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CHAPTER - 5
NETWORK RECONFIGURATION
_______________________________________________________________________________________________________
5.1 INTRODUCTION
Network Reconfiguration is the process of operating switches to
change the circuit topology so that operating costs are reduced while
satisfying the specified constraints. These constraints include radial
configuration, serving all loads, coordination of protective devices,
keeping all the equipment within current capacity limits and the
voltage drop within limits. Distribution network reconfiguration for
loss reduction and load balancing is a complicated combinatorial, non
- differentiable, constrained optimization problem since the
reconfiguration involves many candidate-switching combinations. The
problem precludes algorithms that guarantee a global optimum. Most
existing reconfiguration algorithms fall into two categories. In the first,
branch exchange, the system operates in a feasible radial
configuration and the algorithm opens and closes candidate switches
in pairs. In the second, loop cutting, the system is completely meshed
and the algorithm opens candidate switches to reach a feasible radial
configuration.
An algorithm for minimum loss reconfiguration of distribution
system is proposed based on Sensitivity and Heuristics [100]. A
codification algorithm is proposed for network reconfiguration for loss
reduction [101]. The loss minimum distribution system
reconfiguration is obtained using hyper cube ant colony optimization
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[102]. The algorithm proceeds towards final configuration by
introducing variations according to heuristic rules from the initial
configuration. A sequential method for loss minimum reconfiguration
and an extended algorithm for service restoration are presented in
[108]. The network reconfiguration based on a Benders decomposition
approach integrated with optimal power flow is presented [109]. A
mixed integer quadratic constrained program for solving
reconfiguration problem is proposed [116]. A Meta – heuristic method
using modified Tabu – search algorithm is proposed for distribution
system reconfiguration [120]. Implementation of an evolutionary
algorithm [122] is presented for network reconfiguration to minimize
loss and disruption costs. The efficiency of loss estimation technique
and reconfiguration approach affects the efficiency of network
reconfiguration of distribution systems [125]. A coloured Petri net
algorithm for load balancing in radial distribution system is proposed
[67]. A method using GA is presented for load balancing through
reconfiguration [90].
This chapter presents PGSA for radial distribution system
network reconfiguration to minimize power loss and/or to keep load
balancing while satisfying its constraints. The proposed method
handles objective function inclusive of the constraints. One of the
major advantages of PGSA is better searching performance than the
published random algorithms in the literature [73]. The effectiveness
of PGSA to network reconfiguration is illustrated with the help of
examples.
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5.2 PROBLEM FORMULATION FOR LOSS REDUCTION
The objective function of the network reconfiguration to
minimize the power loss in the system is given below.
Minimize F = min P + λ S + λ SV IT, Loss CV CI (5.1)
where, PT,Loss is the total active power loss in the system.
λV and λI parameters are the penalty constants.
SCI is the squared sum of the violated current constraints and SCV is
the squared sum of the violated voltage constraints.
Moreover, the penalty constants are determined as follows:
(i) Constant λI (λV) is given a value of ‘0’, if the associated current
(voltage) constraint is not violated.
(ii) λI (λV) is given a significant value if the associated current (voltage)
constraint is violated. These considerations make the objective
function to move away from the unfeasible solutions.
The voltage magnitude at each node must be maintained within
specified limits. The current in each branch must satisfy the branch
current carrying capacity.
These constraints are expressed as follows:
maximin VVV (5.2)
max,jj II (5.3)
where iV is voltage magnitude of node i, minV and maxV are
minimum and maximum node voltage magnitude limits, jI and Ij,max
are current magnitude and maximum current limit of branch j,
78
respectively. Backward - forward sweep power flow method is used as
described in the section 2.2 to prevent complicated computation.
5.3 LOAD BALANCING
Usually it appears a mixture of domestic, commercial and
industrial type of loads, varying from time to time, on distribution
lines. Each of these has different characteristics and requirements.
From this one can understand that some parts of the distribution
system are heavily loaded at certain times and less loaded at other
times in a day. In order to reschedule the load currents more
efficiently for loss minimization, it is required to transfer the loads
between the substations or feeders and modify the topology of the
distribution feeders without changing the radial structure.
5.3.1 Load Balancing Problem Formulation
The objective function for load balancing is presented in this
section. The function consists of two components. One is the system
load balancing index and the other is the branch load balancing
index. The branch Load Balancing index (LBj) is defined as a measure
of how much a branch can be loaded without exceeding the rated
capacity of that branch. The load on the entire system is indicated by
system Load Balancing index (LBsys). The objective is to optimize the
branch load balancing indices so that the system load balancing index
is minimized. In other words, all the branch load balancing indices are
set to be more or less the same value and are also nearly equal to the
system load balancing index.
