Using MicroPMUs
Presentation at 50th North American Power Symposium
Mohammed AlqahtaniDepartment of Electrical Engineering
University of South FloridaPrince Sattam bin Abdulaziz University
Dr. Zhixin Miao & Dr. Lingling FanDepartment of Electrical Engineering
University of South Florida
September 10, 2018
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
Utility performance evaluation
I Nowadays, the electric utility industry is a competitive field. Each utility wants to increase productivityand reduce economic losses.
I Reliability indices are a way of evaluating the performance of the utilities. To be a competitive in theutilities market, improve these indices.
I Accoring to IEEE Std 1366 (IEEE Guide for Electric Power Distribution Reliability Indices).– The System Average Interruption Duration Index (SAIDI)=∑
Customer Minutes of Interruption
Total Number of Served Customers
– The Customer Average Interruption Duration Index (CAIDI)=∑Customer Minutes of Interruption
Total Number of Served Customers
I Reducing the interruption duration will ensure improvement in these indices.
9-11 September 2018 - 50th North American Power Symposium
A Common Used MethodImpedance Based Method 1
– Uses voltage and current measurements at the substation to estimate the impedance and then thedistance to the fault point.
– a standard feature in most microprocessor-based relays.– Adopted from the transmission system.– In Distribution systems, The method suffers from multi-estimation due to the radial topology of the
system (multiple points may have the same distance.)
Common practices to improve it: to use external information to narrow the searching area- History of events- Weather status- Construction areas- Costumers calls!! (Do we really want to wait for an angry customer call?!)
1(J. Mora-Florez, J. Melendez, and G. Carrillo-Caicedo, “Comparison of impedance based fault location methods for power distributionsystems,” Electric Power Systems Research, vol. 78, no. 4, pp. 657–666, 2008)
9-11 September 2018 - 50th North American Power Symposium
Example2
Figure: Fault event screen capture
Figure: Spreadsheet for the line parameters
2(K. Zimmerman and D. Costello, “Impedance-based fault location experience,” in Proc. 58th Annu. Conf. Protect. Relay Eng., Apr. 2005, pp.211–226)
9-11 September 2018 - 50th North American Power Symposium
Continue
Two Possible locations
Figure: Distribution Feeder
9-11 September 2018 - 50th North American Power Symposium
IEEE-123How many points will have the same distance to the substation?
Figure: IEEE-123 test feeder
9-11 September 2018 - 50th North American Power Symposium
Our objective
I To reduce the outage time in order to improve the reliability indices and reducerevenue loss caused by outages.
I To achieve that goal: a fast fault location method is required to speed up therestoration process.
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
The Advantages of the MIP-Based Proposed method
I Does not yield to multiple locations.I Only requires the pre and during fault voltages at the end of the branches in
addition to the impedance bus matrix. (no need for current measurements)I Applicable for grounded and ungrounded systems.I The implementation of the proposed method is simple and does not require
multiple stages or iterations.I It determines the fault type, location and magnitude. While other methods rely on
protective devises in substations to classify the fault type or determine the faultmagnitude.
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
MIP Formulation for a Simple Single Phase Network
Figure: Simple 6-Node Network
Only one voltage phasor is required tofind If4, if more than one voltage phasorsare measured, it will be anoverdetermined problem.
