 Research
 Open access
 Published:
Butterfly optimizerassisted optimal integration of REDG units in hybrid AC/DC distribution microgrids based on minimum operational area
Journal of Electrical Systems and Information Technology volumeÂ 8, ArticleÂ number:Â 13 (2021)
Abstract
This paper presents the impact of optimal location and sizing of renewable and nonrenewablebased distributed generators in the AC/DC microgrid system using the latest optimizer called butterfly optimization algorithm with an aim to minimize power loss. Generally, hybrid AC/DC microgrids systems are modeled by separating AC and DC feeders with the help of highpower converters (HPC).AC grids sustained by substation and DC grids are maintained by their individual DG units. While planning of DGs in the hybrid AC/DC systems, the power loss incurred by HPCs is not considered avoiding complexity by many authors. In this paper, the sizing of DGs is determined by the operational area required by the type of DG technology as one variable and all possible candidate buses in the respective zones of AC/DC microgrid system are another variable with due consideration of HPC losses in AC/DC microgrid system. A hybrid AC/DC MG system is developed by classifying the existing benchmark 33bus and 69bus radial distribution systems into various AC/DC zones. To evaluate the proposed approach, it is implemented on aforementioned microgrid systems and the obtained results are verified with other existing approaches in the literature. The results proved that the proposed approach is better than the other approaches in technical aspects.
Introduction
The mass accessibility of sustainable power sources is successfully used in giving uninterruptable power supply to islanded zones. By definition, a microgrid is an assembly of interconnected dispersed energy sources and loads within clearly defined electrical boundaries that can be operated in a coordinated and controlled way either while connected to the central grid or while island mode [1]. Microgrids are categorized into AC and DC microgrids based on the type of power flow and connected loads. The problems associated with AC microgrids such as reactive power flow, current harmonics, failure of transformers and protection equipment and unbalanced loading of phases create a way to encourage DC microgrids with DC loads served by dedicated DC sources like SPVDG (solar photovoltaicbased distributed generator), MTDG (microturbinebased distributed generator), FCDG (fuel cellbased distributed generator) and etc. [2]. In general, a distribution system consists of both AC and DC loads and to serve the DC loads connected to the system they must have interfaced through high power converters (AC/DC) which intern contributes harmonic content and conversion losses to the system. To avoid these, DC microgrid systems are designed and integrated as a part of the AC microgrid system with the help of HPCs (highpower converter) which can act as an individual grid system and also supports the AC grid system in the case of substation failure to meet the load demand [3].
Optimal allocation of DGs in distribution systems is an attractive research area by considering technical as well as economic benefits which is a nonlinear optimization problem and can be solved by either single objective or multiobjective formulation using any efficient optimizers. In the beginning, many authors proposed solutions for OPDG (optimal placement of DG) problem based on technical benefits such as power loss minimization, voltage profile improvement, reliability improvement and economic benefits like net profit maximization, and minimization of operating cost as an objective functions by considering either DG locations or DG sizes as variables under different load models using GA (genetic algorithm) [4,5,6,7,8,9], TS (tabu search) [10], PSO (particle swarm optimization) [11, 12], ACO (ant colony optimizer) [13], ABC (artificial bee colony) [14], DE (differential evolution) [15], HS (harmony search) [16], SA (simulated annealing) [17], BS (back tracking search) and BA (bat algorithm) [18], MOIDSA (multiobjective improved differential search algorithm) [19]. The sensitivity approachbased optimal DG allocation methods and its comparison are presented by authors [20, 21]. Optimal allocations of DGs and DSTATCOMs simultaneously in radial distribution systems using PSO algorithms have been presented by authors [22]. The authors presented [23] the allocation of DGs and DSTATCOMs in a radial distribution system using the WDO (winddriven optimization) algorithm under the daily load pattern. Environmentally committed shortterm planning of renewablebased DGs sizing and siting in electrical distribution systems is presented in [24]. The integration of multiple DGs in the islanded operation of distribution systems in a deregulated environment is presented by authors [24, 25].
