Contracts for Difference Allocation Round 3

UK CfD Allocation Round 3 (AR3, 2019)

The record-breaking round that set the offshore-wind decline-curve benchmark. AR3 was the third UK Contracts for Difference allocation and the last round before the three-pot reform — a single less-established-technology pot ("Pot 2") with a £65 million/year budget and a 6 GW overall capacity cap. On 20 September 2019 (re-issued corrected 11 October 2019) BEIS announced 12 successful applications, 6 of them offshore-wind CFD Units totalling 5,466 MW at clearing prices of £39.650/MWh (2023/24 delivery) and £41.611/MWh (2024/25 delivery) in 2012 prices — roughly 30% below AR2's £57.50/MWh, and the first time CfD offshore-wind prices fell below the forecast wholesale reference price. AR3 introduced Remote Island Wind as a distinct technology (4 Scottish Island projects, 275 MW total) and produced the first generation-weighted negative "notional budget impact" across all delivery years. Its clearing prices served as the competitive anchor for AR4's £37.35/MWh — and became the load-bearing evidence that post-2022 cost inflation had structurally repriced UK offshore wind once AR5 failed and Norfolk Boreas withdrew. Offshore-wind post-award attrition (LCCC Register, 2026-03-31 snapshot): 1 of 6 OSW projects terminated — Forthwind (12 MW, 4 April 2024), 0.22% of awarded OSW capacity. 5,454 MW remains active across 15 phased CFD Units (Dogger Bank A/B/C, Sofia, Seagreen — each split into 3 phase records in the register).

1. At a glance

• Sponsor: Department for Business, Energy and Industrial Strategy (BEIS) — predecessor to DESNZ (Feb 2023)
• Delivery Body: National Grid Electricity System Operator Limited (NG ESO), acting as EMR Delivery Body — subsequently re-constituted as NESO in October 2024
• Counterparty: Low Carbon Contracts Company (LCCC)
• Scrutiny regime: Pre-Brexit EU State aid — CfD scheme approved under case SA.44475; Remote Island Wind addition approved under case SA.49318 (January 2018)
• Allocation Round Notice: 1 May 2019 (Secretary of State — signed by Ashley Ibbett, Director Clean Electricity, on behalf of the Secretary of State)
• Application window opens: 29 May 2019 (commencement date per Allocation Round Notice)
• Results published: 20 September 2019; corrected version 11 October 2019
• Overall budget (2011/12 prices): £65 million total for both Delivery Years 2023/24 and 2024/25; overall capacity cap 6 GW across both years
• Pot structure: single pot — "Pot 2" (less established). No Pot 1 (established) included. No separate offshore-wind pot (that split came with AR4's Pot 3). auction_results records carry pot: 2 across the board.
• Technologies eligible: 8 technologies — Advanced Conversion Technologies (ACT), Anaerobic Digestion (>5 MW), Dedicated Biomass with CHP, Geothermal, Offshore Wind, Remote Island Wind (>5 MW), Tidal Stream, Wave
• Offshore Wind ASP: £56/MWh (2023/24 delivery); £53/MWh (2024/25 delivery) — per-Delivery-Year ASP, not single-across-DYs (AR4 introduced the single-ASP convention)
• Offshore Wind clearing: £39.650/MWh (2023/24); £41.611/MWh (2024/25) — 29% and 21% saving on ASPs respectively
• Auction format: sealed-bid, pay-as-clear within Delivery Year (auction clears once the next bid would exceed the Monetary Budget or Overall Capacity Cap; successful applications with the same Delivery Year all receive the clearing price set by the last accepted bid in that Delivery Year, capped at ASP). No Minima, no Maxima — confirmed by Budget Notice §Use of Maxima or Minima: "No maxima or minima will be applied for the third Allocation Round". Up to 4 Flexible Bids per Application.
• Revenue instrument: two-way CfD, 15-year term, CPI-indexed Strike Price, Reference Price (Baseload Market Reference Price or Intermittent Market Reference Price by technology)
• Contract form: FiT Contract for Difference Standard Terms and Conditions Version 3 (542 pages, 1 May 2019); Generic CfD Agreement wrapper (31 pages, 1 May 2019); Apportioned, Phase-1 and Phase-3, Private Network, Single Metering, and Unincorporated Joint Venture variants published the same day
• Successful applicants: 12 — 6 offshore wind (5,466 MW), 4 Remote Island Wind (275.22 MW), 2 ACT (33.60 MW)
• Offshore wind winners: 6 projects / 4 distinct corporate groups / 5,466 MW
  • Doggerbank Creyke Beck A P1 (SSE Renewables/Equinor JV) — 1,200 MW, England, Delivery Year 2023/24 — 3 phases
  • Doggerbank Creyke Beck B P1 (SSE Renewables/Equinor JV) — 1,200 MW, England, Delivery Year 2024/25 — 3 phases
  • Doggerbank Teeside A P1 (SSE Renewables/Equinor JV) — 1,200 MW, England, Delivery Year 2024/25 — 3 phases
  • Sofia Offshore Wind Farm Phase 1 (innogy → RWE) — 1,400 MW, England, Delivery Year 2023/24 — 3 phases
  • Seagreen Phase 1 (SSE Renewables/TotalEnergies JV) — 454 MW, Scotland, Delivery Year 2024/25 — single-phase CfD on larger consented project
  • Forthwind (Cierco Ltd) — 12 MW, Scotland (Methil, Firth of Forth), Delivery Year 2023/24 — offshore demonstrator
• Remote Island Wind winners: 4 projects / 4 distinct corporate groups / 275.22 MW on Scottish Islands (Orkney, Isle of Lewis)
• ACT winners: 2 projects / 2 groups / 33.60 MW (Bulwell Energy, Small Heath Bio Power)
• Post-award fate: Forthwind CfD terminated 4 April 2024 — the only AR3 CfD termination (LCCC Register entry AR3-FWL-321; pre-Start-Date termination, Longstop Date of 2 October 2026 not reached). Seagreen Phase 1 fully operational October 2023 (first power August 2022). Dogger Bank A/B/C (Creyke Beck A/B and Teeside A) all delayed — each is a single CfD covering multiple phased CFD Units in the LCCC Register. Sofia Phase 1 in offshore construction at year-end 2025 (all monopile foundations installed November 2025) — CfD comprises multiple Apportioned CFD Unit records.

2. Market context at the time of the auction

AR3 opened at the inflection point of UK offshore-wind cost compression. AR2 (2017) had cleared fixed-bottom offshore wind at £57.50/MWh (2012 prices) for the 2022/23 Delivery Year — already a 50% fall on AR1 (2015)'s £114.39–£119.89/MWh. By early 2019, pipeline developers held consented projects built on cost assumptions from 2016–17, but turbine technology had moved on: the industry was moving from the 8 MW-class platform (dominant through 2017–19 commissioning) to 12–14 MW machines for the mid-2020s commissioning wave. Larger turbines reduced per-MW capex via economies of scale on foundations, inter-array cabling, and vessel days.

Three contextual drivers framed AR3 bidder strategy:

• Scale of the AR3 pipeline. 29.5 GW of AR3-eligible offshore wind was reported in the application window — far exceeding the 6 GW cap. BEIS's impact assessment for AR3 noted that the pipeline included more capacity than any prior round by a factor of ~4. Under the pay-as-clear mechanic, an auction was certain to trigger (§6 below).

• Commitment framework tightening for ACT and Biomass with CHP. For AR3, the government introduced a higher efficiency threshold (70% overall, net calorific value) for dedicated biomass with CHP and energy-from-waste with CHP projects, and a new Physical Separation Requirement for ACT between the Synthesis Chamber and the Combustion Chamber. The government's stated expectation was that "at least one of the projects successful in AR2" would still be able to meet these new criteria. This tightening contributed to the modest ACT headcount (2 winners, 33.6 MW).

• Offshore Transmission Owner regime pre-construction. The OFTO regime (2009 onwards) separated the transmission asset from the generating station, requiring the Generator to deliver the transmission assets pre-commissioning and then divest them to an OFTO via a Tender Exercise run by Ofgem. The Generic CfD Agreement Clause 5.8 provides that "for the purpose of Conditions 4.1(A) and 4.1(B), the Project shall exclude the assets comprised or to be comprised within the Offshore Transmission System of the Facility" — i.e. OTS capex is excluded from the 10% spend Milestone test. This distinctive UK treatment remains across AR3-AR7.

