The Crown Estate Offshore Wind Leasing Round 4

UK — The Crown Estate Offshore Wind Leasing Round 4 (2019-2022)

1. At a glance


Auction type	Seabed leasing — multi-round daily sealed-bid option-fee auction; winners commit to annual option fee payments in £/MW/year until lease exercise
Awarding body	The Crown Estate (seabed lessor for England, Wales and Northern Ireland — distinct from Crown Estate Scotland which runs ScotWind)
Site model	Pre-investigated Bidding Areas — TCE spatially refined the seabed opportunity into 4 Bidding Areas (Dogger Bank, Eastern Regions, South East, Northern Wales & Irish Sea) totalling up to 8.5 GW across multiple candidate sites
Pre-qualification	PQQ (Pre-Qualification Questionnaire) — technical experience, financial standing, legal compliance
ITT Stage 1	Project definition envelope + technical criteria (pass/fail) + five-year development expenditure forecast (rolling 18-month look-forward)
ITT Stage 2	Multi-cycle daily sealed-bid process — each Bidder submits one Option Fee Bid per Bidding Cycle for One Eligible Project at the then-current cycle, bids are sealed, highest-priced bid that satisfies cascading eligibility caps wins the cycle
Reserve price	£250/MW/year minimum — all Option Fee Bids must be above this reserve price (IM §7.3)
Award criterion	Highest £/MW/year Option Fee Bid above reserve, subject to eligibility caps
Explicit tiebreak chain	On equal £/MW/year bids: (1) total option fee (£/MW/year × project MW), (2) option fee density (total option fee ÷ km²), (3) Best and Final Offer (BAFO) process with a one-day delay and repeated BAFOs until a unique winner emerges (IM §7.3)
Target capacity	At least 7 GW across at least three Bidding Areas, up to a maximum of 8.5 GW. If 7 GW is reached with projects only in two Bidding Areas, at least one further Bidding Cycle is run in a third Bidding Area
Tender launched	October 2019 (PQQ)
ITT Stage 2 bidding	Was scheduled for September 2020 but was delayed; Bidding Cycles ran in early 2021
Preferred Bidders announced	8 February 2021 — 6 projects across 4 Bidding Areas, totalling 7.98 GW
Agreements for Lease signed	January 2023 — after Plan-Level Habitats Regulations Assessment
Successful Bidders (6 projects, 7.98 GW)	RWE Renewables (2 Dogger Bank projects, 1,500 MW each, £76,203 + £88,900/MW/yr); Green Investment Group–Total (1 Eastern Regions project, 1,500 MW, £83,049/MW/yr); Consortium of EnBW and BP (2 North Wales & Irish Sea projects, 1,500 + 1,500 MW, £154,000/MW/yr each — the highest clearing price); Offshore Wind Limited (Cobra Instalaciones y Servicios + Flotation Energy JV) (1 North Wales & Irish Sea project, 480 MW, £93,233/MW/yr)
Award deposits paid	£114.3m (RWE 1) + £133.4m (RWE 2) + £124.6m (GIG-Total) + £231.0m (EnBW/BP 1) + £44.8m (OWL) + £231.0m (EnBW/BP 2) = ~£879m in aggregate option-fee deposits (excluding VAT)
Option Fee period (AfL)	Minimum 3 years payment commitment, up to 10 years maximum, annual instalments CPI-indexed. Developer has a break right after the second anniversary of the AfL on payment of a break fee equal to one year's option-fee instalment. The Option Fee Deposit paid at Preferred Bidder Letter equals one year's Option Fee Bid × Project Capacity (verified: 1,500 MW × £76,203/MW/year = £114,304,500, matching the published RWE deposit) and converts to the first year's payment on AfL entry. A separate letter-of-credit AfL security covers £500,000 + two further years of option-fee payments initially, reducing to £500,000 + one further year after year 1
Lease term (post-exercise)	60 years Wind Farm Lease with a 25-year break clause after construction completion; rolling three-year break thereafter
Grid connection model	Developer-built, divested to OFTO via Ofgem tender post-commissioning (same as AR6 projects)
Downstream pairing	R4 winners must also compete in subsequent CfD Allocation Rounds (AR5/AR6/AR7+) to secure revenue; commercially essential, not legally required to keep the lease
Headline significance	First UK offshore wind leasing round in nearly a decade; established option-fee auctions as the UK seabed-leasing revenue model; set the reference price for Crown Estate R5 option fees

Sources (3 primary, all mirrored to local corpus): information-memorandum (60 pages — published March 2019), tender-outcome-dashboard (1 page — results published after award), guide-to-offshore-wind-leasing-round-4 (published April 2022 as post-award retrospective).

