UK CfD Allocation Round 7

UK CfD Allocation Round 7 (AR7, 2025)

1. At a glance

Source documents (12 primary sources, ~827 PDF pages, ~253,000 parsed words): pot-and-price-notice, allocation-framework, application-window-notice, cib-budget-notice, cib-allocation-framework, standard-terms-and-conditions (577 pp, 180K words — the master contract), generic-agreement, application-guidance (NESO), cma-report (CMA Subsidy Advice Unit), budget-notice, budget-revision-notice, results.

2. Market context at time of auction

AR7 was designed against a narrower but more acute policy backdrop than its predecessor. By late 2024 three facts had become impossible to ignore:

Clean Power 2030 and the 50 GW target. The Labour government elected in July 2024 adopted the "Clean Power 2030" mission — a commitment to decarbonise the electricity system by the end of the decade, requiring a step-change in offshore wind deployment on top of the existing 50 GW by 2030 target. Great British Energy was established during 2024–25 to supplement private investment, and NESO's Strategic Spatial Energy Plan work began. Against this policy frame, AR6's ~5.3 GW of fixed offshore wind awards (before Hornsea 4's cancellation) was insufficient to meet the 2030 pathway — a CfD round much larger than any previous was required.

Hornsea 4 cancellation (7 May 2025): Ørsted walked away from 2,400 MW of AR6 capacity (71% of AR6 new fixed offshore wind; 48.6% of total AR6 fixed OSW) before Final Investment Decision, citing "continued increase of supply chain costs, higher interest rates, and an increase in the risk to construct and operate". The episode demonstrated that AR6's £58.87/MWh (2012 prices) new-OSW clearing price was insufficient to sustain commitment through financing close. Without design changes, a repeat in AR7 was a real prospect.

Supply chain and cost backdrop. Global offshore wind was in "growing pains": turbine suppliers (Siemens Gamesa, Vestas, GE) all issued loss warnings through 2023–24; vessel supply was constrained for installation windows; steel and copper prices remained elevated; interest-rate environments had shifted the weighted cost of capital meaningfully upward for all renewables projects. Developers had consistently signalled that AR6-era pricing was no longer viable for new-build.

Against that backdrop, DESNZ announced in 2024 a "Targeted Reform of Allocation Rounds" (TRA) package that became AR7's design skeleton:

1. Contract term extended from 15 to 20 years for offshore wind, floating offshore wind, onshore wind, remote island wind, and solar PV. This lowers the blended cost of capital required by a given strike price by spreading the revenue-stabilisation window.
2. A new non-price factor — the Clean Industry Bonus (CIB) — making investment in UK supply chain and Science-Based-Targets manufacturing a pre-requisite for round entry, with an additional competitive budget for "CIB extra" proposals.
3. Anonymised bid information disclosed to the Secretary of State before auction (per Regulation 54 of the CfD (Allocation) Regulations 2014 — pre-existing regulation whose §(3) was amended in 2025 by SI 2025/903 to remove the old restriction on bid-price information being shared early; AR7's allocation-framework Rule 13 is the first application of the amended Reg 54, scoped to Fixed-Bottom Offshore Wind only). This enables the government to see the clearing-price distribution and decide whether to increase the budget mid-round to unlock marginal projects.
4. Permitted Reduction closed — the AR6 rebid mechanism for AR4 winners is no longer available in AR7. Per allocation-framework Rule 5.1(b), applications are excluded if any part of the CFD Unit was "subject to a CFD Agreement signed pursuant to Allocation Rounds 1-6, and surrendered through a capacity adjustment" (i.e. the AR6 PR mechanism). AR7 is strictly a new-capacity round.
5. Unconsented Fixed-Bottom OSW eligibility — projects without full DCO consent may bid provided they meet Rule 4.1(k) (no refusal issued) and submit the Schedule 7 Director's declaration. This enabled Dogger Bank South East / South West (≈3 GW, RWE-Masdar joint venture) to enter AR7.
6. Pot 3 split via Maxima into Offshore Wind vs Offshore Wind Scotland, with a different maximum for each sub-category, producing two separate clearing prices within one pot.
7. Price base shift from 2012 to 2024. AR7 bids are submitted and cleared in 2024 prices. Results are published in both 2012 and 2024 prices for continuity with historical series.
8. Pot 3 and Pot 4 carved out as a dedicated round (AR7); all other technologies run in AR7a. This separates the offshore-wind cadence and budget from the other-technologies cadence and budget, giving DESNZ independent timing and budget control for each.

Subsidy Advice Unit scrutiny. Under the Subsidy Control Act 2022 (the UK's post-Brexit successor to EU state-aid scrutiny), DESNZ referred the proposed AR7 scheme to the CMA Subsidy Advice Unit (SAU), which published its report on 16 October 2025. The referral is voluntary but provides independent assessment of whether the scheme meets the subsidy control principles. The SAU report does not have veto power, but its commentary on design choices (CIB structure, mid-round revision mechanics, Permitted Reduction closure) feeds industry confidence.

Policy narrative. Labour's explicit policy frame — articulated through DESNZ press releases and the 2024 reform consultation response — was that AR7 was the first round built around capacity procurement rather than subsidy cost minimisation. The CIB package, 20-year contracts, and mid-round budget uplift capability collectively shifted the policy objective: the auction's success metric became GW awarded, not £/MWh saving. This matters for how the results should be read — AR7's record 8.4 GW, procured at £91.20/MWh (2024) — is fifteen percent above AR6's equivalent strike price in real terms, but captured roughly twice the capacity. That was, by design, the trade-off.

3. Regulatory frame (brief)

The AR7 auction sits inside the same statutory regime as AR6. Key actors for this round:

Statutory instruments:

• Energy Act 2013 (scheme foundation; empowers CfD Counterparty)
• Contracts for Difference (Allocation) Regulations 2014, as amended by the Contracts for Difference (Sustainable Industry Rewards) Regulations 2024 (introducing the Clean Industry Bonus / SIRs regime)
• Contracts for Difference (Standard Terms) Regulations 2014, as amended
• Electricity Act 1989 (Section 36 consents in Scotland; OFTO regime)
• Planning Act 2008 (NSIP/DCO in England/Wales)
• Subsidy Control Act 2022 (scheme scrutiny via the CMA Subsidy Advice Unit)

Per-AR7 design documents (in hierarchy order, per allocation-framework Rule 30):

1. Allocation Regulations and Eligible Generator Regulations (prevail over Framework)
2. AR7 and AR7a Contract Allocation Framework (the round-specific rulebook)
3. Pot and Price Notice (23 July 2025)
4. Application Window Notice (24 July 2025)
5. Contract Budget Notice (27 October 2025)
6. Contract Budget Revision Notice (19 December 2025, effective 23 December 2025)
7. CIB Allocation Framework (22 January 2025 corrected; originally November 2024)

4. Pre-round preparation and timeline

AR7 followed an extended preparation pattern — the longest end-to-end timeline of any CfD round to date — driven primarily by the CIB pre-qualification window, the AR7/AR7a establishment sequencing, and the mid-round budget revision mechanics.

4.1 Full chronology

4.2 Elapsed time summary

• CIB Framework published → AR7 established: ~3 weeks
• AR7 established → CIB window opens: ~13 weeks
• CIB window closes → Allocation Framework published: ~14 weeks (covers CIB assessment + further reform consultation + legislative amendments)
• Allocation Framework → Application window opens: 2 weeks
• Application window open → close: 3 weeks (20 Working Days: 7 Aug → 27 Aug)
• Application close → Contract Budget Notice: ~9 weeks (covers qualification + appeals)
• Contract Budget Notice → Sealed bid window opens: 15 working days (27 Oct → 11 Nov, matching Rule 11.2(c))
• Sealed bid opens → close: 5 working days (11 Nov → 17 Nov)
• Sealed bid close → Budget Revision Notice: ~4 weeks (17 Nov → 19 Dec — covers Rule 13.4 anonymised bid info transmission + SoS decision)
• Budget Revision effective → Results: ~3 weeks (23 Dec → 14 Jan 2026 — covers auction run 5–9 Jan + audit + SoS review)
• Results → CfD contracts signed: ~10 weeks (14 Jan → 25 Mar 2026)
• Total from AR7 establishment (Nov 2024) to results (Jan 2026): ~14 months
• Total from application open (Aug 2025) to results: ~5 months — similar to AR6's cadence

4.3 Was AR7 on time?

No published timetable suggested an earlier-than-January 2026 results date. The CIB pre-qualification window and the post-AR6 reform cadence both extended the timeline, but DESNZ avoided the kind of "five potential timeline scenarios" language that AR6 used on opening. The round ran to its intended schedule. The 19 December 2025 Budget Revision occurred within the 5-working-day window after NESO's Anonymised Bid Information was received (per Rule 13.4) plus a short decision period by the Secretary of State, confirming that the "see the bidstack, then revise" loop functioned as designed.

4.4 Why the Budget Revision was legally possible and operationally different from AR6

AR6 used a Regulation 12 Budget Revision Notice to uplift all pots after NESO's pre-sealed-bid valuation — a decision made without sight of bid prices. AR7's revision is fundamentally different: per Rule 13 of the Allocation Framework and the 2025-amended Regulation 54 (amended by SI 2025/903 to remove the prior restriction on bid-price information being shared early), NESO may send Anonymised Bid Information to the Secretary of State before the auction is held for Fixed-Bottom Offshore Wind only, "assured by the Auditor", within 5 Working Days of the Submission Closing Date. The Secretary of State can then exercise the upward-only revision power with knowledge of the bid stack. The mechanism targets the specific marginal-bidder problem: the question "would procuring the next few hundred megawatts at a higher marginal strike price represent value for money?" can now be answered empirically rather than on pre-bid forecast alone. AR7 is the first round to apply the amended Reg 54.

Important narrowing: this disclosure applies to Fixed-Bottom Offshore Wind CFD Units only. Floating Offshore Wind bids are not disclosed to the Secretary of State pre-auction. This choice reflects DESNZ's policy assessment that Pot 4's smaller budget and smaller pipeline make a marginal-capacity decision less material than for Pot 3.

The Rule 13 mechanism operated exactly as designed in AR7: Pot 3 budget increased from £900 m to £1,790 m (98.9%), Pot 4 unchanged at £180 m. The £890 m uplift directly enabled the record 6,865 MW fixed OSW + 1,380 MW Scottish OSW awards. Without the uplift, a substantially smaller AR7 would have resulted.

5. The prize — CfD contract mechanics

A winning AR7 bid delivers a 20-year revenue-stabilised subsidy contract with LCCC. The core two-sided CfD mechanics are inherited from AR6, but several AR7-specific parameters and features require separate treatment.

5.1 The two-sided CfD

Unchanged from AR6 in structure. Each Settlement Unit (half-hour), LCCC calculates a Difference Amount per unit of metered output:

Difference Amount = (Strike Price – Reference Price) × Metered Output

• If positive (Reference < Strike), LCCC pays the Generator the top-up.
• If negative (Reference > Strike), the Generator pays LCCC the claw-back.

Over a Billing Period, the half-hourly amounts aggregate to a Net Payable Amount. The mechanics are detailed in Condition 22 (Billing Statements and Net Payable Amounts).

5.2 Strike Price — new 2024 price base

This is where AR7 departs from the historical pattern. The Strike Price is the nominal value awarded at auction, quoted in 2024 prices for the first time. It remains CPI-indexed annually on the Indexation Anniversary using the same ratio formula as AR6, but with a different base year.

AR7 strike prices, all in 2024 prices:

• Offshore Wind (rest of GB): £91.20/MWh
• Offshore Wind Scotland (Berwick Bank B only): £89.49/MWh
• Floating Offshore Wind (Erebus, Pentland): £216.49/MWh

For cross-round comparison, the results document also reports strike prices in 2012 prices using the published CPI conversion factor of 0.7177 (£1 in 2024 prices = £0.7177 in 2012 prices):

• Offshore Wind: £65.45/MWh (2012)
• OSW Scotland: £64.23/MWh (2012)
• Floating: £155.37/MWh (2012)

A June 2025 CPI inflator of 1.0373 for re-basing 2024 prices to then-current money is also published.

