The aim of this paper is to present a novel and comprehensive methodology for the dynamic modeling and experimental validation of a photovoltaic/thermal system. The dynamic model is divided into thermal and electrical subsystems, encompassing the photovoltaic/thermal module and the thermal energy storage. The thermal subsystem of both the photovoltaic/thermal module and the thermal energy storage is described by a one-dimensional dynamic model of heat transfer mechanisms and optical losses, while the electrical subsystem is presented as an electrical equivalent circuit of double diode solar cell. Model validation was conducted on a modern experimental photovoltaic/thermal system over an extended operational period at a five-minute resolution, with validation days classified as sunny, cloudy, or overcast based on weather conditions, thereby demonstrating an applied approach. The results demonstrate the lowest deviation values reported to date, confirmed using six quantitative indicators. The added value of the proposed methodology, not previously addressed in the literature, lies in the following contributions: (i) comprehensive modeling of the entire photovoltaic/thermal system, (ii) accurate consideration of optical losses in the photovoltaic/thermal module, and (iii) long-term experimental validation. Overall, the proposed methodology provides a reliable and efficient framework for PV/T system design, optimization, and long-term performance assessment.

To address the growing integration of renewable energy sources and storage systems into distribution networks, there is a need for effective tools that can assess the impact of these technologies on grid performance. This paper investigates the impact of integrating residential rooftop photovoltaic (PV) systems and battery energy storage systems (BESSs) into low-voltage (LV) distribution networks. A stochastic approach, using the Monte Carlo method, is applied to randomly place PV systems across the network, generating multiple scenarios for power flow simulations in MATLAB Simulink R2024b. The method incorporates real-world consumer load data and grid topology, representing a novel approach in simulating distribution network behaviour accurately. The novelty of this paper lies in its ability to combine stochastic PV placement with real-world load data, providing a more realistic representation of network conditions. The simulation results revealed that widespread PV deployment can lead to overvoltage issues, but the integration of BESSs alongside PV systems mitigates these problems significantly. The findings of this paper offer valuable insights for Distribution Network Operators, aiding in the development of strategies for optimal PV and BESS integration to enhance grid performance.

The aim of this paper is to present the transformation of the network tariff system in Slovenia using a comprehensive assessment methodology for the techno-economic evaluation of electricity costs for households. The novelty of the proposed approach lies in the combined assessment of the previous and new network tariff systems, explicitly accounting for power-based network tariff components, time-block-dependent charges, and different support schemes for household photovoltaic systems, including net metering and credit note-based schemes. The results show that the transition from an energy-based to a more power-based network tariff system, introduced primarily to mitigate congestion in distribution networks, is not inherently disadvantageous for consumers and prosumers. When tariff structures are appropriately designed, the new framework can support efficient grid utilization and maintain favorable conditions for prosumers, particularly those integrating battery storage systems. Overall, the proposed methodology provides a transparent and robust framework for evaluating the economic impacts of network tariff reforms on residential consumers and prosumers, offering relevant insights for tariff design and the development of future low-carbon household energy systems.

This paper evaluates the impact of a floating photovoltaic system on lake temperature using a one-dimensional thermal model. The modeling approach incorporates established heat flux formulations and lake temperature dynamics, utilizing key meteorological inputs such as power density of solar radiation, wind speed, air temperature, humidity, and precipitation. The model analyzes temperature variations at different depths under various floating photovoltaic system coverage scenarios and compares them to a reference case without a floating photovoltaic system. The results indicate that a floating photovoltaic system affects the lake’s thermal regime by enhancing cooling during warmer months and limiting heat loss in colder periods. A floating photovoltaic system also alters latent heat flux and evaporation, further affecting the lake’s energy balance and stratification. These findings highlight the importance of considering FPV-related thermal effects in environmental assessments.

The integration of photovoltaics, heat pumps, and energy storage systems is frequently assessed under the term “power grid integration”, yet studies operationalise grid interaction in different ways. This review addresses this inconsistency by synthesising and classifying assessment approaches according to the explicitness with which grid interactions are represented. A structured narrative review of peer-reviewed studies analysing coordinated photovoltaic–heat pump–storage operation was conducted. The literature is classified into three categories: A—grid-aware approaches that explicitly model distribution networks and evaluate compliance with voltage and loading constraints; B—interface-based approaches that represent the grid at the point of common coupling through aggregated import/export variables embedded as objectives or constraints; and C—grid-oriented approaches that evaluate grid-relevant indicators as proxies for grid stress without enforcing grid constraints. The synthesis shows that the categories align with distinct modelling perspectives, metrics, temporal resolutions, and control paradigms, reflecting different assessment questions rather than methodological quality. The proposed framework supports consistent interpretation and comparison of photovoltaic–heat pump–storage grid-integration studies within their respective modelling contexts.