2. What makes Round 4 structurally different from AR6, Thor, DE N-12.1, and US NY Bight

This is the point of running R4 as a fifth pilot — it differs from all four earlier cases on several axes simultaneously.

Dimension	UK AR6	DK Thor	DE N-12.1	US NY Bight	UK CE R4
Scope	Offtake only	Combined concession + offtake	Seabed right-to-apply + concession fee	Federal lease only	Seabed lease + AfL option period + wind farm lease + grid-build divest-to-OFTO obligation
Auction format	Sealed bid pay-as-clear	Sealed single bid + lottery fallback	Sealed → dynamic ascending	Ascending multi-round English, 6 leases parallel	Multi-round DAILY SEALED bid — one project awarded per daily Bidding Cycle, Bidding Cycles continue until ≥7 GW awarded or 8.5 GW reached
Bid variable	£/MWh strike price	DKK øre/kWh CfD premium (price per kWh)	€ cents/kWh subsidy → €/MW concession fee	$ bonus bid per lease (lump sum)	£/MW/year ANNUAL option fee — a recurring annuity payable throughout the Agreement for Lease period, NOT an upfront lump sum
Price direction	Lower wins	Lower wins	Lower wins (stage 1) → higher wins (stage 2)	Higher wins	Higher wins
Multi-winner structure	131 successful applicants / 130 signed	1 winner	1 winner per site (4 sites in 2023 round = 4 parallel auctions)	6 winners, 1 per lease area	6 winners across 4 Bidding Areas
Eligibility caps	Pot budget caps + per-technology Maxima	Single-site, none	Site-specific prequalification	$100/acre minimum + one-lease-per-bidder + BOEM qualification	Cascading caps per cycle: cash availability + 3 GW Corporate Group Capacity Limit + 3-projects cap per Corporate Group + 3.5 GW Bidding Area cap + 5 km geometric overlap with previously-awarded projects
Bidding Cycle structure	One-shot sealed bid	Single sealed bid + negotiation + final bid	Sealed bid + 65 ascending rounds	64 ascending rounds over 3 days	Daily Bidding Cycles — sealed bids submitted per cycle, evaluated at cycle close, winner declared and announced, next cycle begins the following day, process runs until capacity target is met
Tiebreak	Closest envelope fit then random	Highest capacity → physical lottery	Lottery on equal intra-round bids	Maximise total bid value then pseudorandom	Cascading waterfall — if highest bid fails eligibility cap test, next-highest bid considered; no explicit tiebreak on equal prices stated in the Information Memorandum
Payment structure	15-year CfD settlements (monetary to developer)	20-year CfD + caps + operation licence 30 yrs + concessionaire→state	10% lump + 90% 20-yr tail to TSOs + statutory zero-value market premium	One-time bonus bid + annual rent + 2% operating fee	Annual option fee during AfL period (up to 10 years) — Option Fee Deposit paid at Preferred Bidder Letter execution = ~1.5× annual option fee for the bid project; then annual option fee payments throughout the AfL period (CPI-indexed); on exercise of the AfL option, the project transitions to a Wind Farm Lease with rent calculated differently
Indexation of option fee	CPI from 2012	None (bid price), net price index (caps)	None (zero-valued, nothing to index)	None (one-time bonus bid)	CPI-indexed — both the annual option fee and the base rent under the post-exercise lease are CPI-indexed
Revenue mechanism (Axis 6)	CfD 2-way with LCCC	CfD 2-way with caps	Statutory feed-in premium at zero	Null (no federal revenue-support)	Null — R4 confers no revenue-support instrument; winners must compete separately in CfD Allocation Rounds (or PPA markets) for revenue. Like US NY Bight, R4 is a pure leasing auction where revenue depends on a downstream paired auction.
Prize consideration	None (no fee to win)	Bidirectional CfD caps (DKK 6.5bn state / DKK 2.8bn concessionaire)	Four-recipient €3.75bn split per WindSeeG §23(1a)	One-time bonus bid + rent + operating fee	Annual option fee × Project MW × up to 10 years (e.g. EnBW/BP at £154k/MW × 1,500 MW = £231m/year for up to 10 years = up to ~£2.3bn nominal per 1.5 GW project; RWE at £76,203/MW × 1,500 MW = ~£114m/year for up to 10 years ≈ up to ~£1.14bn nominal per 1.5 GW project). Plus CPI indexation. Plus post-exercise lease rents.
Paired auction for revenue	None — AR6 awards the revenue contract directly	None — Thor awards the CfD directly	None — N-12.1 confers the statutory market premium directly (even though zero-valued)	NYSERDA/NJ BPU OREC solicitations (commercial dependency, not legal prerequisite)	UK CfD Allocation Rounds (AR5/AR6/AR7/AR8+) — R4 winners must compete in a subsequent CfD round to secure revenue. Commercial dependency, not legal prerequisite — the R4 lease is legally complete without a CfD win.