5.3 Reference Price

Unchanged from AR6. For intermittent technologies (offshore wind, floating offshore wind), the Reference Price is the Intermittent Market Reference Price (IMRP) — a time-weighted day-ahead index computed from Initial IMRP Indices specified in the AR7 Standard T&Cs. Baseload technologies use the BMRP (Baseload Market Reference Price).

5.4 Negative pricing rule

Unchanged from AR6. For every Settlement Unit where the IMRP is negative, the Intermittent Difference Amount is zero — LCCC pays nothing, and the Generator receives whatever market revenue (possibly negative) it generates. There is no minimum-duration threshold (no 6-hour rule) — a single negative half-hour results in zero CfD top-up for that half-hour.

5.5 Contract term — the 20-year clock

The single most important financial change from AR6 to AR7. Per Clause 3 and footnotes 4–5:

The "Specified Expiry Date" applicable to this Contract for Difference is: **⁴ / **⁵.

Footnote 4 (15-year clause): delete if the Facility Generation Technology is any of the following: Offshore Wind, Floating Offshore Wind, Onshore Wind, Remote Island Wind or Solar PV.

Footnote 5 (20-year clause): delete if the Facility Generation Technology is not any of the following: Offshore Wind, Floating Offshore Wind, Onshore Wind, Remote Island Wind or Solar PV.

Rule for AR7 offshore wind: the 20-year term applies. All 12 AR7 CFD Units receive 20-year contracts from the earlier of the Start Date and the last day of the Target Commissioning Window. All other technologies (Tidal Stream, ACT, AD, Geothermal, Dedicated Biomass with CHP, Energy from Waste with CHP, Hydro, Landfill Gas, Sewage Gas — relevant to AR7a not AR7) retain the 15-year term.

The clock mechanics are identical to AR6's: earlier-of rule (prevents gaming by slow commissioning); no pause for late delivery (Generator forfeits subsidy years if the project commissions past the TCW end).

Why it matters. Extending the term from 15 to 20 years reduces the required strike price for a given project NPV target by reducing the amortisation pressure — the revenue stream is spread across a longer stable-revenue window. The back-of-envelope impact depends on discount rate and expected wholesale price path, but a rough rule is that a 20-year CfD requires approximately 85-90% of the strike price that a 15-year CfD at the same project economics would require. This is a direct policy lever calibrated to the post-2022 cost environment: DESNZ accepts longer subsidy exposure in exchange for lower per-MWh unit cost. Cross-round comparisons of strike prices between AR6 and AR7 must therefore normalise for term, not just for price base.

5.6 Target Commissioning Window, Conditions Precedent, and Longstop

• Initial Milestone Delivery Date: 18 months after the Agreement Date, unchanged from AR6 pattern; specific date drafted into the Generic Agreement based on the technology's Milestone Delivery specification in the Standard Terms.
• Target Commissioning Window (TCW) per Schedule 6: up to 1 year for Offshore Wind and Floating Offshore Wind (same as AR6). Other AR7a technologies have shorter windows.
• Initial Conditions Precedent: 20 Business Days from Agreement Date per Standard Terms §3.3.
• Operational Conditions Precedent: must be fulfilled before Longstop Date = last day of Longstop Period following the TCW end. Extension grounds (day-for-day) under the AR7 STCs definitions of "Milestone Delivery Date", "Target Commissioning Window", and "Longstop Date":
  • (A) Force Majeure;
  • (B) TSO / Licensed Distributor / OFTO delay in required system reinforcement or connection works;
  • (C) For Offshore Wind or Onshore Wind only (not Remote Island Wind, not Floating Offshore Wind), MoD non-confirmation of Radar Mitigation Scheme mitigation measures;
  • (D) For Offshore Wind only (excluding Floating Offshore Wind): Relevant Applicable Planning Consent not having been granted, having been quashed, or having been refused, prior to the Milestone Delivery Date, where relevant.

This planning-consent extension limb is particularly relevant for AR7's unconsented fixed-bottom cohort (Dogger Bank South East + South West): if DCO is not granted by the Milestone Delivery Date, the Milestone Delivery Date extends day-for-day during the delay (subject to the detailed sub-conditions of paragraph (D), including that the Applicant has properly pursued the consent, observed time limits for Relevant Court Proceedings, etc.). The extension flows through to Target Commissioning Window and Longstop Date.

• Qualifying Change in Law (QCiL) events drive Strike Price adjustments via a separate Change in Law compensation machinery (Part 7 of the STCs) rather than TCW/Longstop extensions.

5.7 What happens if a project fails to commission

Identical to AR6 in mechanics (CfD termination by LCCC if OCPs not met by Longstop Date; the 20-year clock has already started at Start Date or TCW-end whichever is earlier, so late commissioning forfeits subsidy years). The higher stakes in AR7 are entirely about budget exposure per GW: an AR7 failure the size of Hornsea 4 would cancel more capacity than Hornsea 4 itself because the 20-year commitment is longer (though each year's subsidy is potentially smaller depending on actual wholesale prices).

5.8 The Clean Industry Bonus as a second revenue stream

The CIB operates as an additional revenue stream alongside the strike price, for successful "CIB extra proposals" only. For Generators who secure CIB funding in the primary allocation:

• The CIB payment is made by LCCC upon "successful delivery of CIB extra proposals".
• CIB payments are separately indexed per §20 of the CIB Framework.
• Non-delivery of CIB commitments triggers performance-related adjustments to CfD payments per the Standard T&Cs Part integrating CIB enforcement.
• The minimum standard (£100 m/GW for fixed; £50 m/GW for floating) is a pre-condition of eligibility; failure to meet minimum standards bars the generator from AR7 participation, so all 12 AR7 winners necessarily met the minimum.

The CIB is a genuine second competitive dimension — the first time UK CfD has used a non-price factor competitively. The competition is qualification (pass/fail) for the minimum standard and price-quality for the extras.

6. Budget architecture

AR7's revised Overall Budget (£1,970 m/year) is larger in nominal pound terms than AR6's revised peak annual cap (£1,555 m/year) AND much larger in capacity terms once the 20-year contract term is factored in. The per-year subsidy envelope is also calibrated to a different price base (2024 prices instead of 2011/12 prices), so direct numerical comparison is not apples-to-apples — see §6.4.

6.1 The initial Budget (27 October 2025)

From — all values in £m, 2024 prices:

DY = Delivery Year; VY = Valuation Year — the Pot 3 Delivery Years are 2028/29, 2029/30, 2030/31 (with 2031/32 and 2032/33 as follow-on Valuation Years); Pot 4 Delivery Years are 2028/29 and 2029/30 (with 2030/31 and 2031/32 as Valuation Years). The 2032/33 Overall Budget drops to £900 m because Pot 4's valuation period has ended.

How to read this: a Pot 3 project with TCW Start Date in 2029/30 draws from the £900 m/year Pot 3 budget in that Delivery Year and in all applicable subsequent Delivery and Valuation Years (2029/30, 2030/31, 2031/32, 2032/33 in the published table). Subsidy continues to 2048/49+ under the 20-year term, but the Budget Notice only caps annual subsidy during the designated Delivery Years and immediate follow-on Valuation Years — because the rate of new-capacity commissioning is the tractable constraint. The 20-year exposure tail beyond 2032/33 is uncapped by the Budget Notice (though still contract-bound).

6.2 Maxima and their role — the new Pot 3 sub-division

Within Pot 3 (offshore wind), AR7 uses two Maxima that implement the new OSW / OSW-Scotland split:

• "Offshore Wind" Maximum — applies to projects connecting in GUS Tariff Zones 13-27 or DNO Licence Areas 10-16 or 19-23 (rest of GB)
• "Offshore Wind Scotland" Maximum — applies to projects connecting in GUS Tariff Zones 1-12 or DNO Licence Areas 17-18 (Scotland)

The Maxima are capacity-based, each totalling 30 GW, and operate as hard constraints. The Budget Notice is explicit about the design intent:

"Maxima will be applied on a capacity (GW) basis and operate as 'hard' constraints. Two separate Maxima, each totalling 30GW, will be applied to Offshore Wind Scotland projects and Offshore Wind projects in Pot 3. The level of the Maxima is purely technical. It has been set to ensure the auction separates the clearing prices of Offshore Wind Scotland projects and Offshore Wind projects while still awarding contracts in merit order."

30 GW per Maximum is far larger than any conceivable AR7 award volume — so the Maxima are not binding capacity limits. Their real function is mechanical: they are the hook that invokes Rule 19.4(d) of the Allocation Framework, which specifies that each Maximum runs its own separate clearing-price calculation. Without the Maxima, Pot 3 would clear at a single price equal to the highest successful bid across all bidders. With the two Maxima, Scotland and rest-of-GB each clear at the highest successful bid within their sub-category, producing two distinct clearing prices from a single ranked bid stack.

Hard vs Soft constraints: constraints expressed in capacity terms can be Hard or Soft (Soft means they may be exceeded during the interleaving process in Rule 19.6); constraints expressed in monetary terms are always Hard. The Budget Notice explicitly designates both Pot 3 Maxima as Hard, so Rule 16's Soft-Constraint machinery does not apply to them.

The Budget Revision Notice of 19 December 2025 explicitly confirmed that the Maxima were not revised — only the Overall Budget and Pot 3 Monetary Pot changed. The two 30 GW Maxima persist from opening to close.

Floating OSW (Pot 4): a separate Pot with its own Monetary Pot (£180 m) and no Maxima — floating OSW competes on a single clearing price, which Erebus and Pentland both cleared at (£216.49/MWh 2024).

6.3 The 19 December 2025 Budget Revision — triggered by anonymised bid data

Per ¶1:

"The Secretary of State is revising the budget for AR7 (as set out in the Contract Budget Notice given by the Secretary of State on 27 October 2025) with effect from 23 December 2025. The Overall Budget for AR7 will now be £1,970m. The budget for Pot 4 (Floating Offshore Wind) is not being revised; only the budget for Pot 3 (Offshore Wind) is being increased, to £1,790m."

Uplift summary (2024 prices, per Delivery Year in Pot-3 DY years 2028/29 – 2030/31; Pot 3 continues at revised level through 2032/33 Valuation Year):

Why the revision was taken: the Rule 13 anonymised bid information disclosure provided the Secretary of State with sight of the Pot 3 bid stack pre-auction. The bid distribution presumably indicated a meaningful volume of capacity available at prices below the ASP (£113/MWh 2024) with favourable cost-vs-budget economics in the £85-£95/MWh region. The revision enabled the auction to clear at £91.20/MWh (rest-of-GB) and £89.49/MWh (Scotland) against a doubled budget envelope. Without the revision, the auction would have closed substantially earlier in the bid stack.

Regulation 12(5) upward-only constraint — identical to AR6: the revision can only increase the Overall Budget; Maxima and Minima (if monetary) can only be increased if the Overall Budget is increased by at least the same amount. The AR7 revision was compliant: the Pot 3 Monetary Pot uplift of £890 m/year was matched exactly by the Overall Budget uplift of £890 m/year. Because the Pot 3 Maxima are capacity-based rather than monetary, they sit outside the Reg 12(5)(b) parity-with-Overall-Budget test — and they were left unchanged in any case.

6.4 Why this structure matters for cross-round comparisons

AR7's Pot 3 peak annual subsidy exposure of £1,790 m/year (2024 prices) is higher than AR6's £1,100 m/year (2011/12 prices) in both nominal and CPI-adjusted terms. The relevant comparison for procurement cost per MW needs to account for:

• 20-year vs 15-year contract term (AR7 locks in longer exposure per GW of awarded capacity).
• Price base shift (AR7's £1,790 m is in 2024 prices; AR6's £1,100 m is in 2011/12 prices). Using the published 2024-prices CPI conversion factor of 0.7177 (from pot-and-price-notice) — i.e. £1 of 2024 money = £0.7177 of 2012 money, and 2011/12 ≈ 2012 for rough comparison — AR6's £1,100 m/year (2011/12) ≈ £1,533 m/year in 2024 prices. AR7's £1,790 m (2024) is therefore roughly 17% higher in real terms than AR6's Pot 3 envelope.
• The Overall Budget comparison: AR7's revised £1,970 m/year (2024 prices) vs AR6's revised £1,555 m/year (2011/12 prices ≈ £2,166 m in 2024 prices). On that normalisation, AR7's Overall Budget is lower in real terms than AR6's peak — but AR6's Overall envelope had to cover all three Pots (Pot 1 established, Pot 2 less-established, Pot 3 OSW), whereas AR7's £1,970 m covers only Pot 3 and Pot 4. AR7a runs under a separate ~£295 m/year Overall Budget (per gov.uk AR7a Contract Budget Notice, Dec 2025 — not in the AR7 source-doc corpus since AR7a is a statutorily distinct round); combining gives ~£2,265 m (AR7 + AR7a in 2024 prices) vs £2,166 m (2024-equivalent of AR6 total) — roughly flat in real terms but structurally separated into two independent allocation exercises.