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The load balancing problem is formulated in the form of branch
load balancing and system load balancing indices [20] as
The branch load balancing index,SjLB = maxj Sj
(5.4)
The system load balancing index, Snb j1LB =sys maxnb Sj=1 j
(5.5)
where, nb is the total number of branches in the system.
Sj is apparent power of branch j
maxSj is maximum capacity of branch j
5.3.1.1 Objective function
Snb j1Minimize F = maxnb Sj=1 j
(5.6)
By rescheduling the loads the branch load balancing indices
can be optimized and thereby the system load balancing index will be
minimized. In effect, it is made all the branch load balancing indices,
(LBj) are approximately equal to each other and also closely
approximate to the system load balancing index (LBsys).
Mathematically this can be represented as,
SSS nbS j121 n= = ..... = =m ax m ax m ax m axnbS S S Sj=1n1 2 j (5.7)
The objectives to be achieved are,
(i) The system loss must be reduced.
(ii) The voltage magnitude of each node must fall within permissible
limits i.e. maximin VVV
80
(iii) Current capacity of each branch, max,jj II
The condition of a branch will become critical when the load
balancing index of the branch is equal to 1 and if it is greater than 1
the branch rated capacity will be exceeded. The system load balancing
index will be low if the system is lightly loaded and its value will be
closer to zero and the individual branch load balancing indices will
also be low. The load balancing indices of individual branches will
differ widely when the loads are unbalanced. On the other hand the
balanced load will make the load balancing indices of all the branches
nearly equal. Practically it is not possible to make all the branch load
balancing indices exactly equal. However, the branch load balancing
indices can be adjusted with the help of reconfiguration and hence the
system load balancing index can be improved.
5.4 IMPLEMENTATION OF PGSA TO RECONFIGURATION
This section presents implementation of PGSA to the network
reconfiguration problem for loss reduction and/or load balancing.
5.4.1 Decision Variables Design
The switch, usually considered as the decision variable, can be
assigned either a value 0 (zero for open switch) or 1
(one for closed switch) in the distribution network optimization
problem. However, two problems exist, (i) the rudimentary techniques
are unsuitable for the large-scale optimization problem as the number
of possible network states grows exponentially with the number of
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switches, (ii) the optimal reconfiguration may not be obtained since a
lot of unfeasible solutions will appear in the iterative procedure. The
design of decision variables requires more sophisticated techniques to
overcome the above mentioned problems. The independent loops can
be taken as decision variables in distribution system reconfiguration
problem since the number of independent loops is the same as the
number of tie switches.
The network optimization problem to minimize system real
power loss is identical to the problem of selection of an appropriate tie
switch for each independent loop in the system. This can greatly
reduce the network model as the number of the decision variables are
reduced and cause unfeasible solutions to a marked decrease in the
iterative procedure.
Consider an IEEE 16 node distribution system consisting of 13
sectionalizing and 3 tie switches as shown in fig.5.1, to illustrate the
new decision variables. The dotted lines represent initial tie switches
and the sectionalizing switches are represented as thick lines. The
basic procedure to design the new decision variables is given below.
(i) An initial radial network is to be formed with all the sectionalizing
switches in close and all the tie switches in open.
(ii) The first independent loop (nominated loop 1) is to be formed by
closing the first tie switch (S5).
(iii) Number the switches in loop 1 using consecutive integers
assuming the decision variable of loop-1 as x1, and then the numbers
of all switches in loop-1 constitute the possible solution set of x1. For
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example, number the switches S1, S2, S5, S9, S8, S6 in loop-1 using
1, 2, 3, 4, 5, 6 and then get the possible solution set of x1 i.e., integral
set [1 6]. In the same manner, define other decision variables as x2 for
loop 2, x3 for loop 3, and then get their respective possible solution
sets.
Fig. 5.1 Initial configuration of 16 node distribution system
5.4.2 Switch State Description
In the iterative procedure the unfeasible solutions cannot be
avoided when independent loops are taken as decision variables. Here,
to reduce the chance to appear the unfeasible solutions in the iterative
procedure the switches are described in four states. Further it
improves the efficiency of the solution method.
(i) Open state - switch is open in a feasible solution.
(ii) Closed state - switch is closed in a feasible solution.
(iii) Permanent closed state - switch is closed in all feasible solutions.
(iv) Temporary closed state - switch must be closed in a feasible
solution because another switch is open and the switch will be open
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or closed state when the opened switch is closed in another feasible
solution.
The above description makes no need to number the
permanent closed state switches while forming the possible solution
sets of the selected decision variables. Also the number of switches in
temporary closed state can be temporarily deleted in the possible
solution set of the corresponding variable.
Some illuminations about the temporary closed state and
permanent closed state of a switch for fig.5.1 are as given below.
(i) In any feasible and reasonable solution a switch which is close to
the source node should be closed. The switches S1, S6 and S12 in
fig.5.1 belong to such case. Hence no need to number the switches S1,
S6, and S12 while forming the possible solution set of each decision
variable. This reduces the search domain.