The Remote Island Wind introduction is the major AR3-specific policy shift. The June 2018 Part A government response (reform-response-part-a-2018.md) codified RIW as a distinct technology in Pot 2, after EU State aid approval under case SA.49318 in January 2018. The RIW policy was driven by (i) a Conservative manifesto commitment to support wind on remote islands, (ii) the need to justify substantial new transmission capex to Scottish islands (Shetland, Orkney, Western Isles) under Ofgem's Strategic Wider Works / Needs Case regime, and (iii) industry arguments that RIW had distinct cost drivers from mainland onshore wind (longer cables, higher TNUoS, no availability guarantee) that warranted a separate ASP. The resulting ASP of £82/MWh (both Delivery Years) sat below tidal (£225/£217), wave (£281/£268) and biomass (£121) but above offshore wind (£56/£53) — reflecting RIW's subsea-cable cost burden.

3. Regulatory frame

AR3 operates under the same statutory stack as its successors AR4–AR7:

1. Energy Act 2013 (primary). Section 6 empowers contracts for difference; section 11 empowers publication of Standard Terms and Conditions; section 13 establishes Allocation Rounds; section 14 (CFD notification: offer to contract on standard terms); sections 15–22 on delivery-body, counterparty, and enforcement arrangements.

2. Contracts for Difference (Allocation) Regulations 2014 (SI 2014/2011, as amended). Principal amendments affecting AR3 were made by the Contracts for Difference (Allocation) (Miscellaneous Amendments) Regulations 2018 (SI 2018/1018) — which introduced Regulation 27A (Remote Island Wind conditions). The Allocation Framework (§1 — "These Rules are made under Regulation 4 of the Allocation Regulations") and Budget Notice (Regulation 11) are issued under this instrument.

3. Contracts for Difference (Definition of Eligible Generator) Regulations 2014 (SI 2014/2010). Defines which stations can apply; amended in 2018 to update the definition of "waste" (to align with EU Directive 2008/98/EC) and to remove the legislative reference to the CHPQA Standard (moving CHPQA requirements into the CfD contract terms instead of the regulations).

4. Contracts for Difference (Standard Terms) Regulations 2014 (SI 2014/2012). Defines the CfD Counterparty (LCCC) and the authority to publish Standard Terms.

A set of AR3-specific statutory notices was published on 1 May 2019, signed by Ashley Ibbett, Director Clean Electricity on behalf of the Secretary of State:

• Allocation Round Notice (Regulation 4) — establishing AR3 and setting 29 May 2019 as the Application Window opening date
• Budget Notice (Regulation 11) — setting the £65m overall budget and 6 GW overall capacity cap (budget-notice.md)
• CFD Framework Notice — identifying the AR3 Allocation Framework as applicable
• Standard Terms Notice — identifying the FiT CfD Standard Terms and Conditions Version 3 as the applicable contract
• Counterparty Costs Notice — covering LCCC costs passed through to levy
• Allocation Framework — the 61-page rule book (allocation-framework.md)

The Budget Notice footnote 3 confirms the 6 GW overall capacity cap was subject to the Department "seeking State aid approval" — the underlying SA.44475 authorisation for the CfD scheme had already been extended to cover AR3 by the European Commission through the January 2018 SA.49318 amendment.

Unlike AR4 onwards, AR3 did not publish a mid-round Budget Revision Notice. The Budget Notice explicitly confirmed "the Department is seeking State aid approval" for the 6 GW cap but did not reserve a revision mechanism for mid-round use. The AR3 auction closed within its originally-notified budget.

4. Pre-round preparation and timeline

AR3 is the first round to benefit from an explicit consultation-and-response cycle on its own scheme amendments (a pattern AR4–AR7 inherited). The table below records the full lifecycle from policy signal to post-auction events.

5. The prize — CfD contract mechanics

Each AR3 winner receives a Contract for Difference Agreement between the Generator and the CfD Counterparty (Low Carbon Contracts Company Ltd). The CfD is a 15-year revenue-support instrument: Generic Agreement Clause 3 defines the Specified Expiry Date as "the 15th anniversary of the earlier of the Start Date and the last day of the Target Commissioning Window" (generic-agreement.md). The Generic Agreement is a 31-page wrapper that incorporates the 542-page FiT CfD Standard Terms and Conditions Version 3 by reference (standard-terms-and-conditions.md).

Revenue mechanism in essence:

• If the market price (Market Reference Price, defined by technology) < Strike Price: LCCC pays Generator the difference per MWh of Loss Adjusted Metered Output (after TLM, RQM, and CHPQM adjustments).
• If the market price > Strike Price: Generator pays LCCC the difference per MWh.
• Payments calculated against the Net Payable Amount (Condition 22.4(D)): Net Payable Amount = Aggregate Difference Amount + Reconciliation Amount + Compensatory Interest Amount.
• LCCC pays Generator within 28 calendar days of the relevant Billing Period (Condition 23.1).
• Generator pays LCCC within 10 Business Days of Billing Statement delivery if the Net Payable Amount is negative (Condition 23.2).

The Strike Price is set in 2012 prices and CPI-indexed annually on the Indexation Anniversary per Condition 14, using the formula Inflation Factor (Πt) = CPIt / CPIbase where CPIt is the CPI for January of the relevant calendar year and CPIbase is the CPI for October of the calendar year preceding the Base Year (2012).

Reference Price — two layers, not to be conflated:

Valuation (pre-auction, NG ESO): Allocation Framework Schedule 2 Appendix 2 sets out reference-price series in 2012 prices used to value each Qualifying Application against the budget. For AR3 these are Baseload (for ACT, AD, Dedicated Biomass with CHP, Geothermal) and Intermittent (for Offshore Wind, Remote Island Wind, Tidal Stream, Wave). AR3 Intermittent Reference Prices (2012 prices): 2023/24 £48.13/MWh; 2024/25 £50.90/MWh; 2025/26 £51.92/MWh; 2026/27 £51.23/MWh.

In-life settlement (post-award, LCCC): the Budget Notice accompanying note §10 describes the post-award reference prices:

"payments are made to developers based on the difference between their strike price and the market reference price, which is a season-ahead price for baseload technologies (such as fuelled technologies) and a day-ahead hourly price for intermittent technologies (such as offshore wind)."

These correspond to the Baseload Market Reference Price (BMRP) and Intermittent Market Reference Price (IMRP) defined in Annexes 4 and 5 of the Standard Terms respectively. The Settlement Unit is a half-hour period for baseload technologies and a one-hour period for intermittent technologies (Generic Agreement Annex 3 Parts A and B).

Negative-pricing rules — the six-hour threshold.

AR3 uses the pre-reform "rolling" negative-pricing exclusion rather than AR4's strict-negative rule. Per Standard Terms definitions:

• Intermittent Rolling Negative Price Period = "a period of six (6) or more consecutive Settlement Units (irrespective of whether such Settlement Units fall within the same Billing Period) in respect of which the Intermittent Market Reference Price is negative (that is, less than £0/MWh)". During such a period, the Intermittent Difference Amount is set to zero (Condition 18.2–18.3).

• Baseload Rolling Negative Price Period = "a period of twelve (12) or more consecutive Settlement Units (irrespective of whether such Settlement Units fall within the same Billing Period) in respect of which the Intermittent Market Reference Price during the corresponding six (6) Intermittent Settlement Units is negative". During such a period, the Baseload Difference Amount is set to zero (Condition 10.2–10.3).

This rolling-window threshold — six consecutive hours of negative prices — is a material difference from AR4 onwards, where the strict-negative rule applied to any individual negative Settlement Unit. The 2020 consultation response (docs/research/.../uk_ar4/reform-response-2020.md, §Negative Prices) is the regulatory-decision source that reformed the rule from AR4 onwards. AR3 CfD holders benefit from more generous negative-price treatment than any subsequent UK offshore-wind cohort.