The combination of (a) roughly flat real-terms envelope and (b) a larger share of that envelope dedicated to offshore wind + floating (AR6 Pot 3 was £1,100m of £1,555m = 71%; AR7 Pot 3+4 is £1,970m of £2,265m combined = 87%) is what enables AR7's record fixed-OSW capacity outcome. DESNZ chose to concentrate a consistent real-terms envelope on offshore wind, sacrificing nominal Pot 1 / Pot 2 participation volume for AR7a.

7. Administrative Strike Prices

AR7 publishes Administrative Strike Prices (ASPs) in both 2012 and 2024 price bases. The 2024 prices are operational (used for bidding and valuation); the 2012 prices are informational (for historical series continuity).

From Tables 2 and 3:

Key observations:

Offshore wind and floating offshore wind ASPs raised ~11% in real terms vs AR6. DESNZ explicitly notes in the Pot and Price Notice that part of this increase reflects updated load-factor assumptions (load factors for OSW, Onshore Wind including Remote Island Wind, and Floating OSW are lower in AR7 than in AR6 due to updated internal departmental modelling) rather than any unit-cost change. Lower load factor → higher ASP for the same assumed £/kW capex, because budget impact per MW falls with lower output.

Solar PV ASP fell 11.8% — reflecting continued cost-reduction progress in solar manufacturing. Hydro rose notably (+18.3%) — small hydro has specific cost-escalation pressures that the ASP methodology picked up.

DESNZ's explicit framing of ASP role in AR7:

"amending the information that Government sees in the auction ('seeing the bidstack') means that Government has greater control over the price of Offshore Wind projects procured, hence the ASP will not play a meaningful role for AR7 beyond allowing National Energy System Operator (NESO) to run the auction."

This is the first time DESNZ has publicly stated that the ASP is essentially a technical backstop rather than a meaningful auction ceiling. The anonymised-bid-info + budget-revision loop effectively replaces the ASP as the price-discovery mechanism for Fixed-Bottom OSW. ASPs remain operationally important (they define Valuation Formula budget impact, cap the clearing price, and act as a fallback bid when none is submitted), but they no longer shape the auction's price outcome the way they did in AR5 and AR6.

The AR7 clearing discount on ASP was 19.29% (OSW, rest-of-GB), 20.81% (OSW Scotland), and 20.11% (floating) — consistent with AR6's 19-26% band but now achieved via a two-stage mechanism (bid → revise budget to admit → clear at marginal price) rather than a single-shot clearing.

8. Qualification criteria

AR7 introduces significant qualification-gate changes vs AR6 — primarily the Clean Industry Bonus pre-qualification, the new Unconsented Fixed-Bottom OSW pathway, and the closure of Permitted Reduction.

8.1 Planning consent — with a new unconsented-OSW carve-out

For most CfD Units, the planning-consent requirement is inherited from AR6:

• England/Wales ≥100 MW: Development Consent Order (DCO) under the Planning Act 2008.
• Scotland: Section 36 consent under the Electricity Act 1989.

NEW for AR7 — Unconsented Fixed-Bottom Offshore Wind pathway:

Projects without full Applicable Planning Consent may qualify if:

1. At Application time, no refusal of Applicable Planning Consent has been issued by the relevant issuing authority (or, if refused, formally overturned on appeal).
2. The Applicant submits a signed Director's declaration in the form prescribed by Schedule 7, confirming that no relevant Pending Applicable Planning Consents have been refused, no later than the Working Day before the Submission Closing Date.
3. The Director's signature must be dated no earlier than 11 Working Days before the Submission Closing Date — a freshness requirement.

Failure to submit the declaration in the proper form triggers withdrawal from the round.

Operational significance: this rule enabled Dogger Bank South East (1,500 MW) and Dogger Bank South West (1,500 MW) — neither of which had DCO consent at AR7 application time — to participate in AR7. Both are RWE–Masdar joint-venture developments (RWE 51% / Masdar 49%), with RWE as lead developer of the project company. This is the single most material qualification reform in AR7 relative to AR6, and the primary driver behind the ~3 GW of AR7 capacity attributed to the RWE-led development pipeline.

8.2 Grid connection

Unchanged from AR6: applicant must hold a valid grid connection offer with a defined connection date and point. AR7 happens against a backdrop of the NESO TMO4+ grid connection queue reform, which was progressing during AR7's application window — but TMO4+ reforms were not directly binding on AR7 qualification.

8.3 Clean Industry Bonus as a pre-requisite (NEW)

This is AR7's most consequential qualification innovation. Per §3.2:

"Eligible generators must successfully apply for a CIB Statement if they wish to enter the relevant CfD Allocation Round."

Mechanics:

1. CIB eligibility: only offshore wind and floating offshore wind generators, regardless of size. No other technologies are CIB-eligible in AR7 — pointing to the CIB as specifically a fixed + floating OSW supply-chain reform.

2. CIB application window: 13 February – 14 April 2025 (~43 working days). Pre-round — closed well before the main CfD application window opened on 7 August 2025.

3. Minimum standards:

   • Fixed-bottom OSW: ≥£100 m/GW of CfD Unit capacity invested in qualifying supply chain / sustainable-production components.
   • Floating OSW: ≥£50 m/GW of CfD Unit capacity.
   • Values indexed per §20.
   • Investment must be made by the CfD Unit's expected CfD Start Date.
   • Investment must be in tangible assets (ports, manufacturing facilities, installation firms, components including blades, nacelles, towers, foundations, cables, OFTO/network, installation vessels, mooring systems, floating substructures). Intangible assets (skills programmes, R&D) do not qualify.
   • A share may be invested via the Offshore Wind Industrial Growth Plan (IGP) delivery body as a pooled-investment vehicle.

4. Two CIB criteria:

   • Criterion 1 — Investment in shorter supply chains: manufacturing facility, installation firm, or port located in a UK deprived area (Local Authorities in England with 1-4 deprivation measures in the bottom quartile per "Levelling Up the UK"; Scottish SIMD 2020 deciles 1-5 on overall deprivation or deciles 1-2 on geographic-access-to-services; Welsh IMD 2019 deciles 1-5; NI NIMDM 2017 deciles 1-5).
   • Criterion 2 — Investment in more sustainable means of production: manufacturing facilities or installation firms that have set or committed to a Science-Based Target (per the SBTi) by the first day of the CIB application window.

5. Minimum standard assessment: the aggregate value of minimum-standard proposals must be ≥£100 m/GW (fixed) or ≥£50 m/GW (floating). DESNZ issues a CIB Statement confirming minimum standard met (or a refusal notice). Failure to secure a CIB Statement = no AR7 participation.

6. Performance-related adjustments post-award: if a Generator is awarded a CfD but fails to deliver CIB minimum-standard commitments, the Standard T&Cs impose performance-related adjustments to CfD payments — effectively a reduction in strike price applied to the full 20-year contract. This is how the CIB pre-requisite gets enforcement teeth.

7. IGP delivery body option: allows Generators to pool minimum-standard investment via the Offshore Wind Industrial Growth Plan's delivery body, which then invests on their behalf according to the framework's criteria. Particularly relevant for smaller players or consortia where direct supply-chain investment is harder to structure.

8. CIB "extra" proposals: up to 10 extras per CfD Unit, each with up to 3 variants (effectively up to 30 variants per Unit). These compete for a separate CIB budget (see §9 below).

8.4 Bid submission constraints — different for fixed vs floating

Major change from AR6:

• Fixed-Bottom Offshore Wind CFD Units may submit only ONE sealed bid per application. Flexible Bids are not available to fixed-bottom OSW. Per Rule 12.1, the single bid must specify Strike Price (2024 prices), Target Dates, and capacity of the CFD Unit.
• Floating Offshore Wind CFD Units may submit up to four Flexible Bids per application, with varying capacities and/or Target Dates, no more than two bids with a Target Commissioning Window Start Date in the same Delivery Year. All Flexible Bids must be at different Strike Prices, expressed to the nearest £0.001, with the lowest-Strike-Price bid in each Delivery Year expressed to the nearest £0.01.
• Bid precision: lowest bid per Delivery Year to nearest £0.01; other Flexible Bids to nearest £0.001.
• No submission = default ASP bid: the Delivery Body assigns the application a bid of the relevant ASP with the original capacity and dates. A qualified applicant cannot accidentally exit by non-submission.

Operational significance of the fixed-vs-floating asymmetry: AR7's fixed-bottom CfD Units (all 10 of them: Awel y Môr, Berwick Bank B, Dogger Bank SE, Dogger Bank SW, Norfolk Vanguard East A/B/C, Norfolk Vanguard West A/B/C) each entered at a single strike price. The result that the auction cleared fixed-bottom at a uniform £65.45/MWh (2012) / £91.20/MWh (2024) for all non-Scottish projects therefore reflects both the Maximum-only clearing mechanic AND the fact that no bidder had flexibility to "step up" at a later Flexible Bid price. Floating OSW (Erebus and Pentland) had Flexible Bid capability but appears not to have needed it — both cleared at a common £155.37 / £216.49.

8.5 Phased Offshore Wind CFD Units — constraints mostly inherited

Phased structure unchanged in core mechanics from AR6:

• Maximum 1,500 MW total across all completed phases (project-level cap).
• First phase ≥25% of total capacity.
• First phase TCD ≤ 31 March of the last applicable Delivery Year.
• Final phase TCD ≤ 2 years after first phase TCD.
• Phased OSW CFD Units originating from Crown Estate Round 4 or ScotWind leases are generally not available for phased structure — restricted to older Round 2, Round 3, Scottish Territorial Waters leases (the AR6 restriction carried into AR7).

New in AR7:

"a sealed bid must include a single Strike Price to apply to all phases (but Flexible Bids may be submitted in accordance with Rule 12.6 above in respect of a Phased Floating Offshore Wind CFD Unit)"

Combined with Rule 12.5, this creates an interesting asymmetry: Phased Fixed-Bottom OSW must bid a single Strike Price for the whole CfD Unit with no Flexible Bids. Phased Floating OSW may still submit Flexible Bids. Pentland Floating Offshore Wind Farm (2 phases, 92.5 MW) is the only phased floating CfD Unit in the AR7 results, and it cleared at £155.37/MWh (2012) across both phases.

8.6 Excluded applications:

(a) Commissioned assets excluded (unchanged from AR6): "no Application may be made in respect of a CFD Unit where the CFD Unit is or is part of a Generating Station which has been Commissioned, unless it is (or is to be) a Repowered CFD Unit that falls within Rule 4.1(h)".

(b) AR1-AR6 CfD surrender + rebid excluded (NEW): "any part of the CFD Unit was (i) subject to a CFD Agreement signed pursuant to Allocation Rounds 1-6, and (ii) surrendered through a capacity adjustment exercised in accordance with Condition 6 ('Adjustment to Installed Capacity Estimate: Permitted Reduction') and/or Condition 7 ('Final Installed Capacity: Maximum Contract Capacity') of the CFD Standard Terms and Conditions".

This closes the Permitted Reduction route used in AR6. AR4 winners who wanted to lift their strike price had exactly one chance to do so (AR6); AR7 is closed to any rebid that would interact with existing CfDs. Policy rationale: AR6's Permitted Reduction was a bridge mechanism for projects caught by the 2022 cost shock; it is not a standing feature of the CfD design.

8.7 Geographic-connection zone qualification (NEW Maxima-aligned):

Applicants must demonstrate at Application time that the proposed CFD Unit is expected to connect to one of two geographic zones, corresponding to the OSW vs OSW Scotland Maxima:

• Offshore Wind: TS in GUS Tariff Zones 13-27 or DS in DNO Licence Areas 10-16 or 19-23.
• Offshore Wind Scotland: TS in GUS Tariff Zones 1-12 or DS in DNO Licence Areas 17-18.

