North Falls Offshore Wind Farm: development consent order, Planning Act 2008

What changed

The Secretary of State granted a development consent order for North Falls on 14 May 2026, authorising construction, operation, maintenance, and decommissioning of an offshore wind farm of up to 57 turbines and roughly 1 GW capacity, sited about 40km off the East Anglia coast in the southern North Sea. The DCO is the consenting route for nationally significant infrastructure under the Planning Act 2008: it bundles the planning permission, deemed marine licences, and compulsory acquisition powers into a single instrument, so the grant clears the principal planning barrier in one decision rather than a sequence of separate consents.

The applicant is North Falls Offshore Wind Farm Limited, the joint venture vehicle held by SSE Renewables and RWE. The decision takes effect on grant, subject to the standard six-week judicial review window during which the order can be challenged in the High Court. Absent a successful challenge, the development rights are now fixed and the project moves from a consenting question to a financing and connection question.

What this means in practice

The constraint that has been lifted is binary. North Falls could not be built without the DCO; it now can. That matters more than any marginal change in the project's economics, because availability precedes affordability: a consented project that reaches financial close adds ~1 GW of capacity, while an unconsented one adds nothing regardless of its strike price. For the developer, the value of the consent is partly that it removes the planning option's expiry risk and partly that it converts the project into a bankable asset that can be taken into a CfD round and a connection negotiation.

It is necessary but not sufficient. Three things still gate financial close, and none is in the developer's gift:

- CfD allocation. North Falls needs an award in a future allocation round to secure a fixed strike price. Until then the developer carries construction and capital risk on a merchant basis, which for a ~1 GW fixed-bottom project running into the billions is not a position SSE/RWE will hold to FID. The CfD is the mechanism that transfers price risk from developer to consumer: if North Falls clears a round, the strike-price top-up is paid by the Low Carbon Contracts Company and recovered from suppliers through the levy, which passes through to bills. The cost is not the strike price in isolation; it is the difference between strike and captured wholesale price, multiplied by output, over 15 years, and it is unseen on any single bill. - A grid connection date. The consented capacity adds to a southern North Sea / East Anglia transmission corridor that is already congested. A connection offer with a credible energisation date is the harder of the two gates: the queue, not the planning system, is now the binding constraint for projects in this corridor. The DCO does not move North Falls up the connection queue. - No successful judicial review. The six-week challenge window applies. DCOs for offshore wind are routinely challenged, usually on habitats or seascape grounds; the consent is not unconditional until that window closes.

The cost allocation is the standard split. Pre-CfD, construction and capital risk sit entirely with the developer. Post-CfD, price risk sits with consumers via the supplier levy. Curtailment and transmission reinforcement in the East Anglia corridor are socialised: curtailment is paid through balancing costs and reinforcement through TNUoS, both smeared across the demand base rather than borne by the project that adds to the congestion. Adding ~1 GW into a constrained corridor is precisely the situation where the locational cost the developer does not face shows up later as a system cost everyone faces.

What happens next

The immediate milestone is the close of the judicial review window roughly six weeks from 14 May 2026. If unchallenged, the DCO is final and the project's path runs through commercial gates rather than the planning system.

The decisive event is the next CfD allocation round. North Falls' timeline to FID is set by when it can enter a round and clear it at a strike price that supports the capital stack; that, not the consent, determines whether and when the 1 GW is built. Watch the AR parameters (the administrative strike prices and budget for fixed-bottom offshore wind) as the leading indicator of whether projects in this cohort are financeable at current capex.

Running in parallel, the developer will be pressing for a firm connection offer and energisation date. Connections reform and the Gate 2 reordering of the queue are the relevant backdrop: a consented project with a CfD but no credible connection date is still stranded. The sequence that gets North Falls onto the system is consent (done), CfD (pending), connection (pending), in that order, and the last two are where the delivery risk now lives.