A connection date can shape an entire development. It influences when equipment can run, when a building can open and how much capacity a business can use. For a project facing a constrained electricity supply, the practical question is simple: what power will be available, where, and when?
The much-quoted 700GW queue captured the scale of Britain’s connection problem. In December 2025, the National Energy System Operator (NESO) described the old queue as more than 700GW of generation and storage seeking access to the network. That is a historical description, not today’s queue total. NESO’s December 2025 announcement provides the starting point.
“The queue is the product” expresses a commercial reality: access to usable capacity has value alongside the electricity itself. But a national headline cannot tell you when an individual site will be ready. That requires a closer look at both the network offer and the site’s needs.
What 700GW actually measured
A gigawatt is a unit of power: a measure of capacity, rather than the amount of electricity consumed over a year. Proposed wind farms, solar projects and batteries do not behave like continuous electrical loads. Their connection capacities cannot simply be treated as demand that Britain must supply at once.
The queue was also a pipeline of proposals. A connection agreement does not establish that a project has secured every consent, completed its financing or become ready to build. Queue size and deliverable capacity are different things.
This matters when interpreting comparisons with national peak demand. Such comparisons can make an arresting headline while concealing differences between generation, storage and consumption. The useful question is whether the right capacity can connect in the right place, at the right time.
Reform changed who moves forward
In April 2025, Ofgem approved reforms that introduced readiness and strategic-alignment tests for the connection process. Its impact assessment recorded 765GW of contracted projects in February 2025 and described new connection offers extending into the late 2030s. Those figures describe the conditions behind the reform, rather than a standard waiting time for every business. Ofgem’s impact assessment explains the rationale.
By December 2025, NESO announced a prioritised pipeline of 283GW of generation and storage, alongside 99GW of transmission-connected demand. More than 300GW of projects would not advance at that stage, although reapplication remained possible. These were different categories within a reformed process; they should not be combined casually with earlier totals or read as capacity already delivered. NESO’s announcement sets out the distinctions.
Nor does a smaller queue build the network. In August 2026, Ofgem reported that the queue was less than half its size before queue formation, while acknowledging continuing delays. Reform can improve the order in which projects progress. Physical infrastructure and delivery still matter. Ofgem’s progress update makes that distinction clear.
Demand connections need their own assessment
A factory or data centre seeking electricity is not in the same position as a generator seeking to export it. Ofgem’s February 2026 review distinguished the readiness rules for demand from the readiness-and-need tests applied to generation, storage and interconnection. Distribution-connected demand also sat outside the Gate 2 Criteria Methodology. Ofgem’s demand review explains these differences.
Demand reform has continued separately. In July 2026, Ofgem consulted on proposed data-centre connection reforms, including a commitment fee and evidence of project progress. At the editorial check on 20 October 2026, that consultation was closed and awaiting a decision. The proposals should therefore not be presented as settled requirements. The consultation page records its status.
For a site owner, the next step is to obtain a clear account of the available import capacity, proposed energisation date, required network works and conditions attached to the offer. Establish whether an initial phase can operate within existing capacity and what a later expansion would require.
A national average, even where available, cannot replace those answers. Neither can a promise that queue reform will automatically bring a particular site forward.
Start with the load, then compare the routes
The most useful starting point is the site’s operating profile. How much electricity does it need through the day? Which loads are essential? Are there short start-up peaks, seasonal changes or processes that can move to another time?
Use that picture to compare demand reduction, phased expansion, flexibility and on-site generation. Set out what each option delivers, what it depends on and what happens if its timetable slips. Pinion’s How it works page provides a route into discussing the assessment process.
On-site generation deserves consideration where it could reduce imported power or support a different operating plan. Its value must be tested against the site’s requirements, including fuel availability, electrical integration and maintenance. The government’s CHP project-development guide treats interconnections, site services and commissioning as part of the project, rather than incidental details.
The Technology page introduces the system approach, while Deployments offers further context for considering applications. Neither a configuration nor an example establishes the timetable or economics for a new site. Those need their own evidence.
Generating locally still requires integration
On-site power is not automatically independent power. Generation operating in parallel with the public distribution network falls within the relevant connection process. Electricity North West’s G99 guidance describes the technical-compliance and protection-testing requirements. Designing for no export should not be mistaken for removing all network obligations.
A credible proposal also explains what supplies essential loads during maintenance, a generator trip or a fuel interruption. Independent operation must be designed deliberately; the presence of a generator alone does not answer the resilience question.
Heat and cooling deserve the same attention. Combined heat and power recovers heat for useful demand, so matching that demand to the system is central to the assessment. Government CHP guidance explains the principle. If the site needs cooling, recovered heat can also be assessed as an input to absorption chilling. That still involves auxiliary electricity and heat rejection, as the US Department of Energy’s chiller guide explains. Explore Cooling with those system boundaries in mind.
Environmental performance needs an explicit comparison too. Assess fuel use, useful heat and cooling, and the electricity and heat displaced; do not assume a universal carbon saving. Pinion’s Sustainability page is a starting point for that discussion. Check the applicable environmental controls as part of feasibility: Environment Agency and Natural Resources Wales guidance explains when specified-generator permits are needed in England and Wales.
Make the power plan specific
The strongest response to a constrained connection is a plan with defined dependencies. Put the network offer, operating profile and alternative supply options alongside one another. Compare complete costs, realistic delivery stages, environmental effects and the arrangements that keep essential operations running.
The queue headline explains why access to power deserves early attention. The decision belongs at site level: a dependable supply plan, supported by evidence, that fits the business you intend to operate.