DGs based on renewable energy are more popular and beneficial, due to abundant availability of sources, the latest advancements in technology and encouragement from the government side. Renewable energybased DGs are capable of acting as a standalone mode as well as gridconnected mode. This idea leads to the microgrids concept suggestible not only for rural areas (where the transportation of fuel is difficult) but also for the urban areas to cater to the needs of various customers. So, many researchers have been concentrated on the planning of energy resources in microgrids for achieving maximum profits. The grid system is always a combination of AC and DC loads. Hence, highpower converters are essential and inevitable to serve DC loads. The utilization of HPC in the AC grid system may increase the system loss level and also injects harmonics into the system. So, DC microgrids are separated from the AC grid system with the help of HPCâ€™s and independent energy sources to cater the needs of particular DC zones. In case, if the AC grid fails to serve the connected load due to some reasons, then DC microgrid can share the priority loads of AC grid through HPC. Fuel cells can potentially be integrated with solarPV technology to provide zeroemissions alternatives to fossil fuels. The energy generation cost of solarPV systems continues to decrease year by year. By extension, hydrogen technologies that run with solar power also become cheaper to operate. Microgrids with energy storage devices act as energy hubs that can store both electrical and thermal energy to serve the load demand [26]. A twostage methodology is used to determine optimal locations based on LRSF (loss reduction sensitive factor) and then optimal sizing of REDGs in prefixed locations by using HNMCS algorithm with an objective of minimization of power loss by considering area required by DG type to calculate DG size as variable in AC/DC microgrids [27] with neglected HPC losses and operating efficiency. In AC/DC networks, HPCs will have a significant role that can control bidirectional power flows. A typical HPC will operate with an average efficiency of 90% remaining 10% is considered as conversion losses [28].
From the literature, it is evident that the optimal allocation of DGs in a distribution system will definitely improve the system performance. Hence, the selection of suitable DG type followed by identifying the optimal size of DG and its placement is a nonlinear optimization problem that can be solved by proper formulation of the objective function and efficient optimizer. This paper presents a methodology to determine optimal allocation of REDGs in AC/DC microgrid system with an objective of power loss minimization which includes HPC conversion losses by considering not only area required by REDGs to compute the size of REDG but also locations for the integrating REDGs simultaneously as variables using efficient and novel optimizer called butterfly optimizer (BO) to satisfy the AC/DC loads under various system constraints. The proposed methodology is tested on small and mediumscale hypothetical AC/DC microgrids under different cases, and obtained results are compared with the existing results from the literature.
Methods
AC load flow model
AC load flow algorithm is performed to calculate the voltage magnitudes of the buses and branch currents of the system. Traditional backward/forward sweepbased load flow has taken as a load flow algorithm.
AC microgrid with N_{AC} number of buses, ith bus current \(I_{{i,{\text{AC}}}}\) is given by
where \(P_{{{\rm Li,AC}}}\), \(Q_{{{\rm Li,AC}}}\) are the active and reactive power demand at ith bus and \(V_{{i, {\text{AC}}}}\) is the voltage magnitude of an ith bus.
During backward sweep of the backward/forward based load flow, the branch currents are obtained with the help of businjections to branch currents matrix (BIBC) as follows
During forward sweep of the backward/forward based load flow, the bus voltages are calculated with the help of branch current to bus voltage matrix (BCBV) as follows:
Repeat Eqs. (2) and (3) until the difference between the voltages of two adjacent iterations is less than the tolerance value (Îµ).
DC load flow model
DC microgrid with N_{DC} number of buses, ith bus current \(I_{{i,{\text{DC}}}}\) is given by
where \(P_{{{\rm Li,DC}}}\), \(P_{{{\text{REDG}}}} ,P_{{{\rm Li,DCeff}}}\) are the active power demand, REDG active power and effective active power demand at ith bus, respectively, and \(V_{{i,{\text{DC}}}}\) is the voltage magnitude of an ith bus.
During backward sweep of the backward/forward based load flow, the branch currents are obtained with the help of businjections to branch currents matrix (BIBC) as follows:
During forward sweep of the backward/forward based load flow, the bus voltages are calculated with the help of branch current to bus voltage matrix (BCBV) as follows:
Repeat Eqs. (7) and (8) until the difference between the voltages of two adjacent iterations is less than the tolerance value (Îµ).
Highpower converter (VSC) model
The active (\(P_{{{\text{AC}}}}\)) and reactive (\(Q_{{{\text{AC}}}}\)) power absorbed by HPC from the AC grid with ignored converter losses can be expressed as follows
\(V_{{{\text{AC}}}}\) is the amplitude of AC grid voltage, \(V_{{{\rm C}}}\) is converter output voltage, \(X_{{{\text{HPC}}}}\) is equivalent reactance of converter, and \(\delta\) converter modulation angle. However, the converter loss is ignored so that the active power is equal on the AC and DC side. Then the active power can be expressed as
\(V_{{{\text{DC}}}}\) is voltage on the DC side and M is a modulation index of the converter. Since the power supply on the DC side of the network is poor inactivity, the losses of the converter can be expressed by the current and resistance of the converter as follows
where \(P_{{C{\text{,Loss}}}}\) is power lost in the converter and R is the resistance offered by HPC.
Problem formation
Optimal allocation of REDG units in a hybrid AC/DC microgrid system is to find the best location as well as the size of REDG units that gives minimum power loss as an objective function with the area required by REDG units as variables while satisfying various operating constraints. The objective function minimization of power loss is described as follows:
Constraints
Power balance constraint
Inequality constraints
\(\sum\nolimits_{k = 1k = 1}^{{N_{{{\text{AC}}}} }} {J_{{K,{\text{AC}}}}^{2} *R_{K} }\) is power loss in AC microgrid system, \(\sum\nolimits_{k = 1}^{{N_{{{\text{DC}}}} }} {J_{{K,{\text{DC}}}}^{2} *R_{K} }\) is power loss in DC microgrid system, \(P_{{{\text{REDG}}}}\) is power injected by REDG units in DC microgrid system, NB is number of branches in the system, N_{DG} is number of REDG units connected, N is number of buses in the system, i is bus number, k is branch number, \(A_{{{\text{PV}}}} ,A_{{{\text{FC}}}}\) are area required by PV and FC units, \(n_{{{\text{PV}}}} ,n_{{{\text{FC}}}}\) are the number of PV and FC units connected, \(I_{{{\text{PV}}}} ,\eta_{{{\text{PV}}}} , A_{{{\text{PV}}}}\) are solar insolation (W/m^{2}), the efficiency of solar PV, the area required by PV unit (m^{2}) and \(V_{{{\text{FC}}}} ,A_{{{\text{FC}}}} ,J\) are the output voltage of FC, area required by FC unit (m^{2}), current density (A/m^{2}), \(P_{{{\text{Slack}}}}\) is slack (substation) bus power, and \(P_{D}\) is the real power load connected at ith bus.
Butterfly optimization algorithm
Butterfly optimization is based on the ability of the butterflies to locate the source of fragrance accurately. They can also differentiate various fragrances and sense their intensities. In BO algorithm, butterflies are the searching agents. Fitness is correlated with the intensity of fragrance that can be generated by the butterfly. The movement of butterflies in search space will change its fitness. The sharing of information between butterflies is established through the propagation of fragrance. The searching ability of a butterfly depends on the sensing capability of the fragrance. This property will decide the movement of the butterfly towards a global search or local search (random). In BOA, the fragrance is formulated as a function of the physical intensity of stimulus as follows:
where f is the perceived magnitude of the fragrance, i.e., fragrance receiving property by other butterflies, c is the sensory modality, I is the stimulus intensity, and a is the power exponent dependent on modality, which accounts the varying degree of absorption. Most of the cases \(a \& c \in \left[ {0, 1} \right]\). If aâ€‰=â€‰1, it means there is no absorption of fragrance, i.e., the amount of fragrance emitted by a particular butterfly is sensed in the same capacity by the other butterflies (fragrance propagation in an idealized environment). Thus, a butterfly emitting fragrance can be sensed from anywhere in the domain which in turn helps to reach the global optimum easily. On the other hand, if aâ€‰=â€‰0, it means that the fragrance emitted by any butterfly cannot be sensed by the other butterflies at all. Another important parameter \(c \in \left[ {0, \infty } \right]\) determines the convergence speed. The values of a and c crucially affect the convergence speed of the algorithm. For the maximization problem, the intensity can be proportional to the objective function [29].
In BO algorithm, the characteristics of butterflies are idealized as follows:

1.
Every butterfly is supposed to emit some fragrance which enables the butterflies to attract each other (propagation of information).

2.
Every butterfly will move randomly or toward the best butterfly emitting more fragrance.

3.
The stimulus intensity of a butterfly is affected or determined by the topography of the objective function.
The detailed steps for implementation of BO algorithm are as follows.
Step 1: Initialize algorithm parameters such as the number of agents N, the dimension of the problem d, the maximum number of iterations Iter_{max}, probability switch P, power exponent PE and sensor modality SM.
Step 2: Generate initial random solution \(x_{i}^{j}\)
where N is the number of agents and d is the number of decision variables,\(x_{i }^{j}\) represents the position of the ith agent in jth dimension generated randomly between the limits as \(x_{\max ,d}\) and \(x_{\min ,d}\) and rand() is a random number between 0 and 1.
where kâ€‰=â€‰1: N_{DCMG}, N_{DCMG} is number of DC microgrids, L, A_{PV} and A_{FC} represents location of REDG, area of PV and area of FC, respectively.
Step 3: Evaluate the fitness (objective functions) of agents using Eq.Â 14. Record the gbest solution so far and set iteration count t as zero.
Step 4: Calculate the fragrance \(f_{N}\) for each agent or butterfly using Eq.Â 20.
Step 5: Perform a global search using Eq.Â 25 if \({\text{rand}} < {\text{probability}}\;P\) or local search using Eq.Â 26 if \(d > P\).
where \(x_{j}^{d} \left( t \right)\) and \(x_{k}^{d} \left( t \right)\) are jth and kth butterflies from the solution space which belongs to the same swarm and r is a random number in [0, 1] and then Eq.Â 27 becomes a local random walk.
Step 6: Evaluate the fitness of each agent in the new population using Eq.Â 14.
Step 7: Update the gbest vector.
Compare each new solution with the previous solution, if the new solution is better than the previous solution, record the gbest; otherwise, discard the new solution and preserve the previous solution as it is.
Step 8: Stopping criterion.
If the maximum number of iterations has reached (iter_{max}), computation is terminated. Otherwise, Step 4 to Step 7 are repeated.
The implementation flowchart for the BO algorithm is illustrated in Fig.Â 1.
Results and discussions
Standard radial distribution systems are modified as hybrid AC/DC microgrid systems for the purpose of the study. The buses in the AC zone will have real and reactive power loads and lines will have resistance and reactance. But in DC zone buses will have only real power loads and lines will have only resistance. Based on the system topology, it was divided into several zones in which laterals and far end buses of the main feeder are considered as DC zones and they are separated with the help of HPCs (highpower converters) from the AC Zone or Main substation in this study. To calculate the system parameters like power losses, bus voltages, and line power flows, AC/DC Forward/Backward sweep load flow is used. Standard 33bus, 69bus [17] hybrid AC/DC distribution microgrids systems are considered for the study. Hybrid AC/DC 33bus microgrid system is connected to a substation rated 100Â MVA, 12.66Â kV having a connected base load of 3715Â kW and 840Â kVAr, the base power loss of 139.77Â kW and minimum voltage 0.9319 at 18th bus. For 69bus system base power 100 MVA, base voltage 12.66Â kV, base load 3801.89Â kW and 766.6 kVAr, base case power loss 144.31Â kW and minimum bus voltage are0.9318 at 65th bus. Note that all post performance numerical calculations presented in this work are based on reference [27] and uncertainty of REDG units are not considered to avoid complexity.
In order to demonstrate the effectiveness of the proposed approach for optimal allocation of REDG units in a hybrid AC/DC microgrid system, it is applied to small and mediumscale hypothetical 33 and 69bus AC/DC hybrid distribution microgrid systems. Tuned algorithm parameters of BO for the implementation are given in Table 1. The details of the REDG units used in this study are furnished in Table 2. All simulations are developed in MATLAB R2017a platform on Intel Core i5 2.7Â GHz processor, 8Â GB RAM. The optimal allocation of REDG units in a hybrid AC/DC microgrid system is analyzed through two different cases.
Case 1: Optimal REDG units sizing at locations fixed by LRSF (Eq.Â 15 in [27]) using the BO algorithm without considering HPC losses.
Case 2: Simultaneous optimal allocation of REDG units using BO algorithm with and without considering HPC losses.
Optimal REDG unit allocation for 33bus hybrid AC/DC microgrid system