Key Standard Terms provisions relevant to extraction (drawn from the 542-page FiT CfD STCs Version 3, 1 May 2019):

• Target Commissioning Window (TCW): specified per Facility Generation Technology in Table G of the AR3 Standard Terms Notice (1 May 2019). For AR3 offshore wind, the TCW is 1 year (per application-guidance.md confirmation — "TCW is always 1 year" at AR3 for all Pot 2 technologies).
• Longstop Period and Longstop Date: specified per Facility Generation Technology in Table H of the AR3 Standard Terms Notice. The Longstop Date formula is TCW End + Longstop Period + FM Extensions (Standard Terms definitions, Part 1). After Longstop, LCCC may terminate under Condition 51.1(E) if Operational Conditions Precedent are not fulfilled.
• Milestone Requirements (Condition 4): Generator must deliver a Milestone Requirement Notice by the Milestone Delivery Date, evidenced either by (A) 10% of Total Project Pre-Commissioning Costs spent, or (B) compliance with Project Commitments. Generic Agreement Clause 5.5 sets the Initial Milestone Delivery Date at twelve (12) months after the Agreement Date — a key AR3-vs-AR4 difference, since AR4 extended this to 18 months. LCCC has 20 Business Days to respond (Condition 4.3), may request further information (Condition 4.4), and if still not satisfied may terminate under Condition 51.1(A).
• Non-Delivery Disincentive: AR3 does not use a financial-penalty NDD of the form later introduced. Instead, AR3's NDD mechanism is contract termination without payment — Condition 51.1(A) grants LCCC the right to terminate Pre-Start Date if MDD is missed; Condition 52.2 confirms no termination payment is due on a Pre-Start Date termination. This is a non-monetary NDD in the form of lost contract optionality. The NDD framework referenced by the 2020 reform response as "currently penalises non-compliant developers" is this Pre-Start Date termination right — not a cash penalty regime. (The Application Guidance line 5000 notes: "Qualifying Applicants have the opportunity to withdraw their Application entirely from the CfD process in the sealed bids window without incurring the Non-Delivery Disincentive" — confirming NDD operated in AR3.)
• Change in Law (CIL) mechanism: Condition 33–36. Three compensation methodologies: QCiL Capex Payment (capital impact), QCiL Adjusted Revenues Payment (operating impact), QCiL Operations Cessation Event Payment (shutdown). Pass-through is asymmetric: before Start Date, Generator recovers full QCiL Compensation or may terminate; after Start Date, CIL must be Material to trigger compensation, otherwise the impact stays with the Generator (Condition 34.3).
• EU State Aid regime: AR3 Standard Terms retain extensive EU State Aid references (unlike AR4, which stripped them post-Brexit). Condition 32.4–32.15 contains the No Cumulation of State Aid Warranty; Condition 3.31 provides for set-off of prior State Aid (including interest calculated at the EU Reference Rate Methodology); Condition 32.11 sets the State Aid Interest Rate. State Aid Competent Authority means the European Commission.
• Phased Offshore Wind CFD Units: the Standard Terms do not contain per-phase sub-contracts — a Phased Offshore Wind CFD Unit is a single CfD covering the full project capacity, with Installed Capacity Estimate adjustments available per Condition 5 (Relevant Construction Event) and Condition 6 (Permitted reduction). The Allocation Framework Rule 4(a) and Rule 12 provide the phased-unit structural rules (see §6.4 below).
• Curtailment compensation (Condition 49): Generator can recover "Defined Curtailment Compensation" shortfall if a Qualifying Curtailment occurs (requiring all four conditions in the definition to be met — change in Law, Balancing Mechanism failure limb, causation, and compensation shortfall). Curtailment Compensation may be paid lump sum or staged at LCCC election, first payable on the Curtailment Compensation Anniversary.

There is no Clean Industry Bonus in AR3 — the CIB was introduced for AR7 via the 2024 Targeted Reform. AR3 is purely price-competitive (see §9 on Scoring).

6. Budget architecture

AR3's budget architecture is the simplest of any post-AR1 round. Single pot, two Delivery Years, no Minima, no Maxima, no Soft Constraints.

6.1 Budget Notice (1 May 2019)

Overall budget (2011/12 prices, per the Budget Notice):

• £65 million total for both Delivery Years combined — interpreted as the maximum annual support payable under CfDs awarded in this round, applied across 2023/24 and 2024/25
• 6 GW overall capacity cap spanning both Delivery Years (i.e. the cap applies to the aggregate Installed Capacity Estimate across the whole AR3 pipeline, not per year)

Delivery Years: 2023/24 and 2024/25. Valuation Years: 2025/26 and 2026/27 (i.e. budget impact was valued across four years — the two Delivery Years plus two additional valuation years for phased projects).

Pot allocation: "The available budget has been allocated to the less established technology group ('Pot 2')" (Accompanying Note §2). No Pot 1, no separate offshore-wind pot — every applicant competed in a single Pot 2 auction.

Eligible technologies (Budget Notice §Eligible Technologies for Pot 2):

• Advanced Conversion Technologies (ACT)
• Anaerobic Digestion (>5 MW)
• Dedicated Biomass with CHP
• Geothermal
• Offshore Wind
• Remote Island Wind (>5 MW) — NEW at AR3
• Tidal Stream
• Wave

Use of Maxima or Minima: "No maxima or minima will be applied for the third Allocation Round" (Budget Notice §Use of Maxima or Minima). This was a deliberate policy choice despite consultation responses requesting a ringfenced minimum for RIW (§Wind on remote islands, reform-response-part-a-2018.md).

Phased Offshore Wind Projects: the Budget Notice explicitly permits Offshore Wind CfD Units up to 1,500 MW of capacity to be delivered in multiple phases. Phases subsequent to the first phase may have Target Commissioning Dates up to two years after the final Delivery Year (i.e. final phase TCD can be as late as 31 March 2027).

6.2 CPI-indexing of budget

Inflator factor 1.0193 (2011/12 → 2012 CPI) to convert the £65m 2011/12-price budget to 2012 prices for valuation against 2012-price bids. This yields a 2012-price budget of £65 million rounded to the nearest £5m (Budget Notice §Re-basing CfD Budgets).

An illustrative inflator to current prices was published as 1.1335 (February 2019 prices at time of publication), for stakeholders converting the budget to current terms.

6.3 No Budget Revision Notice

AR3 did not issue a Budget Revision Notice during the round. The initial £65m Overall Budget was sufficient to accommodate the successful bids after the auction cleared at below-reference-price strike prices (see §12 Results).

6.4 Phased Offshore Wind capacity rules

AR3 introduced Phased Offshore Wind CFD Units as a first-class structural concept in the Allocation Framework Rule 4(a):

• (i) after all phases complete, CFD Unit capacity ≤ 1,500 MW
• (ii) the first phase must represent at least 25% of the total capacity
• (iii) the first phase must target completion by no later than 31 March 2025 (i.e. within the final Delivery Year)
• (iv) the Target Commissioning Date of the final phase must be no later than 2 years after the first phase's TCD
• (implied by the Budget Notice Phased OSW provision and the Framework's Rule 4(a)(iv), the maximum number of phases is 3)

All three Dogger Bank winners and Sofia were Phased Offshore Wind CFD Units; Seagreen Phase 1 and Forthwind were single-phase CfDs on larger consented projects (Seagreen's "Phase 1" in the CfD designation is the first 454 MW of the project's larger multi-phase development — distinct from any CfD phase structure).

7. Administrative Strike Prices

ASPs in AR3 cap the Strike Price each Generator can receive: even if the auction clears at a higher price, no Generator receives more than its technology's ASP for its Delivery Year (Allocation Framework Rule 11.1(a)(i): "the Applicant's proposed Strike Price in pounds sterling that it will accept for each megawatt hour of Metered Output, which must not be more than the applicable Administrative Strike Price"; Rule 16.2(a): "capped at the relevant Administrative Strike Price").

AR3's ASPs are per-Delivery-Year (distinct from AR4's single-ASP-per-technology-across-DYs convention). This means Offshore Wind has separate 2023/24 and 2024/25 ASPs, though in AR3 they happen to be different (£56 and £53).

7.1 AR3 ASPs (2012 prices)

From Budget Notice Table 1:

7.2 Methodology — uniform 25% supply-curve targeting

The ASP methodology (asp-methodology.md) sets ASPs by modelling each technology's supply curve (strike-price vs cumulative MW of pipeline that would be NPV-zero at that price), then targeting the price at which the lowest-cost 25% of the pipeline becomes economically viable.

Consistent 25% of the supply curve across all AR3 technologies — Section 1, Table 2: "Target 25% of the supply curve when setting reserve prices … target the same proportion of the supply curve (25%) for each technology". No offshore-wind-specific override (AR4 later doubled this to 50% for offshore wind alone). The AR2 target was 19% — so AR3 widened the targeted proportion by 6 percentage points, implicitly raising ASPs slightly relative to AR2.

ASPs are rounded to the nearest £1/MWh (ASP methodology §Section 3 Step 5 footnote 6): "Previously ASPs have been rounded to the nearest £5/MWh but given the level of cost reduction seen and estimated over successive allocation rounds, the Government now deems it appropriate to reduce the level of rounding applied."

