The Irish regulator is advancing a tariff reform that could materially reshape the economics of battery storage by eliminating dual grid charging structures that industry participants have long identified as a barrier to deployment.
Commission for Regulation of Utilities has issued a Minded To decision proposing that energy storage units be charged solely under Generation Transmission Use of System tariffs, rather than facing both generation and demand related grid fees. The move is intended to address distortions linked to volumetric charging models, which have historically treated storage assets inconsistently within the Single Electricity Market spanning Ireland and Northern Ireland.
The regulatory shift reflects a reassessment of a temporary framework introduced in 2020, when storage systems were assigned Demand Transmission Use of System charges as an interim measure. At the time, the approach aimed to facilitate early market entry, but the regulator now acknowledges that the structure did not accurately reflect how battery systems interact with the grid and may have constrained investment. Since then, storage assets have evolved from primarily providing ancillary services to participating more actively in wholesale electricity markets, fundamentally altering their operational profile.
From a system design perspective, the distinction between demand and generation tariffs is not merely administrative. Storage assets both consume and inject electricity, making them difficult to categorize within traditional tariff frameworks designed for one directional flows. Charging both demand and generation fees effectively penalizes storage for performing its core function of shifting energy across time, which can discourage utilization even where system benefits are clear.
The proposed shift to generator only charges introduces a more neutral treatment, aligning storage with other generation technologies that provide similar services. The regulator argues that this approach will also deliver clearer locational signals, potentially guiding storage deployment toward areas of grid congestion or renewable curtailment. However, the redistribution of network costs will not be neutral across all users. The CRU estimates that remaining demand side customers could see network charges increase by around 2 percent, translating into an approximate 0.2 percent rise in standard household electricity bills.
Industry analysis cited in the decision suggests that removing demand side charges could increase storage utilization by around 30 percent, generating net system savings of approximately 37 million euros annually. These projected gains are tied to more efficient use of existing renewable generation, particularly during periods of excess supply that would otherwise be curtailed or sold at depressed prices.
Energy Storage Ireland has characterized the proposal as a positive development for the sector, reflecting long standing calls for tariff structures that better reflect the system value of storage. The policy direction is also closely linked to Ireland’s legally binding target of achieving 80 percent renewable electricity by 2030, a threshold that will require significantly higher levels of flexibility to maintain system stability.
The timing of the reform highlights a divergence in regulatory approaches across Europe. While Ireland is moving toward reducing cost burdens on storage assets, uncertainty in other markets is having the opposite effect. In Germany, for example, proposals by the federal regulator to remove existing grid fee exemptions for storage systems have introduced investment risk, particularly given the possibility of retrospective application. Market participants have indicated that such uncertainty can disrupt capital allocation decisions even in otherwise favorable market conditions.