A hypothetical 33bus hybrid AC/DC microgrid system consists of three zones: Zone 1 is ACMG supported by substation and Zone 2, and 3 are DCMG supported by HPC and REDG units. The detailed 33bus hybrid AC/DC microgrid system is shown in Fig.Â 2. The maximum limit for area required by FC and PV REDG is taken as 3000 m^{2}and 500 m^{2}, respectively. The results obtained for the 33bus hybrid AC/DC microgrid system for two cases are given in Table 3. From Table 3, it is observed that the result obtained by BO is better than other results. In Case 1, i.e., without considering HPC losses, the lowest total area required by REDG units is 4537.2 m^{2} with minimum system power loss of 46.05Â kW and the total power loss reduction is 67.05%. The optimal power required by PV is 283Â kW and FC is 1054Â kW at 7th bus with 142 PV panels and 42 FC arrays. Similarly, the optimal power required by PV is 165Â kW and FC is 988Â kW on 26th bus with 83 PV panels and 39 FC arrays. However, the results obtained by BO in Case 2 are quite interesting and encouraging. The total area required by REDG units is 3843.6 m^{2} with minimum system power loss of 26.83Â kW, and the total power loss reduction is 80.8%. The optimal power required by PV is 203Â kW and FC is 643Â kW at 13th bus with 102 PV panels and 26 FC arrays. Similarly, the optimal power required by PV is 183Â kW and FC is 950Â kW on 30th bus with 92 PV panels and 38 FC arrays. It is observed that the reduction in system power losses is significant in Case 2. The reason is in Case 1 the REDG unit locations are predetermined by the LRSF method and then optimal sizes are calculated at those fixed locations. But in Case 2, REDG unitâ€™s locations and respective sizes are determined simultaneously. It is also observed that the base case power loss is 171.7Â kW (including HPC losses). The optimal power required by PV is 108.5Â kW and FC is 860.4Â kW at 12th bus with 54 PV panels and 34 FC arrays. Similarly, the optimal power required by PV is 80.5Â kW and FC is 957Â kW at 30th bus with 40 PV panels and 38 FC arrays obtained by BO for Case 2.
A detailed comparison of the area required by REDG units versus total power losses of the system by various optimization algorithms is presented in Fig.Â 3. From Fig.Â 4, it is clear that in both cases the BO algorithm performed better than other algorithms. Another significant benefit of the REDG unitâ€™s optimal allocation in hybrid AC/DC microgrid is voltage profile improvement which is shown in Fig.Â 4. From Fig.Â 6, it is observed that the bus voltage profile has been improved in all three zones of the system for both cases with and without considering HPC losses. Convergence characteristics of the BO algorithm for the minimization of the desired objective function for different cases are given in Fig.Â 5. From Fig.Â 6, it is understood that the BO algorithm reached the final solution with good convergence i.e., 13th iteration for Case 1 without HPC losses, at 57th iteration for Case 2 without HPC losses and at 36th iteration for Case 2 with HPC losses. It is identified that the energy supplied through substation is 92514.38 kWh, the amount of coal consumed is 64.76 ton, and CO_{2} emission into the atmosphere is 55.14 ton without the integration of REDG units into the system. Energy flow results of the system under REDG units standalone mode of operation are presented in Table 4. From Table 4, it is clear that the proposed approach can improve the power loss reduction percentage, i.e., with HNMCS its value is 67% and with BO is 80%. Energysaving from the substation is improved from 65 to 67%, coal consumption is reduced from 22 to 19 tons that intern reduced the CO_{2} emission from 18.9 tons to 16 tons. And it is also observed that integrated REDG units under the standalone mode of operation in Zone 2 and 3 (DC grid) are producing sufficient energy to cater to the needs of AC grid without any shortfall and excess energy is useful to support the AC grid.
Optimal REDG unit allocation for 69bus hybrid AC/DC microgrid system
69bus hybrid AC/DC microgrid system consists of three zones: Zone 1 is ACMG supported by substation and Zone 2, Zone3 and Zone 4 are DCMG supported by HPC and REDG units. The detailed 69bus hybrid AC/DC microgrid system is shown in Fig.Â 6. The maximum limit for area required by FC and PV REDG is taken as 500 m^{2} and 800 m^{2}, respectively. Numerical outcomes obtained by casewise based on BO algorithm for 69b*us hybrid AC/DC microgrid system are in Table 5. And a comparison of outcomes based on various algorithms is furnished in Table 6. From Table 6, it is observed in Case 1, i.e., without considering HPC losses the lowest total area required by REDG units is 1361.84 m^{2} with minimum system power loss of 11.50Â kW and the total power loss reduction is 92%. The optimal power required by PV is 15Â kW and FC is 1017Â kW at 8th bus with 8 PV panels and 40 FC arrays. Similarly, the optimal power required by PV is 8Â kW and FC is 277Â kW at 28th bus with 4 PV panels and 11 FC arrays and power required by PV is 3Â kW and FC is 1656Â kW at 61st bus with 2 PV panels and 66 FC arrays. However, the results obtained by BO and HNMCS are almost the same. But the results obtained by BO in Case 2 are surprising. The total area required by