Offshore Wind ASP derivation: Supply curves constructed from specific pipeline projects, informed by planning consents. Key inputs:

• Capex varies with turbine size — larger turbines → lower £/MW capex
• Load factors — estimated from Met Office wind-speed data + turbine power-curve models at project-specific sites
• TNUoS charges — per-project estimates from National Grid forecast tariffs and network charging assumptions
• Decommissioning costs — from BEIS's ARUP-developed decommissioning cost model using project characteristics from planning consents
• Hurdle rates from the Europe Economics report commissioned by BEIS (not specifically disclosed for offshore wind)

Remote Island Wind ASP derivation: RIW was not separately modelled in BEIS's generation-cost data at the time. The methodology used Baringa's 2013 Scottish Islands Renewable Project Final Report as the primary data source, updated for onshore-wind cost reductions since 2013 (ASP methodology §Section 5).

7.3 AR3 ASP vs AR2 / AR4 in context

AR3's Offshore Wind ASP of £56/£53 was ~45% below AR2's ASP range. AR4's £46 ASP was a further ~17% below AR3's lower-year ASP. The ASP trajectory broadly tracked the Cost-Reduction Trajectory submitted by the sector through the Offshore Wind Cost Reduction Task Force (2012–18), reflecting real-terms capex declines from 8 MW-class to 10+ MW-class turbines and supply-chain maturation.

8. Qualification criteria

To submit a bid, every applicant must first be determined a Qualifying Application by NG ESO under Regulation 19. The Delivery Body applies a set of checks codified in Allocation Framework Schedule 4 (general eligibility, technology-specific conditions, project-specific evidence). AR3's qualification is strictly binary — no Soft Constraints were applied (confirmed by Allocation Framework; the Framework does not include any Soft Constraint flag for the round).

8.1 General qualification gates (binary pass/fail, all technologies)

• Eligible Generator status under the Contracts for Difference (Definition of Eligible Generator) Regulations 2014 — excludes, inter alia, Commissioned Generating Stations
• Company incorporation evidence — UK Certificate of Incorporation, VAT registration, or non-UK equivalent
• Applicable planning consents (Regulations 23, 24) — signed and dated Planning Decision Notice consistent with the Application's technology, capacity (≥ stated Application capacity), and location
• Grid Connection Agreement (Regulation 25) — evidence of:
  • For Direct Connection to Transmission System: "Transmission Entry Capacity for the CFD Unit at least equal to 75% of the Initial Installed Capacity Estimate"
  • For Distribution System: Connection Agreement permitting "at least 75% of the Initial Installed Capacity Estimate"
  • For Phased Offshore Wind: "a separate Connection Agreement in relation to each phase of that Application" (Schedule 4)
• Non-receipt of other government support (Regulations 14, 18) — confirm no NFFO, SRO, RO accreditation, or Capacity Market contract applicable
• Target Commissioning Date within window — TCD must fall within the Delivery Year specified in the Application (Schedule 5 specifies 1-year TCW for all AR3 technologies with ±1-year flexibility on TCW start)
• Supply Chain Plan Statement — for projects of 300 MW or more, a BEIS-issued SCP Approval Certificate (see §8.3 below) — application window closed 10 February 2019

8.2 Technology-specific gates

• Phased Offshore Wind structural rules — Rule 4(a): 1,500 MW cap, first-phase ≥ 25%, first phase TCD ≤ 31 March 2025, final phase TCD ≤ 2 years after first phase
• Remote Island Wind conditions (Regulation 27A(3), Schedule 4) — the CFD Unit must:
  • (a) generate electricity by the use of wind
  • (b) be located on a Remote Island (defined as an island in offshore waters with the entirety of its coastline ≥ 10 km from mainland Great Britain; the three specifically-named areas — Comhairle nan Eilean Siar, Orkney Islands Council, and Shetland Islands Council — are deemed to meet this criterion)
  • (c) be connected to the national Transmission System or to a Distribution System
  • (d) have a Generation Circuit (for Transmission connection) or Grid-Supply-Point-to-MITS electrical connection (for Distribution connection) consisting of ≥ 50 km of cabling, ≥ 20 km of which is subsea cabling Applicants from Western Isles / Orkney / Shetland connecting to the national Transmission System are deemed to meet the cabling length requirements "however, must still submit a schematic diagram" (Schedule 4). The AR3 eligibility was geographically neutral — "applications from any geographical location will be considered" (Application Guidance line 3712–3713).
• Advanced Conversion Technology — Physical Separation Requirement (Regulation 28, Schedule 4) — Applicant must provide a process flow diagram demonstrating that the Synthesis Chamber and the Combustion Chamber are separated by a pipe or conduit, with all Purification Units and Compression Units labelled. This was new for AR3 and tightened eligibility relative to AR2.
• CHP efficiency — Dedicated Biomass with CHP and Energy from Waste with CHP must meet the new AR3 efficiency standards: 70% overall efficiency (net calorific value), 10% primary energy saving (gross calorific value), 10% heat efficiency (gross calorific value). Also extended to schemes under 25 MWe (previously exempt). Introduced by the June 2018 Part A response (reform-response-part-a-2018.md §CHP).
• Floating Offshore Wind — NOT ELIGIBLE at AR3. Floating Offshore Wind is not listed as a Technology Type in the Budget Notice Table 1 or the Allocation Framework Schedule 4. FOW was first admitted as a distinct CfD technology at AR4 (following the 2020 consultation). All AR3 offshore-wind applications were fixed-bottom — including the 12 MW Forthwind demonstrator at Methil, which uses fixed foundations at the existing Energy Park Fife port.

8.3 Supply Chain Plan — the binary quality gate

For all projects of 300 MW or more, a BEIS-issued SCP Approval Certificate is a hard pre-auction qualification gate (Allocation Framework Schedule 4; supply-chain-plan-guidance.md §1 Purpose). At AR3, the 300 MW threshold applied to any Pot 2 technology of sufficient size — but in practice this was the offshore-wind gate (no other AR3 Pot 2 technology had pipeline projects approaching 300 MW).

The SCP process required applicants to describe their approach across three dimensions:

• Infrastructure — UK supply-chain infrastructure investment commitments
• Innovation — innovation investment, demonstrator commitments, R&D
• Skills — skills/apprenticeship commitments in the UK supply chain

BEIS scored responses; applicants passing the threshold received an SCP Approval Certificate. The AR3 SCP window closed 10 February 2019 — applicants had to secure their SCP Certificate before the 29 May 2019 main application window opened. Without the Certificate, the application was non-qualifying.

AR3's SCP regime was lighter-touch than AR4's — but not because post-award monitoring was absent. AR3 has a PBR/iPBR regime (Post Build Report / Interim Post Build Report) per SCP Guidance §3.13-3.20 and Annex D/E (see §15.4 for detail): BEIS monitors implementation post-CfD-award, may request a PBR within 3 months of first CfD payment, and iPBR at subsequent-round SCP application. What AR4 introduced was the SIS (Supply Chain Implementation Statement) as an Outstanding Condition Precedent — wiring failure-to-monitor into the CfD's termination machinery. AR3's PBR/iPBR has no in-contract termination bite; the bite is reputational and on subsequent-round eligibility.

8.4 Non-Qualification and Appeals

• Delivery Body must issue qualification determination "no later than 15 working days after the application closing date" (Allocation Framework Rule 7.1; Regulation 19).
• Applicant may request a Non-Qualification Review within 5 working days of the determination notice. Delivery Body must issue Non-Qualification Review Notice within 10 working days (per Rule 8.1, not 15 as in AR4).
• Applicant may further appeal to the Authority (Ofgem) within 5 working days of the Review Notice — a Qualification Appeal under Regulation 43.

9. Evaluation criteria, process, and scoring

AR3 uses a pay-as-clear sealed-bid auction with single-price-dimension scoring (price only). No non-price factors are scored. This is identical in form to AR4–AR6; AR7 introduced the Clean Industry Bonus as a separate non-price stream.

9.1 Application Valuation formula

Per Allocation Framework Schedule 2, NG ESO values each application using:

$$ \text{Budget impact}{s,yr,p} = (\text{Strike Price}{cy,t} - \text{Reference Price}{yr}) \times \text{Load Factor}{t,yr} \times \text{YR1F}{s,c,p} \times \text{Capacity}{s,p} \times (\text{Days}{yr} \times 24) \times (1 - \text{TLM}{yr}) \times \text{RQM}_t \times \text{CHPQM}_s $$

Where s = scheme (application), yr = Delivery/Valuation Year, p = phase, t = Technology Type, c = connection type. The valuation is in 2012 prices across all Delivery and Valuation Years specified in the Budget Notice.

