Quantiﬁcation of E ﬃ ciency Improvements from Integration of Battery Energy Storage Systems and Renewable Energy Sources into Domestic Distribution Networks

: Due to the increasing use of renewable, non-controllable energy generation systems energy storage systems (ESS) are seen as a necessary part of future power delivery systems. ESS have gained research interest and practical implementation over the past decade and this is expected to continue into the future. This is due to the economic and operational beneﬁts for both network operators and customers, battery energy storage system (BESS) is used as the main focus of this research paper. This paper presents an analytical study of the beneﬁts of deploying distributed BESS in an electrical distribution network (DN). The work explores the optimum location of installing BESS and its impact on the DN performance and possible future investment. This study provides a comparison between bulk energy storage installed at three di ﬀ erent locations; medium voltage (MV) side and low voltage (LV) side of the distribution transformer (DT) and distributed energy storage at customers’ feeders. The performance of a typical UK DN is examined under di ﬀ erent penetration levels of wind energy generation units and BESS. The results show that the minimum storage size is obtained when BESS is installed next to the DT. However, the power loss is reduced to its minimum when BESS and wind energy are both distributed at load busbars. The study demonstrates that BESS installation has improved the loss of life factor of the distribution transformer. as this led to a minimum rating of BESS installation. The study shows the beneﬁt of extending the distribution transformer life cycle by adopting BESS at the same bus where wind installed. The researchers recommend investigating the impacts of other renewable sources to be installed in the DN in the near future like PV and vehicle-to-grid (V2G), also to look into the impacts on the feeders of the DN at 33 kV.


Introduction
The traditional electricity market had to deal with challenges in supply-demand balance, but the introduction of renewable energy sources has resulted in a market need for energy storage systems. The traditional view has been that electricity should be consumed at the same instant that it is generated, i.e., the amount of electricity generated must always match the load demand. Any imbalance between generation and consumption will damage the stability and quality of the electrical supply grid parameters [1]. Although electrochemical storage elements, e.g., batteries, have played vital roles in everyday applications for many decades, the power demand has tended to be at low levels. For power plants and substations, batteries are used as a reliable power source for the operation of switchgear, critical standby systems and possibly black start of stations [2]. In more recent times, due to the variability of generation of electricity from wind, solar, etc., the need for larger-scale storage of energy has developed. Grid-scale battery storage units have recently shown an improvement in both

Fundamentals
The flow of electrical energy from generation source to end user (industrial, commercial or residential) via a transmission system, transformers and distribution cables, suffers from losses due to network components' impedances. The power losses are a function of the square of the load current.

Impact of ESS on System Losses
In general, the recorded losses in a power system network fall into three main categories; variable losses, referred to as copper losses, and the main concern of this research; these occur in transmission lines, transformers, and cables, and are dependent on the load current transmitted. Fixed losses occur mainly in transformer cores and do not vary with load current, these are normally ignored due to their low value compared to variable losses. Non-technical losses: Represent the electrical energy produced and consumed but not paid for due to meter errors or illegal abstraction. Variable losses, labeled as power losses, are high during the peak load period due to high current flow, as shown generally in Figure 1. It is clear from the graph that for the same change in load current (5 Amps) the losses are significantly higher during peak times (~2 kWatt) than in off-peak periods (~1 kWatt). Using ESS to shift a fraction of the peak load current to the off-peak period is expected to impact on the system energy losses. It should, however, be noted that some of the savings made during peak times are offset by increased off-peak losses due to the current supplied from the ESS. In contrast, savings will result from the fact that the net resistance losses due to higher cable temperature at peak times will be decreased. These factors can outweigh the losses within the storage elements. The degree of savings through a reduction in energy losses will be affected by the location, rating, and efficiency of the ESS. Figure 2 shows the main components of losses in a generic model of a radial power system: G is the generating source. Using ESS to shift a fraction of the peak load current to the off-peak period is expected to impact on the system energy losses. It should, however, be noted that some of the savings made during peak times are offset by increased off-peak losses due to the current supplied from the ESS. In contrast, savings will result from the fact that the net resistance losses due to higher cable temperature at peak times will be decreased. These factors can outweigh the losses within the storage elements. The degree of savings through a reduction in energy losses will be affected by the location, rating, and efficiency of the ESS. Figure 2 shows the main components of losses in a generic model of a radial power system: G is the generating source.
where PL is the power loss, To obtain the ideal situation of level load, the average load current (Iav) is determined based on the average power consumption, as indicated in Figure 3. In the proposed system, the average current is maintained at this level through charging and discharging of the BESS, as indicated in Figure 3. Although the network current downstream of the BESS will be load driven, i.e., variable profile, the current upstream will be kept consistent and level by the BESS operation cycle, resulting in potential savings and impact on the expected/remaining life of network components. This study investigates the potential energy savings from BESS installation in a DN as either bulk-storage or diversely distributed. The impact of BESS on the loss of life of the system components, particularly the DT will be addressed in detail. The investigation of the loss of life of the considered component will be considered under different scenarios for BESS installations. Three situations of BESS installation within the DN are addressed; the corresponding power loss equation in each case is given as follows:  Bulk BESS installed at MV-side of the distribution transformer (DT),  Total losses in a network over a period of time (e.g., daily or annually): where P L is the power loss, R eq = R T.Line + R Trans + R Cables is the equivalent resistance of the grid elements; R T-Line is transmission line resistance, R Trans is transformer resistance and R Cables is the resistance of distribution cables. I eq is the equivalent current taking into consideration the voltage levels on both sides of a transformer.
To obtain the ideal situation of level load, the average load current (I av ) is determined based on the average power consumption, as indicated in Figure 3. In the proposed system, the average current is maintained at this level through charging and discharging of the BESS, as indicated in Figure 3. Although the network current downstream of the BESS will be load driven, i.e., variable profile, the current upstream will be kept consistent and level by the BESS operation cycle, resulting in potential savings and impact on the expected/remaining life of network components. This study investigates the potential energy savings from BESS installation in a DN as either bulk-storage or diversely distributed. The impact of BESS on the loss of life of the system components, particularly the DT will be addressed in detail. The investigation of the loss of life of the considered component will be considered under different scenarios for BESS installations. Total losses in a network over a period of time (e.g., daily or annually): where PL is the power loss, is the equivalent resistance of the grid elements; RT-Line is transmission line resistance, RTrans is transformer resistance and RCables is the resistance of distribution cables. eq I is the equivalent current taking into consideration the voltage levels on both sides of a transformer.
To obtain the ideal situation of level load, the average load current (Iav) is determined based on the average power consumption, as indicated in Figure 3. In the proposed system, the average current is maintained at this level through charging and discharging of the BESS, as indicated in Figure 3. Although the network current downstream of the BESS will be load driven, i.e., variable profile, the current upstream will be kept consistent and level by the BESS operation cycle, resulting in potential savings and impact on the expected/remaining life of network components. This study investigates the potential energy savings from BESS installation in a DN as either bulk-storage or diversely distributed. The impact of BESS on the loss of life of the system components, particularly the DT will be addressed in detail. The investigation of the loss of life of the considered component will be considered under different scenarios for BESS installations.   Three situations of BESS installation within the DN are addressed; the corresponding power loss equation in each case is given as follows: Bulk BESS installed at MV-side of the distribution transformer (DT), Bulk BESS installed at LV-side of the DT, Uniformly distributed BESS at load buses, where, P L is the power loss, R values are as defined above, I var is the time dependent current taken by the variable loads and I av , is the average current in the segment, as driven by the BESS operating cycle.

