Active Electrical Distribution Network. Группа авторов
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Название: Active Electrical Distribution Network
Автор: Группа авторов
Издательство: John Wiley & Sons Limited
Жанр: Физика
isbn: 9781119599579
isbn:
Nbs = total number of buses
Number of branches should be:
Nbs = number of buses
Ns = number of sources
All the loads should get a supply every time of reconfiguration.
The use of heuristic approaches can reduce the complexity of the network reconfiguration problem. In this chapter, a heuristic approach has been used to solve network reconfiguration problems. The following points show the detail outlines of the used heuristic algorithm.
2.6.3 Algorithm
1 Read the system input data required for load flow.
2 Run the load flow program for the distribution network and compute the power loss and voltages at various nodes.
3 Calculate the differences in voltages ΔVtie(x) between the two buses across which different tie switches are placed to be connected; x = 1, 2, 3, … Stie, where Stie = number of tie switches.
4 Form a table for the above calculated voltage differences for all of the tie switches.
5 From the above table, select the tie switch for which the value of ΔVtie(x) is maximum. Suppose it is the tie switch ‘n’ such that (ΔVtie,max = ΔVtie(n)).
6 Compare the value of the (ΔVtie,max) with a set threshold value (θ). If ΔVtie,max is greater than the threshold value, go to the next step, else stop.
7 Compare the node voltages of the two nodes across which the tie switch ‘n’ is connected. Select the node with the smallest value. Let it be the node ‘m’ with node voltage Vm.
8 Close the tie switch ‘n’ and simultaneously open the sectionalizing switch connected to node ‘m’.
9 Run the load flow for the above reconfigured distribution network and compute the power loss. Let it be Ploss.
10 In the next step, close the previously opened sectionalizing switch and open its adjacent sectionalizing switch within the same loop.
11 Run the load flow for the above reconfigured distribution network and compute the power loss. Let it be P !loss.
12 If P !loss ≥ Ploss, declare the present reconfiguration as the best reconfiguration corresponding to tie switch n, else replace Ploss by P !loss and go to step 10.
13 i = number of iterations. If i < Stie then replace i by i + 1 and go to step 2 to repeat the program to find out the best reconfiguration corresponding to other tie switches, else go to next step.
14 Consider the current reconfiguration as the optimal reconfiguration of the distribution network and run the load flow to calculate the total technical loss (I2R), individual bus voltages, and different line flows.
15 Stop.
At last, the total technical loss (I2R) obtained during the best reconfiguration corresponding to tie switch n (n = 1, 2,…, n) and normal case load flow will be compared. Among all these n + 1 cases, the case for which the total technical loss (I2R) obtained will be minimum will be adopted as the operational network.
2.7 Conclusion
The basic objective behind this chapter is to discuss a theft-handling mechanism for protecting various power equipment/appliances fitted in agricultural feeders during off-feed hours. The discussed method is based on network reconfiguration in which the normal topological structure of the distribution feeder is changed to a new objective-based structure through closing and opening of the sectionalizing and ties switches. If the agricultural feeder is to be included as the part of the feeder reconfiguration, electricity will be made available during off-feed hours, and hence the thieves will not take any risk. The main tasks involved with the discussed methodology are as follows:
To develop a method to decide the locations of different sectionalizing and tie switches in such a way that the inclusion of some of the section of the agricultural feeder in network reconfiguration will not energize the connected pumps.
To develop a method for the selection of tapping points for the agricultural pumps in such a way that the pumps do not draw power during off-feed hours.
To deduce a best suitable method for network reconfiguration based on the contemporary situation and as per the demand of the Feeder Segregation Plan.
To draw up a plan for distribution system automation (DSA) to manage the network reconfiguration.
To determine the optimal switching frequency for network reconfiguration while considering all its dynamics and impacts.
To validate the above proposed methodologies using high-end tools like ETAP/MATLAB.
The potential threat in the theft of line conductors, transformers, and other electrical elements while segregating the agriculture feeder can be reduced through the use of the discussed scheme. Apart from its basic objective, the inclusion of network reconfiguration will also help in reducing technical losses, improving voltage profile, minimizing outages, reducing device failures, minimizing overloading, smoothing peak demand, and increasing the network reliability. It will further contribute towards the national target of achieving AT&C loss minimization. The outcomes from the discussed methodology will give thrust to the implementation of the Feeder Segregation Plan (FSP) across different Indian states. It will enhance the confidence of the various Indian utilities and provide motivation in implementing the FSP.
As the network reconfiguration has been proposed to be implemented through distribution system automation in the discussed work, this methodology can be initiated as a demand-side management (DSM) program. The nature of the discussed scheme is such that the utilities can implement the plan without depending upon consumer mind sets to control their consumption. The discussed scheme will also help toward improved management of environmental resources through husbanding ground water.
References
1 [1] P. Rathore, G. Agnihotri, B. Khan, and G. Gupta, “Transmission pricing scheme under contingency conditions in open access market,” 18th IEEE National Power Systems Conference (NPSC), pp. 1, 6, 18–20 December 2014.
2 [2] P. Rathore, G. Agnihotri, B. Khan, and G. Gupta, “Transmission pricing based on power flow tracing methodology with consideration of system reliability,” IEEE Students Conference on Engineering and Systems (SCES), pp. 1–6, May 2014.
3 [3] A.S. Mishra, B. Khan, and G. Agnihotri, “Embedded cost allocation with Shapley approach using tracing and sensitivity factors to identify coalition cost: A comparative study,” Proceedings of The EE Centenary Conference, IISc, Bangalore, 15–17 December 2011.
4 [4] B. Khan, G. Agnihotri, G. Gupta, and P. Rathore, “A power flow tracing based method for СКАЧАТЬ