REDG units is 1344.2 m^{2} with minimum system power loss of 4.65Â kW and the total power loss reduction is 98.2%. Optimal locations obtained for the integration of REDG units are 18, 61 and 54 buses. The optimal power produced by PV and FC at these locations is 3.8Â kW, 8.03Â kW, 24.21Â kW, and 470.8Â kW, 163.8Â kW, and 427.6Â kW, respectively. It is observed that the reduction in system power losses is significant in Case 2. The reason is in Case 1, the algorithm does not have the flexibility to choose the optimal locations because they are fixed based on LRSF. At those fixed locations algorithm has to find the best suitable size of REDG units. But, in Case 2 the algorithm has the freedom to choose optimal locations as well as optimal sizes simultaneously. It is worth noting point that the proper size of REDG units at proper locations always guarantees the better performance of the system. It is also observed that the base case power loss is 227.4Â kW (including HPC losses). The total area required and power produced by REDG units is 1301 m^{2} and 2486.2Â kW, respectively. The optimal locations are 19, 61 and 54 buses. In this case, the system power loss is increased from 144 to 227Â kW. The reason is power loss due to HPCâ€™s will alter the power flow in the respective feeder, and as a result, the change in branch currents may increase the feeder losses.
A detailed comparison of the area required by REDG units versus total power losses of the system by various optimization algorithms is presented in Fig.Â 7. From Fig.Â 8, it is clear that in both cases the BO algorithm performed better than other algorithms. Another significant benefit of REDG unitâ€™s optimal allocation in hybrid AC/DC microgrid is voltage profile improvement which is shown in Fig.Â 8. From Fig.Â 9, it is observed that the bus voltage profile has been improved in all three zones of the system for both cases with and without considering HPC losses. Convergence characteristics of the BO algorithm for the minimization of the desired objective function for different cases are given in Fig.Â 9. From Fig.Â 9, it is understood that the BO algorithm reached the final solution with smooth convergence. It is identified that the energy supplied through substation is 25848 kWh, the amount of coal consumed is 12.07 ton, and CO_{2} emission into the atmosphere is 10.2 ton without the integration of REDG units into the system. Energy flow results of the system with REDG unitâ€™s standalone mode of operation are presented in Table 7. From Table 7, it is clear that the proposed approach can improve the power loss reduction percentage i.e., with HNMCS its value is 90.1% and with BO is 97.5%. Energysaving from the substation is improved from 76 to 80%, coal consumption is reduced from 15.5 to 12Â ton that intern reduced the CO_{2} emission from 13.2 to 10.2Â ton. And it is also observed that integrated REDG units under the standalone mode of operation in Zone 4 (DC grid) are producing excess, i.e., 8601Â kWh, energy which is not sufficient to cater the needs of Zone 1 (AC grid), Zones 2 and 3 (DC Grid) and hence it requires load shedding or additional REDG support from other DC grids or through the substation to satisfy the demand.
Since BOA is a heuristic search method, its outcome may have certain randomness. In this work, it has been handled carefully by proper selection of decision variable limits. So, BO algorithm is tested by running 100 times for each case. Further, the computational complexity of the proposed BOA is analyzed by popular statistical methods such as Friedman and Quade test. The obtained ranks by BOA are compared with existing results available in the literature and also furnished in Table 8. From Table 8, it is observed that solutionquality and robustnesswise BOA is almost closer to HNMCS. However, HNMCS proves to be better than other algorithms in the race due to its hybrid nature.
Conclusions
In this paper, an efficient approach was proposed for optimal integration of REDG units in hybrid AC/DC distribution microgrids to maximize the technical benefits of the system with minimum operational area required by REDG units. Optimal locations and sizes for REDG units are determined simultaneously using a butterfly optimizer which is proved as a better approach by obtained results. It is identified that additional REDG units are required in DC zones of the 69bus system to produce the energy to satisfy the present demand. The proposed approach is an efficient technical tool for achieving better results in an optimal allocation of REDG units in hybrid AC/DC distribution microgrids. The future scope of this work is to include economic and technical benefits of REDG units with uncertainties, effects of probabilistic load models (daily load pattern) and PEV loads with different charging scenarios using Pareto optimal approach.
Availability of data and materials
Not Applicable.
Abbreviations
 \(P_{{{\rm Li,AC}}}\) :