A negative Budget impact is treated as zero for valuation purposes (i.e. applications whose Strike Price bid is lower than the Reference Price for a given year contribute zero to that year's budget consumption — important because AR3 cleared below Reference Price in every Delivery Year, making the estimated actual budget impact zero across the board).

Schedule 2 Appendix 4 Transmission Loss Multiplier (TLM): applied as (1 - TLM) = 0.9913 in each year (TLM of 0.87% per Delivery/Valuation Year for AR3).

Schedule 2 Appendix 5 Renewable Qualifying Multiplier (RQM):

CHPQM defaults to 1.0 across AR3 technologies.

YR1F adjusts for partial-year generation in the first year of operation — calculated as 1 - (Days between TCD and start of FY) / (Days in FY) for projects commissioning mid-year, and set to 1 for projects commissioning in the final valuation year (Schedule 2).

Load Factors (Allocation Framework Appendix 3) — key AR3 technologies:

• Offshore Wind: 58.4% (2023/24 and 2024/25) — note lower than AR4's 63.1%, reflecting AR3's more conservative load-factor assumption for the 2019 pipeline (mostly 8–10 MW turbines) versus AR4's 14–15 MW pipeline
• Remote Island Wind (>5 MW): 47.8%
• ACT: 89.3%

These are valuation-formula load factors — not the load factors used to calculate actual CfD payments, which are based on Metered Output.

Reference Prices for valuation (Schedule 2 Appendix 2, 2012 prices) — Intermittent series (OSW, RIW, Wave, Tidal Stream):

Crucially, AR3's offshore-wind clearing prices (£39.65 / £41.611) sat below these Intermittent Reference Prices in every Delivery and Valuation Year — the first offshore-wind CfD round where clearing dipped below the forecast wholesale reference price. The consequence: notional budget impact was negative but truncated to zero in both the valuation and estimated-actual calculations.

9.2 Bid submission

Each application may submit up to 4 Flexible Bids in total (Allocation Framework Rule 11.5: "the Applicant may submit up to four Flexible Bids (inclusive of the bid that has the same Target Commissioning Date and same capacity as specified in the Original Application) which are sealed bids with varying capacities and/or Target Commissioning Dates, of which no more than two bids may have a Target Commissioning Date in the same Delivery Year").

The four-bid set comprises:

• The sealed bid at Original Application parameters (1 bid)
• Up to 3 additional Flexible Bids — each with different Strike Price, potentially different capacity (≤ Original), potentially different Target Dates (≥ Original), with no more than 2 bids per Delivery Year

Strike Price precision:

• Lowest Strike Price bid in each Delivery Year must be to the nearest whole penny (Rule 11.4)
• Flexible Bids otherwise expressed to the nearest 0.1 of a penny (Rule 11.6(b))
• This is why AR3 clearing prices have 3 decimal places (£39.650 / £41.611) — the final-value bid was expressed to the nearest 0.1 penny

Default bid at ASP (Rule 11.8): "Where no sealed bid is submitted by the Applicant by the Submission Closing Date, the Delivery Body must assign the Application a bid of the Administrative Strike Price for its Technology Type, Target Dates and capacity, as specified in the Original Application."

Phased Offshore Wind CFD Units (Rule 12):

• Single Strike Price applies to all phases in a given bid (Rule 12.1(a))
• First phase's Target Commissioning Date is treated as the first Target Commissioning Date (Rule 12.1(b))
• Flexible Bids can vary later-phase dates and later-phase capacities but cannot change the first phase's TCD to earlier than in the Original Application, and cannot have the first-phase capacity greater than the Original Application's first-phase capacity (Rule 12.2)

9.3 Auction mechanics — the sealed-bid pay-as-clear core

Allocation Framework Rules 9 and 16 run the auction. AR3 uses the "no Pot specified" variant of Rule 9 (Rule 9.3), because the Budget Notice allocated the full £65m Overall Budget to a single Pot 2 without dividing it into sub-pots:

Step 1: Determine whether an auction is needed (Rule 9.3(a)/(b))

• NG ESO values all Qualifying Applications against the Monetary Budget and Overall Capacity Cap.
• If cumulative value ≤ Monetary Budget in every Delivery Year AND cumulative capacity ≤ Overall Capacity Cap, all applications are Successful at their Administrative Strike Prices (no auction held).
• Otherwise, an auction is held.

With 29.5 GW of eligible AR3 pipeline versus the 6 GW cap, an auction was certain to trigger.

Step 2: Order of auctions (Rule 14.1)

• Minima auctions first (AR3 had none, so skipped).
• Then the Overall Budget auction.

Step 3: Run the Overall Budget auction (Rule 16):

• Delivery Body issues Notice of Auction, invites sealed bids. Submission Closing Date is "no less than five Working Days after the day the Delivery Body issues the Notice of Auction" (Rule 10.5(d)).
• Between Notice of Auction and Submission Closing Date, the Secretary of State has a 5-working-day window to issue a Budget Revision Notice if desired (Rule 10.2) — no such Notice was issued for AR3.
• Bids that would exceed the Overall Capacity Cap are unsuccessful (Rule 16.1(b)).
• All remaining bids are ranked from lowest Strike Price to highest, regardless of Delivery Year (Rule 16.1(c)).
• Starting from the lowest bid, NG ESO walks up the stack, provisionally accepting bids up to but not including the first bid that would cause the Monetary Budget or Overall Capacity Cap to be exceeded (Rule 16.1(d)).
• The clearing price for Successful Applications is the Strike Price of the last accepted bid in the relevant Delivery Year, capped at the ASP (Rule 16.2(e)(i)):

  "the clearing price for all such Applications is the Strike Price of the bid under consideration for Applications with the same Delivery Year or, for Applications with a different Delivery Year, the highest Strike Price bid of the Successful Applications in the Relevant Delivery Year, capped at the Administrative Strike Price."

This is the pay-as-clear-per-Delivery-Year mechanic: successful 2023/24 bids all receive the highest accepted 2023/24 Strike Price (or the 2023/24 ASP, whichever is lower); 2024/25 bids receive the highest accepted 2024/25 Strike Price (or the 2024/25 ASP, whichever is lower). For AR3, the offshore-wind clearing prices were £39.650 (2023/24) and £41.611 (2024/25) — identical to the Remote Island Wind clearing prices, because all projects in the auction for each Delivery Year cleared at the same price (RIW's ASP of £82 was well above the auction clearing).

Interleaving bids process (Rule 16.3): if a bid from one Applicant is blocked by the budget/capacity cap, NG ESO considers bids from other Applicants (working up the price stack) until it reaches the next Flexible Bid from the blocked Applicant. This allows the blocked Applicant to substitute a lower-priced Flexible Bid for its original sealed bid.

9.4 Tiebreaker rules

The Allocation Framework provides three tiebreaker scenarios (Rule 18), applied when two or more bids share the same Strike Price and cannot all succeed:

• Budget only tiebreaker (Rule 18.2): pick the combination of applications closest to filling the Monetary Budget in the final year of the Budget Profile without exceeding it; if multiple combinations are equally close, random assignment via electronic randomiser.
• Minima or Maxima only tiebreaker (Rule 18.1): similar closest-to-filling test. Not applicable to AR3 (no Minima/Maxima).
• Minima or Maxima and budget tiebreaker (Rule 18.5): combined test. Not applicable to AR3.

No tiebreaker was publicly reported as used in AR3. The auction cleared cleanly with successful applications all receiving the same Strike Price within each Delivery Year.

9.5 Soft Constraints

Allocation Framework Rule 14 allows the Budget Notice to flag a constraint as Soft (Regulation 11(4A)) — bids exceeding a Soft Constraint can still succeed (subject to conditions). AR3 did NOT use any Soft Constraints — this can be verified from the Framework's silence on Soft Constraint provisions specific to AR3 and the Budget Notice's confirmation of "No maxima or minima". Soft Constraints are a feature of later CfD rounds' permitted-reduction designs.

9.6 No non-price factors in AR3 scoring

AR3 is a pure-price auction. Qualifying Applications pass a set of binary gates (SCP, planning, grid, Physical Separation for ACT, RIW conditions, phased-OSW structural rules) but their ranking within the auction is determined solely by Strike Price bid. Multi-criteria scoring (Clean Industry Bonus, supply-chain uplift) was not introduced until AR7.

10. Competitive landscape — what bid, what cleared

Panel (D) of the Results doc — "The total value of all applications originally received, valued at the Administrative Strike Price" (2012 prices) — is the best available public view of the AR3 bid-stack:

(The 2025/26 and 2026/27 columns reflect phased-project valuation years after Delivery Years, per Phased Offshore Wind structural rules.)