This is the qualification-time counterpart to the Maxima sub-division — the zone the project is expected to connect to determines which Maximum it competes against. Projects cannot move between sub-categories mid-round. For AR7 results, Berwick Bank Phase B (NT730745 grid ref, Firth of Forth) is Offshore Wind Scotland; all other fixed-bottom winners (E2-TT44 grid refs) are Offshore Wind (rest of GB).

8.8 INTOG exclusivity alone does not qualify — unchanged from AR6:

"Where the Applicant is an Offshore Generating Station, it must confirm that it is aware that an exclusivity agreement granted by Crown Estate Scotland, such as through the Innovation and Targeted Oil and Gas leasing round, does not satisfy Regulation 27(2) of the Allocation Regulations."

INTOG-origin projects need additional lease/rights documentation beyond INTOG exclusivity to qualify for CfD. Note: Pentland Floating Offshore Wind Farm (NC981666 grid ref, Pentland Firth) may have ScotWind-origin rather than INTOG-origin seabed rights.

8.9 Repowering

Unchanged in concept from AR6: repowered CfD Units are eligible for AR7 if the underlying generating station has reached or will reach end of its 25-year operating life on or before the new CfD Unit's Target Commissioning Date. No repowered units appear in AR7 offshore wind results (repowering is more likely to apply to Pot 1 onshore wind in future AR7a rounds).

8.10 Capacity Caps — no Pot/Overall Capacity Caps, but capacity-based Maxima ARE present

For completeness: the Allocation Framework supports Pot Capacity Caps (per Pot, in MW) and Overall Capacity Caps (across all Pots, in MW), which can be designated Soft or Hard. AR7 sets no Pot Capacity Caps or Overall Capacity Caps. However — crucially for the auction mechanics — the Contract Budget Notice does set two capacity-based Maxima of 30 GW each (one for Offshore Wind Scotland, one for Offshore Wind, both hard constraints) inside Pot 3. The Budget Revision Notice of 19 December 2025 revised the Pot 3 Monetary Pot upward from £900 m to £1,790 m but left the Maxima unchanged at 30 GW each. So AR7 operates with a mix: Pot 3 and Pot 4 Monetary Pots (£ terms), two Pot 3 Maxima (GW terms), and no Pot Capacity Cap or Overall Capacity Cap at any level. See §6.2 for the design rationale (the 30 GW Maxima are purely technical — the mechanical hook for Rule 19.4(d) separate clearing — rather than binding capacity limits).

9. Evaluation criteria, process, and scoring

AR7 has two competitive dimensions for the first time in UK CfD history: the Strike Price auction (Pot 3 and Pot 4) and the CIB extras auction (cross-pot, across all offshore wind and floating OSW applicants). This section covers both.

9.1 Scope of evaluation — what IS and ISN'T evaluated

Binary qualification gates (identical pass/fail treatment as AR6):

• Planning consent / DCO / S36 OR Unconsented declaration (Rule 4.1(k)) — new route
• Grid connection offer
• CIB Statement (minimum standard met) — NEW
• Other technology-specific requirements (Rule 4.1)

Competitive scoring dimensions:

• Strike Price — the single sealed-bid price dimension (2024 prices, nearest £0.01 for lowest per Delivery Year and £0.001 for others)
• CIB "extra" proposals — scored by formulae (Criterion 1 and Criterion 2), with raw scores of 0-100 each; all proposals ranked cross-criterion; budget allocated in rank order

What is NOT evaluated competitively:

• Applicant financial strength (no credit rating affects scoring)
• Technical competence or tech-readiness (not scored at auction stage)
• Local content or ESG weighting (these moved INTO the CIB layer — so partially evaluated there but NOT in the Strike Price auction)
• Developer track record
• Stakeholder or community benefits

The scoring hierarchy: CIB minimum standard is pass/fail (gates entry). CIB extras are scored within the CIB budget separately. The Strike Price is scored in the main auction against the Pot/Maxima constraints. CIB outcome does NOT affect Strike Price clearing. Strike Price clearing does NOT affect CIB outcome (though in the "secondary allocation" of leftover CIB budget, only CfD-successful generators can rebid — so CfD outcome constrains access to the secondary CIB allocation).

9.2 Scoring exercise #1 — the CIB Minimum Standard gate (pre-requisite)

Pass/fail, as described in §8.3. All 8 AR7 winning applicant legal entities necessarily met the CIB minimum standard in February-April 2025, well before the main CfD application window.

9.3 Scoring exercise #2 — CIB extras (pre-auction, separate budget)

Per §13:

Criterion 1 scoring (investment in UK deprived areas):

Raw score = Value of eligible generator's investment / Cost of the CIB proposal

• Raw ≤ 1 → 0 points
• 1 < Raw < 14 → normalised: (Raw − 1) / (14 − 1) × 100
• Raw ≥ 14 → 100 points

Criterion 2 scoring (Science-Based Targets proportion):

Raw score = / Cost per GW (£m)

Where:

• Proportion = (Number of relevant key components from SBT firms / Total relevant key components) − 0.4
  • Total = 13 for fixed-bottom OSW, 15 for floating OSW
  • The −0.4 is the "above minimum threshold" baseline (40% = business-as-usual expectation)
  • Range: −0.4 to +0.6
• Cost/GW (£m) = Cost of CIB proposal / Gross project size in GW
• Raw ≤ 0 → 0 points
• 0 < Raw < 14 → normalised: (Raw − 0) / 14 × 100
• Raw ≥ 14 → 100 points

Criteria 1 and 2 are not weighted — proposals compete on raw 0-100 score regardless of which criterion they meet.

Ranking: all CIB extras ranked in descending score order, regardless of generator, criterion, or whether two proposals come from the same generator. Tiebreakers:

1. Higher raw score wins (applicable only when both proposals meet the same criterion).
2. Lower requested CIB revenue support wins.
3. Random electronic assignment.

Budget allocation:

• Primary allocation runs in score order.
• The CIB budget is split into a regular budget and a FLOW sub-budget (Floating Offshore Wind Only — applies to dynamic cables, mooring/anchoring systems, floating substructures, floating assembly/marshalling facilities — per §16.6).
• FLOW sub-budget drawn down first by FLOW-eligible proposals; then regular budget.
• Secondary (discretionary) allocation of unused budget can occur per §19 for generators who lost in the CfD allocation round.

CIB budget for AR7 per the Final Budget Notice (7 May 2025):

• £20.1 million per GW of capacity applying for a Clean Industry Bonus
• Total budget: over £544 million
• FLOW sub-budget (ring-fenced for Floating Offshore Wind per cib-allocation-framework §16.6): "The sub-budget is applied on a monetary budget basis, to support and encourage the development of the more expensive nascent floating offshore wind supply chain. The value of the sub-budget is not disclosed publicly to preserve competition."

Two important caveats:

1. The budget is scaled to capacity applying (i.e. total qualifying CIB applications) rather than capacity awarded in the CfD round. The two are not equivalent: CIB applicants may be unsuccessful in the CfD allocation, in which case their CIB primary allocations lapse (though they can rebid for unused budget in the secondary allocation per §19).
2. The FLOW sub-budget split is deliberately undisclosed by DESNZ to preserve competition. Public knowledge of the CIB budget is therefore incomplete — we know the £544m+ total but not the regular-vs-FLOW split.

Aggregate CIB outcome now public at a summary level. In the July 2025 AR8 CIB consultation outcome, DESNZ disclosed that the first CIB round (AR7) allocated approximately £204 million of public investment — materially less than the £544m+ ceiling, indicating that the primary-allocation phase closed with substantial headroom. Quoting the AR8 consultation outcome: industry reporting (Bird & Bird, July 2025) further characterises AR7 CIB as "£544 million of investment allocated to support the offshore wind supply chain" — the Bird & Bird phrasing likely refers to the total private investment leveraged (per DESNZ's own multiplier framing: £204m public leveraging up to £3.4bn private investment) rather than CIB public spend itself.

Proposal-level opacity remains: individual CIB rankings and scores are not disclosed, to protect commercial sensitivities. We therefore cannot publicly determine which of the 8 AR7 applicant legal entities secured CIB extras or at what values. But at the aggregate level the £204m public-investment figure is known. The regular-vs-FLOW budget split remains publicly undisclosed per cib-budget-notice ¶"Use of Floating Offshore Wind Sub-budget".

9.4 Scoring exercise #3 — the Valuation Formula (budget impact scoring, deterministic)

Deterministic pre-auction formula, inherited from AR6 pattern. Per Schedule 2, for each Application in each Delivery Year the Applications Valuation is:

Annual budget impact (£) = (Strike Price OR ASP − Reference Price) × IICE × Days × YR1F × Technology Load Factor × General Conversion Factors

Where:

• Strike Price = the bid price in 2024 prices; for pre-auction valuation, the ASP is used
• Reference Price = Appendix 2 (Intermittent or Baseload, by technology) in 2024 prices
• IICE = Initial Installed Capacity Estimate (MW) from the Application
• Days = 365 or 366 (Appendix 6)
• YR1F = Year-1 Factor (partial-year handling)
• Technology Load Factor = Appendix 3 (e.g. specific values per technology per Delivery Year)
• General Conversion Factors = Transmission Loss Multiplier (Appendix 4, 0.90% for all years for OSW) + Renewable Qualifying Multiplier (Appendix 5, 1.0 for OSW and Floating OSW) + standard time-unit conversions

The formula is identical in structure to AR6's but uses 2024-price coefficients. Load factors for OSW are lower than AR6, which mathematically shifts the Valuation Formula — fewer £ of budget consumed per MW at a given Strike Price — requiring higher ASPs to maintain the same "budget impact" envelope coverage.

9.5 Constrained vs unconstrained auction trigger

Per Rules 10.3-10.4: if the Valuation Formula total across all qualifying applications ≤ Monetary Pot AND ≤ any applicable Capacity Cap, all applicants are declared Successful at the ASP (no auction). Otherwise a Notice of Auction is issued.

For AR7, both Pots were constrained. The Valuation Formula total for Pot 3 at the ASP would have been substantially greater than £1,790 m/year in the peak Delivery Year — confirmed by the results document's Table (C), which shows applications originally received valued at ASP at £5,308 m/year in 2012 prices (= £7,397 m/year in 2024 prices) for Pot 3 in 2032/33 — roughly 4x the revised budget, and much higher than the initial £900 m budget. Pot 4 was similarly oversubscribed at the ASP (2032/33 applications at ASP: £291 m in 2012 prices = £406 m in 2024 prices, vs £180 m budget).

9.6 Sealed bid submission — what applicants submit and when

Mechanics described in §8.4 above — the key new constraint is that Fixed-Bottom OSW can only submit one sealed bid. The Notice of Auction must specify Submission Opening and Closing Dates, with the open date ≥10 Working Days after Notice of Auction issuance and the close date ≥15 Working Days after Notice of Auction issuance.

9.7 Anonymised Bid Information — the pre-auction disclosure loop (NEW, Fixed-Bottom OSW only)

Per Rule 13:

"Pursuant to Regulation 54, the Delivery Body may send Anonymised Bid Information to the Secretary of State, before the Auction is held. For Allocation Round 7, this will apply in relation to Fixed-Bottom Offshore Wind CFD Units only... The Delivery Body is responsible for ensuring all Anonymised Bid Information is assured by the Auditor, before being sent to the Secretary of State... The Delivery Body must send any Anonymised Bid Information to the Secretary of State no later than 5 Working Days after the Submission Closing Date."

The mechanism has three steps:

1. Submission window closes (Rule 12) — applicants have submitted sealed bids.
2. NESO prepares Anonymised Bid Information in a format requested by the Secretary of State, maintaining anonymity.
3. Independent Auditor assures the anonymised bid data (ensuring no identity leakage, formula correctness).
4. NESO sends to Secretary of State within 5 WD of Submission Closing Date.
5. Secretary of State decides whether to issue a Budget Revision Notice under Regulation 12.
6. Budget Revision Notice takes effect (with the upward-only constraints inherited).
7. Auction is run against the (revised) budget.

Narrowing to Fixed-Bottom OSW only: Floating OSW (Pot 4) bids are NOT disclosed to the Secretary of State pre-auction, because the Pot 4 budget is considerably smaller and the marginal-capacity value judgement less material.