Impact of DG on System Losses
A number of studies have been conducted to increase the value of wind power in the deregulated market, e.g., [24]. The integration of energy storage to wind generation systems in the frequency control market has shown the importance of merging the two technologies together [25,26]. In order to study the impact of an integrated system (wind and storage) on the distribution system operation, particularly the system losses, the power produced by the DG is transformed into its equivalent current that will be used to offset the load demand or to contribute directly to the stored energy in the ESS, battery bank for example. Two situations of DG installation were considered in this research; bulk penetration installed at the LV-side of the DT or uniformly distributed at the load buses. The power losses in these two cases are, respectively, given as follows: where P L , R T-Line , R Trans and R Cables , I av and I var values are as defined previously, I av_WT and I var_WT are the time dependent and average currents from the wind turbines I av_WT = I av − average(I WT ), and I var_WT = I var − I WT . In this study, 11 kW wind turbines are assumed to be suitable for installation at the LV side. The data employed in this study has been collected from an 11 kW rated wind turbine which is installed in a test site. The data are collected over one year, to include all-seasonal environmental impacts. As shown in Figure 4, the power-wind speed curve satisfies the standard formula of wind generation.
where, PL is the power loss, R values are as defined above, Ivar is the time dependent current taken by the variable loads and Iav, is the average current in the segment, as driven by the BESS operating cycle.

Impact of DG on System Losses
A number of studies have been conducted to increase the value of wind power in the deregulated market, e.g., [24]. The integration of energy storage to wind generation systems in the frequency control market has shown the importance of merging the two technologies together [25,26]. In order to study the impact of an integrated system (wind and storage) on the distribution system operation, particularly the system losses, the power produced by the DG is transformed into its equivalent current that will be used to offset the load demand or to contribute directly to the stored energy in the ESS, battery bank for example. Two situations of DG installation were considered in this research; bulk penetration installed at the LV-side of the DT or uniformly distributed at the load buses. The power losses in these two cases are, respectively, given as follows: In this study, 11 kW wind turbines are assumed to be suitable for installation at the LV side. The data employed in this study has been collected from an 11 kW rated wind turbine which is installed in a test site. The data are collected over one year, to include all-seasonal environmental impacts. As shown in Figure 4, the power-wind speed curve satisfies the standard formula of wind generation. An example of an average daily variation in output power for this WT at the test site is presented in Figure 5. It is clear that the maximum wind energy production is around 60% of rated power for 25% of the day.  An example of an average daily variation in output power for this WT at the test site is presented in Figure 5. It is clear that the maximum wind energy production is around 60% of rated power for 25% of the day. The annual distribution of wind speeds and the power production which resulted for this wind generator is shown in Figure 6, where the negative values at low wind speed are due to power absorbed from the grid to keep the wind induction generator running.

Typical Distribution Network
A typical UK distribution network has been defined in [27] and is adopted in this work to investigate the research objectives. As shown in Figure 7, it consists of a 33 kV, 500 MVA grid point that is connected to a 33/11 kV substation which supplies six 11 kV feeders, each 11 kV feeder supplies eight 11 kV/400 V (500 kVA) distribution transformers, each DT supplies 384 homes. The annual distribution of wind speeds and the power production which resulted for this wind generator is shown in Figure 6, where the negative values at low wind speed are due to power absorbed from the grid to keep the wind induction generator running. The annual distribution of wind speeds and the power production which resulted for this wind generator is shown in Figure 6, where the negative values at low wind speed are due to power absorbed from the grid to keep the wind induction generator running.