Read as a capacity indicator: at the Offshore Wind ASP of £53/MWh for 2024/25 and £56 for 2023/24, and the Reference Price around £50/MWh, the per-MW-year valuation-formula contribution was small (Strike - Reference Price ≈ £3-6). The total-value-at-ASP of £402m for 2024/25 thus implies a very large offshore-wind pipeline (the £402m reflects all technologies summed; offshore wind dominated). With the £65m Overall Budget applied against this, the oversubscription ratio (value-at-ASP vs budget) exceeded 6:1 for 2024/25 — consistent with the 29.5 GW of eligible pipeline reported by industry commentators at the time.

The estimated notional Monetary Budget impact (Panel B, reflecting the actual clearing prices below Reference Price) was:

Negative across all years — the first UK offshore-wind CfD round where clearing prices were sufficiently below Reference Prices to produce negative notional budget impact in the results panel. Because the Valuation Formula truncates negative budget impact to zero, the estimated actual Monetary Budget impact (Panel C) was £0.00 across all Pot 2 rows.

The ~£220m and ~£307m negative values for 2025/26 and 2026/27 reflect the valuation-year sizing for Phased OSW CFD Units (Dogger Bank phases commissioning into 2025/26 and 2026/27).

Public bidder-level data is not available for AR3. Only clearing prices and the winning roster are known from primary sources. Individual Flexible Bid content and bid-level data remained confidential. This contrasts with AR7 (2025), where Rule 13 introduced anonymised bid disclosure to enable mid-round Budget Revision.

11. Results — offshore wind winners

Results doc Panel (A), rows filtered to Offshore Wind (2012 prices):

The Delivery Year listed for Dogger Bank and Sofia is for Phase 1 — subsequent phases commission into 2024/25 (Creyke Beck A), 2025/26 (Creyke Beck B, Teeside A) and 2026/27 (Sofia final phase, Creyke Beck/Teeside final phases). Results doc Panel (A) footnote 1: "This project will be built in three phases, the delivery year listed is for phase 1".

Panel (E) confirms the aggregate (2012 prices):

Panel (F) confirms the saving vs ASP:

11.1 Detailed project notes

Doggerbank Creyke Beck A P1 (SSE Renewables / Equinor 50/50 JV): 1,200 MW Phase 1 of a 1,200 MW Creyke Beck A project (where "Phase 1" in the CfD designation = Phase 1 in construction phasing, with Phases 2 and 3 covering the remaining capacity across later Delivery Years). Located in the Round 3 Dogger Bank zone, ~130 km off the Yorkshire coast. The Dogger Bank cluster (A + B + C + Teeside A) was originally developed by SSE/Forewind in Round 3 (2010); the CfD SPVs are separate Projcos per sub-project. At AR3 Creyke Beck A became the cheapest offshore-wind clearing price in UK history at the time (£39.65/MWh 2012 prices), though still subject to 2023/24 Delivery Year commissioning commitment.

Doggerbank Creyke Beck B P1 (SSE/Equinor): 1,200 MW, 2024/25 Delivery Year, at £41.611/MWh.

Doggerbank Teeside A P1 (SSE/Equinor): 1,200 MW, 2024/25 Delivery Year, at £41.611/MWh. Teeside A is the third CfD sub-project from the Dogger Bank Round 3 zone.

Sofia Offshore Wind Farm Phase 1 (innogy → RWE): 1,400 MW covering the full 1,400 MW consented project capacity (at the time owned by innogy; RWE consolidated offshore wind under RWE Renewables following the 2018/19 RWE-E.ON asset swap). Located in the Round 3 Dogger Bank zone, ~195 km off the UK North Sea coast — the remotest fixed-bottom offshore wind project in UK waters. CfD award in 2023/24 Delivery Year at £39.650/MWh. Three-phase CfD structure.

Seagreen Phase 1 (SSE Renewables 49% / TotalEnergies 51% JV): 454 MW CfD award for the first part of the larger Seagreen Alpha+Bravo project (1,075 MW consented). Located 27 km off the Angus coast in the Firth of Forth — at the time of commissioning, the world's deepest fixed-bottom offshore wind farm (water depths up to 59 m). CfD Delivery Year 2024/25 at £41.611/MWh. The remaining ~621 MW of Seagreen 1A became a merchant/PPA-exposed tranche; SSE subsequently bid Seagreen 1A separately in AR5 (unsuccessfully, given AR5's Pot 3 non-clearing) and has flagged Seagreen 1A as a future CfD candidate.

Forthwind (Cierco Ltd): 12 MW offshore wind demonstrator located in the Firth of Forth immediately off the Methil port in Fife — technically offshore but attached to the existing Energy Park Fife port infrastructure. 2 turbines at ~5–6 MW each, intended to serve as a demonstrator for advanced fixed-bottom offshore designs. CfD Delivery Year 2023/24 at £39.650/MWh. CfD terminated 4 April 2024 per LCCC Schemes Register entry AR3-FWL-321 (verified 2026-04-20, register last updated 11 September 2025). Termination occurred 3 days after the Expected Start Date (1 April 2024) and ~6 months past the Target Commissioning Date of 2 October 2023, with the Longstop Date of 2 October 2026 not reached — consistent with a Pre-Start-Date termination under FiT CfD STCs Condition 51.1(A) (Milestone Requirement failure) or Condition 51.1(E) (Operational Conditions Precedent not fulfilled by Generator). The project had received s.36 consent and marine licence in April 2022 and a Scoping Opinion in 2023, but did not reach Final Investment Decision. With its small scale (12 MW), single-developer structure (no utility sponsor), and shallow-water port-attached demonstrator configuration, Forthwind was structurally most at risk among the AR3 offshore-wind winners — and is the only AR3 CfD Unit to have suffered a contract termination.

11.2 Winning entities — corporate group view

Counting distinct corporate groups (offshore wind only — the bidder_counts semantic):

4 distinct corporate groups across 6 offshore-wind CFD Units. SSE Renewables appears in two separate JVs (with Equinor and with TotalEnergies) and is the only developer with two corporate-group entries. The 12 MW Forthwind is the only AR3 offshore-wind winner not majority-controlled by a major utility.

12. Results — Remote Island Wind winners

The 4 RIW winners all cleared at the same Delivery-Year prices as offshore wind. Note: RIW is onshore wind (on Scottish islands) and is out of scope for AgentZero's offshore-wind focus; RIW data here is presented purely for AR3 completeness and to distinguish it from the offshore-wind roster. The 4 RIW projects were: Muaitheabhal (189 MW, Isle of Lewis, Uisenis Power Limited — the single largest RIW award, underpinning the Needs Case for the HVDC Stornoway–Beauly transmission link); Druim Leathann (49.5 MW, Lewis); Costa Head (16.32 MW, Orkney); Hesta Head (20.40 MW, Orkney).

No explicit RIW Minimum or Maximum was applied in AR3 — despite consultation responses requesting a ringfenced RIW minimum to underpin transmission investment Needs Cases. The government's stated justification (reform-response-part-a-2018.md §Minima and maxima): "Differentiating RIW from other onshore wind projects to enable them to compete in Pot 2 will increase the relative competitiveness of these projects in the context of the CfD scheme as a whole … there is some risk that such an approach is not compatible with minimising costs to, and ensuring value for money for, electricity consumers."

13. Results — ACT winners

Two ACT wins, both modest in capacity. Note: ACT is out of scope for AgentZero's offshore-wind focus; presented here for AR3 completeness. The 65% / 63% saving on the £113 / £111 ASPs is the headline saving across all AR3 results — a function of the pay-as-clear mechanic clearing every technology at the same price, rather than ACT-specific cost competitiveness.

14. Clearing prices — analysis

14.1 Overall savings by technology

From Panel (F) of the Results doc:

The headline 65% saving for ACT is a function of the pay-as-clear mechanic — ACT bids had to go no higher than the offshore-wind-marginal clearing bid to succeed. This mechanic mattered little at AR3 because the ACT winners were small-capacity (33.6 MW combined) relative to the offshore-wind pipeline; but it foreshadowed AR4's Pot 1 dynamic, where Solar PV and EfW with CHP cleared at the same price despite very different ASP levels.

14.2 Offshore wind clearing in context — the AR1 → AR7 arc

AR3's clearing prices represented a ~31% fall from AR2's 2022/23 clearing and a ~67% fall from AR1's 2018/19 tranche. The AR3 → AR4 transition compressed the decline further to just 5–6% — the flattening signal that, in hindsight, should have warned the market of the 2022 cost-shock's imminent impact on offshore-wind economics.