Why this matters analytically: this is the structural reform that closes the loop between DESNZ's capacity target and the market's cost-recovery needs. Pre-AR7, DESNZ had to guess (via ASP-setting and initial Budget Notice) what price would attract adequate capacity and what budget would be sufficient — a guess that failed at AR5 (zero cleared) and only partially worked at AR6 (Hornsea 4 cancelled). With Rule 13, DESNZ can observe the actual bid distribution and decide post-hoc whether to commit more budget. In effect, AR7's auction is a two-round auction with a budget-tuning step in between — even though the formal rules describe a single sealed-bid auction.

9.8 Auction process — Rule 19 with two-Maxima complications

When the sealed bid window closes and bid information has been disclosed + budget revised, NESO runs the auction per Rule 19. For AR7, two Maxima exist within Pot 3 (Offshore Wind, Offshore Wind Scotland), and Pot 4 has its own separate auction.

Rule 19 process for AR7 Pot 3 (two Maxima):

1. Exclude bids that exceed the Monetary Pot, Maxima, or any Capacity Cap (Rule 19.2). Hard exclusion.

2. Rank remaining bids ascending by Strike Price, regardless of Delivery Year (Rule 19.3). One ordered stack for all Pot 3 bids.

3. Walk the stack admitting bids, updating running totals for:

   • Pot 3 Monetary Pot (£1,790 m/year after revision) — expressed in money
   • Offshore Wind Maximum (30 GW) — expressed in capacity
   • Offshore Wind Scotland Maximum (30 GW) — expressed in capacity

   Per Rule 19.4(a), the Delivery Body sums the capacity or monetary value of each bid under consideration depending on how each constraint is expressed. The Monetary Pot running total is in £; both Maxima running totals are in GW. (The 30 GW Maxima are non-binding in practice — AR7 cleared at ~8.4 GW total, far below either Maximum — so the clearing is driven by the Monetary Pot constraint, while the Maxima still operate mechanically to enforce Rule 19.4(d) separate per-Maximum clearing prices.)

4. Per-Maximum separate clearing prices (Rule 19.4(d)) — this is the key mechanic:

   • Maximum bids are cleared at a separate clearing price per Maximum, not the Pot-wide clearing price.
   • Non-Maximum bids (in AR7, there are none — all Pot 3 bids are subject to one of the two Maxima) clear at the Pot clearing price.

Per Rule 19.4(d)(i): "if a Maximum bid is the bid under consideration, the Delivery Body must use the Strike Price of the bid under consideration as the provisional clearing price for that Qualifying Application, for any Qualifying Application(s) subject to that same Maximum... and for any relevant Qualifying Application(s) which are not subject to any Maximum".

Applied to AR7: the highest-priced successful OSW Scotland bid sets the OSW Scotland clearing price (£65.45 / £91.20 in 2012/2024 terms — Berwick Bank B at £64.23 / £89.49, but wait — that's lower). Correction: the OSW Scotland clearing price is £64.23 (2012) / £89.49 (2024). This is the clearing price within the OSW Scotland Maximum, driven by the single successful bid (Berwick Bank B). The OSW (rest-of-GB) clearing price is £65.45 (2012) / £91.20 (2024) — the highest successful bid within that Maximum.

Why the two clearing prices differ: the auction admits bids in ascending Strike Price order from a single stack, but each Maximum has its own clearing. Berwick Bank B, the only OSW Scotland bid, was admitted at its bid price and set its own clearing. The OSW Maximum clearing was set by the highest among 6 successful OSW bids (the Awel y Môr, Dogger Bank SE/SW, Norfolk Vanguard E/W bundle). The two clearing prices converge on a single underlying bid-ordering, but the separation reflects the Maxima-based pricing regime: two separate markets with shared admission logic.

5. Interleaving bids (Rule 19.6): when the stack hits a bid that would breach a constraint, NESO considers Flexible Bids from the breaching applicant (if any) at different strike prices. For AR7's Fixed-Bottom OSW, no Flexible Bids are available (Rule 12.5), so interleaving only applies to Pot 4 (Floating OSW) applicants. For Pot 3, a breaching bid immediately closes the auction at the current clearing level.

6. Tiebreakers (Rule 21): if two or more sealed bids at the same Strike Price cannot all be admitted without breach, NESO applies envelope-fit tiebreaker. AR7 results do not report any tiebreaker invocation; the 10 Pot 3 CFD Units cleared at two distinct prices (6 at £65.45/MWh 2012, one at £64.23 2012), no tie disambiguation apparently required.

9.9 Clearing price determination — Rule 19.4(d) separate Maxima clearing

The critical clause is Rule 19.4(d) (paraphrased above). In AR7 its practical effect is:

• OSW Maximum clearing price = £65.45/MWh (2012) / £91.20/MWh (2024) → applies to Awel y Môr, Dogger Bank SE, Dogger Bank SW, Norfolk Vanguard E (all 3 units), Norfolk Vanguard W (all 3 units) = 9 CFD Units, 6,865 MW.
• OSW Scotland Maximum clearing price = £64.23/MWh (2012) / £89.49/MWh (2024) → applies to Berwick Bank B = 1 CFD Unit, 1,380 MW.
• Pot 4 (floating OSW) clearing price = £155.37/MWh (2012) / £216.49/MWh (2024) → applies to Erebus + Pentland = 2 CFD Units, 192.5 MW.

Two clearing prices within Pot 3 is the structural innovation, enabled by the Maxima and by Rule 19.4(d). This is a mechanic the auction extraction model must handle — sub_category on AuctionResult groups by Maximum (Pot 3 | Offshore Wind | 2030/31 vs Pot 3 | Offshore Wind Scotland | 2030/31), and clearing_prices on the Auction holds separate entries per Maximum.

9.10 Post-auction audit and Secretary of State review

Same process as AR6 (Independent Auditor → SoS review → NESO notification → DESNZ results publication), plus the additional audit step on Anonymised Bid Information under Rule 13.3.

9.11 From evaluation to results — AR7 end-to-end

1. Nov 2024 – Apr 2025: CIB application window; DESNZ assesses; eligible generators receive CIB Statements (minimum standard met, extras scored).
2. 7 Aug – 27 Aug 2025: Main CfD application window (20 Working Days per application-window-notice).
3. Aug – Oct 2025: NESO qualification assessment; Non-Qualification Reviews; Ofgem appeals.
4. 27 Oct 2025: Contract Budget Notice issued by DESNZ (£900 m Pot 3 + £180 m Pot 4, plus two 30 GW Pot 3 Maxima).
5. 27 Oct 2025: Notice of Auction issued by NESO to qualifying AR7 applicants (bilateral instrument, not a public PDF).
6. 11–17 Nov 2025: Sealed bid window (5 working days). Applicants submit sealed bids via EMR Delivery Body Portal.
7. By 24 Nov 2025: NESO sends Anonymised Bid Information (Fixed-Bottom OSW only) to SoS after Auditor assurance per Rule 13 (within 5 Working Days of Submission Closing Date).
8. 19 Dec 2025: Budget Revision Notice signed (Pot 3 Monetary Pot £900 m → £1,790 m; Maxima unchanged).
9. 23 Dec 2025: Budget Revision effective.
10. 5–9 Jan 2026: Auction run per Rule 19 (Pot 3 with OSW and OSW Scotland Maxima) and separately for Pot 4.
11. Jan 2026: Independent Auditor reviews; SoS Proceed decision.
12. 14 Jan 2026: Results published.
13. 25 Mar 2026: LCCC signs 20-year CfD contracts with the 8 AR7 applicant legal entities (per official LCCC announcement; some trade press reported 26 Mar — LCCC's post is authoritative).

10. Competitive landscape — what bid, what cleared

AR7's results document publishes the total value of all applications originally received at ASP alongside the actual monetary budget impact of the awarded contracts — the same competitive-tension read that AR6 provided.

10.1 Pot 3 (fixed-bottom offshore wind) — extreme oversubscription by value

Interpretation: the peak-exposure year (2032/33) saw applicants bring £7.4 bn/year of subsidy demand valued at £113/MWh ASP, of which £1.78 bn/year was admitted — a clearance rate of ~24%. Roughly three-quarters of Pot 3 applications by value did not clear. This is substantially more oversubscribed than AR6 (AR6 Pot 3 peak clearance was ~31%).

The peak-year awarded impact of £1,783.92 m/year sits essentially at the revised £1,790 m Pot 3 budget — Pot 3 was saturated in the peak year at the revised budget. Any additional bids would have breached the Pot 3 Monetary Pot constraint.

10.2 Pot 4 (floating offshore wind) — moderate oversubscription

Peak Pot 4 annual exposure is £133.06 m/year against a £180 m budget — leaving about £47 m/year headroom. Pot 4 was NOT saturated — the auction closed because no further bids could be admitted without violating the Monetary Pot floating budget cap or the Floating OSW ASP ceiling. Concretely, this means the two successful floating projects (Erebus 100 MW, Pentland 92.5 MW) were the only floating applicants whose bid prices fit within the budget. Other unsuccessful floating applicants (not publicly disclosed) presumably bid above the clearing price.

10.3 Non-OSW winners (for completeness — these belong to AR7a)

This writeup covers AR7 only; AR7a winners (Pot 1 onshore wind, solar, etc. and Pot 2 tidal stream, etc.) are a separate allocation round and will appear in a future auction record. AR7 and AR7a share the Pot and Price Notice, Allocation Framework, and Application Window Notice (all included in this corpus) but have separate Budget Notices and separate sealed bid windows (AR7a sealed-bid 5–9 Jan 2026 vs AR7 11–17 Nov 2025). The AR7a Contract Budget Notice is NOT included in the AR7 source-doc corpus.

10.4 Geographic distribution — AR7 only

From §(F):

Noteworthy features:

• Wales received 10.4% of capacity — driven by Awel y Môr (775 MW OSW, Liverpool Bay) and Erebus (100 MW floating, Celtic Sea). First material Welsh offshore wind award since Crown Estate Round 2/3 Extensions.
• Scotland's share dropped from AR6 — AR6 Scotland share was 20.6% but largely from Permitted Reduction projects (Inch Cape, Moray West) whose new-capacity equivalents don't fit AR7's scope. AR7 Scotland = Berwick Bank Phase B (largest single project, £89.49/MWh) + Pentland floating.
• England dominated — the RWE-led Dogger Bank South + Norfolk Vanguard sets (both in English waters) took 6,090 MW alone.

11. Results — Fixed offshore wind (Pot 3, rest-of-GB)

Fixed-bottom OSW in the rest-of-GB Maximum cleared at £65.45/MWh (2012 prices) / £91.20/MWh (2024 prices) for 6,865 MW across 9 CFD Units and 5 projects:

Total OSW (rest-of-GB): 6,865 MW across 9 CFD Units and 5 projects.

Concentration — RWE-led development pipeline

All 9 of these CFD Units are developed by RWE-led project companies — but the project companies are joint ventures rather than RWE-sole SPVs. Ownership per current public sources:

• Awel y Môr (775 MW, Wales): RWE 60% / Stadtwerke München 30% / Siemens 10%. RWE is development lead. (Note: an earlier draft stated "RWE took full ownership in 2023 after BP's offshore wind divestment" — that framing is incorrect; Awel y Môr is a three-party joint venture.)
• Dogger Bank South East + Dogger Bank South West (2 × 1,500 MW, England): RWE 51% / Masdar 49% — a joint development announced by RWE and Masdar (the Abu Dhabi clean-energy company). RWE is operator/development lead. (Note: these are NOT Vattenfall-lineage projects — that lineage applies to Norfolk Vanguard East/West.)
• Norfolk Vanguard East + Norfolk Vanguard West (both 1,545 MW comprising Unit A + B + C): originally developed by Vattenfall; acquired by RWE in 2023 as part of Vattenfall's UK offshore-wind development pipeline divestment. (Specific post-acquisition equity split — whether RWE is now sole owner or has brought in partners — is.)

The correct framing: RWE leads the development of ~6.865 GW of AR7 capacity, but treats that capacity across joint-venture ownership structures rather than as RWE-sole holdings. In the Offshore Wind (rest-of-GB) Maximum, RWE leads 100% of the 6,865 MW awarded. Combined with SSE's Berwick Bank B in the Scotland Maximum (see §12), the AR7 fixed-OSW winners list is concentrated among a handful of major developers, with RWE the single largest by a wide margin.