[0 0 −If4 0 0
]T = YNN ∆VN (1)
∆V = V post − V pre
∆VN = ZNN
[0 0 −If4 0 0
]T (2)
ZNN =z12 z12 z12 z12 z12z12 z12 + z23 z12 + z23 z12 + z23 z12z12 z12 + z23 z12 + z23 + z34 z12 + z23 + z34 z12z12 z12 + z23 z12 + z23 + z34 z12 + z23 + z34 + z45 z12z12 z12 z12 z12 z26
9-11 September 2018 - 50th North American Power Symposium
MIP Formulation For a Simple Single Phase Network
I Now we will assume that the fault location and magnitude are unknown.I Hence a binary variable is introduced for each bus ui as shown in (3). If there a
fault on bus i then ui=1 , If not ui = 0
∆VN = ZNN
[−u2If2 −u3If3 −u4If4 −u5If5 −u6If6
]T(3)
9-11 September 2018 - 50th North American Power Symposium
MIP Formulation For a Simple Single Phase Network
I Now will replace uiIfi with Ixi
∆VN = ZNN
[−Ix2 −Ix3 −Ix4 Ix5 Ix6
]T(4)
Ixi ={
Ifi, if ui = 10, if ui = 0
(5)
I If the system has only one fault, then the inequality constrains is imposed
6∑i=2
ui ≤ 1 (6)
9-11 September 2018 - 50th North American Power Symposium
MIP formulation for a simple single phase networkI Note that If is a phasor so its real and imaginary parts will be considered
separately using the big-M technique as shown in (6)
− (1 − ui)M + Re(Ifi) ≤ Re(Ixi) ≤ Re(Ifi) + (1 − ui)M− (1 − ui)M + Im(Ifi) ≤ Im(Ixi) ≤ Im(Ifi) + (1 − ui)M− uiM ≤ Re(Ixi) ≤ +uiM
− uiM ≤ Im(Ixi) ≤ +uiM
(7)
if ui = 1
Re(Ixi) = Re(Ifi)Im(Ixi) = Im(Ifi)
−M ≤ Re(Ixi) ≤ M
−M ≤ Im(Ixi) ≤ M
if ui = 0
Re(Ixi) = 0Im(Ixi) = 0
9-11 September 2018 - 50th North American Power Symposium
The Overall MIP Problem FormulationI The objective function is the sum of the norm 2 of the error between the
measured and estimated voltage deviation values.I The measured voltage values are collected using MicroPMUs located at the end of
the branched + the first bus after the source bus.
minimize∑i∈E
‖∆Vmeas
i −∆Vi‖ (8a)
subject to∑i∈N
ui ≤ 1 (8b)
∆VN = −ZNN Ix (8c)
−uiM ≤ Re(Ixi) ≤ +uiM (8d)
−uiM ≤ Im(Ixi) ≤ +uiM (8e)
−(1− ui)M + Re(Ifi) ≤ Re(Ixi) ≤ Re(Ifi) + (1− ui)M (8f)
−(1− ui)M + Im(Ifi) ≤ Im(Ixi) ≤ Im(Ifi) + (1− ui)M (8g)
(8h)
where E is the set of the buses located at the end of each branch and the bus closest to the substation bus, N is the set of the buses exceptthe substation bus.
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
MIP Formulation for Three-Phase Distribution SystemsI If three phase fault occurs at Bus4, the faults currents can be calculated as shown
in (8).
Figure: Simple 6-Node Network
A fault location binary variable ui isdesignated to each phase in each busexcept substation bus
0...0−Ia
f4−Ib
f4−Ic
f40...0
= Y
abcNN
∆V a
2∆V b
2∆V c
2...
∆V a6
∆V b6
∆V c6
(9)
∆Vabc
N = ZabcNN
−u2 Ia
f2−u3 Ib
f2−u4 Ic
f2...
−u14 Iaf6
−u15 Ibf6
−u16 Icf6
(10)
9-11 September 2018 - 50th North American Power Symposium
MIP Formulation For Three-Phase Distribution SystemsI To exclude the possibility of having faults between phases from different buses,
Another location binary variable ki is designated to each bus except thesubstation bus.
I For the 6-node network, The dimension of u is 15, and the dimension of k is 5.
u2 + u3 + u4 = 3(k2)u5 + u6 + u7 = 3(k3)u8 + u9 + u10 = 3(k4)u11 + u12 + u13 = 3(k5)u14 + u15 + u16 = 3(k6)
(11)
∑ki = 1 (12)
I When a fault happened at Bus 2 , k2 = 1 and all the phase binaries at that busare equal to 1, however that does not mean all the phases are under fault.
I The magnitude of the current will determine the faulted phase.
9-11 September 2018 - 50th North American Power Symposium
The Overall Three-Phase MIP Problem Formulation
minimize∑i∈E
‖∆V abc,measi −∆V abc
i ‖
subject to ∆V abcN = −Zabc
NN Iabcx (13a)
−uiM ≤ Re(Ixi) ≤ +uiM (13b)−uiM ≤ Im(Ixi) ≤ +uiM (13c)
−(1− ui)M + Re(Ifi) ≤ Re(Ixi) ≤ Re(Ifi) + (1− ui)M (13d)−(1− ui)M + Im(Ifi) ≤ Im(Ixi) ≤ Im(Ifi) + (1− ui)M (13e)
for all i ∈ Bua + ub + uc = 3(ki) (13f)∑i∈E
ki = 1 (13g)
for all i ∈ N
where E is the set of the microPMU phases, N is the set of the buses except the substation bus. B is the set ofthe phases except the substation bus’s phases.