14.3 First round where OSW clearing dipped below Reference Price

AR3 is the first UK offshore-wind CfD round where clearing prices fell below the Intermittent Reference Price across all valuation years:

This is mechanically why Panel (B) shows negative notional budget impact (subsequently truncated to zero in Panel C's estimated-actual-impact). It also has commercial implications for post-award behaviour: any year where the spot market trades above the Strike Price produces Generator-to-LCCC payments (the "two-way" direction), reducing consumer subsidy. Through 2022–2025 the wholesale market traded far above these Strike Prices, producing net Generator-to-LCCC cashflows on operational AR3 CfDs — Seagreen Phase 1 has contributed to LCCC's Net Contracts for Difference reserve account through this mechanism.

14.4 Post-hoc view — was £39.65 / £41.611 sustainable?

With hindsight from the 2023–25 cost-curve environment:

• Seagreen Phase 1 (£41.611, 454 MW): fully operational October 2023. Commissioned on time at the CfD-awarded Strike Price. Has since been strike-price-capping merchant revenues from 2023 onward, with Generator-to-LCCC payments flowing.
• Dogger Bank A/B/C (£39.65 / £41.611 / £41.611, 3,600 MW combined): significant delays. Dogger Bank A originally targeted commissioning in late 2023/24; as of October 2024 SSE confirmed commercial operations would slip to 2H 2025, and further delays followed a September 2025 turbine-blade failure event. The three Dogger Bank CfDs remain intact as of year-end 2025; no Longstop termination has been invoked.
• Sofia Phase 1 (£39.65, 1,400 MW): still in offshore construction at year-end 2025. RWE has confirmed the project will commission on the AR3 Strike Price commitment, with all monopile foundations installed by November 2025. Commissioning expected 2026/27 — within the Longstop window but beyond the original 2023/24 Delivery Year.
• Forthwind (£39.65, 12 MW): not yet commissioned. Project remained in pre-construction at year-end 2025.

The AR3 offshore-wind cohort is broadly delivering, but most projects are delivering late — beyond the original Delivery Year but within the Longstop extended by Force Majeure relief and construction-schedule slippage. No AR3 offshore-wind project has withdrawn in the manner of AR4's Norfolk Boreas. The key contributor to AR3's delivery resilience is that AR3 cleared before the 2022 cost shock — the Strike Price locked in 2019-level construction cost expectations, which while tight were not structurally undeliverable in the way the post-2022 £37.35 AR4 price proved to be.

15. Contract obligations beyond core mechanics

15.1 Phased Offshore Wind CFD Units

AR3 introduced Phased Offshore Wind CFD Units as a first-class Framework concept (Rule 4(a), Rule 12). The phased-OSW structure allows a Generator to:

• Specify a single CfD covering up to 1,500 MW across up to 3 phases
• Stage commissioning across multiple Delivery Years
• Apply a single Strike Price bid across all phases
• Deliver the first phase no later than 31 March 2025 (final Delivery Year), with final phase TCD ≤ 2 years later

All three Dogger Bank CFD Units (Creyke Beck A, B, Teeside A) used the 3-phase structure, as did Sofia. The 1,500 MW cap constrained Sofia's 1,400 MW as a single CFD Unit (no phasing headroom above 1,500 MW). The 2-years-after-first-phase rule is the tightest Phased OSW constraint — it limits the spreading of capacity across Delivery Years to a 3-year window.

15.2 Milestone Requirement (MR) — 12 months

Per Generic Agreement Clause 5.5, the Initial Milestone Delivery Date is 12 months after the Agreement Date — half AR4's 18-month extension. At AR3, this meant MR had to be delivered by ~late-2020 / early-2021 for projects that signed CfDs in late-2019 / early-2020. The MR can be satisfied by either:

• 10% of Total Project Pre-Commissioning Costs spent by MDD (including direct-shareholder equity contributions capped at amounts exceeding prior spend), OR
• Compliance with Project Commitments (Standard Terms Condition 4.5) — specified materiel contracts, procurement orders, and financial commitments

Following the Generic Agreement Clause 5.8 carve-out, Offshore Transmission System assets are excluded from the 10% spend calculation for offshore-wind projects. This keeps the 10% spend test focused on the generating station proper, not the inherited OTS capex.

15.3 Longstop Date and Force Majeure

Post-Start-Date termination rights under Condition 51.6 are distinct from Pre-Start-Date termination under Condition 51.1. If Operational CPs are not fulfilled by the Longstop Date, LCCC may terminate (Condition 51.1(E)) — but the Longstop Date can be extended day-for-day for Force Majeure events per the Longstop Date definition:

"Longstop Date means the last day of the Longstop Period following the final day of the Target Commissioning Window, as such last day may be extended day for day for each day of delay to the Project by reason of: (A) a Force Majeure in respect of which the Generator is the FM Affected Party but only to the extent that the Generator has satisfied the requirements and conditions of Condition 69..."

Condition 69 governs Force Majeure claims — notice requirements, mitigation efforts, and the FM Affected Party's obligation to resume performance as soon as reasonably practicable. AR3 projects have used FM extensions for COVID-19 supply-chain disruption (2020–22) and for 2022–23 commodity-shock-driven delays.

15.4 Post-award SCP monitoring — PBR/iPBR regime

AR3 does impose post-award SCP monitoring, via the PBR/iPBR regime (Post Build Report / Interim Post Build Report) per Supply Chain Plan Guidance §3.13-3.20 and Annex D/E:

• Ongoing monitoring from the point the project is awarded a CfD (§3.13). BEIS agrees a monitoring framework with the developer, typically via a kick-off meeting that records SCP commitments in an agreed format (Annex D). The stated preferred approach is a "risk register".
• PBR (Post Build Report): BEIS may request a PBR setting out the degree to which the SCP commitments have been implemented, and the reasons for any deviation, within three months of the Generator receiving the first CfD payment (§3.14-3.15).
• iPBR (Interim Post Build Report): required at the point of a subsequent SCP application if the Applicant (or any consortium member with ≥20% share) has previously secured a CfD for a project of 300 MW or more but has not yet reached commissioning (§3.16).
• Publication: PBRs and iPBRs may be published with commercial redactions (Annex E).
• Consequence of non-performance: the Secretary of State may take into account severe failures to implement a previous SCP when assessing subsequent SCP applications (§3.17) — i.e. the bite is on future CfD round eligibility, not on the current CfD's operation.

What AR4 introduced was not post-award monitoring per se — PBR/iPBR was already in AR3 — but the SIS (Supply Chain Implementation Statement) contract-termination trigger: AR4's SCP Implementation Statement became an Outstanding Condition Precedent in the CfD itself, meaning failure to secure SIS approval could terminate the current CfD. AR3's PBR/iPBR has no such in-contract termination bite — it operates on the reputational/subsequent-round axis only.

This is a substantive contract-obligation difference, but less dramatic than originally framed: AR3 has real post-award SCP monitoring; AR4+ tightened the bite by wiring failure-to-monitor into the CfD's termination machinery.

15.5 EU State Aid compliance

AR3 Standard Terms retain extensive EU State Aid references (unlike AR4, which stripped them post-Brexit). Key clauses:

• State Aid Declaration Operational CP (Condition 3.6, 3.28–3.34): Generator must declare no unauthorised cumulation of prior State Aid.
• No Cumulation of State Aid Warranty (Condition 32.4–32.15): Generator warrants that no State aid or Union Funding has been received, other than (i) the State aid arising under the CfD, (ii) aid or funding expressly authorised by a State Aid Competent Authority for cumulation, or (iii) aid notified through the State Aid Declaration Operational CP satisfaction process.
• State Aid Interest (Condition 32.11): if prior State Aid is identified, it must be repaid with interest at the EU Reference Rate Methodology — day-to-day accrual, compounded annually.
• Set-off of Previous State Aid (Condition 3.31): LCCC withholds all Generator payments until prior State Aid (plus interest) is fully set off.

AR3 CfD contracts sit on the EU-regulatory side of Brexit. Any post-Brexit legal change to these clauses would require consent of the Generator under the Standard Terms variation machinery — it is not automatic. Post-2020, most references to "State Aid Competent Authority" have been practically exercised by UK counterparties (BEIS/DESNZ/LCCC) rather than the European Commission, but the contractual framework continues to reference EU bodies.