Active power demand of the ith AC bus
 \(Q_{{{\rm Li,AC}}}\) :

Reactive power demand of the ith AC bus
 \(I_{{i,{\rm AC}}}\) :

Bus current of a jth bus in AC grid
 \(N_{{{{\rm AC}}}}\) :

Number of AC buses
 \(J_{{k,{{\rm AC}}}}\) :

Branch current of a jth branch in AC grid
 BIBC:

Bus injected Brach current matrix
 BCBV:

Brach current to bus voltage matrix
 \(V_{{i,{{\rm AC}}}}\) :

Voltage of an ith AC bus
 \(V_{0}\) :

Reference voltage of the buses
 \(V_{{i,{{\rm AC}}}}^{{{{\rm iter}}}}\) :

Voltage of an ith AC bus during iteration
 \(\varepsilon\) :

Tolerance value
 \(P_{{{\rm Li,DCeff}}}\) :

Effective active power demand of an ith DC bus
 \(V_{{i,{{\rm DC}}}}\) :

Voltage of an ith DC bus
 \(I_{{i,{{\rm DC}}}}\) :

Bus current of a jth bus in DC grid
 \(P_{{{\rm Li,DC}}}\) :

Active power demand of the ith DC bus
 \(P_{{{{\rm REDG}}}}\) :

Active power supplied by REDG
 \(J_{{k,{{\rm DC}}}}\) :

Branch current of a jth branch in DC grid
 \(V_{{i,{{\rm DC}}}}\) :

Voltage of an ith DC bus
 \(V_{{i,{{\rm AC}}}}^{{{{\rm iter}}}}\) :

Voltage of an ith DC bus during iteration
 \(P_{{{{\rm AC}}}}\) :

Active power observed by the convertor from the AC grid
 \(Q_{{{{\rm AC}}}}\) :

Reactive power observed by the convertor from the AC grid
 \(I_{{{{\rm DC}}}}\) :

Current on the DC side of the convertor
 \(V_{{{{\rm DC}}}}\) :

Voltage on DC side of the convertor
 \(P_{{C,{{\rm Loss}}}}\) :

Power lost in the convertor
 R :

Resistance offered by the HPC
 \(X_{{{{\rm HPC}}}}\) :

Equivalent reactance of the convertor
 \(P_{{C, {{\rm Loss}}}}\) :

Power loss in the convertor
 \(R_{K}\) :

Resistance of the kth branch
 \(n_{{{{\rm PV}}}}\) :

Efficiency of the PV panel
 \(I_{{{{\rm PV}}}}\) :

Output current of PV panel
 \(V_{{{{\rm PV}}}}\) :

Output voltage of PV panel
 \(A_{{{{\rm PV}}}}\) :

Area required by PV unit
 \(n_{{{{\rm FC}}}}\) :

Efficiency of the PV panel
 \(V_{{{{\rm FC}}}}\) :

Output voltage of FC panel
 \(A_{{{{\rm FC}}}}\) :

Area required by FC unit
 \(J\) :

Current density of FC unit
 \(P_{{{{\rm Slack}}}}\) :

