Carport PV

Pools have a daytime load profile that fits PV well: pumps run during opening hours (typically 9 a.m.-9 p.m.), ventilation ramps up in day operation, heat-pump heat-up can be time-shifted. Without load management the self-consumption ratio is 30-40 %. With load management (all main loads controlled): 60-75 %. Adding BESS: 80-90 % is possible but only economic at high day-ahead spreads. Example potential: 643 kWp × 815 kWh/kWp/a = 524 MWh/a; at 60 % self-consumption = 314 MWh/a × (0.25 − 0.06) €/kWh = 60 k€/a of extra saving from load management.

Basis: Practice studies

The market master-data registry requires all PV and storage systems above 800 W to be registered within one month of commissioning. An existing 243 kWp roof PV is registered; a new 400 kWp car-port PV must be registered at commissioning. Registration is a precondition for feed-in tariffs, and the registry entry is often required as proof for grant funding.

Basis: Grid registry (BNetzA MaStR)

This regional renewables programme funds market-introduction investments at 30 %, with faster processing than ISEK (typically 3-4 months). It applies to PV systems, load-management systems and (limited) storage. It combines with ISEK on the same property but not on the same measure. Relevant example: a 400 kWp car-port PV array could be funded at 30 % here or 50 % via ISEK — the higher ISEK rate is strategically better but not guaranteed to be eligible for PV.

Basis: Regional renewables market-introduction grant

VDE-AR-N 4105 governs the connection of generation systems to the low-voltage grid. Systems above 30 kVA must participate in the grid-operator control scheme — the operator may curtail feed-in when the grid is critically loaded. A pool with 643 kWp is well above this threshold. The local low-voltage cluster score is 7/10, so the probability of curtailment is low but technically possible. Load management lowers this risk because less power is fed in.

Basis: VDE-AR-N 4105

Stationary battery storage (BESS) in a public pool is currently not economical at sites without redispatch stress and with a low day-ahead spread. Typical site: redispatch score 0/10 (no curtailment), grid-control score 7/10 (little curtailment leverage). Day-ahead spread ~150 €/MWh — too little for BESS arbitrage. Re-evaluate in 2028/29 if the spread exceeds 200 €/MWh or a grant co-funds storage. For now, load management (synchronising HP/ventilation/filters to PV) with a payback below 1 year is the far better investment.

Basis: Practice + site analysis