3. The Round 4 auction mechanism in detail

3.1 The multi-cycle daily sealed-bid process

R4's ITT Stage 2 is unlike any other auction in the pilot set. Per information-memorandum §7 and the Tender process overview:

A multi-cycle bidding process, using option fees bid by Eligible Bidders to determine award. One project will be awarded per daily Bidding Cycle, with Bidding Cycles continuing until the 7 GW has been awarded or exceeded (up to 8.5 GW).

Each day during the Bidding Cycles window, the Crown Estate runs one Bidding Cycle:

Each Bidder is invited to submit a single Option Fee Bid for one Eligible Project.
Bids are sealed — Bidders do not see each other's bids before submission.
At the close of the Bidding Cycle, bids are evaluated in descending order of price.
The highest-priced bid is tested against the cascading eligibility caps (see §3.2). If it passes, that Bidder wins the cycle and is required to pay an Option Fee Deposit + enter into a Preferred Bidder Letter.
If the highest-priced bid fails any cap test, the next-highest bid is tested against the caps, and so on until a qualifying bid is found or all bids are exhausted for that cycle.
After one project is awarded, the remaining Eligible Projects proceed to the next Bidding Cycle the following day.
Bidding Cycles continue until the aggregate awarded capacity reaches at least 7 GW (with a hard maximum of 8.5 GW).

This produces one winner per day rather than a single-moment-of-truth sealed bid (AR6) or a simultaneous ascending auction (NY Bight). The process self-paces based on how many projects meet the capacity threshold.

3.2 The cascading eligibility caps

Per the information-memorandum capacity-limits decision tree (a primary-source Mermaid flowchart in the IM), each bid at each cycle is tested against these caps in order:

Cash availability — does the bid exceed the Bidder's declared cash availability from ITT Stage 1? (If yes → reject, consider next-highest bid.)
Corporate Group Capacity Limit — 3 GW — would this award take the Bidder's total awarded capacity across all R4 projects above 3 GW? (If yes → reject.)
Corporate Group Capacity Limit — 3 projects — would this award take the Bidder above 3 projects in total? (If yes → reject.)
Bidding Area Cap — 3.5 GW per Bidding Area — would this award take the aggregate awarded capacity in the Bidding Area above 3.5 GW? (If yes → reject.)
5 km geometric overlap — does the project overlap within 5 km of a previously-awarded Preferred Project? (If yes → require consent from the earlier Preferred Bidder, subject to conditions.)

A bid that passes all caps wins the cycle. A bid that fails any cap falls through to the next-highest bid, which is re-tested against all caps. This mechanism enforces portfolio diversification without prohibiting consortia from winning multiple projects — they can still win up to 3 projects and 3 GW in total.

3.3 Why the option-fee annuity, not an upfront bonus bid

Per the information-memorandum Operation section (page 37+) and the Agreement for Lease terms:

Agreement for Lease (AfL) Option for 10 years maximum Lease 60 years with a 25 year break clause

The Option Fee Bid is the annual rate the Bidder commits to pay (in £/MW/year). This annuity is payable throughout the AfL period, which can last up to 10 years before the developer exercises the option to transition from the AfL to the Wind Farm Lease. During the AfL period, the developer is working through consenting, site investigations, FID, supply chain contracts, and construction. The option fee is their rent-like commitment during that period.

Contrast with US NY Bight: NY Bight winners paid a one-time upfront bonus bid at lease execution (~3 months post-auction), with annual rent of ~$3/acre and an operating fee during operations. R4's mechanism is an annual option fee annuity during development, then separate lease rents during operation, with no one-time bonus payment at award. The Option Fee Deposit paid at Preferred Bidder Letter execution (~1.5× the annual option fee) is a security deposit against the obligation, not a bonus bid.

Contrast with Thor's CfD caps: Thor's DKK 2.8bn concessionaire-pays-state cap is a bounded aggregate-payment cap tied to the revenue mechanism. R4's option fee is a rent-like fixed-rate annuity — there is no cap because the payment rate is fixed at the winning bid × project MW × CPI.

