Britain’s energy regulator Ofgem has opened a consultation on a new refundable Data Centre Commitment Fee for large data center grid connections, part of an effort to clear a badly congested connection queue in Great Britain. The proposal pairs the fee with deliverability milestones requiring developers to show financial capability, commercial maturity, and procurement activity before their projects can move forward. The consultation runs through September 16.
The move responds to a sharp spike in contracted demand offers, which rose from 41 GW to 125 GW between November 2024 and June 2025. Ofgem estimates data centers now account for roughly 73 GW of that queue, and the regulator is concerned that speculative, nonviable applications are crowding out credible projects and skewing long-term network planning.
From First-Come to Prove-It
Under the proposal, the fee would range from £237,500 to £712,500 per megawatt (roughly $315,000 to $946,000 per MW), equivalent to about 2.5% to 7.5% of average project costs. For a 100 MW development, that translates to a security requirement of approximately £23.8 million to £71.3 million, according to analysis from law firm Walker Morris. The fee would be refunded once a project is energized, but forfeited if the developer exits the queue early. It would apply on top of existing transmission security requirements.
Kristina Lesnjak, EMEA research manager at DCByte, said the change effectively shifts grid access from a largely chronological process to one based on demonstrated deliverability, which should filter out speculative projects while rewarding developments that can prove they will actually get built. She stressed that transparent evidence requirements and firm deadlines will be essential to prevent the process from becoming an arbitrary barrier for credible but smaller developers.
A Potential Two-Tier Market
The policy fits into a broader trend of grid operators demanding proof of both demand and the ability to support it. In the US, PJM has proposed similar rules requiring large loads to secure generating capacity or accept curtailment during shortages, aiming to keep costs of unverified demand off existing ratepayers.
In Great Britain, Lesnjak said the likely beneficiaries are operators with a track record of delivering large campuses, deep capital reserves, and projects viewed as strategically important. That could create a two-tier market where fast-tracked strategic projects move ahead while smaller, non-strategic schemes face lengthy delays, even if those projects are genuinely viable.
Rethinking Site Selection
The fee could also push smaller developers to reconsider where and how they build. Options include looking beyond congested clusters toward lower-demand regions such as northern England and Scotland, pooling resources to finance local generation, or combining non-firm grid connections with on-site energy assets. Power procurement, Lesnjak noted, is becoming a central part of project planning rather than a step that follows site selection.