Typical Distribution Network
A typical UK distribution network has been defined in [27] and is adopted in this work to investigate the research objectives. As shown in Figure 7, it consists of a 33 kV, 500 MVA grid point that is connected to a 33/11 kV substation which supplies six 11 kV feeders, each 11 kV feeder supplies eight 11 kV/400 V (500 kVA) distribution transformers, each DT supplies 384 homes.

Typical Distribution Network
A typical UK distribution network has been defined in [27] and is adopted in this work to investigate the research objectives. As shown in Figure 7, it consists of a 33 kV, 500 MVA grid point that is connected to a 33/11 kV substation which supplies six 11 kV feeders, each 11 kV feeder supplies eight 11 kV/400 V (500 kVA) distribution transformers, each DT supplies 384 homes.
The detailed distribution of the 384 homes on the 400-V feeder is shown in Figure 8. The upper figures in this diagram are the cable length between adjacent busbars: the lower figures are the number of homes connected to a particular busbar. It is assumed that each busbar has four parallel branches of 96 homes each and equal cable length. The network parameters (cable lengths, resistances, and reactances) are provided in detail in Appendix A [28].

Typical Distribution Network
A typical UK distribution network has been defined in [27] and is adopted in this work to investigate the research objectives. As shown in Figure 7, it consists of a 33 kV, 500 MVA grid point that is connected to a 33/11 kV substation which supplies six 11 kV feeders, each 11 kV feeder supplies eight 11 kV/400 V (500 kVA) distribution transformers, each DT supplies 384 homes. The detailed distribution of the 384 homes on the 400-V feeder is shown in Figure 8. The upper figures in this diagram are the cable length between adjacent busbars: the lower figures are the number of homes connected to a particular busbar. It is assumed that each busbar has four parallel

UK Load Profile and DT Losses
The daily load profile of the UK distribution network is shown in Figure 9, based on after-diversitymaximumdemand (ADMD) referenced to 100 consumers [29]. Although the load profile is known to vary from winter to summer, for the purpose of simplicity an average annual load profile is adopted in this work. Transformer loading conditions are probably most influential as far as optimum selection of DT is concerned. Generally, for heavily loaded transformers, the focus should be on load losses while for lightly loaded, it should be on no-load losses. In Figure 10 Peak Load is shown as a solid line, the average load (Load Aver) is shown as a dotted line, transmission losses (Trans Loss) is a dash-dot line, and average transmission (Trans Aver) is shown as a dashed line. It is obvious from Figure 10 that, for the distribution transformer being studied, high levels of losses occur around 50% to 60% of peak load time. However, if the load curve is a flat line (equal load all the year with the help of demand-side techniques or ESS) both peak load and peak losses time will be constant.

Loss of Life of a Distribution Transformer
The life of a transformer depends on the life of its solid insulation, which ages mainly due to the effect of temperature. The application of ESS will affect the load profile applied to the equipment and, as a consequence, will also alter the evolution of the temperature profile within the transformer insulation through time.
Simulations have been carried out to determine the effect on the life of a transformer of using BESS. The model proposed by IEEE Standard C57.92-1995 has been applied to calculate the temperature distribution in the transformer, and also to calculate the transformer loss of life under

UK Load Profile and DT Losses
The daily load profile of the UK distribution network is shown in Figure 9, based on after-diversitymaximumdemand (ADMD) referenced to 100 consumers [29]. Although the load profile is known to vary from winter to summer, for the purpose of simplicity an average annual load profile is adopted in this work.

UK Load Profile and DT Losses
The daily load profile of the UK distribution network is shown in Figure 9, based on after-diversitymaximumdemand (ADMD) referenced to 100 consumers [29]. Although the load profile is known to vary from winter to summer, for the purpose of simplicity an average annual load profile is adopted in this work. Transformer loading conditions are probably most influential as far as optimum selection of DT is concerned. Generally, for heavily loaded transformers, the focus should be on load losses while for lightly loaded, it should be on no-load losses. In Figure 10 Peak Load is shown as a solid line, the average load (Load Aver) is shown as a dotted line, transmission losses (Trans Loss) is a dash-dot line, and average transmission (Trans Aver) is shown as a dashed line. It is obvious from Figure 10 that, for the distribution transformer being studied, high levels of losses occur around 50% to 60% of peak load time. However, if the load curve is a flat line (equal load all the year with the help of demand-side techniques or ESS) both peak load and peak losses time will be constant.

Loss of Life of a Distribution Transformer
The life of a transformer depends on the life of its solid insulation, which ages mainly due to the effect of temperature. The application of ESS will affect the load profile applied to the equipment and, as a consequence, will also alter the evolution of the temperature profile within the transformer insulation through time.
Simulations have been carried out to determine the effect on the life of a transformer of using BESS. The model proposed by IEEE Standard C57.92-1995 has been applied to calculate the temperature distribution in the transformer, and also to calculate the transformer loss of life under Transformer loading conditions are probably most influential as far as optimum selection of DT is concerned. Generally, for heavily loaded transformers, the focus should be on load losses while for lightly loaded, it should be on no-load losses. In Figure 10 Peak Load is shown as a solid line, the average load (Load Aver) is shown as a dotted line, transmission losses (Trans Loss) is a dash-dot line, and average transmission (Trans Aver) is shown as a dashed line. It is obvious from Figure 10 that, for the distribution transformer being studied, high levels of losses occur around 50% to 60% of peak load time. However, if the load curve is a flat line (equal load all the year with the help of demand-side techniques or ESS) both peak load and peak losses time will be constant.

