## 8 Results and Discussion
### Scenario 4 (40% DR)  
The 40% DR program is designed to achieve significant shifts in energy consumption, leading to further cost reductions and enhanced system efficiency. This scenario evaluates the impact of the DR program on hourly energy load, generation from PV and wind, the utilization of backup systems like batteries, FCs, and EVs, and the total operating costs and LPSP. The degree of participation from both primary and backup systems in satisfying the load demand in scenario 4 is shown in Figure 16.  
Under the 40% DR program, the household's energy load exhibits notable variations throughout the day. In the early hours (1:00 a.m. to 6:00 a.m.), the load starts at 1153.08 W and decreases to 895.44 W by 6:00 a.m. During this period, there is no PV generation due to the absence of sunlight. Wind generation remains relatively consistent, ranging from 320.3 W to 376.1 W. By 7:00 a.m., PV generation begins with 304.7 W, reaching its peak of 910.00 W at 2:00 p.m. Wind generation also peaks at 880.1 W around 4:00 p.m. The highest load demand is observed in the evening, reaching 1452.99 W at 9:00 p.m., with PV generation ceasing after sunset and wind generation gradually declining. BESSs play a critical role in balancing the energy supply, particularly during periods when PV and wind generation are insufficient. The battery discharge pattern shows significant activity in the early morning, with a discharge of 488.32 W at 1:00 a.m., peaking at 743.00 W at  
Figure 16: The degree of participation from both primary and backup system in satisfying the load demand in scenario 4. Figure 15: The LPSP values in Scenario 3. 8:00 p.m. FCs provide intermittent support, particularly during peak demand periods. Notable contributions include 331.71 W at 1:00 a.m., increasing to 439.85 W at 2:00 a.m., and a significant discharge of 866.43 W at 9:00 p.m. EVs also participate through both charging and discharging cycles. In the early hours, EVs discharge \(-\)42.35 W at 1:00 a.m. and \(-\)56.80 W at 3:00 a.m., with charging phases occurring at \(-\)156.00 W during several hours including 6:00 a.m. and 7:00 a.m. The cumulative operating costs for the day are tracked based on hourly expenses. These costs increase significantly during periods of high load. For instance, the cumulative cost is $16.73 at 1:00 a.m., rising to $31.71 by 2:00 a.m., and reaching $749.09 by the end of the study period. The LPSP, a metric indicating the chance of not meeting load demand, remains within the acceptable range of 0 to 0.05 throughout the day as shown in Figure 17. The highest LPSP value recorded is 0.0009 at midnight, indicating a reliable system capable of meeting energy demands with minimal risk of power shortages. In the early morning, the load starts at 1153.08 W, decreasing to 895.44 W by 6:00 a.m. PV generation is zero during this period, while wind generation ranges from 320.3 W to 376.1 W. Batteries and FCs discharge significantly, with EVs providing additional support. During the daytime, PV generation begins at 6:00 a.m., peaking at 910.00 W by 2:00 p.m. Wind generation varies but remains substantial, reaching a high of 880.1 W at 4:00 p.m. The load peaks at 1452.99 W at 9:00 p.m., with backup systems adjusting to maintain energy balance. In the evening, the load remains high, peaking at 1452.99 W at 9:00 p.m. PV generation ceases after sunset, while wind generation gradually declines. Backup systems, including batteries and FCs, play an essential role in fulfilling high load demands.  
The 40% DR program results in a significant reduction in peak load demand, leading to notable energy cost savings and optimized use of renewable and backup energy sources. The household effectively shifts its energy usage to off-peak periods, resulting in a balanced and efficient energy system. The cumulative operating cost for the day is $749.09, which is lower than the previous scenarios, highlighting the economic benefits of an aggressive DR program.