(ii) Some switches, which belong to the same two or three independent
loops, are interrelated. Only one of the interrelated switches may be in
open state in a feasible solution. In other words, the possible switches
corresponding to two independent loops must be temporarily closed
while only one switch is in open state. The unfeasible solutions due to
the interrelation of some switches can be avoided by introducing the
concept of temporary closed state.
5.4.3 Constraints Treatment
In PGSA, the constraints are treated in the following way.
(i) Adopting independent loops as decision variables the radial
characteristic of the network is enforced.
84
(ii) The branch capacity and node voltage limits are executed by
checking every possible solution obtained.
Fig.5.2 Flow chart for Network Reconfiguration
5.4.4 Algorithm for Network Reconfiguration
The flow chart is shown in fig.5.2.
Step 1: Read the distribution system data such as line and load data,
constraints limits, Nmax etc. and set iteration count N=0.
85
Step 2: Form the search domain by giving possible tie-line switches,
which corresponds to the length of the trunk and the branch of a
plant.
Step 3: Give the initial solution X0 (X0 is initial configuration) which
corresponds to the root of a plant, and calculate the initial value of
objective function (power loss or load balancing index).
Step 4: Let the initial value of the basic point Xb, which corresponds to
the initial preferential growth node of a plant, and the initial value of
optimization Xbest equal to X0, and let Fbest that is used to save the
objective function value of the best solution Xbest be equal to f(X0),
namely, Xb = Xbest = X0 and Fbest = f(X0).
Step 5: For k=1: n (n is the number of tie lines)
Step 6: For j=1: m (m is the maximum number of possible switches for
kth tie line)
Step 7: Get a possible solution (configuration) Xp from basic point Xb
(initial or updated configuration) by replacing kth element in the basic
point Xb with jth possible switch of kth tie line.
Step 8: Calculate the corresponding objective function (power loss or
load balancing index) for Xp (new configuration).
Step 9: Check for limit constraints and if the objective function f(Xp) <
f(Xb), then save the Xp in feasible solution set, otherwise abandon the
possible solution Xp.
Step 10: From the set of all feasible solutions find the minimal
solution.
86
Step 11: Calculate the probabilities C1, C2, C3,…., Ck of feasible
solutions X1, X2, X3,…., Xk by using equation (3.1), which corresponds
to the morphactin concentration of the nodes of a plant.
Step 12: Calculate the accumulating probabilities ∑C1, ∑C2,………,∑Ck
of the solutions X1, X2, … Xk. Select a random number β from the
interval [0 1], β must belong to one of the intervals [0 ∑C1], [∑C1, ∑C2],
….,[∑Ck-1, ∑Ck], the accumulating probability of which is equal to the
upper limit of the corresponding interval, and in the next iteration this
will be the new basic point Xb, which corresponds to the new
preferential growth node of a plant for next step.
Step 13: Check for N>=Nmax, if yes go to next step else set N=N+1 and
go to step 6 by replacing Xb and Fbest with new growth point and its
corresponding objective function respectively.
Step 14: Print the results for the optimal configuration obtained.
Step 15: Stop.
5. 5 ILLUSTRATIVE EXAMPLES
The proposed method is demonstrated through two different cases.
Case-I: Three different systems consisting of 16, 33 and 69-node
radial distribution systems are tested to demonstrate the loss
reduction through network reconfiguration.
Case-II: Illustrates testing of the Load Balancing through network
reconfiguration of 2 different systems consisting of 33 and 69-node
radial distribution systems.
87
5.5.1 Case I
5.5.1.1 Example - 1
The line and load data of 16 node system is given in table C.1.
The results obtained from the PGSA for a 16 node system are
compared with the existing method [116] in table 5.1. The minimum
voltage is improved in PGSA. The average real power loss reduction is
8.86%. The convergence characteristics are shown in fig.5.3. The node
voltages are tabulated in table 5.2. The power losses are given in table
5.3. The voltage profile is shown in fig.5.4. The final configuration
arrived is shown in fig.5.5 (b).
Table5.1. Results of 16-node radial distribution networkreconfiguration for loss reduction
ItemInitial
Configuration
Final Configuration
Existingmethod
[116]
ProposedPGSA
Tie Switches 5,11,16 7,9,16 7, 9,16
Real Power Loss (kW) 511.44 466.1 466.13
Loss Reduction (%) - 8.85 8.86
Min. Voltage (pu) 0.9693 0.9716 0.9717
No. of Switches Changed - 2 2
Table5.2. Node voltages before and after reconfiguration for 16node system
NodeNo.
|V| (pu) beforeReconfiguration
|V| (pu) afterReconfiguration
1 1.0000 1.0000
2 1.0000 1.0000
3 1.0000 1.0000
88
4 0.9906 0.9907
5 0.9878 0.9879
6 0.9859 0.9860
7 0.9848 0.9849
8 0.9791 0.9814
9 0.9711 0.9734
10 0.9769 0.9899
11 0.9709 0.9879
12 0.9693 0.9717
13 0.9944 0.9923
14 0.9948 0.9907
15 0.9918 0.9897
16 0.9913 0.9891
Table5.3. Power loss before and after reconfiguration for 16 nodesystem
BranchNo.