Calculation of Transformer Temperatures
The thermal model of IEEE Standard C57.92-1995 provides equations to calculate the top oil temperature (Tto) and the hottest spot point temperature (Th). The hottest spot of the transformer tends to be in the upper part of the winding and its temperature will determine the aging rate of the equipment when it is subjected to certain loading conditions.
The top oil temperature (∆ _ ) rise over ambient temperature under steady state conditions and can be calculated for a load factor k as: where ∆ _ is the top oil temperature rise over ambient temperature at rated load, R is the ratio of rated loss at rated load to no-load loss and n is a coefficient that depends on the cooling mode of the transformer.
The model considers that the top oil temperature in the transformer varies following a first-order law. Accordingly, the top oil temperature rise over ambient temperature at time, t, can be calculated as follows: where ∆ _ is the top oil rise over ambient at the beginning of the studied period (t = 0), and is the time constant of the oil, which depends on the weight of different elements of the transformer. The hottest spot temperature rise over top oil temperature (∆ = − ) can be calculated according to Equation (9) below.
where ∆ _ is the hottest spot rise over top oil temperature at the beginning of the studied period, is the time constant of the winding, and ∆ _ is the hottest spot rise over top oil temperature in the steady-state for the considered load which can be calculated as: where ∆ _ is the hottest spot rise over top oil temperature for rated load, and m is a coefficient that depends on the transformer cooling mode.

Loss of Life Calculation
The IEEE standard considers that if the hottest spot temperature exceeds 95 °C, the aging process of the transformer will be accelerated in a factor FAA; which can be calculated as follows: Power % of Max.

Peak Load
Load Aver Trans Losses Trans Aver Figure 10. Relationship between DT peak load and peak loss time.

Loss of Life of a Distribution Transformer
The life of a transformer depends on the life of its solid insulation, which ages mainly due to the effect of temperature. The application of ESS will affect the load profile applied to the equipment and, as a consequence, will also alter the evolution of the temperature profile within the transformer insulation through time.
Simulations have been carried out to determine the effect on the life of a transformer of using BESS. The model proposed by IEEE Standard C57.92-1995 has been applied to calculate the temperature distribution in the transformer, and also to calculate the transformer loss of life under different operation scenarios.

Calculation of Transformer Temperatures
The thermal model of IEEE Standard C57.92-1995 provides equations to calculate the top oil temperature (T to ) and the hottest spot point temperature (T h ). The hottest spot of the transformer tends to be in the upper part of the winding and its temperature will determine the aging rate of the equipment when it is subjected to certain loading conditions.
The top oil temperature (∆T to_u ) rise over ambient temperature under steady state conditions and can be calculated for a load factor k as: where ∆T to_r is the top oil temperature rise over ambient temperature at rated load, R is the ratio of rated loss at rated load to no-load loss and n is a coefficient that depends on the cooling mode of the transformer. The model considers that the top oil temperature in the transformer varies following a first-order law. Accordingly, the top oil temperature rise over ambient temperature at time, t, can be calculated as follows: where ∆T to_i is the top oil rise over ambient at the beginning of the studied period (t = 0), and τ to is the time constant of the oil, which depends on the weight of different elements of the transformer.
The hottest spot temperature rise over top oil temperature (∆T h = T h − T to ) can be calculated according to Equation (9) below where ∆T h_i is the hottest spot rise over top oil temperature at the beginning of the studied period, τ w is the time constant of the winding, and ∆T h_u is the hottest spot rise over top oil temperature in the steady-state for the considered load which can be calculated as:. ∆T h_u = ∆T h_r × (k) 2·m (10) where ∆T h_r is the hottest spot rise over top oil temperature for rated load, and m is a coefficient that depends on the transformer cooling mode.

Loss of Life Calculation
The IEEE standard considers that if the hottest spot temperature exceeds 95 • C, the aging process of the transformer will be accelerated in a factor F AA ; which can be calculated as follows: Finally, to calculate the equivalent loss of life (F EQA ), in hours or minutes, that is consumed in a period of time t composed of n periods t n , Equation (11) is proposed as Equation (12). The loss of life is expressed in minutes or hours depending on the unit considered for the time-periods t n .

Case Studies
The single line diagrams of the system under study were shown in Figures 7 and 8. As previously indicated, for simplicity, only variable losses are considered. The impact of BESS and DG installation on the system losses is investigated for various locations, i.e., centralized and distributed. Three locations for the BESS are considered: (i) bulk installation at 11 kV (MV) side of the DT, (ii) bulk installation at the 400 V (LV) side of the DT and (iii) distributed installation at 400 V busbars, of course the converter size at each location is proportional to the level of BESS installation. Different penetration levels of DG's are considered at two locations (i) bulk installation at the LV side of the DT and (ii) distributed installation at the 400 V busbars. Four scenarios were investigated to determine the impact of BESS and DG's on-grid losses and cost savings opportunities.

Scenario 1: Bulk BESS is Installed at the MV/LV Side of the DT
The annual load demand of the system under consideration is 10,248 MWh. Table 1 shows the annual MV cable, DT and distributed (D) cable losses with no BESS and with BESS installed at either side of the DT. It is clear that with BESS installed at the LV side of the DT, there is a reduction in loss equivalent to 43.3 MWh annually and, as a result, significant financial saving opportunities. Also, the losses are reduced by 0.423% with respect to the total annual load demand energy.

