Energy Newsletter

In Q1 2026, renewable energies reached 53% of German electricity consumption for the first time – a historic milestone for the energy transition. At the same time, current data shows that Amprion and the TSOs curtailed 3.5 GWh of renewable energy to ensure grid stability. The discrepancy between renewable oversupply in the north and shortage in the south exacerbates congestion costs and increases pressure for grid expansion.

German wholesale prices stand at €86.80/MWh, French prices at €22.06/MWh – a 4:1 disparity driven by gas price shocks following the Iran conflict and missing nuclear capacity. Households pay 35–38 ct/kWh, 50–80% above UK and US prices. The structural problems of the German electricity market threaten competitiveness and industrial location.

The four TSOs (50Hertz, Amprion, TenneT, TransnetBW) published the NEP 2037/2045 and demand that green energy generators participate in grid expansion costs. Ultranet is to be completed by end of 2026, A-Nord by 2027. The call for cost allocation to renewable operators signals a turning point in burden-sharing of the energy transition.

Vattenfall as default supplier in Berlin/Germany automatically creates electricity accounts after relocations without customers being aware – cases sometimes remain undiscovered for 2 years. The discussion reveals regulatory and transparency gaps for default suppliers and generates legal uncertainty for consumers. Relevant for customer service and regulatory compliance in the energy industry.

Online discussions reveal knowledge gaps about exchange market mechanics: negative prices occur when oversupply meets weak demand (e.g., Easter 2026), but price-setting functions through gas marginal-pricing, not average generation costs. This asymmetry explains why renewable expansion alone does not lower household electricity prices without market reforms.