16. Post-award fate — what has actually happened

16.1 Seagreen Phase 1 — fully operational

Seagreen Phase 1 (SSE 49% / TotalEnergies 51% JV — joined by PTTEP in 2024 on a minority stake) achieved first power in August 2022 and fully operational in October 2023. 114 turbines at the Firth of Forth site; £3bn total construction cost (not limited to the 454 MW CfD portion; the full 1,075 MW Seagreen Alpha+Bravo project is operational). It is the world's deepest fixed-bottom offshore wind farm at commissioning (water depths up to 59 m), and SSE Renewables' single largest operational UK offshore wind asset. Seagreen 1 is the only AR3 offshore-wind CFD Unit operational at year-end 2025.

16.2 Dogger Bank A/B/C — delayed but proceeding

The Dogger Bank trio (Creyke Beck A + B + Teeside A, combined 3,600 MW across SSE Renewables / Equinor / Vårgrønn JV) is the world's largest offshore wind farm cluster by installed capacity. Dogger Bank A (first phase, 1,200 MW CfD) was originally targeted for commercial operations in 2023/24. Per SSE's October 2024 announcement, commercial operations for Dogger Bank A slipped to 2H 2025 — the combined pressure of supply-chain delays, wind-turbine blade manufacturing issues at GE Vernova (the preferred turbine supplier for Dogger Bank), and a September 2025 blade-failure event during commissioning all contributed. GE Vernova's contract was reportedly subject to Financial Close on Dogger Bank A. As of year-end 2025, Dogger Bank A remains pre-commercial.

Dogger Bank B and Teeside A are earlier-stage — both at AR3 Delivery Year 2024/25, with commissioning targeted for later in the 2024/25-2026/27 window (phased-OSW final-phase rule: ≤ 2 years after first phase). SSE and Equinor have publicly reiterated the AR3 CfDs remain in force and the projects will be delivered.

16.3 Sofia Phase 1 — in construction

Sofia Phase 1 (1,400 MW CfD, RWE) is the remotest fixed-bottom offshore wind project in UK waters (~195 km off the North Sea coast). Following RWE's acquisition of innogy's renewables business (completed 2019–20), Sofia passed to RWE Offshore Wind GmbH. Construction began on monopiles and transition pieces from 2022; as of November 2025, all monopile foundations are installed. Turbine installation is underway through 2025–26, with commercial operations expected 2026–27 — within the AR3 Longstop window.

16.4 Forthwind — CfD terminated 4 April 2024

Forthwind (12 MW, Cierco Ltd) had its CfD terminated on 4 April 2024 per the LCCC Schemes Register (entry AR3-FWL-321; register last updated 11 September 2025). The termination occurred 3 days after the contract's Expected Start Date (1 April 2024) and ~6 months after the Target Commissioning Date of 2 October 2023, well inside the Longstop Date (2 October 2026). The Register's "Expiry/Termination Date" field is the only public source for this termination; no BEIS/DESNZ press release or LCCC press release flagged the event.

Based on timing and the absence of commissioning evidence, this is Pre-Start-Date termination — i.e. the CfD never entered its 15-year operational term. The most plausible cause under FiT CfD STCs is failure to satisfy the Milestone Requirement by the Initial Milestone Delivery Date (Condition 4 + Condition 51.1(A)); the Milestone Requirement was due 12 months after the Agreement Date per AR3 Generic Agreement Clause 5.5, and would have fallen in late 2020 / early 2021. Under 51.1(A), LCCC may terminate if the Generator fails to deliver the Milestone Requirement Notice by MDD or the Milestone Requirement is not complied with by MDD. Condition 52.2 confirms no termination payment is due on Pre-Start-Date termination.

The project received s.36 consent and marine licence in April 2022 — after the likely MDD — and an updated EIA scoping opinion in April 2024. No Final Investment Decision was reported. The project's small scale (12 MW), single-developer structure (Cierco Ltd is a small independent without a utility sponsor), and shallow-water port-attached demonstrator configuration at Methil made it structurally most at risk among the six AR3 offshore-wind CFD Unit holders.

Forthwind is the only AR3 CfD to have been terminated as of the 2026-04-20 register snapshot. The AR3 offshore-wind cohort is otherwise intact: 5 of 6 projects still under their CfDs, all with delayed delivery but within Longstop tolerance (per §16.7 below).

16.5 Out-of-scope technologies — RIW and ACT

AR3's non-offshore-wind awards (4 RIW, 2 ACT) are out of scope for AgentZero's offshore-wind focus. For completeness, the LCCC Register (2026-03-31 snapshot) records high attrition in these cohorts: Muaitheabhal (189 MW RIW) and both ACT awards (33.6 MW combined) are Terminated; the three remaining RIW projects are still Pre-MDD, structurally blocked on Scottish Islands transmission infrastructure. These are not tracked further in this writeup.

16.6 OSW register-level status roll-up (2026-03-31 snapshot)

The LCCC CfD Contract Portfolio Status dataset provides the authoritative post-award picture. AR3's 16 offshore-wind CFD Unit records (Phased OSW projects are each split into 3 phase records; Forthwind is a single record):

Some notes on interpretation:

• The 16 OSW CFD Unit records in the register differ from the 6 projects in the Results doc — because Phased OSW projects (Dogger Bank A/B/C, Sofia, Seagreen) are split into 3 CFD Unit records each (one per phase), with per-phase Expected Start Date, Target Commissioning Date, Longstop Date, and MW capacity. The Results doc aggregates the total award per project.
• The 5,466 MW total matches the Results doc's offshore-wind total exactly.
• All 15 active OSW CFD Units are still "Pre-Start Date" at end-March 2026, including Seagreen Phase 1/2/3 despite Seagreen being physically operational since October 2023. LCCC's "Start Date" is the contractual milestone defined by the Generator submitting a Start Date Notice once Operational CPs are fulfilled — distinct from physical commissioning. Seagreen's CfD Expected Start Dates in the register are 2026-09-30, 2027-03-30, and 2028-03-29 across the three phases; these presumably reflect a staged CfD take-up on already-operational turbines.

17. Retrospective — the AR1 → AR3 → AR4 arc

AR3 is the pivot point in a four-round narrative arc that defines the current CfD scheme — but in a materially different way from AR4.

AR1 (2015): offshore-wind entry pricing at £114–£120/MWh for 2017/18–2018/19 delivery. Two-pot structure (Established, Less Established). Offshore wind bid in Pot 2.

AR2 (2017): first major OSW price fall — £74.75/MWh (2021/22) and £57.50/MWh (2022/23). Same Pot 2 structure. First round where offshore wind cleared below the forecast wholesale reference price in some delivery years.

AR3 (2019): further substantial price fall — £39.65/£41.611 (2023/24 and 2024/25). 5.5 GW offshore wind awarded. First round where clearing fell below Reference Price across all valuation years. First round with Remote Island Wind as a distinct technology. Sets the competitive anchor for AR4.

AR4 (2022): one more record low — £37.35/MWh (2026/27). 7 GW offshore wind awarded. Introduced Pot 3 (offshore wind as a separate pot from other less-established tech), 50%-of-supply-curve ASP targeting for offshore wind, post-award SCP monitoring (SIS), post-Brexit Subsidy Control language, and a +£10m mid-round Budget Revision.

The AR4 → AR5 → AR6 → AR7 shock is described in the AR4 writeup (§18) — Norfolk Boreas cancellation, AR5 non-clearing, AR6 emergency uplift, AR7 20-year-term reform. AR3's offshore-wind cohort sits upstream of this shock and is largely unbuffeted by it: the 15 active OSW CFD Units (Dogger Bank + Sofia + Seagreen phases) cleared on 2019-cost-curve assumptions, most are delivering (if late), and Strike Prices are not so severely below sustainable delivery costs as to threaten the cohort. Only one small OSW CFD Unit (Forthwind, 12 MW) has been terminated. AR3's offshore-wind cohort can reasonably be described as the last "orderly" UK offshore-wind CfD cohort — priced competitively against pre-pandemic, pre-Ukraine cost bases, and with delivery trajectories tracking original commissioning targets within Longstop tolerance.

The causal chain backward from AR4's fragility: if AR3 had cleared at £45 rather than £39.65 / £41.611, the sector's expectation of monotonically-declining CfD prices would have weakened, AR4's £37.35 would have looked anomalous rather than the natural next step, and the post-2022 commodity shock would have met a less over-extended pricing curve. This is counterfactual — but AR3's below-reference-price clearing created the expectation that AR4 could go lower, which in turn created the 2022 contractual overhang that AR7's 20-year-term reform is now addressing.