Scenario 2: BESS is Installed at Distribution Buses
In this scenario, the energy storage system is locally installed at each busbar that connects to a group of houses, as depicted in Figure 8. The main purpose is to minimize variation in consumed  Table 2 shows that, compared to the case when bulk BESS is installed at the LV-side of the DT (Scenario 1), although there is no significant change in the power losses for both TL cable and DT, there is 4.2% savings in the D-cables. On the other side, and as a demerit for this scenario, the storage capacity has to be increased by 78.6%. Economically, the benefit of the power loss reduction in the D-cables is offset by the cost associated with high capacity of BESS at busbar level.

Scenario 3: Integration of DG's and BESS
It is anticipated that the installation of DG in the distribution network will contribute to energy savings and reduction of power demand from macro-generators. The impact of the location of installed WT's on the BESS rating and grid losses are considered in this scenario. WT's capable of producing 10% of the distribution transformer rating is installed at the DT LV-side or as distributed small-scale generation (DWT) at the busbars. This is studied for situations where BESS has been installed on either side of the DT. Table 3 shows, for comparison with the previous scenarios, the energy-saving opportunities. It is clear that the aggregate losses are reduced when bulk storage is installed at the LV-side of the DT and WT's are installed at homes busbars, as shown in Figure 11. Although the storage capacity required is slightly increased over scenario 1, it is lower than the case when distribution BESS is considered as discussed in scenario 2. The penetration of WT's (10%) has resulted in reduction of the power losses in each network component with aggregate value of 3.24%, this is clear through comparison of data from Table 1 (BESS@LV) and Table 3 (DWT, BESS@LV). installed WT's on the BESS rating and grid losses are considered in this scenario. WT's capable of producing 10% of the distribution transformer rating is installed at the DT LV-side or as distributed small-scale generation (DWT) at the busbars. This is studied for situations where BESS has been installed on either side of the DT. Table 3 shows, for comparison with the previous scenarios, the energy-saving opportunities. It is clear that the aggregate losses are reduced when bulk storage is installed at the LV-side of the DT and WT's are installed at homes busbars, as shown in Figure 11. Although the storage capacity required is slightly increased over scenario 1, it is lower than the case when distribution BESS is considered as discussed in scenario 2. The penetration of WT's (10%) has resulted in reduction of the power losses in each network component with aggregate value of 3.24%, this is clear through comparison of data from Table 1 (BESS@LV) and Table 3 (DWT, BESS@LV).  Figure 11. Detailed 400-V feeder with BESS and distributed WT's.

Scenario 4: High Penetration of DG's and BESS
In this scenario the impact of distributing both WT and BESS at busbars is addressed, different levels of DG's penetration are also considered. As demonstrated through a comparison of data in Table 2 (D-BESS) and Table 3 (WT, BESS@LV), the installation of small scale D-BESS at each busbar significantly increases the storage capacity required to maintain the power consumption at its average, regardless of the level of WT installation. Also, by comparing data in Table 3 (DWT and

Scenario 4: High Penetration of DG's and BESS
In this scenario the impact of distributing both WT and BESS at busbars is addressed, different levels of DG's penetration are also considered. As demonstrated through a comparison of data in Table 2 (D-BESS) and Table 3 (WT, BESS@LV), the installation of small scale D-BESS at each busbar significantly increases the storage capacity required to maintain the power consumption at its average, regardless of the level of WT installation. Also, by comparing data in Table 3 (DWT and BESS@LV) and Table 4 (DWT and D-BESS), with the same 10% installed level of WT, the required D-BESS capacity is increased by 22.4%. However, the installation of small scale WT at load busbars has resulted in a reduction of the losses in each component individually and overall. This is clear from comparing the second row of Table 2 and first row on Table 4, where 2.44% reduction in power losses is shown. Consequently, further increasing the level of WT penetration reduces the losses and required storage capacity as shown in Table 4.

Scenario 5: DT Loss of Life Incorporating BESS
The model proposed in IEEE Standard C57.92-1995 [30], has been applied to calculate the temperatures in a distribution transformer subjected to the load factor and ambient temperature profile given in Figure 12.

Scenario 5: DT Loss of Life Incorporating BESS
The model proposed in IEEE Standard C57.92-1995 [30], has been applied to calculate the temperatures in a distribution transformer subjected to the load factor and ambient temperature profile given in Figure 12. The distribution transformer parameters used for this study were obtained from the IEC Standard 354.1991 [31], the time constants considered, Table 5, were taken from [30,32]. Table 5. Parameters of the distribution transformer.

Parameter
Value The distribution transformer parameters used for this study were obtained from the IEC Standard 354.1991 [31], the time constants considered, Table 5, were taken from [30,32].