4. The six Round 4 winners

Per tender-outcome-dashboard:

#	Bidding Area	Capacity	Area (km²)	Successful Bidder	Option Fee Deposit (£ excl. VAT)	Option Fee Bid (£/MW/year)
1	1 (Dogger Bank)	1,500 MW	494.89	RWE Renewables	£114,304,500	£76,203
2	1 (Dogger Bank)	1,500 MW	493.58	RWE Renewables	£133,350,000	£88,900
3	2 (Eastern Regions)	1,500 MW	499.62	Green Investment Group – Total	£124,573,500	£83,049
4	4 (North Wales & Irish Sea)	1,500 MW	497.48	Consortium of EnBW and BP	£231,000,000	£154,000
5	4 (North Wales & Irish Sea)	480 MW	125.64	Offshore Wind Limited, a joint venture between Cobra Instalaciones y Servicios, SA and Flotation Energy plc	£44,751,840	£93,233
6	4 (North Wales & Irish Sea)	1,500 MW	322.21	Consortium of EnBW and BP	£231,000,000	£154,000
Total	4 Bidding Areas	7,980 MW	2,433 km²	4 corporate groups, 6 projects	£878,979,840	(range: £76k-£154k/MW/yr)

Corporate group attribution and caps reached

RWE Renewables: 2 projects × 1,500 MW = 3,000 MW (at the 3 GW Corporate Group cap). RWE could not win any further R4 projects.
EnBW + BP consortium: 2 projects × 1,500 MW = 3,000 MW (at the 3 GW Corporate Group cap). Also at 2 projects (under the 3-project cap). Highest option fee bid in the round at £154,000/MW/year — Bidding Area 4 (the North Wales & Irish Sea region) was the most competitively contested.
Green Investment Group + TotalEnergies consortium: 1 project × 1,500 MW = 1,500 MW. Headroom for more projects, but apparently did not win further cycles.
Offshore Wind Limited (Cobra + Flotation Energy JV): 1 project × 480 MW = 480 MW. This is the only non-1,500-MW project in the round — a smaller site within Bidding Area 4 that the larger consortia evidently passed on.

Bidding Area allocation

Bidding Area 1 (Dogger Bank region): 2 projects, 3,000 MW (within the 3.5 GW Bidding Area cap — headroom of 500 MW left unused)
Bidding Area 2 (Southern North Sea, The Wash, East Anglia): 1 project, 1,500 MW
Bidding Area 3 (South East region): 0 projects, 0 MW awarded — this Bidding Area received no winning bids, suggesting Eligible Projects there either did not attract competitive bids or were outpriced by projects in other areas
Bidding Area 4 (North Wales, Irish Sea, northern Anglesey): 3 projects, 3,480 MW (essentially at the 3.5 GW Bidding Area cap)
Total across all Bidding Areas: 7,980 MW — comfortably above the 7 GW target, below the 8.5 GW maximum

5. The price signal and subsequent events

Dramatic price spread: the range of winning option fee bids (£76,203 – £154,000 per MW per year) is roughly 2× wide across projects. EnBW+BP's £154,000/MW/year bids in the Irish Sea area were the clear outlier — the sum total over a 10-year AfL period for a single 1.5 GW project at £154,000/MW/year = £2.31bn nominal (ignoring CPI indexation), compared to RWE's lowest bid at £76,203/MW/year = £1.14bn nominal. The Irish Sea projects' option fees were therefore roughly double the Dogger Bank projects' — a cross-region price differential whose drivers include project economics (Irish Sea may have had more favourable wind/grid conditions), corporate strategy (BP+EnBW's push to establish a UK offshore wind position), and scarcity in Bidding Area 4 (3 winning projects in one area, bidding competitively).

Aggregate upfront commitment: the aggregate Option Fee Deposits paid at Preferred Bidder Letter execution totalled £878.98m (excluding VAT). This is significant up-front cash for four corporate groups to commit years before construction start. Over the 10-year AfL period, the aggregate nominal option fee payments sum to approximately £8.8bn (excluding CPI indexation), making R4 the largest revenue-to-state offshore wind seabed leasing outcome in UK history up to that point.

Comparison to NY Bight: US NY Bight's total bonus bids of $4.37bn over 6 leases (one-time upfront) vs R4's ~£8.8bn nominal over 10 years (annuity). In real terms (accounting for the time value of money), R4's present value is significantly less than the $4.37bn headline figure from NY Bight, but the nominal aggregate is 2×. The R4 mechanism shifts cash flow from upfront to spread across the development period, making it more financeable for developers but more politically ambiguous (payments span two parliamentary cycles rather than landing in one year).

Post-award downstream pairing: all 6 R4 projects need to secure a CfD to monetise their output. As of the AR7 results publication on 14 January 2026, two R4 projects have already won CfDs: Dogger Bank South East CfD Unit A and Dogger Bank South West CfD Unit A, both RWE (corresponding to the two RWE R4 wins in Bidding Area 1 / Dogger Bank). Further R4 winners are expected to compete in AR8 and beyond.