RWE's industry messaging framed the AR7 result: "RWE has been awarded Contracts for Difference at a strike price of £91.20/MWh for its Norfolk Vanguard East and Norfolk Vanguard West, its two Dogger Bank South and the Awel y Môr offshore wind development projects, with a combined capacity of 6.9 GW." The "its" here is development-lead language, not outright ownership — Dogger Bank South and Awel y Môr are both joint ventures where RWE is the operator but not sole owner.

Phased CFD Unit structure — Phased Offshore Wind in practice

Five of the 9 CFD Units use the Phased Offshore Wind CFD Unit structure under allocation-framework Rule 4.1(a) and Rule 14:

• Dogger Bank South East: 3 phases totalling 1,500 MW (at the Rule 4.1(a)(i) cap)
• Dogger Bank South West: 3 phases totalling 1,500 MW (at the cap)
• Norfolk Vanguard East CFD Unit A: 2 phases totalling 1,380 MW
• Norfolk Vanguard West CFD Unit A: 2 phases totalling 1,380 MW
• Awel y Môr: 2 phases totalling 775 MW

This is the first AR round to fully exploit the 1,500 MW phased cap — AR6 saw phased structure on Hornsea 3 (3×360=1,080 MW); AR7 has Dogger Bank South E/W each maxing out at the cap.

The Norfolk Vanguard sub-unit structure (A/B/C) represents a distinct AR7 mechanic: Norfolk Vanguard East/West each has a 1,380 MW Phased CFD Unit (Unit A) plus two additional non-phased CFD Units (B at 90 MW and C at 75 MW, both single-phase, both in 2028/29). This suggests the projects split their bid into a large phased unit (to spread commissioning) plus smaller early-delivery units committing to 2028/29 capacity. The smaller units function like warranty delivery or pre-commissioning test units — delivering into the earliest available delivery year in exchange for inclusion.

The 3 GW unconsented pathway — Dogger Bank SE+SW

Dogger Bank South East (1,500 MW) and Dogger Bank South West (1,500 MW) are the flagship beneficiaries of AR7's new Unconsented Fixed-Bottom OSW pathway (Rule 4.1(k), Schedule 7). Both projects were in pre-DCO consenting status at application time. Each submitted a Schedule 7 Director's declaration confirming no refusal of Applicable Planning Consents, enabling them to enter the auction. ~3 GW of AR7's 8.4 GW was enabled by the unconsented-OSW eligibility reform — a reform that directly addressed post-Hornsea-4 industry pressure for faster pipeline development.

12. Results — Fixed offshore wind Scotland (Pot 3, Scotland Maximum)

Fixed-bottom OSW in the Scotland Maximum cleared at £64.23/MWh (2012 prices) / £89.49/MWh (2024 prices) for 1,380 MW across a single CFD Unit:

Single-entity sub-category clearing — the OSW Scotland Maximum had exactly one successful applicant, Berwick Bank B (an SSE Renewables SPV). The clearing price was set by this single bid.

Why Scotland cleared cheaper than rest-of-GB (£89.49 vs £91.20 in 2024 prices = 1.9% lower): the explanation is not published, but possible factors include:

• Berwick Bank B's bid economics may have been marginally better than the rest-of-GB projects (different onshore grid connection costs, developer cost curve).
• The Maximum mechanic isolates the Scotland bid from the England/Wales competition — the Scottish bidder didn't face direct competition from the more aggressive bidders in England, so its bid didn't need to be as low as the rest-of-GB equilibrium.
• The absence of a competing Scottish applicant meant the auction admitted Berwick Bank B at its own bid price rather than forcing it to clear at the marginal price of a competing Scottish bidder.

Regulatory context for Berwick Bank: Scottish Ministers granted the Section 36 consent on 31 July 2025 (confirmed public record). The project has been subject to substantial public-interest and seabird-impact scrutiny as part of its consenting process; whether any active court challenges remained unresolved at AR7 contract signature (25 March 2026) is — the acquired source corpus does not establish a specific active challenge timeline, and ChatGPT's earlier "extensive legal challenges" framing may have been under-sourced. The Berwick Bank Phase B capacity at 1,380 MW represents only a portion of the full Berwick Bank wind farm's eventual capacity (likely ~4 GW across multiple phases if fully consented) — AR7 captures the first tranche.

The Maximum-driven separate clearing produced a valuable AR7 natural experiment: with identical Framework mechanics and a 20-year contract term, a single Scottish bidder cleared at 1.9% lower than the English competitive clearing. This is worth tracking in downstream analysis and comparing to ScotWind's 2022 £100 k/km² option-fee auction economics, which separately revealed Scottish offshore wind cost-recovery dynamics.

13. Results — Floating offshore wind (Pot 4)

Floating OSW cleared at £155.37/MWh (2012 prices) / £216.49/MWh (2024 prices) for 192.5 MW across 2 CFD Units:

Total floating: 192.5 MW across 2 CFD Units and 2 projects.

Erebus — 100 MW, Celtic Sea, Blue Gem Wind

Blue Gem Wind Limited is a joint venture between TotalEnergies and Simply Blue Group. Erebus is a demonstration-scale floating offshore wind project in the Welsh Celtic Sea — originating from the Crown Estate Test & Demonstration (T&D) leasing regime (pre-CE R5 Celtic Sea commercial round). At 100 MW, Erebus is at the upper end of demonstration-scale but below the commercial-scale projects that will emerge from CE R5 (the 4.5 GW Celtic Sea floating auction results of 2025).

Why Erebus cleared: the Pot 4 budget (£180 m/year) and ASP (£271/MWh 2024) were calibrated to allow ~200 MW of floating at clearing prices well below the ASP. Erebus at £216.49/MWh is ~20% below the ASP — consistent with a bid pitched to fit within the Pot 4 budget rather than to maximise developer returns.

Pentland — 92.5 MW, Pentland Firth, Highland Wind

Highland Wind Limited is the SPV for the Pentland Floating Offshore Wind Farm, operated by Copenhagen Offshore Partners (COP) with equity partners including Great British Energy (the UK's publicly-owned clean energy company, established 2024) as an initial shareholder per Westwood Energy reporting. Pentland originated from the Crown Estate Scotland ScotWind 2022 leasing round — making it one of the earliest ScotWind projects to progress to a CfD.

Why Pentland cleared: similar logic to Erebus — strike price designed to fit within the Pot 4 budget envelope. The 2-phase structure suggests Pentland is using the Phased CFD Unit pathway under Rule 4.1(a).

Floating OSW market signal: AR7's £216.49/MWh (2024 prices) for floating OSW is the second publicly-cleared data point on UK floating OSW CfD economics (following Green Volt at AR6: £139.93/MWh 2012 = ~£195/MWh 2024). Adjusted for the price-base shift and for differences in scale and project maturity, AR7 floating OSW is ~11% above AR6 floating in real 2024-price terms — consistent with the ~11% uplift in the ASP from AR6 to AR7. Commercial-scale floating OSW (CE R5's 4.5 GW of 1.5 GW+ commercial PDAs) will feed future AR8/AR9/AR10 rounds at much larger scale.

14. Clearing prices — analysis

Consolidated AR7 clearing prices vs ASPs:

Key analytical takeaways

Tight clustering in the 19-21% saving band. All three technology sub-categories cleared in a narrow 19-21% band below their respective ASPs. This is similar to AR6's pattern (19-26% band for OSW, onshore wind, solar, floating) and suggests DESNZ's ASP calibration methodology continues to target consistent relative spread. The narrowness of the band reduces the signal-to-noise: AR7's clearing prices are predictable once the ASP is known.

Same-Pot clearing-price divergence between sub-categories is the new normal. Under the OSW/OSW-Scotland split, Pot 3 produces two clearing prices for the first time. The 1.9% gap (£89.49 vs £91.20 in 2024 prices) is small but measurable — and tells us the Scottish sub-category is (modestly) cheaper on the margin. Downstream analytics should track this as a "per-Maximum clearing price" field rather than a single "pot clearing price".

Year-on-year real-terms OSW strike price has risen from AR6 to AR7:

• AR6 new OSW cleared at £58.87/MWh (2012 prices).
• AR7 OSW clears at £65.45/MWh (2012 prices).
• +11.2% in real 2012-price terms — roughly tracking the ASP uplift of ~11%.

Since the contract term also extended from 15 to 20 years, the cost-equivalent strike price comparison requires a term-adjustment: a 20-year CfD at £65.45 delivers a longer revenue stream than a 15-year CfD at £58.87. A rough normalisation (discounting at 6% real, assuming flat generation profile, ignoring indexation differences): AR7's 20-year strike price has a present-value equivalent to roughly £65.45 × (1 − 0.0625) = £61.36/MWh if it were 15-year, i.e. around +4% vs AR6's £58.87 — a much smaller real-terms price uplift than the headline £65.45 figure suggests.

The combined effect of the TRA reforms (longer term + higher real ASP + CIB as a separate investment lever + mid-round budget uplift) effectively holds the all-in-cost price of UK offshore wind roughly flat in real terms while doubling procured capacity. This is the design-target outcome.

Floating OSW — where to from here?

AR7's £216.49/MWh (2024 prices) for floating OSW is the new benchmark. Unlike fixed OSW where AR7 represents a small real-terms cost increase, floating OSW is approximately flat (AR6 £139.93/MWh 2012 ≈ £195/MWh 2024; AR7 £155.37/MWh 2012 = £216.49/MWh 2024; +~11% in real terms, primarily price-base-shift). Commercial-scale CE R5 floating OSW deliveries (TwinHub, Llŷr, Gŵynt Glas totalling 4,500 MW) will enter later AR rounds and should eventually exert downward price pressure as the supply chain scales. The 2030 / 2035 floating OSW cost curve is the key unknown here.

The "record saving" framing vs the "record capacity" framing

DESNZ's results messaging emphasised the 8.4 GW record and noted the 19-21% saving as "competitive". Industry commentary (Westwood, Smith School, Carbon Brief, OEUK, Energy UK) focused primarily on the capacity record, reading AR7's success as "the largest offshore wind auction anywhere in Europe". The implicit comparison is AR6 (5.3 GW headline, later 2.9 GW post-Hornsea 4) — AR7 delivers roughly 3× the sustained post-Hornsea-4 AR6 capacity, enough to meaningfully move the 50 GW-by-2030 pipeline.

Under our durable analytical frame, the substantive achievement is:

• 8.4 GW at £91.20/MWh (2024) on 20-year CfDs delivers roughly the same per-GWh cost exposure as AR6 on a term-adjusted basis but captures twice the capacity per £1 bn of annual budget commitment.
• The design reforms (CIB, Rule 13 disclosure, 20-year contracts, unconsented pathway, OSW/Scotland Maxima split) collectively reshape the UK CfD from a price discovery mechanism to a capacity procurement mechanism, with price as an output rather than the primary optimisation target.

15. Unsuccessful / notable absences

The AR7 results document does not publish the list of unsuccessful applicants — NESO maintains commercial confidentiality over losing bids. From Rule 13 + the published oversubscription-by-value, we know roughly £5.6 bn/year of Pot 3 subsidy demand at peak was left on the table, corresponding to perhaps 6 GW of unsuccessful OSW capacity at the clearing price. The specific projects that did not win are not publicly disclosed, but candidates that were publicly expected to bid in AR7 include:

• Hornsea 3 (Ørsted, 2,852 MW DCO capacity, remaining portion not in AR6): Ørsted retained Hornsea 3 A/B/C from AR6 Permitted Reduction but may have bid new Hornsea 3 capacity. Ørsted's post-Hornsea-4 strategic review may have muted participation.
• Hornsea 4 (Ørsted, 2,400 MW DCO): Ørsted explicitly discontinued in May 2025. Unlikely to have re-entered, though Ørsted retains the seabed rights and DCO and may re-apply in AR8 under different pricing.
• East Anglia projects beyond Phase 1: ScottishPower Renewables had East Anglia Two Phase 1 in AR6; subsequent phases may have entered AR7.
• Outer Dowsing (Corio Generation / TotalEnergies / Gulf Energy Development, 1.5 GW): indicated AR7 as a target window; results appearance not confirmed.
• Inch Cape extension / further phases.
• ScotWind projects still in consenting (Morven, Bellrock, West of Orkney, Campion, etc. — mostly at pre-DCO stage and may not have met the unconsented-fixed-bottom declaration requirements).