9-11 September 2018 - 50th North American Power Symposium
Outline
IntroductionUtility performance evaluationA common used methodOur objective
The Advantages of the MIP-Based Proposed method
MIP Formulation for a Simple Single Phase Network
MIP formulation for Three-Phase Distribution Systems
Numerical example
9-11 September 2018 - 50th North American Power Symposium
Numerical example
I Very unbalanced feeder.I (PQ,I and Z) loads.I UngroundedI micro-PMUs are placed at the end of
the branches as shown in the figure.
799
701 742
705 702 720
704 713
707 722
703 744 729
728
727 706
725 718
714
730
731 709
708 732
775 733 736
734 710
735 737 738 711 741
740
724
712
Micro-PMU
Figure: Modified version IEEE-37 Test Feeder
9-11 September 2018 - 50th North American Power Symposium
Numerical exampleI All the single phase faults were identified correctly. (108 tests for each transformer
configuration)
Table: Phase-to-Ground faults (∆ - ∆)
Identification Results OpenDSS MeasurementsLocation Obj IF ∠IF Iflow ∠Iflow729.b 0.070 2.111 -36 2.225 -33.5711.c 0.170 2.064 -158.9 2.188 -156.1702.b 0.053 2.124 -36 2.240 -33.5775.a 0.002 4.9e10−4 -97.5 5.3e10−4 -94.2
Table: Phase-to-Ground faults (∆ - Y )
Identification Results OpenDSS MeasurementsLocation Obj IF ∠IF Iflow ∠Iflow702.a 89.6 2636.2 -100.4 2832.9 -97.3741.c 100.2 1210 38.5 1285.4 41.5707.b 94.2 1513 159.8 1591.9 162.2710.c 99.88 1414.1 36.9 1503.3 39.9
9-11 September 2018 - 50th North American Power Symposium
Double and Three Phase faults
I More than 97% of the double and Three-phase faults were identified correctly.I Only 2-3p Faults at 707 were identified as faults at Bus 722, which is adjacent bus
to Bus 707. By excluding Bus 722 from the searching space, the proposed methodcorrectly identified the faulted bus, which means it was at the second leastobjective function value.
9-11 September 2018 - 50th North American Power Symposium
Double and Three Phase Faults
Table: Double-Phase to Ground faults (∆ - ∆)
Identification Results OpenDSS MeasurementsLocation Obj Ia
F IbF Ia
flow Ibflow
736.ab 155.1 1147.7 1168.5 1263.8 1262.9714.ab 165.8 1992.8 2027.1 2191.5 2191742.ab 153.3 1954.4 1990 2151.1 2150.4775.ab 39.07 10630.7 10869.4 11796 11796
Table: Double-Phase Faults (∆ - Y )
Identification Results OpenDSS MeasurementsLocation Obj Ia
F IbF Ia
flow Ibflow
735.ab 140.6 1581.4 1446.2 1706.4 1583.4704.ab 172.7 2407.3 2172 2576.5 2375.5728.ab 119 2150.6 1934.4 2309.4 2120.3731.ab 84.5 2018.3 1788.3 2171.7 1962
Table: Three-Phase Faults (∆ - ∆)
Identification Results OpenDSS MeasurementsLocation Obj Ia
F IbF Ic
F Iaflow Ib
flow Icflow
727.abc 131.69 2231.8 2377.5 2242 2500.8 2573.9 2434.4708.abc 140.2 1998.6 2159.2 2027.1 2242.2 2337.3 2197.2738.abc 216.4 1545.8 1715.9 1606.5 1741.1 1859.7 1738.3720.abc 257 2030.3 2188.6 2070.9 2261.3 2366.7 2253.6
Table: Three-phase faults (∆ - Y )
Identification Results OpenDSS MeasurementsLocation Obj Ia
F IbF Ib
F Iaflow Ib
flow Ibflow
725.abc 265 1757.7 1904.1 1807.7 1956.6 2059.5 1966.6744.abc 152.7 2142.3 2282.5 2152.9 2399.9 2472.2 2336.3732.abc 153.2 1864.8 2015.8 1899.3 2092.1 2182.2 2058.3737.abc 204 1631.1 1787.8 1683.1 1836.2 1938.5 1820.9
9-11 September 2018 - 50th North American Power Symposium
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