Slack Bus power
References
Pecas Lopes JA, Moreira CL, Madureira AG (2008) Defining control strategies for analysing microgrids islanded operation. IEEE Trans Power Syst 21(2):1â€“7
Guerrero JM, Vasquez JC, Matas J, De VicuĂ±a LG, Castilla M (2011) Hierarchical control of droopcontrolled AC and DC microgrids: a general approach toward standardization. IEEE Trans Ind Electron 58(1):158â€“172
Hamad AA, Azzouz MA, El Saadany EF (2016) A sequential power flow algorithm for islanded hybrid AC/DC microgrids. IEEE Trans Power Syst 31(5):3961â€“3970
Kim JO, Nam SW, Park SK, Singh C (1998) Dispersed generation planning using improved Hereford ranch algorithm. Electr Power Syst Res 47(1):47â€“55
Borges CLT, FalcĂŁo DM (2006) Optimal distributed generation allocation for reliability, losses, and voltage improvement. Int J Electr Power Energy Syst 28(6):413â€“420
Singh RK, Goswami SK (2009) Optimum siting and sizing of distributed generations in radial and networked systems. Electr Power Compon Syst 37(2):127â€“145
Singh D, Singh D, Verma KS (2009) Multiobjective optimization for DG planning with load models. IEEE Trans Power Syst 24(1):427â€“436
Shukla TN, Singh SP, Srinivasarao V, Naik KB (2010) Optimal sizing of distributed generation placed on radial distribution systems. Electr Power Compon Syst 38(3):260â€“274
Singh RK, Goswami SK (2011) Multiobjective optimization of distributed generation planning using impact indices and tradeoff technique. Electr Power Compon Syst 39(11):1175â€“1190
Novoa C, Jin T (2011) Reliability centered planning for distributed generation considering wind power volatility. Electr Power Syst Res 81(8):1654â€“1661
Moradi MH, Abedini M (2012) A combination of genetic algorithm and particle swarm optimization for optimal distributed generation location and sizing in distribution systems with fuzzy optimal theory. Int J Green Energy 9(7):641â€“660
ElZonkoly AM (2011) Optimal placement of multidistributed generation units including different load models using particle swarm optimisation. IET Gener Transm Distrib 5(7):760
Wang L, Singh C (2008) Reliabilityconstrained optimum placement of reclosers and distributed generators in distribution networks using an ant colony system algorithm. IEEE Trans Syst Man Cybern Part C Appl Rev 38(6):757â€“764
AbuMouti FS, ElHawary ME (2011) Optimal distributed generation allocation and sizing in distribution systems via artificial bee colony algorithm. Power Deliv IEEE Trans 26(4):2090â€“2101
Arya LD, Koshti A, Choube SC (2012) Distributed generation planning using differential evolution accounting voltage stability consideration. Int J Electr Power Energy Syst 42(1):196â€“207
Rao RS, Ravindra K, Satish K, Narasimham SVL (2013) Power loss minimization in distribution system using network reconfiguration in the presence of distributed generation. IEEE Trans Power Syst 28(1):317â€“325
Injeti SK, Prema Kumar N (2013) A novel approach to identify optimal access point and capacity of multiple DGs in a small, medium and large scale radial distribution systems. Int J Electr Power Energy Syst 45(1):142â€“151
Kumar Injeti S, Shareef SM, Kumar TV (2018) Optimal allocation of DGs and capacitor banks in radial distribution systems. Distrib Gener Altern Energy J 33(3):6â€“34
Injeti SK (2016) A Pareto optimal approach for allocation of distributed generators in radial distribution systems using improved differential search algorithm. J Electr Syst Inf Technol 5:908â€“927
Murthy VVSN, Kumar A (2013) Comparison of optimal DG allocation methods in radial distribution systems based on sensitivity approaches. Int J Electr Power Energy Syst 53(1):450â€“467
Singh AK, Parida SK (2016) Novel sensitivity factors for DG placement based on loss reduction and voltage improvement. Int J Electr Power Energy Syst 74:453â€“456
Devi S, Geethanjali M (2014) Optimal location and sizing determination of distributed generation and DSTATCOM using particle swarm optimization algorithm. Int J Electr Power Energy Syst 62:562â€“570
Injeti SK, Kumar TV (2018) A WDO framework for optimal deployment of DGs and DSCs in a radial distribution system under daily load pattern to improve technoeconomic benefits. Int J Energy Optim Eng 7(2):1â€“38
MelgarDominguez OD, PourakbariKasmaei M, Mantovani JRS (2019) Adaptive robust shortterm planning of electrical distribution systems considering siting and sizing of renewable energy based DG units. IEEE Trans Sustain Energy 10(1):158â€“169
Zeng B, Wen J, Shi J, Zhang J, Zhang Y (2016) A multilevel approach to active distribution system planning for efficient renewable energy harvesting in a deregulated environment. Energy 96:614â€“624
Bharothu JN, Sridhar M, Rao RS (2018) Modified adaptive differential evolution based optimal operation and security of ACDC microgrid systems. Int J Electr Power Energy Syst 103(January):185â€“202
Senthil Kumar J, Charles Raja S, Jeslin Drusila Nesamalar J, Venkatesh P (2018) Optimizing renewable based generations in AC/DC microgrid system using hybrid Nelderâ€“Meadâ€“Cuckoo search algorithm. Energy 158:204â€“215
Bahrami S, Wong VWS, Jatskevich J (2015) Optimal power flow for ACDC networks. In: 2014 IEEE international conference on smart grid communication. SmartGridComm 2014, pp 49â€“54
Arora S, Singh S (2018) Butterfly optimization algorithmâ€Ż: a novel approach for global optimization. Soft Comput 23:715â€“734
Acknowledgements
The authors were thankful to the Director NIT Warangal and the faculty of department of Electrical Engineering for their valuable support towards the smooth execution of the work.
Funding
Not Applicable.
Author information
Authors and Affiliations
Contributions
Single author contribution. The author read and approved the manuscript.
Corresponding author
Ethics declarations
Competing interests
The authors declare that they have no competing interests.
Additional information
Publisherâ€™s Note
Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations.
Rights and permissions
Open Access This article is licensed under a Creative Commons Attribution 4.0 International License, which permits use, sharing, adaptation, distribution and reproduction in any medium or format, as long as you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons licence, and indicate if changes were made. The images or other third party material in this article are included in the article's Creative Commons licence, unless indicated otherwise in a credit line to the material. If material is not included in the article's Creative Commons licence and your intended use is not permitted by statutory regulation or exceeds the permitted use, you will need to obtain permission directly from the copyright holder. To view a copy of this licence, visit http://creativecommons.org/licenses/by/4.0/.
About this article
Cite this article
Injeti, S.K. Butterfly optimizerassisted optimal integration of REDG units in hybrid AC/DC distribution microgrids based on minimum operational area. Journal of Electrical Systems and Inf Technol 8, 13 (2021). https://doi.org/10.1186/s4306702100035w
Received:
Accepted:
Published:
DOI: https://doi.org/10.1186/s4306702100035w