Parameter
Value Units The temperatures for the transformer under study were then calculated with and without the BESS connected at the LV side of the transformer. With BESS, a constant load factor of 0.8152 was applied to the transformer, equal to the average value of the daily load.
The evolution of T to and T h are shown in Figures 13 and 14 for both cases. As can be seen for the case of connecting an BESS at the secondary side of the transformer, Figure 13, the evolution of the temperatures is very smooth, and the maximum T h attained is below 85 • C even during the peak ambient temperature. For the case of applying the daily load displayed in Figure 12, the temperature profile, despite its minimum being 45 • C, presents a peak of T h that exceeds 100 • C, Figure 14: This elevated temperature lasts for over four hours.   The aging acceleration factor has been calculated according to Equation (11), the results for both cases, with and without BESS, are shown in Figures 15 and 16, respectively. Note the change in scale   The aging acceleration factor has been calculated according to Equation (11), the results for both cases, with and without BESS, are shown in Figures 15 and 16 The aging acceleration factor has been calculated according to Equation (11), the results for both cases, with and without BESS, are shown in Figures 15 and 16 demand. Integration of energy storage systems and renewable energy sources are considered an optimal combination for minimizing the grid losses, while also leading to the possibility of extending the lifetime of the grid components.   demand. Integration of energy storage systems and renewable energy sources are considered an optimal combination for minimizing the grid losses, while also leading to the possibility of extending the lifetime of the grid components.   Finally, the total loss of life in hours accumulated during the studied period has been calculated according to Equation (12). As can be seen, in Figure 17  This study investigated the integration of BESS and WT's at various locations in the distribution network. It is very obvious and expected as well that the installation of renewable sources (WTs in this case) is significantly reducing the power losses in the three studied components (line, cables, and transformer), as can be seen from Figure 18. In that figure, the minimum losses are recorded when both the renewable sources and battery energy storage are distributed at each load busbar. However, this has not led to the installation of minimum battery capacity. In comparing Figure 19 to the same cases in Figure 18, it is clear that the total rating of the battery capacity is obtained when the storage component is located either side of the distribution transformer as bulk storage. As shown in Figure 19, the minimum BESS required capacity occurs with distributed DG's sources and bulk storage BESS installed next to the LV side of the DT.

Discussion
With the growth of global electrical energy demand and limited energy resources available, it is vital to improve the performance of the current energy infrastructure. Electrical energy is the main type of energy used in the dwells and, therefore, has a significant on climate change and greenhouse gas (GHG) emissions based on the method used to be generated. Using the current grid to its maximum capacity is a necessity for future sustainable development. Reduction in the grid losses is considered an essential means to increase grid efficiency and to extend the component's life, providing more cost-effective delivery of power to consumers. Installation of DG's, such as WT's, is expected to reduce the GHG emissions and to provide local energy generation for local load demand. Integration of energy storage systems and renewable energy sources are considered an optimal combination for minimizing the grid losses, while also leading to the possibility of extending the lifetime of the grid components.
This study investigated the integration of BESS and WT's at various locations in the distribution network. It is very obvious and expected as well that the installation of renewable sources (WTs in this case) is significantly reducing the power losses in the three studied components (line, cables, and transformer), as can be seen from Figure 18. In that figure, the minimum losses are recorded when both the renewable sources and battery energy storage are distributed at each load busbar. However, this has not led to the installation of minimum battery capacity. In comparing Figure 19 to the same cases in Figure 18, it is clear that the total rating of the battery capacity is obtained when the storage component is located either side of the distribution transformer as bulk storage. As shown in Figure 19, the minimum BESS required capacity occurs with distributed DG's sources and bulk storage BESS installed next to the LV side of the DT.
Following Figure 10, the peak load and transformer losses are given in Figure 20, as a result of the installation of WT's, the peak load is reduced by 7% and the peak transformer losses is reduced by 11%. However, with the aid of distributed BESS and WT's the peak losses are reduced significantly, to about 50% of its original value and improvement was shown through the year. and transformer), as can be seen from Figure 18. In that figure, the minimum losses are recorded when both the renewable sources and battery energy storage are distributed at each load busbar. However, this has not led to the installation of minimum battery capacity. In comparing Figure 19 to the same cases in Figure 18, it is clear that the total rating of the battery capacity is obtained when the storage component is located either side of the distribution transformer as bulk storage. As shown in Figure 19, the minimum BESS required capacity occurs with distributed DG's sources and bulk storage BESS installed next to the LV side of the DT.  Following Figure 10, the peak load and transformer losses are given in Figure 20, as a result of the installation of WT's, the peak load is reduced by 7% and the peak transformer losses is reduced by 11%. However, with the aid of distributed BESS and WT's the peak losses are reduced significantly, to about 50% of its original value and improvement was shown through the year.   Following Figure 10, the peak load and transformer losses are given in Figure 20, as a result of the installation of WT's, the peak load is reduced by 7% and the peak transformer losses is reduced by 11%. However, with the aid of distributed BESS and WT's the peak losses are reduced significantly, to about 50% of its original value and improvement was shown through the year. Installing bulk BESS and WT's at the LV-side of the DT has flattened the current (power loss) profile in the transformer and upstream components i.e., transmission cables. The averaged transformer power loss is 31.32% compared to 44.13% in the case where no BESS or WT's are installed. This leveled power loss rises to 36.36% if only distributed BESS is used, i.e., no WT's installation. However, there is no significant change (31.93%) for the case when BESS and WT's are both distributed over the low voltage busbars. It was very obvious from simulation that in scenarios where BESS is connected the DT loss of life is much lower than the case of variable load profile. The loss of life calculated in both cases for the 24 h period was 7.72 h and 0.47 h. Installing bulk BESS and WT's at the LV-side of the DT has flattened the current (power loss) profile in the transformer and upstream components i.e., transmission cables. The averaged transformer power loss is 31.32% compared to 44.13% in the case where no BESS or WT's are installed. This leveled power loss rises to 36.36% if only distributed BESS is used, i.e., no WT's installation. However, there is no significant change (31.93%) for the case when BESS and WT's are both distributed over the low voltage busbars. It was very obvious from simulation that in scenarios where BESS is connected the DT loss of life is much lower than the case of variable load profile. The loss of life calculated in both cases for the 24 h period was 7.72 h and 0.47 h.