A systematic unsuccessful-list would require cross-referencing against the projects collection and press coverage — the kind of analysis the AgentZero data model enables once AR7 winners and losers are recorded.

Dogger Bank D (SSE + Equinor + Vårgrønn, ~2 GW) is a notable mid-development project that publicly targeted AR7 but is not in the winners list.

16. Contract obligations beyond the core mechanics

Section 5 covered financial mechanics. Section 16 covers the non-financial obligations AR7 Generators take on, with a focus on items that differ from AR6.

16.1 The 20-year contract and its milestones

All AR7 OSW + Floating OSW CfDs are 20-year contracts. Key dates within the 20-year horizon:

• Agreement Date: CfD signature (25 March 2026 for AR7 per official LCCC announcement).
• Initial Milestone Delivery Date: 18 months after Agreement Date — ~September 2027.
• Target Commissioning Window Start Date: defined in each CfD per Generic Agreement §5.1, bounded by the Delivery Year of the award.
• Target Commissioning Date: within the TCW per the Delivery Year.
• Target Commissioning Window: up to 1 year for OSW + Floating OSW per Schedule 6.
• Longstop Date: TCW end + Longstop Period (AR7-specific value set in Standard Terms Notice Table H).
• Specified Expiry Date: 20th anniversary of the earlier of Start Date and TCW end.

For the Dogger Bank South East / South West 2030/31 projects: Agreement Date March 2026 → Initial Milestone ~September 2027 → TCWSD 2030/31 → TCD ~2030 → Specified Expiry ~2050/51.

16.2 CIB post-award enforcement

A genuine novelty in AR7. Per the CIB integrates into the Standard T&Cs via three enforcement mechanisms:

1. Facility CIB Implementation Statement (Standard Terms Schedule/Part X — definitions visible in the Standard Terms corpus): a document issued by DESNZ confirming that the Generator has delivered the CIB minimum-standard investment commitments. Issued before the CfD Agreement's Start Date.
2. CIB Minimum Standard Performance Amount: if the Facility CIB Implementation Statement is not issued, or if CIB commitments are partially delivered, a Performance Amount (a reduction in CfD payment) is calculated and applied to the Generator's payments.
3. Ongoing reporting and verification: the Generator must give notice to the CfD Counterparty of (a) any Facility CIB Implementation Statement being issued, revised or withdrawn; (b) any CIB Refusal being issued; (c) details and copies of relevant statements.

Practical effect: failure to deliver on CIB minimum-standard investment (e.g. RWE commits £100 m/GW × 6.865 GW = £686.5 m in manufacturing / port / supply-chain investments, but delivers only £500 m) triggers a Performance Amount reduction in the 20-year CfD payments. This is the teeth of the CIB pre-requisite — not a pass/fail termination, but a scaled reduction in revenue. The specific formula is in the Standard T&Cs.

16.3 Milestone Delivery — inherited from AR6, with a new planning-consent extension limb

Mechanics broadly inherited. AR7 introduces slightly different Target Commissioning Window values and Longstop Periods per Standard Terms Notice Tables G and H, but the core framework (Initial Milestone Delivery Date 18 months after Agreement, TCW up to 1 year for OSW/Floating OSW, Longstop + extension grounds) is AR6-style.

Extension grounds for Milestone Delivery Date, Target Commissioning Window, and Longstop Date per the AR7 STCs definitions of those terms: Force Majeure; TSO/Distributor/OFTO delay in system reinforcement; MoD Radar Mitigation Scheme non-confirmation (Offshore Wind or Onshore Wind only); and — specifically for Offshore Wind excluding Floating Offshore Wind — Relevant Applicable Planning Consent not having been granted, having been quashed, or having been refused prior to the Milestone Delivery Date, including delay attributable to Relevant Court Proceedings (judicial review or statutory appeal) per the detailed sub-conditions. See §5.6 for the full list; this limb is material for AR7 given Dogger Bank South East / South West entered via the unconsented-OSW pathway.

16.4 Permitted Reduction mechanics — effectively removed

AR6's Permitted Reduction (Condition 6 "Adjustment to Installed Capacity Estimate" surrender-and-rebid mechanism) is explicitly closed to AR7 applicants per Rule 5.1(b) of the AR7 Allocation Framework — applications are excluded if any part of the CFD Unit was the subject of a capacity adjustment from an AR1-AR6 CfD. The CfD Standard Terms still define the Condition (for AR6 contracts running through to their 15-year expiry), but AR7 generators cannot use it to enter AR8+ rounds.

16.5 Phased OSW CFD Units — 20-year clock interaction

A subtle open question about the 20-year clock for Phased CFD Units: the Specified Expiry Date is "the 20th anniversary of the earlier of the Start Date and the last day of the Target Commissioning Window" — and for Phased CFD Units, each phase has its own Target Commissioning Window. Rule 14.1(b) of the Allocation Framework says "the Target Dates for the first phase will be treated as the first Target Dates", but this does not clearly specify whether the first phase's TCW end or each phase's own TCW end anchors the 20-year clock for that phase's subsidy. An earlier draft asserted that the first phase's TCW end anchors the entire CFD Unit's clock — but the Standard Terms definitions of "Specified Expiry Date", "Start Date", and "Target Commissioning Window" need to be read carefully in combination with the phased-unit-specific provisions to reach a confident answer. This interpretation has been flagged as against the Standard Terms Conditions pertaining to Phased Offshore Wind CFD Units. Regardless of the exact clock mechanics, Rule 4.1(a)(iv) caps the final phase at 2 years after the first phase TCD — compressing the phase spread and limiting the practical difference between the two candidate interpretations.

16.6 Curtailment, Change in Law, Generation Tax

Mechanics inherited from AR6 pattern — unchanged in principle:

• Curtailment rules (Condition 11) — specific handling of output curtailed by the System Operator.
• Change in Law (Part 7) — Strike Price adjustment for Qualifying Changes in Law.
• Generation Tax (Part 9) — Strike Price adjustment if a generation tax is introduced.

16.7 Termination

LCCC termination rights under Standard Terms Condition 51 are inherited from AR6 pattern: specified Generator defaults (failed Milestones, failed OCPs, unpaid amounts, insolvency, etc.). AR7 adds the CIB non-delivery mechanics (which are handled via Performance Amounts rather than outright termination for minor breaches).

17. Post-award fate — what has actually happened

AR7 results were published on 14 January 2026; CfD contracts were signed on 25 March 2026 (per official LCCC announcement). At the time of this writeup (April 2026), only a few weeks have elapsed since contract signature — very little has yet happened post-award. Indicative status:

17.1 RWE-led development pipeline — the dominant position

The 5 project vehicles led by RWE that hold 6.865 GW of AR7 awards represent the deepest single-developer commitment in UK offshore wind history. RWE's stated position (per the March 2026 LCCC-contracts press coverage): the company treats AR7 awards as a major development programme for 2028-2034 delivery. Key early signals:

• Norfolk Vanguard East/West (3,090 MW combined, RWE-led, Vattenfall-origin post-2023 acquisition): DCO already in place (granted to Vattenfall predecessor, now held by RWE). Initial Milestone Delivery Date ~Sep 2027; TCWSD 2028/29 for the earliest units (NVE Unit B, NVE Unit C at 90+75 MW; NVW Unit A at 1,380 MW; NVW Unit B, NVW Unit C at 90+75 MW) and 2029/30 for NVE Unit A at 1,380 MW. Supply chain lock-in (turbine orders, foundation fabrication, cable contracts) is the next 18 months' critical path.
• Dogger Bank South East + South West (3,000 MW combined, RWE 51% / Masdar 49% joint venture): DCOs not yet granted at AR7 signature — the projects entered via the unconsented-OSW pathway. DCO applications are progressing through the NSIP process; as of 7 January 2026 the DCO decision deadline had been pushed back to 30 April 2026, making the 2030/31 Delivery Year schedule meaningfully tighter than an uncomplicated 4-5-year window would suggest (DCO → financial close → procurement → construction → commissioning within ~4 years of April 2026, with procurement lead times for 15+ MW turbines and bespoke offshore foundations measured in 24-36 months alone).
• Awel y Môr (775 MW, RWE 60% / Stadtwerke München 30% / Siemens 10% joint venture, 2030/31): DCO granted September 2023 (development consent in place — no longer a item). Welsh Celtic Sea CE R2-lineage project; Liverpool Bay location.

RWE's industry framing of AR7 is as the "largest developer commitment in a single UK auction" — a counter-narrative to post-Hornsea-4 fears about developer withdrawal. The joint-venture ownership structures (Masdar in Dogger Bank South; Stadtwerke München + Siemens in Awel y Môr) spread the equity commitment across multiple balance sheets, which may insulate the AR7 portfolio from the single-developer walk-away risk that materialised with Hornsea 4.

17.2 SSE — Berwick Bank Phase B sole Scottish award

Berwick Bank B Limited (SSE Renewables SPV) holds the 1,380 MW Scottish award. Berwick Bank's full development is ~4 GW; Phase B captures the first tranche. Scottish Ministers granted the Section 36 consent on 31 July 2025 (confirmed public record). Whether any active court challenges remained unresolved at AR7 contract signature is; the acquired source corpus does not establish a specific active challenge timeline.

17.3 Blue Gem Wind (TotalEnergies / Simply Blue) — Erebus floating

Blue Gem Wind Limited holds the 100 MW Erebus CfD. Demonstration-scale floating OSW; Welsh Celtic Sea T&D lease in place. Moving to construction-readiness is the next 2-3 years.

17.4 Highland Wind — Pentland floating (CIP-led with mixed equity stack)

Highland Wind Limited holds the 92.5 MW Pentland floating CfD, with 2029/30 Delivery Year. Per public ownership sources:

• Lead developer / manager: Copenhagen Infrastructure Partners (CIP); Copenhagen Offshore Partners (COP) is the CIP platform's development management arm. CIP (via one of its funds) is the majority owner.
• Other equity investors: Eurus Energy; Hexicon; the UK National Wealth Fund; Great British Energy (the UK's publicly-owned clean-energy company established 2024); and the Scottish National Investment Bank.

(Note: an earlier draft described the ownership as "Copenhagen Offshore Partners (COP) with equity partners including Great British Energy as an initial shareholder" — that framing was loose on two counts: (a) CIP not COP is the correct equity-ownership label, and (b) the equity stack is wider than just GB Energy.)

ScotWind-origin project. Pentland Firth location adds tidal stream exposure considerations to floating OSW engineering (operational not eligibility — tidal is not an eligible ScotWind land-use).

17.5 Overall early read

Too early for meaningful post-award fate assessment. The leading indicators to watch through 2026-27 will be:

• Supply chain contract announcements — first 12 months post-AR7 awards typically see the major turbine/foundation/cable supply contracts.
• CIB Implementation Statement issuance — DESNZ must confirm CIB minimum-standard delivery before the CfD Start Date can be set.
• DCO progression for Dogger Bank South E+W — if either project's DCO is refused, the Generator must demonstrate the refusal has been formally overturned on appeal OR risk CfD termination.
• Initial Milestone Delivery Date (~September 2027) — the 18-month post-signature milestone, typically the first real construction-progress checkpoint.

A Hornsea-4-style cancellation would be disproportionately material for AR7 given the RWE-led pipeline's 6.865 GW share — though the joint-venture structures (RWE–Masdar for Dogger Bank South; RWE + Stadtwerke München + Siemens for Awel y Môr) may moderate the single-developer walk-away risk compared with the Ørsted-sole Hornsea 4. Industry and DESNZ confidence in AR7 depends materially on the RWE-led project companies' execution across the next 24 months, especially on Dogger Bank South where the DCO decision deadline (pushed to 30 April 2026) and the 2030/31 Delivery Year leave a compressed delivery timetable.

18. Retrospective — the AR5 → AR6 → AR7 arc

AR7 is best understood as the third chapter of a three-round narrative.

18.1 AR5 (September 2023) — the zero round

AR5's Pot 3 ASP was set at £44/MWh (2012 prices) based on pre-2022 cost data. Zero offshore-wind bids. A calibration failure. DESNZ responded with +66% ASP uplift for AR6, introduction of Permitted Reduction, and retention of Pot 3 offshore-only ringfencing.

