## 1 Introduction
To assess the technical suitability of such installations for specific roof regions, they created a methodology that integrates machine learning algorithms, geographic information systems, and physical models with hourly temporal resolution. To quantify the uncertainty in the final PV potential, they further evaluate the uncertainties linked to each stage of the capacity assessment and combine them. The approach is used on 9.6 million Swiss rooftops, but it may be applied to any sizable area or nation given enough data. The results show that it is possible in Switzerland to install PV panels on 55% of the total roof area, representing the annual technical potential of PV panels on roofs. This would make it possible to cover more than 40% of Switzerland's current annual electricity demand. The reported method of hourly estimation of rooftop PV potential and uncertainty applies to a broad assessment of future energy systems with decentralized electricity grids. The results can be used to design effective strategies for integrating rooftop PV systems into the built environment. As a background for long-term heat accumulation, we used the following literature:  
[PERSON]'s [7] 2015 paper is devoted to developing thermal modeling of borehole heat storage systems. The major goal was to improve physical phenomena representation by introducing aspects typically not employed in current models. The mathematical description of the borehole heat exchanger network's structure and the modeling of borehole fields with variable borehole orientation are included in these services. A network model was used to approach the detailed modeling of the topology of borehole heat exchangers. Components are smaller, discrete versions of the larger geothermal system. These are interconnected through a network to build the logical connections required to define a certain borehole connection geometry. His method shows that combining a sufficient system discretization and network representation yields the granularity or flexibility required to describe any wellfield connection configuration. According to [PERSON] and [PERSON]'s work from 2019 [8], they looked at how a ground source heat storage system responded thermally during two successive charging intervals from June 2016 to August 2017. In the summer, the ground source heat storage system holds the thermal energy that the solar collectors collected. In order to maximize the efficiency of the ground heat storage, the authors created a charging method based on the findings of the experimental measurements. According to the study's findings, the ground warmed from 8 to 18 \({}^{\circ}\)C in a year. Over a five-year operating period, a temperature distribution of 24 \({}^{\circ}\)C was assumed for the ground source heat store. The temperature response of the ground source heat store is expected to range from 18 \({}^{\circ}\)C to 34 \({}^{\circ}\)C over a year for injection power adjustments from 30 kW to 60 kW. The average multi-year heat transfer in ordinary ground storage in Finland is estimated to be 1.2 GJ. [PERSON] et al. [9], 2020, describe the design of a novel solar-powered ground-source heat pump (SAGSHP) system with a thermal cascade formed by borehole heat exchangers in North China. The core and peripheral regions of the borehole heat exchangers were separated into two groups. A high temperature, such as 45 \({}^{\circ}\)C, which is substantially higher than in earlier research, can be maintained in the core region. Without using the heat pump, it is possible to use the heat from this region directly. The outcomes show that a suitable soil temperature gradient may be established and maintained. The monthly average borehole-wall temperature difference between borehole heat exchangers in the core and at the periphery can be up to 30.1 \({}^{\circ}\)C. This points to the possibility of implementing both cascading heat storage and heat recovery.