Economic Evaluation of the Integrated System
In future utility-scale operations, energy storage is expected to be the default approach for solving standard peak capacity challenges, rather than a traditional generator. BESS and DG have the ability to be modularized and placed in areas of the grid that require the most attention whereas traditional sources of generation, and the transmission and distribution system, are either impossible or too expensive to install. Placing the right storage technology at a key location can improve shortage of the supply conditions, relieve congestion, defer transmission, distribution or substation upgrades, or delay new capacity installation. Total capital cost (TCC) and life cycle cost (LCC) are the two main factors to evaluate and compare for different BESS systems. TCC includes purchase, installation, costs of power conversion systems and the balance of the equipment. LCC accommodates all expenses related to fixed/variable operation and maintenance, replacement, disposal and recycling in addition to TCC [36,37]. According to many researchers, there is lack of adequate information regarding the economy of utility-scale BESS, as many BESS costs are site-specific technologies, Table 6 presents the average cost analysis of Li and NaS battery energy storage collected from literature [38][39][40] for the capital cost including the power electronic ancillaries, the storage facilities, and the operation and maintenance. In addition, the BESS total cost for different scenarios addressed in Figure 19 is also presented reflecting a 15-years operational life cycle with consideration of 3.5% depreciation rate, as will explained below. Original price was in Euro, 1€ = 1.05$ is used for unifying the cost in $.

Assumptions:
According to the average load calculation used in this research, the BESS is charging for 9 h and discharging for 15 h. The BESS charging/discharging cycle is daily based; hence the number of life cycles is the number of life-days. The calculation is based on 15-year life of the transformer and batteries before replacement is required. For simplicity, the electricity price per kWh is assumed constant over the period of equipment life at $168/MWh. The cost of wind power installation, maintenance and connection is not included in the calculation. Two types of battery technology (NaS, Li) have been used to explore the power loss savings achieved using BESS and investigate the cost of the BESS for the scenarios described above.
As shown in Figure 21, the savings over the life time of the proposed system are significant when the BESS is distributed at busbar levels: This mainly eliminates the losses in the distribution cables and will payback for the BESS total cost. In this study the authors considered the rate of discount of 3.5% as estimated in [41], the present worth of an amount obtained annually for 15-years is calculated based on Equation (13) as follows:

= ·
(1 + ) − 1 · (1 + ) (13) where n = 15, i = 0.035, A is the present value, p is the present worth value, therefore, the savings are multiplied by 11.517 instead of 15. This coefficient is applied to the calculation of the savings in energy losses in all studied scenarios and also to the maintenance and operation costs of the BESS, however flat rate of electricity price over the 15-years is assumed. Based on this economic consideration of the savings, all possible savings in the distribution transformer losses, transmission line losses and the distribution LV cables are summarised in Table 7. As the Li batteries storage cost with grid integration converters are quite similar to the overall cost of NaS batteries, its attributed savings is promising in the near future due to sharp reduction in its cost per kWh over the past few years and expected to continue, it is expected to reach $100/kWh. In this study the authors considered the rate of discount of 3.5% as estimated in [41], the present worth of an amount obtained annually for 15-years is calculated based on Equation (13) as follows: where n = 15, i = 0.035, A is the present value, p is the present worth value, therefore, the savings are multiplied by 11.517 instead of 15. This coefficient is applied to the calculation of the savings in energy losses in all studied scenarios and also to the maintenance and operation costs of the BESS, however flat rate of electricity price over the 15-years is assumed. Based on this economic consideration of the savings, all possible savings in the distribution transformer losses, transmission line losses and the distribution LV cables are summarised in Table 7. As the Li batteries storage cost with grid integration converters are quite similar to the overall cost of NaS batteries, its attributed savings is promising in the near future due to sharp reduction in its cost per kWh over the past few years and expected to continue, it is expected to reach $100/kWh. Issues like protection and hazard control of the Li batteries, which are main barriers for deployment on large scale, are not part of this research investigation but expected to be overcome.
As can be predicted from Figure 22, distributing WT's and BESS at the same busbar will lead to considerable savings, yet this will shift the responsibility and ownership of both WT and BESS to the individual customers. The use of Li batteries may lead to savings due to its price drop and investment in its mass production.