18.2 AR6 (September 2024) — the recovery that partially failed

AR6 delivered 5,341 MW of fixed offshore wind + 400 MW floating (Green Volt), at clearing prices of £58.87/MWh new and £54.23/MWh Permitted Reduction (both 2012 prices). Celebrated on publication as a successful recovery from AR5. Eight months later, Ørsted cancelled Hornsea 4 (2,400 MW, 48.6% of total fixed OSW), leaving AR6 with an effective ~2.9 GW fixed OSW outcome. The round's structure worked — sealed bid, Pot 3 ringfence, Permitted Reduction for AR4 rebid — but the price (£58.87/MWh in 2012 prices = ~£82/MWh in 2024 prices with a 15-year contract) was insufficient for new-build execution commitment in the 2024-25 cost environment.

18.3 AR7 (August 2025 → January 2026) — the reformed round

AR7's TRA reform package is an integrated response to the AR5 calibration failure AND the AR6 post-award attrition. The key structural moves:

1. Higher ASP (£113/MWh in 2024 prices, ~+10% real vs AR6): a direct cost-curve calibration upward to match observed 2025 developer economics.
2. 20-year contract term (vs 15): longer revenue-stabilisation window reduces required strike price by diffusing amortisation.
3. Clean Industry Bonus as non-price factor: separate revenue stream AND separate budget for supply-chain investment. Addresses the "local content / industrial strategy" objectives without distorting the Strike Price auction.
4. Anonymised bid information + mid-round Budget Revision: closes the loop between bidder economics and budget envelope. Government can now see whether more capacity would be good-value at a marginal strike price.
5. Unconsented Fixed-Bottom OSW pathway: accelerates pipeline-to-CfD timeline by not requiring DCO before bidding. Addresses the 5-7-year DCO bottleneck that was slowing the 50 GW 2030 delivery curve.
6. Pot 3 Maxima sub-split by connection zone: allows Scottish and rest-of-GB offshore wind to clear at separate prices reflecting different cost/grid realities — without forcing either sub-category into a single average.
7. Permitted Reduction closed: PR was a bridge for AR4-vintage projects; AR7 is strictly a new-capacity round, reflecting that AR4 PR was a one-time fix.
8. Fixed-bottom can only bid one sealed price: removes Flexible Bid optionality for fixed OSW, forcing bidders to commit to a single price. Mechanically simplifies the auction for the dominant technology; preserves Flexible Bids for smaller/newer floating OSW.

The headline outcome: 8,437.5 MW cleared, at clearing prices 19-21% below ASP, at a budget envelope (Pot 3 £1,790 m revised) roughly doubled from the initial opening. This is what a post-Hornsea-4, post-2022-cost-shock CfD round looks like when DESNZ has repriced its willingness to pay and developers have repriced their required returns.

18.4 The meta-pattern: price discovery + capacity procurement

AR5/AR6/AR7 represent three distinct operating points on the same mechanism:

• AR5: Price Discovery — revealed the market floor (bidders below £44/MWh required extraordinary assumptions to participate).
• AR6: Price Discovery + Recovery — ASP raised, bids admitted at ~£59/MWh, capacity achieved but commitment unstable.
• AR7: Price Discovery + Capacity Procurement — ASP raised further (+11% real), term extended, budget uplift mechanic used, capacity record set at ~£91/MWh (2024) equivalent.

The underlying auction mechanism (sealed bid, pay-as-clear, Maxima, Minima, budget notices, valuation formula) has been stable across all three rounds. What changed was (a) the calibration inputs (ASP, budget) and (b) supporting mechanisms (PR in AR6, CIB + Rule 13 + 20-year in AR7). This is a mechanism that behaves well given correctly-calibrated inputs; the policy challenge is getting the calibration right.

18.5 Looking forward to AR8

AR8 is committed to an annual cadence (2024 reform response) — likely opening in mid-2026 for early-2027 results. The key questions:

• Does the Rule 13 anonymised-bid mechanic get extended to Floating OSW?
• Does CIB continue as a pre-requisite, or shift to a purely competitive dimension?
• Does the unconsented-OSW pathway remain (or tighten)?
• Will the 20-year term persist, or extend further for immature technologies?
• What ASP levels and budget envelopes will DESNZ set based on the AR7 read?

AR8 will also reveal whether AR7's RWE-dominated concentration is a structural feature (a handful of scale-committed developers are now the UK OSW market) or a one-off (AR7 captured an unusual pipeline clustering).

20. Schema implications

AR7 stresses the auction data model in several new ways that AR6 did not. Grouped by entity:

20.1 auctions collection — new or extended fields

• contract_term_years: AR7 uses 20 years for OSW/Floating/Onshore/RIW/Solar PV and 15 years for everything else. The field was present in the AR6-era model (contract_term_years: int) — but AR7 demonstrates that the field is technology-dependent within a round, not a single scalar on the auction. Model implication: contract_term_years likely needs to move to AuctionTechnologyParameters or be stored per-AuctionResult row rather than per-Auction.

• non_price_factors: AR7 introduces the CIB as a non-price factor. The auction model needs a non_price_factors: list field where each NonPriceFactor has: name (e.g. "Clean Industry Bonus"), type (e.g. pre_qualification_gate | competitive_scoring_dimension | both), scope (technologies + capacities applicable), minimum_standard_value (per MW / per GW), scoring_formula (pointer to the external framework document), enforcement_mechanism (e.g. performance_related_adjustment | contract_termination), budget (monetary/capacity envelope).

• bid_disclosure_pre_auction: new AR7 concept — the Rule 13 anonymised-bid-info disclosure to the Secretary of State. Model: bid_disclosure_mechanism: { enabled: bool, scope: list, timing: str ("before_auction"), authority_recipient: enum, trigger_for_budget_revision: bool }.

• mid_round_budget_revision_trigger: AR7's 19 Dec 2025 revision was triggered by the anonymised-bid disclosure. Model: per-revision-notice, record triggered_by: enum (pre_bid_valuation | anonymised_bid_info | other) and the resulting revision (already captured via budget_revised).

• maxima as per-sub-category structured data: AR7 has two Maxima inside Pot 3 — OSW and OSW Scotland. The existing budget_constraints list captures this, but the LINK between auction_result.sub_category and budget_constraints.scope needs to be tight. Model: BudgetConstraint.scope as a structured enum/set {pot_3_offshore_wind_rest_of_gb, pot_3_offshore_wind_scotland, pot_3, pot_4, etc.}, with auction_result.sub_category derivable from the connection zone.

• anonymous_bid_disclosure_scope: the Rule 13 disclosure applies to Fixed-Bottom OSW only in AR7 — not to Floating OSW. This needs a per-technology flag.

• permitted_reduction_enabled: AR6 allowed PR; AR7 explicitly excludes it (Rule 5.1(b)). Model: permitted_reduction_enabled: bool, with optional permitted_reduction_source_rounds: list if applicable.

• unconsented_eligibility_pathway: AR7 added Unconsented Fixed-Bottom OSW. Model: alternate_qualification_paths: list where each path has name (e.g. "Unconsented Fixed-Bottom OSW"), applies_to: list, conditions: list (e.g. "no planning refusal", "Director's declaration per Schedule 7"), required_artefact: str (Schedule 7 template).

20.2 auction_results collection — new sub-category handling

• Sub-categorisation by connection zone: AR7 Pot 3 results split into sub_category: "Offshore Wind" and sub_category: "Offshore Wind Scotland". The existing sub_category free-text convention works (pipe-delimited Pot 3 | Offshore Wind | 2030/31 etc.), but the display and aggregation logic in framework_snapshot.py needs to group by this sub-category for per-Maximum clearing price display.

• Multi-unit winners (Norfolk Vanguard East A/B/C, Norfolk Vanguard West A/B/C): AR7 demonstrates a pattern where a single Applicant Legal Entity wins multiple CFD Units with different Delivery Years. Model: keep as 3 separate auction_result rows, linked by project_id (if projects exist for Norfolk Vanguard East/West in the projects collection). This is already the AR6 pattern (Hornsea 3 A/B/C).

• Phased CFD Unit representation: AR7's Dogger Bank South E/W (3-phase) and Norfolk Vanguard A-units (2-phase) need auction_result.phases: list where each Phase has capacity_mw, target_commissioning_date, phase_number. Alternative: keep as single auction_result with scalar capacity + number_of_phases int — but loses the per-phase TCD data. Recommendation: phases as a structured sub-list.

• Connection zone metadata: auction_result.connection_zone field with values like GUS_1-12_or_DNO_17-18 vs GUS_13-27_or_DNO_10-16_or_19-23 — to trace the Maxima-sub-category mapping.

20.3 auction_documents collection — new document types

AR7 introduces new document types the schema enum should cover:

• pot_and_price_notice — new for AR7 (a Regulation 10A instrument that didn't exist for AR6).
• cib_allocation_framework — new CIB framework document.
• cib_budget_notice — CIB-specific budget notice (separate from CfD Contract Budget Notice).
• state_aid_or_subsidy_advice — CMA Subsidy Advice Unit reports.
• application_window_notice — new Regulation 4A instrument.
• budget_revision_notice — existed for AR6 but AR7 shows the variant where the revision is triggered by anonymised bid data; add metadata field revision_trigger: enum.

20.4 CIB-specific schema needs

The CIB is analytically rich enough that it may warrant its own collection or sub-document structure:

• CIBApplication: one per applicant per CfD Unit. Fields: applicant_legal_entity, cfd_unit_capacity_mw, minimum_standard_required_gbp (derived: 100 * capacity_gw for fixed, 50 * capacity_gw for floating), minimum_standard_proposals_total_gbp, minimum_standard_met: bool, extra_proposals: list, cib_statement_issued: bool, cib_statement_issued_date.

• CIBExtraProposal: per proposal. Fields: criterion: enum (criterion_1 | criterion_2), investment_target: str (component/port/manufacturer), investment_value_gbp, cib_revenue_support_requested_gbp, raw_score, normalised_score_out_of_100, rank, allocation_successful: bool.

• Aggregation on Auction: cib_budget_total_gbp, cib_flow_sub_budget_gbp, cib_regular_budget_gbp, cib_extras_allocated_gbp, cib_extras_unallocated_gbp_going_to_secondary.

20.5 Post-award events — extended for AR7 patterns

New LifecycleEventType values the auction-model needs to accommodate AR7-specific post-award patterns:

• cfd_awarded_at_dual_clearing_price — already implicit but worth an explicit enum value for Maxima-split cases.
• cib_statement_issued — DESNZ confirms CIB minimum-standard delivery.
• cib_refusal_issued — DESNZ refuses to issue CIB Statement.
• cib_implementation_statement_issued — post-award CIB performance check.
• performance_related_adjustment_applied — CIB non-delivery triggers CfD payment reduction.
• budget_revision_notice_signed_for_unrelated_round — (not per-project, but per-auction).

20.6 Cross-auction analytics — new comparisons enabled

AR7 unlocks analytical comparisons that need model support:

• Contract term vs clearing price: the AR6 15-year vs AR7 20-year comparison requires contract_term_years to be consistently captured and a normalisation utility.
• Non-price factor revenue stream breakdown: analytics over CIB spend per developer, CIB proposals per criterion, FLOW sub-budget utilisation — requires the CIBApplication/CIBExtraProposal collections.
• Budget revision effectiveness: compare AR6 (pre-bid valuation trigger) vs AR7 (anonymised-bid-info trigger) — did the latter produce a tighter "clearing just below the marginal admitted bid" outcome? Needs per-revision-notice metadata.
• Unconsented OSW pipeline progression: tracking projects that entered AR7 via Schedule 7 to see whether they achieve DCO on time, whether any are refused post-award, etc.

20.7 Where this sits in the broader analytics surface

The AR7 writeup strongly implies that the auctions grid and detail page now need:

• A CIB column or detail-card section surfacing the CIB pre-requisite + extras mechanics.
• A "bid-disclosure / mid-round revision" indicator showing whether the auction used anonymised bid info + revision.
• A Maxima sub-category breakdown on the Capacity column (showing per-sub-category winners and clearing prices).
• An unconsented-OSW badge on projects that entered via that pathway.

These are all downstream UI concerns; the backend data must be structured to support them.