Germany’s uniform DE–LU bidding zone masks large internal congestion and therefore gives renewable generators no locational

price signal.We quantify how moving from zonal to nodal pricing would redistribute market revenue across the existing German

wind and solar fleet. A full-year hourly DC optimal power flow for 2025 is solved on a 541-bus transmission model and compared

with an otherwise identical copper-plate zonal case. Across the 144.7 GW of wind and solar analysed, annual market revenue

falls by EUR 3.10 billion (24.3%). The change is dominated by locational repricing (EUR 3.83 billion), while the dispatchvolume

component offsets EUR 0.73 billion because most output reductions occur at negative local prices. Offshore wind is most

exposed, followed by onshore wind, whereas photovoltaic effects are smaller in aggregate and largely redistribute north to south.

Losses are highly concentrated: 80% of gross losses fall on 18% of capacity, while the median onshore cluster gains. The results

show that nodal pricing creates a strong asset-level redistribution whose incidence depends materially on renewable-support

design.