Before Reconfiguration After Reconfiguration
Ploss (kW) Qloss (kVAr) Ploss (kW) Qloss (kVAr)
1 61.63 82.18 67.80 90.40
2 7.51 10.33 10.63 14.62
3 11.95 23.89 11.94 23.89
4 1.52 1.52 1.52 1.52
5 278.34 278.34 0.25 0.25
6 2.09 2.09 220.94 220.94
7 87.01 119.64 76.53 105.23
8 0.71 0.71 19.61 26.97
9 19.71 27.09 42.51 42.51
10 29.08 29.08 7.87 10.82
11 7.84 10.77 3.71 4.94
12 2.01 2.68 0.74 0.74
13 2.06 2.06 2.07 2.07
Total 511.44 590.38 466.13 544.9
89
Fig.5.3 Convergence characteristics of 16 node system
Fig.5.4 Voltage profile of 16 node radial distribution systembefore and after reconfiguration
(a) Initial Configuration (b) Final configurationFig.5.5 Reconfiguration of 16 node distribution system
90
5.5.1.2 Example - 2
The single line diagram of initial configuration of 33 node RDS is
shown in fig.5.6. The line and load data is tabulated in table C.2. The
node voltages and power loss before and after reconfiguration are
given in table 5.4 and table 5.5 respectively. The proposed PGSA
results are compared with the existing method [116] in the table 5.6.
The loss reduction is 31.39%, which is better compared to existing
method. The minimum voltage is 0.9381 whereas it is 0.9378 with the
existing method. The node voltages before and after reconfiguration
are shown in fig.5.7. The convergence characteristics are shown in
fig.5.8. The final configuration of the 33 node RDS obtained by PGSA
is shown in fig.5.8. It is seen that the PGSA is converged 94 times to
optimum solution.
Table5.4. Node voltages before and after reconfiguration of 33node system
Node No. |V| (pu) beforeReconfiguration
|V| (pu) afterReconfiguration
1 1.0000 1.0000
2 0.9970 0.9971
3 0.9830 0.9870
4 0.9755 0.9825
5 0.9681 0.9781
6 0.9499 0.9673
7 0.9462 0.9667
8 0.9414 0.9626
9 0.9351 0.9592
10 0.9290 0.9627
91
11 0.9282 0.9628
12 0.9269 0.9631
13 0.9208 0.9605
14 0.9185 0.9597
15 0.9171 0.9532
16 0.9157 0.9514
17 0.9137 0.9485
18 0.9132 0.9475
19 0.9965 0.9951
20 0.9929 0.9782
21 0.9922 0.9736
22 0.9916 0.9701
23 0.9794 0.9834
24 0.9727 0.9768
25 0.9694 0.9735
26 0.9478 0.9655
27 0.9452 0.9632
28 0.9337 0.9526
29 0.9254 0.9451
30 0.9220 0.9419
31 0.9178 0.9385
32 0.9169 0.9381
33 0.9166 0.9472
Table5.5. Power loss before and after reconfiguration of 33 nodesystem
BranchNo.
