## 6 Simulation Results
### Daily Optimal Dispatches of VVC Devices  
Tables 4 and 5 present the data of DERs, including information characterizing the capability diagrams of the generator, components of offered prices of reactive power, the generator adjustment price, and the maximum admitted change as a percentage of its IAPD. The cost of reactive power \begin{table}
\begin{tabular}{c c c c} \hline \hline
**Generation Unit** & **Capacity** & **Location** & **CO2 (ton/MWh)** \\ \hline Disco & 20 MVA & - & 0.927 \\ DG1 & 400 kW & Bus 11 in feeder 2 & 0.489 \\ DG2 & 1000 kW & Bus 9 in feeder 1 & 0.724 \\ WT & 500 kW & Bus 8 in feeder 1 & 0 \\ \hline \hline \end{tabular}
\end{table} 
Table 1: Capacity, location, and emissions of generation units. \begin{table}
\begin{tabular}{c c c c c} \hline \hline
**Generation Unit** & **Hour** & **Block Number** & **Quantity (kW)** & **Price (S/kWh)** \\ \hline \multirow{4}{*}{DG1} & \multirow{4}{*}{1–24} & 1 & 200 & 0.045 \\  & & 2 & 100 & 0.05 \\  & & 3 & 100 & 0.06 \\ \hline \multirow{4}{*}{DG2} & \multirow{4}{*}{1–24} & 1 & 400 & 0.042 \\  & & 2 & 400 & 0.05 \\  & & 3 & 200 & 0.06 \\ \hline \multirow{4}{*}{WT} & 1–6 & 1 & 100 & 0.041 \\  & 7–10 & 1 & 366 & 0.041 \\  & 11–15 & 1 & 442 & 0.041 \\  & 16–18 & 1 & 500 & 0.041 \\  & 19–22 & 1 & 480 & 0.041 \\  & 23–24 & 1 & 100 & 0.041 \\ \hline \multirow{4}{*}{Disco} & \multirow{4}{*}{1–8} & 1 & 8000 & 0.04 \\  & & 9–10 & 1 & 8000 & 0.045 \\  & 11–13 & 1 & 8000 & 0.05 \\  & 14–15 & 1 & 8000 & 0.052 \\  & 16 & 1 & 8000 & 0.053 \\  & 17 & 1 & 8000 & 0.054 \\  & 18–19 & 1 & 8000 & 0.053 \\  & 20–22 & 1 & 8000 & 0.052 \\  & 23–24 & 1 & 8000 & 0.05 \\ \hline \hline \end{tabular}
\end{table} 
Table 2: Selling bids offered by generation units. generated by Disco, corresponding adjustment price, and maximum admitted change in its IAPD are 0.022 ($/kVArh), 0.09 ($/kWh), and 40%, respectively. The mandatory power factor (\(pf_{mand}\) ) has been taken to be 0.95. The maximum variability of the actual hourly wind power from the forecasted value is considered to be 10% of the forecasted value. In order to calculate the depreciation cost of OLTC, the installation cost of an OLTC is assumed to be $400,000 (=$ 20,000/MVA\(\times\) 20 MVA), as reported in [26]. The total number of acceptable switching operations of each OLTC can be 143,080 times (=20 steps/day \(\times\) 365 days/year \(\times\) 20 years \(\times\) 0.98 availability factor). Thus, the depreciation cost for each step change (\(D_{Tap}\)) is $2.79. Also, the installation cost for each Sh.C is $11,600 (=$ 11,600/MVA\(\times\) 1 MVA) as given in [26]. Each Sh.C can be operated 71,540 times (=10 switching operations/day \(\times\) 365 days/year \(\times\) 20 years \(\times\) 0.98 availability factor). Therefore, the depreciation cost for each switching operation of Sh.C (\(D_{S}\)) is equal to $0.162. The daily VVC problem proposed in this paper will be tested on three different cases, as follows: \begin{table}
\begin{tabular}{c c c c c c c c c c} \hline \hline \multirow{2}{*}{**DER**} & \multirow{2}{*}{\(\mathbf{P_{DG}^{max}}\)} & \multirow{2}{*}{\(\mathbf{Q_{DG}^{min}}\)} & \multirow{2}{*}{\(\mathbf{Q_{DG}^{x}}\)} & \multirow{2}{*}{\(\mathbf{\rho_{0}}\)} & \multirow{2}{*}{\(\mathbf{\rho_{1}}\)} & \multirow{2}{*}{\(\mathbf{\rho_{2}}\)} & \multirow{2}{*}{\(\mathbf{\rho_{Adj}}\)} & \multirow{2}{*}{\(\mathbf{x^{max}}\)} \\  & & & & & & & & & \\  & **(kW)** & **(kVAr)** & **(kVAr)** & **(kVAr)** & **(S)** & **(S/MVArh)** & **(S/MVArh)** & **(S/kWh)** \\ \hline DG1 & 400 & 400 & \(-\)400 & 400 & 0.6 & 23 & 23 & 0.08 & 50\% \\ DG2 & 1000 & 1000 & \(-\)600 & 800 & 0.8 & 30 & 30 & 0.075 & 50\% \\ \hline \hline \end{tabular}
\end{table} 
Table 4: Characteristics of the DGs.