The Powerland 4.2 project set out to demonstrate how biogas‑based combined heat and power (CHP) plants can be operated in a way that maximises renewable electricity use while meeting local heat and power needs. The core technical achievement was a modular, heuristic‑algorithm‑based control system that integrates real‑time forecasts of photovoltaic and wind generation, local electricity demand, heat demand, and the residual load that must be supplied by the CHP unit. By continuously adjusting the plant’s operating point, the system can shift production to periods of high renewable output, reduce the need for grid imports, and smooth out the characteristic peaks of biogas generation.
The control logic was developed and validated in a real‑lab environment that mimics the operating conditions of a typical rural CHP plant. Forecast models use weather data and weekly cycles to predict the next day’s electricity and heat demand with a mean absolute error of less than 5 %. The CHP controller then selects the optimal power‑to‑heat ratio, ensuring that the plant’s electrical output matches the forecasted renewable surplus while still delivering the required district‑heating heat. In pilot tests the system achieved a 15 % increase in CHP utilisation compared with a conventional, fixed‑output strategy, and reduced the plant’s peak electrical output by up to 25 %, thereby easing pressure on the local distribution network.
Beyond the technical core, the project explored the broader integration of biogas CHP into a sector‑coupled energy system. Scenarios were analysed in which the CHP plant is coupled to a village’s own photovoltaic array or to a small wind farm, creating a self‑contained microgrid that can supply almost all local electricity and heat needs. In such configurations the CHP plant acts as a flexible buffer, absorbing excess renewable generation and providing power during low‑generation periods. The study also quantified the potential for the CHP plant to supply surplus electricity back to the grid during peak demand, offering a revenue stream that could offset capital costs.
The research was carried out by a consortium of academic and industrial partners. The lead institution, a university with expertise in renewable energy systems, coordinated the development of the control algorithms and the real‑lab testing. A national research institute supplied the forecasting models and contributed to the system integration. Several biogas plant operators participated as field partners, providing real‑world data and validating the control strategy under commercial operating conditions. A local municipality acted as a stakeholder, representing the interests of the village community that would benefit from the integrated CHP‑renewable system. The project was funded by the German Federal Ministry of Economic Affairs and Energy under the Powerland programme, with a total budget of €3.5 million over a three‑year period from 2019 to 2022.
In summary, Powerland 4.2 delivered a proven, modular control framework that enables biogas CHP plants to operate in harmony with variable renewable generation, improving utilisation, reducing peak demand, and supporting the transition to a fully renewable electricity and heat supply. The collaborative effort combined academic research, industrial expertise, and community engagement, demonstrating a scalable pathway for rural energy systems to achieve high renewable penetration while maintaining reliability and economic viability.