Before Reconfiguration After Reconfiguration
Ploss (kW) Qloss (kVAr) Ploss (kW) Qloss (kVAr)
1 12.24 6.33 11.87 6.14
2 51.79 26.38 26.79 13.65
3 0.16 0.15 2.26 2.16
4 0.83 0.75 18.06 16.27
92
5 0.10 0.12 4.23 4.94
6 0.04 0.06 1.18 1.56
7 19.90 10.14 5.62 5.62
8 3.18 2.17 1.24 0.89
9 5.14 4.06 1.74 1.74
10 1.29 1.01 0.45 0.33
11 18.70 9.52 0.48 0.65
12 37.12 33.02 0.15 0.12
13 1.91 6.33 0.02 0.02
14 2.60 1.32 2.15 2.15
15 3.33 1.69 0.03 0.01
16 11.30 6.86 0.46 0.36
17 7.83 6.82 0.08 0.10
18 3.90 1.98 0.01 0.00
19 1.59 1.58 7.55 3.84
20 0.21 0.25 3.16 2.16
21 0.01 0.02 5.10 4.03
22 4.84 1.60 1.28 1.00
23 4.18 3.00 6.65 3.39
24 3.56 2.52 13.19 11.39
25 0.55 0.18 0.06 0.21
26 0.88 0.29 2.23 1.14
27 2.69 2.10 2.84 1.45
28 0.73 0.96 9.60 8.46
29 0.36 0.32 6.62 5.77
30 0.28 0.21 3.25 1.65
31 0.25 0.34 1.09 1.08
32 0.05 0.04 0.12 0.14
TotalLoss
201.54 132.11 138.46 102.42
93
Table5.6. Results of 33-node radial distribution networkreconfiguration for loss reduction
ItemInitial
Configuration
Final Configuration
Existingmethod
[116]by PGSA
Tie Switches 33,34,35,36,37 7,9,14,37,32 7,14,9,32,37
Real Power
Loss (kW)201.54 139.55 138.46
Loss
Reduction
(%)
- 30.76 31.39
Min. Voltage
(pu)0.9132 0.9378 0.9381
No. of
Switches
Changed
- 4 4
Fig.5.6 Initial configuration of 33 node system
94
Fig.5.7 Voltage profile of 33 node radial distribution systembefore and after reconfiguration
Fig.5.8 Convergence characteristics of 33 node system
Fig.5.9 Final configuration of the 33 node system
95
5.5.1.3 Example – 3
The initial configuration of the 69 node system is shown in
fig.5.10. The line and load data is given in the table C.3. In table 5.7
the summary of results obtained by the PGSA for the 69 node system
is given. It is run for 100 times out of which PGSA converged to
optimum solution 94 times with an average loss reduction of 55.59%.
The convergence characteristics are shown in fig.5.11. The node
voltages before and after reconfiguration is given in table 5.8 and also
is shown in fig.5.12. The power losses are given in table 5.9. The
reconfigured 69 node radial distribution system is shown in fig.5.13.
Fig.5.10 Initial configuration of 69 node system
Table5.7. Results of 69-node radial distribution networkreconfiguration for loss reduction
ItemInitial
ConfigurationFinal Configurationby proposed PGSA
Tie switches 69,70,71,72,73 69,70,14,56,61
96
Real Power loss (kW) 224.44 99.62
Power loss reduction (%) - 55.59
Min. Voltage (pu) 0.9094 0.9428
No. of switches changed - 3
Fig.5.11 Convergence characteristics of 69 node system
Fig.5.12 Voltage profile of 69 node radial distribution system
before and after reconfiguration
97
Fig.5.13 Final configuration of the 69 node systemTable5.8. Node voltages before and after reconfiguration of 69
node system
NodeNo.
|V| (pu) beforeReconfiguration
|V| (pu) afterReconfiguration
1 1.0000 1.0000
2 1.0000 1.0000
3 0.9999 0.9999
4 0.9998 0.9999
5 0.9990 0.9997
6 0.9901 0.9975
7 0.9808 0.9954
8 0.9786 0.9947
9 0.9775 0.9945
10 0.9726 0.9917
11 0.9715 0.9912
12 0.9684 0.9900
13 0.9653 0.9898
14 0.9624 0.9898
15 0.9596 0.9802
16 0.9590 0.9792
98
17 0.9581 0.9774
18 0.9580 0.9773
19 0.9578 0.9761
20 0.9575 0.9752
21 0.9569 0.9739
22 0.9569 0.9738
23 0.9569 0.9734
24 0.9566 0.9723
25 0.9565 0.9703
26 0.9565 0.9694
27 0.9563 0.9689
28 0.9999 0.9999
29 0.9998 0.9999
30 0.9997 0.9997
31 0.9997 0.9997
32 0.9996 0.9996
33 0.9994 0.9993
34 0.9992 0.9990
35 0.9990 0.9989
36 0.9999 0.9999
37 0.9997 0.9990
38 0.9996 0.9980
39 0.9996 0.9977
40 0.9995 0.9977
41 0.9988 0.9914
42 0.9987 0.9888
43 0.9985 0.9884
44 0.9985 0.9883
45 0.9984 0.9874
46 0.9984 0.9874
47 0.9998 0.9997
99
48 0.9986 0.9964
49 0.9948 0.9854
50 0.9942 0.9828
51 0.9788 0.9947
52 0.9788 0.9947
53 0.9747 0.9944
54 0.9716 0.9943
55 0.9669 0.9942
56 0.9627 0.9942
57 0.9402 0.9942
58 0.9291 0.9523
59 0.9248 0.9523
60 0.9197 0.9484
61 0.9126 0.9428
62 0.9124 0.9628
63 0.9118 0.9628
64 0.9112 0.9630
65 0.9094 0.9654
66 0.9715 0.9911
67 0.9715 0.9911
68 0.9679 0.9896
69 0.9679 0.9896
Table5.9. Power loss before and after reconfiguration of 69 nodesystem
BranchNo.