Economic Evaluation of DT
As was calculated in Section 5, the transformer loss of life for the 24 h period analyzed is 7.72 h in the base case and 0.47 h in the case of connecting the BESS at the LV side of the distribution transformer. According to those calculations, the life expectancy of the transformer solid-insulation would be multiplied by 16-fold and consequently, the "theoretical life" of the transformer, which is generally considered to be within 15 to 20 years [26], would be extended.
It is important to note that these calculations are only referred to as the thermal life of solid insulation, which is the main factor that determines the transformer remaining life. As the cellulosic insulation ages, it loses its mechanical properties and becomes weak and breakable which can give rise to different types of failures, such as short circuits, partial discharges or hot spots in the windings. If the solid insulation of a transformer is kept in good condition, the reliability of the equipment increases and its failure probability drops significantly. However, it must be noted that even transformers with non-aged solid insulation can suffer unexpected failures of external origin, or at other elements such as the core or bushings. Different criteria can be applied for the estimation of the end of life of a transformer's cellulosic insulation [42], namely a 50% loss of the tensile strength of the insulation, a 75% loss of the tensile strength of the insulation, a degree of polymerization of insulation <200, or a definition of the end of life according to the experience derived from transformer's functional life test data. Depending on the adopted criterion, the life expectancy of a transformer with dry insulation that operates at rated load (i.e., hottest spot temperature around 110 °C) is estimated as 65,000 h (7.4 years), 135,000 h (15.4 years), 150,000 h (17.12 years) or 180,000 h (20.5 years) respectively [42]. Overloading a transformer or operating it with a high moisture content in the solid insulation, would shorten the expected life below these estimations. On the other hand, it is not unusual that transformers operate below their rated load (and thus with hottest spot temperatures below 110 °C) which would extend the life expectancy of the solid insulation to 30 years or more. It should be noted that, although in some cases transformers remain in service for more than 40 years, experience shows that after 30 years of service transformers are more likely to fail.
For the economical evaluation of the transformer loss of life carried out in this work, it is assumed that the transformer under analysis is replaced after 15 years of service for the base case and after 30 years of service if the BESS is connected in the LV side of the system.
Considering a cost for a 500 kVA transformer of 20,000$, and an interest rate 3.5%, as recommended in the UK Government Green book [41], the saving in transformer purchase if the BESS is installed could be estimated as $11,937 in a 15 years period (i.e., present net value with one replacement is $31,937 (Net cost of the system with one replacement after n years = cost for year 0 + Cost for year 0/(1+interest rate) n ) vs. $20,000 if only one transformer is installed).

Economic Evaluation of DT
As was calculated in Section 5, the transformer loss of life for the 24 h period analyzed is 7.72 h in the base case and 0.47 h in the case of connecting the BESS at the LV side of the distribution transformer. According to those calculations, the life expectancy of the transformer solid-insulation would be multiplied by 16-fold and consequently, the "theoretical life" of the transformer, which is generally considered to be within 15 to 20 years [26], would be extended.
It is important to note that these calculations are only referred to as the thermal life of solid insulation, which is the main factor that determines the transformer remaining life. As the cellulosic insulation ages, it loses its mechanical properties and becomes weak and breakable which can give rise to different types of failures, such as short circuits, partial discharges or hot spots in the windings. If the solid insulation of a transformer is kept in good condition, the reliability of the equipment increases and its failure probability drops significantly. However, it must be noted that even transformers with non-aged solid insulation can suffer unexpected failures of external origin, or at other elements such as the core or bushings. Different criteria can be applied for the estimation of the end of life of a transformer's cellulosic insulation [42], namely a 50% loss of the tensile strength of the insulation, a 75% loss of the tensile strength of the insulation, a degree of polymerization of insulation <200, or a definition of the end of life according to the experience derived from transformer's functional life test data. Depending on the adopted criterion, the life expectancy of a transformer with dry insulation that operates at rated load (i.e., hottest spot temperature around 110 • C) is estimated as 65,000 h (7.4 years), 135,000 h (15.4 years), 150,000 h (17.12 years) or 180,000 h (20.5 years) respectively [42]. Overloading a transformer or operating it with a high moisture content in the solid insulation, would shorten the expected life below these estimations. On the other hand, it is not unusual that transformers operate below their rated load (and thus with hottest spot temperatures below 110 • C) which would extend the life expectancy of the solid insulation to 30 years or more. It should be noted that, although in some cases transformers remain in service for more than 40 years, experience shows that after 30 years of service transformers are more likely to fail.
For the economical evaluation of the transformer loss of life carried out in this work, it is assumed that the transformer under analysis is replaced after 15 years of service for the base case and after 30 years of service if the BESS is connected in the LV side of the system.
Considering a cost for a 500 kVA transformer of 20,000$, and an interest rate 3.5%, as recommended in the UK Government Green book [41], the saving in transformer purchase if the BESS is installed could be estimated as $11,937 in a 15 years period (i.e., present net value with one replacement is $31,937 (Net cost of the system with one replacement after n years = cost for year 0 + Cost for year 0/(1+interest rate) n ) vs. $20,000 if only one transformer is installed).
If the saving in power losses, as detailed in Table 7, and transformer life are aggregated for the different considered scenarios, the economic benefits of integrating BESS and renewables are very obvious. To calculate the saving in transformer losses, only the load losses were considered since the no-load losses are not influenced by the presence of BESS.
Finally, although it is not easy to quantify from the economic point of view, it must be added that the value of operating a transformer with a lower probability of failure is an important factor to consider. Reduction in customer complaints and in the economic penalties that result from repair and replacement must be taken into consideration.

Conclusions
This study has addressed the integration of energy storage systems and renewable energy sources into a distribution network. Various scenarios address the impact of bulk and/or distributed installation on the grid performance from the losses point of view. The storage capacity that is required to achieve maximum savings is identified.
It is clear from the simulation results that distributing the renewable source, WT's in this case, across the load busbars has a great effect on reducing the aggregated losses in the transmission line, transformer and distribution cables. However, from the storage capacity point of view, the bulk installation of the energy storage system at the low voltage side of the distribution transformer is the best solution as this led to a minimum rating of BESS installation. The study shows the benefit of extending the distribution transformer life cycle by adopting BESS at the same bus where wind turbines are installed. The researchers recommend investigating the impacts of other renewable sources that likely to be installed in the DN in the near future like PV and vehicle-to-grid (V2G), also to look into the impacts on the feeders of the DN at 33 kV.

Acknowledgments:
The author would like to thank TUVNEL for the collaboration and providing raw data for system under study.

Conflicts of Interest:
The authors declare no conflict of interest.