On the post-award fate front more broadly, the Crown Estate announced on 29 January 2026 that Morecambe and Mona entered Wind Farm Lease from AfL status — the first two R4 projects to cross that transition point. In the same release, the Crown Estate noted it was reviewing options for Morgan after the developers indicated they were not looking to continue with that project. So R4's six projects are already showing divergent trajectories: 2 at Wind Farm Lease (Morecambe, Mona), 2 with AR7 CfDs secured (Dogger Bank South East/West, both RWE), 1 discontinued (Morgan), and 1 still progressing through the AfL development period.

Hybrid projects and innovation discounts: R4 offered a 50% rental discount on up to 10% of Project Capacity for innovative technologies. The R4 Information Memorandum explicitly permits hybrid projects integrating offshore wind with interconnectors or other energy technologies — a design feature that overlaps with AgentZero's interconnector pilot focus.

6. Regulatory frame (brief)

Awarding body: The Crown Estate — the seabed lessor for England, Wales, and Northern Ireland waters, acting under the Crown Estate Act 1961 as amended. Crown Estate Scotland runs the separate ScotWind round.
Authorisation: The Crown Estate's own leasing powers. R4 is NOT a statutory auction under a specific Act in the way AR6 is under the Energy Act 2013 — it is a commercial procurement process run by a public body under general procurement principles.
Downstream regulator: Ofgem (for grid connection / OFTO tender), DESNZ (for subsequent CfD auctions), Planning Inspectorate (for DCO), Marine Management Organisation and Natural Resources Wales (for marine licences).
HRA: Plan-Level Habitats Regulations Assessment runs in parallel with the tender; successful bids are conditional on HRA conformity. AfLs were signed in January 2023 after HRA conclusion.
ITT process stages: PQQ → ITT Stage 1 (pass/fail technical + financial) → ITT Stage 2 (competitive option-fee bidding) → Preferred Bidder Letter → Plan-Level HRA → Agreement for Lease → (10-year development period) → Wind Farm Lease.

8. Schema implications — what R4 adds beyond AR6/Thor/DE/NYB

Preliminary observations (to be sharpened in the validation summary and potentially drive v0.6 sketch revisions):

Annual option fee annuity structure — R4's prize_consideration is neither a one-time bonus bid (US NY Bight), nor a hypothecated split (DE N-12.1), nor a bidirectional CfD cap (Thor). It's a recurring annuity in £/MW/year payable over a development period with a fixed maximum duration, CPI-indexed, then transitioning to a different post-exercise rent calculation. v0.5's prize_consideration sub-structure needs an annuity_rate_per_capacity_per_year component type plus a duration_mechanism that can express "X years from AfL signing" or "until AfL option exercise".
Daily sealed Bidding Cycles — R4's auction format is neither one-shot sealed (AR6/Thor initial tender), sealed-then-dynamic (DE N-12.1), nor ascending multi-round (NYB). It's a daily-repeated sealed cycle with cascading eligibility caps, each cycle awarding at most one project, running until aggregate capacity hits a target. This stresses Axis 2's bid_format in a way that v0.5 doesn't fully model — the submission_phases and selection_envelope sub-structures together can probably express R4, but the daily-cycle cadence is a new cadence-level concept.
Cascading eligibility caps as a first-class mechanism — R4's 5-step decision tree (cash → 3 GW → 3 projects → 3.5 GW area → 5 km overlap) is not a tiebreak (Axis 5) — it's applied to the highest-priced bid to determine whether it's eligible at all. This is a pre-award filter on the winning bid, distinct from qualification gates (Axis 3, applied before bidding) and distinct from the selection envelope (Axis 2, monetary/capacity envelopes). The schema may need a new sub-structure on Axis 2 for eligibility-cap cascades that gate winners at the moment of award.
First Axis 4 + Axis 6 pure-lease case with recurring annuity — R4 is the second pilot (after NYB) where Axis 6 is cleanly null and the monetary flow is entirely on Axis 1's prize_consideration. But unlike NYB's one-time bonus, R4's flow is a multi-year annuity. The two cases together confirm that prize_consideration must support both lump-sum and annuity schedules cleanly.
Downstream CfD pairing is commercial, not legal — confirms v0.4 R9 (legal vs commercial dependency split). R4 winners technically hold their lease indefinitely without winning a CfD; they simply have no revenue until they do. AgentZero's cross-auction analytics should model the R4 → AR(N) pipeline as a paired_auctions link with required_for_commercial_viability=true, required_for_project_completion=false.