Before Reconfiguration After ReconfigurationPloss (kW) Qloss (kVAr) Ploss (kW) Qloss (kVAr)
1 0.08 0.18 0.07 0.17
2 0.08 0.18 0.07 0.17
3 0.20 0.47 0.12 0.30
4 0.00 0.00 0.00 0.00
5 0.00 0.00 0.03 0.07
6 0.02 0.04 0.42 1.02
100
7 0.02 0.02 0.64 0.75
8 0.01 0.01 0.19 0.22
9 0.00 0.00 0.01 0.01
10 0.05 0.06 3.93 4.59
11 0.02 0.02 1.67 1.95
12 0.00 0.00 0.22 0.26
13 0.00 0.00 0.05 0.06
14 0.01 0.01 0.58 0.73
15 0.00 0.00 0.00 0.01
16 0.00 0.01 4.25 4.25
17 0.01 0.00 0.84 0.28
18 0.00 0.00 1.38 0.46
19 0.01 0.00 0.01 0.00
20 0.01 0.00 0.81 0.27
21 0.01 0.00 0.52 0.17
22 0.00 0.00 0.84 0.28
23 1.94 2.27 0.02 0.01
24 0.02 0.06 0.23 0.07
25 0.58 1.43 0.49 0.16
26 1.63 4.00 0.91 0.30
27 0.12 0.28 0.37 0.12
28 28.30 14.41 0.19 0.06
29 28.40 14.98 1.03 1.03
30 6.91 7.10 0.71 0.36
31 3.38 2.92 0.01 0.00
32 0.00 0.00 0.00 0.00
33 0.00 0.00 0.00 0.01
34 4.79 1.58 0.01 0.00
35 5.79 2.95 0.00 0.00
36 6.73 3.43 0.01 0.00
37 9.14 4.66 0.01 0.00
38 8.81 4.49 0.01 0.00
101
39 49.78 16.71 0.00 0.00
40 24.54 8.23 0.11 0.13
41 9.52 3.15 0.17 0.41
42 10.69 3.25 4.19 10.25
43 14.05 7.16 13.29 32.52
44 0.11 0.06 2.55 6.25
45 0.14 0.07 38.24 38.24
46 0.66 0.34 0.00 0.00
47 0.04 0.02 6.33 1.92
48 1.02 0.34 8.32 4.24
49 2.20 0.73 1.59 0.81
50 0.00 0.00 1.64 0.84
51 0.00 0.00 0.35 0.36
52 1.29 0.43 0.12 0.11
53 0.02 0.01 0.00 0.00
54 0.00 0.00 0.00 0.00
55 1.25 0.41 1.43 0.47
56 1.21 0.40 0.01 0.00
57 0.22 0.07 0.00 0.00
58 0.32 0.11 0.00 0.00
59 0.00 0.00 0.00 0.00
60 0.10 0.03 0.00 0.00
61 0.07 0.02 0.29 0.09
62 0.11 0.04 0.32 0.11
63 0.00 0.00 0.00 0.00
64 0.01 0.00 0.00 0.00
65 0.01 0.00 0.00 0.00
66 0.01 0.00 0.02 0.01
67 0.00 0.00 0.00 0.00
68 0.00 0.00 0.00 0.00
TotalLoss 224.44 107.14 99.62 114.9
102
5.5.2 Case II
5.5.2.1 Example – 1
The proposed method for load balancing is tested on 33 node
radial distribution system shown in fig.5.6. The node voltages and
power loss before and after load balancing is given in tables 5.10 and
5.11 respectively. The summary of results obtained from the PGSA is
given in table 5.12. The minimum voltage is improved from 0.9132 pu
to 0.9171 pu. The configuration of the 33 node system after load
balancing is shown in fig.5.14. The voltage profile and convergence
curves are shown in fig.5.15 and 5.16 respectively.
Table5.10. Node voltages of a 33 node system before and after
Load Balancing
NodeNo.
|V| (pu) before loadbalancing
|V| (pu) after loadbalancing
1 1.0000 1.0000
2 0.9970 0.9970
3 0.9830 0.9830
4 0.9755 0.9755
5 0.9681 0.9681
6 0.9499 0.9498
7 0.9462 0.9463
8 0.9414 0.9415
9 0.9351 0.9353
10 0.9291 0.9331
11 0.9282 0.9328
12 0.9269 0.9325
13 0.9208 0.9316
14 0.9185 0.9270
103
15 0.9171 0.9277
16 0.9157 0.9264
17 0.9137 0.9244
18 0.9132 0.9238
19 0.9965 0.9965
20 0.9929 0.9929
21 0.9922 0.9922
22 0.9916 0.9916
23 0.9794 0.9794
24 0.9727 0.9727
25 0.9694 0.9694
26 0.9478 0.9478
27 0.9452 0.9453
28 0.9337 0.9338
29 0.9254 0.9256
30 0.9220 0.9221
31 0.9178 0.9179
32 0.9169 0.9175
33 0.9166 0.9171
Table5.11. Power loss before and after Load balancing
BranchNo.
Before load balancing After load balancing
Ploss (kW) Qloss (kVAr) Ploss (kW) Qloss (kVAr)
1 12.24 6.33 12.20 6.31
2 51.79 26.38 51.61 26.29
3 0.16 0.15 0.16 0.15
4 0.83 0.75 0.83 0.75
5 0.10 0.12 0.10 0.12
6 0.04 0.06 0.04 0.06
7 19.90 10.14 19.80 10.09
8 3.18 2.17 3.18 2.17
9 5.14 4.06 5.14 4.06
104
10 1.29 1.01 1.29 1.01
11 18.70 9.52 18.60 9.48
12 37.12 33.02 38.05 32.85
13 1.91 6.33 1.89 6.26
14 2.60 1.32 2.60 1.32
15 3.33 1.69 3.33 1.69
16 11.30 6.86 11.30 9.96
17 7.83 6.82 7.83 6.82
18 3.90 1.98 3.89 1.98
19 1.59 1.58 1.59 1.57
20 0.21 0.25 0.21 0.25
21 0.01 0.02 0.01 0.02
22 4.84 1.60 4.77 1.58
23 4.18 3.00 4.11 2.95
24 3.56 2.52 0.49 0.35
25 0.55 0.18 2.64 2.63
26 0.88 0.29 0.09 0.08
27 2.69 2.10 0.28 0.20
28 0.73 0.96 0.25 0.33
29 0.36 0.32 0.05 0.04
30 0.28 0.21 0.05 0.02
31 0.25 0.34 0.05 0.02
32 0.05 0.04 0.05 0.04
TotalLoss 201.54 132.12 196.48 131.15
Table5.12. Summary results of 33-node system for load balancing
Item Before load balancing Proposed PGSA
Tie Switches 33,34,35,36,37 33,13,35,36,37
LB Index 0.9438 0.7543
LBsys Reduction (%) - 18.95
Minimum Voltage (pu) 0.9132 0.9171
105
Fig.5.14 Final configuration of 33 node distribution systemafter load balancing
Fig.5.15 Voltage profile of 33 node radial distribution systembefore and after load balancing
Fig.5.16 Convergence curve of 33 node radial distribution systembefore and after load balancing
106
5.5.2.2 Example – 2
Consider 69-node radial distribution network as shown in
fig.5.10. The results obtained from the PGSA are compared with GA
[90] in the table 5.13. The convergence characteristic is shown in
fig.5.17. The PGSA is converged to same solution for 95 times out of
100 times with an average system load balancing index of 0.5667,
whereas genetic algorithm is converged to solution for 59 times, with
an average system load balancing index of 0.6187. The network
diagram after load balancing is shown in fig.5.18. The node voltages
before and after load balancing is given in table 5.14 and also shown
in fig.5. 19. The power loss is given in table 5.15.
Table5.13. Results of 69-node system for load balancing
ItemBeforeload
balancing
After load balancing
GA [90] PGSA
Tie Switches69, 70, 71,
72, 7310,20,13,57,25
10,20,13,58,
25
LB Index 0.9438 0.6187 0.5699
LBsys Reduction (%) - 32.51 37.39
No. of Switches
Changed- 5 5
No. of times best
solution occurred- 59 95
Average execution
time (seconds)- 45.7687 27.3468
107
Fig.5.17 Convergence characteristics of 69 node system for loadbalancing
Fig.5.18 Final configuration of 69 node distribution system afterload balancing
Fig.5.19 Voltage profile of 69 node distribution system before andafter load balancing
108
Table5.14. Node voltages of 69 node system before and after Load
Balancing
NodeNo.
|V| (pu) before loadbalancing
|V| (pu) after loadbalancing
1 1.0000 1.0000
2 1.0000 1.0000
3 0.9999 0.9999
4 0.9998 0.9999
5 0.9990 0.9998
6 0.9901 0.9989
7 0.9808 0.9980
8 0.9786 0.9978
9 0.9775 0.9977
10 0.9726 0.9976
11 0.9715 0.9848
12 0.9684 0.9828
13 0.9653 0.9816
14 0.9624 0.9856
15 0.9596 0.9856
16 0.9590 0.9854
17 0.9581 0.9850
18 0.9581 0.9850
19 0.9578 0.9850
20 0.9575 0.9850
21 0.9569 0.9808
22 0.9569 0.9808
23 0.9569 0.9807
24 0.9566 0.9807
25 0.9565 0.9807
26 0.9565 0.9245
27 0.9563 0.9243
109
28 0.9999 0.9999
29 0.9998 0.9999
30 0.9997 0.9997
31 0.9997 0.9997
32 0.9996 0.9996
33 0.9994 0.9993
34 0.9992 0.9990
35 0.9990 0.9989
36 0.9999 0.9999
37 0.9997 0.9989
38 0.9996 0.9979
39 0.9996 0.9976
40 0.9995 0.9976
41 0.9988 0.9909
42 0.9987 0.9881
43 0.9985 0.9877
44 0.9985 0.9877
45 0.9984 0.9874
46 0.9984 0.9874
47 0.9998 0.9997
48 0.9986 0.9958
49 0.9948 0.9827
50 0.9942 0.9796
51 0.9788 0.9978
52 0.9788 0.9978
53 0.9747 0.9977
54 0.9716 0.9976
55 0.9669 0.9975
56 0.9627 0.9975
57 0.9402 0.9975
58 0.9291 0.9975
59 0.9248 0.9407
110
60 0.9197 0.9357
61 0.9126 0.9282
62 0.9124 0.9279
63 0.9118 0.9275
64 0.9112 0.9255
65 0.9094 0.9246
66 0.9715 0.9848
67 0.9715 0.9848
68 0.9679 0.9825
69 0.9679 0.9825
Table5.15. Power loss before and after Load balancing for 69 nodedistribution system
BranchNo.
Before load balancing After load balancing
Ploss (kW) Qloss (kVAr) Ploss (kW) Qloss (kVAr)
1 0.08 0.18 0.07 0.18
2 0.08 0.18 0.07 0.18
3 0.20 0.47 0.12 0.30
4 0.00 0.00 0.00 0.00
5 0.00 0.00 0.03 0.08
6 0.02 0.04 0.46 1.13
7 0.02 0.02 0.71 0.83
8 0.01 0.01 0.21 0.24
9 0.00 0.00 0.01 0.01
10 0.05 0.06 4.40 5.13
11 0.02 0.02 1.86 2.18
12 0.00 0.00 0.25 0.29
13 0.00 0.00 0.01 0.01
14 0.01 0.01 1.41 1.41
15 0.00 0.00 0.88 0.29
16 0.00 0.01 0.00 0.00
17 0.01 0.00 0.00 0.00
111
18 0.00 0.00 0.24 0.08
19 0.01 0.00 0.02 0.01
20 0.01 0.00 0.00 0.00
21 0.01 0.00 0.11 0.11
22 0.00 0.00 0.00 0.00
23 1.94 2.27 0.00 0.00
24 0.02 0.06 0.00 0.00
25 0.58 1.43 0.00 0.00
26 1.63 4.00 0.06 0.08
27 0.12 0.28 0.00 0.00
28 28.30 14.41 0.27 0.27
29 28.41 14.98 0.00 0.00
30 6.91 7.10 0.05 0.02
31 3.38 2.92 0.05 0.02
32 0.00 0.00 0.00 0.00
33 0.00 0.00 0.00 0.00
34 4.79 1.58 0.00 0.00
35 5.79 2.95 0.00 0.01
36 6.73 3.43 0.01 0.00
37 9.14 4.66 0.00 0.00
38 8.81 4.49 0.01 0.00
39 49.78 16.71 0.01 0.00
40 24.54 8.23 0.01 0.00
41 9.52 3.15 0.00 0.00
42 10.69 3.25 0.02 0.02
43 14.05 7.16 0.23 0.57
44 0.11 0.06 5.77 14.13
45 0.14 0.07 18.52 45.31
46 0.66 0.34 3.79 9.28
47 0.04 0.02 62.44 62.44
48 1.02 0.34 10.68 3.24
49 2.20 0.73 14.04 7.15
112
50 0.00 0.00 0.13 0.07
51 0.00 0.00 0.16 0.08
52 1.29 0.43 0.77 0.39
53 0.02 0.01 0.09 0.04
54 0.00 0.00 0.01 0.01
55 1.25 0.41 0.00 0.00
56 1.21 0.40 0.26 0.13
57 0.22 0.07 0.27 0.14
58 0.32 0.11 0.05 0.05
59 0.00 0.00 0.01 0.01
60 0.10 0.03 0.00 0.00
61 0.07 0.02 0.00 0.00
62 0.11 0.04 0.01 0.00
63 0.00 0.00 0.01 0.00
64 0.01 0.00 0.00 0.00
65 0.01 0.00 0.00 0.00
66 0.01 0.00 0.00 0.00
67 0.00 0.00 0.00 0.00
68 0.00 0.00 0.00 0.00
TotalLoss 224.45 107.14 128.59 155.92
5.6 CONCLUSIONS
In this chapter, the PGSA has been proposed to reconfigure
distribution network for loss reduction and/or to keep load balancing.
The problem is formulated as a non-linear optimization problem with
an objective function of minimizing system losses and/or load
balancing index subject to security constraints. The test results have
been presented for loss minimization and/or load balancing through
the network reconfiguration.