Gülermak Secures £35M NORD/LB Loan for 48 MW Essex Solar Farm

A Turkish-origin renewables developer that only came into existence in 2023 has closed its first UK project financing, locking in £35 million from a German state-owned lender to build a 48 MW solar farm in Essex.

Gülermak Renewables secured the construction financing from NORD/LB to fund its Hanningfield photovoltaic project, the company confirmed on 25 September 2026. The deal lands in a market where the UK’s Allocation Round 7 (AR7) has just delivered 4.9 GW of new solar capacity across 157 projects, creating a well-worn template for bankable sub-100 MW solar that new entrants can now follow.

That template is the story here. Understanding how the Contract for Difference (CfD) and route-to-market power purchase agreement (PPA) layers interlock to make a construction loan possible is what turns Hanningfield from a small deal announcement into a readable signal about the state of UK solar project finance, and about how far the door has opened for international capital.

A £35 million debut: how the Hanningfield deal was structured

The financing rests on three contractual layers, each closing a gap the others leave open. Strip any one away and the construction loan does not happen.

Here are the core parameters of the deal:

• Capacity: approximately 48 MW ground-mounted solar in Hanningfield, Essex (reported as 48-49.5 MW / MWp)
• Financing: £35 million senior construction facility from NORD/LB
• CfD term: 20 years under AR7, covering 100% of electricity generated
• Route-to-market PPA: 10 years with ElectroRoute
• Commercial operations target: August 2027
• Developer/borrower: Gülermak Renewables, established 2023

The revenue foundation is the 20-year AR7 CfD. A Contract for Difference guarantees the developer a fixed price for every unit of electricity generated, topping up payments when wholesale prices fall below the strike price. That price certainty is the floor that makes non-recourse debt possible, meaning debt secured against the project’s cash flows rather than the parent company’s balance sheet.

The CfD structure that underpins Hanningfield exists within a broader UK electricity pricing reform agenda, where the government is actively pursuing mechanisms to reduce the link between gas market volatility and the wholesale power prices that determine CfD top-up payments.

But a CfD alone does not get a deal financed. It sets the price; it does not manage the physics of selling power into the grid.

That is the job of the 10-year ElectroRoute PPA. It handles forecasting, balancing, and intraday trading, the operational functions the CfD leaves untouched. For NORD/LB, this second layer is what closes the operational risk gap. Lenders will not proceed on price certainty alone.

Rounding out the structure is a familiar cast of UK advisers, and their presence matters as much as the capital. The table below sets out who did what.

The read for you is straightforward: securing a solar construction loan in the UK today is not simply a matter of holding a government contract. It requires a stacked structure covering trading and operational risk, and lenders will not move without it.

What AR7’s record solar round made possible for new UK entrants

Hanningfield did not happen in isolation. It is a predictable output of the pipeline AR7 created earlier this year.

The Department for Energy Security and Net Zero (DESNZ) confirmed the AR7 results on 10 February 2026, and the scale was the headline.

The AR7 allocation round results, confirmed by DESNZ on 10 February 2026, recorded 4.9 GW of solar PV across 157 projects, the largest volume of solar capacity ever secured in a single UK CfD auction cycle.

AR7’s Pot 1 awarded 6.2 GW across 189 projects, of which solar accounted for 4.9 GW over 157 projects, the largest volume of solar ever secured in a UK CfD auction.

The key metrics worth holding onto:

• 6.2 GW total Pot 1 capacity across 189 projects
• 4.9 GW of solar PV across 157 projects
• Solar strike price of £65.23/MWh (2024 prices)
• Approximately 13% below the auction ceiling price

That volume did something more useful than set a record. It standardised the financing playbook. When 157 solar projects clear a single auction on near-identical CfD terms, lenders, law firms, and technical advisers all learn the same structure, price it the same way, and repeat it. The template becomes replicable.

The result is that a first-time UK developer no longer has to invent a bankable structure. It can adopt one that the market has already validated dozens of times over.

RWE offers the scale comparison. The established international developer took five solar awards totalling 215 MW in the same AR7 round, expanding an existing UK portfolio. Gülermak, by contrast, financed a single 48 MW first project using the same underlying framework.

The gap in scale is large. The gap in structure is not. That is the point.

For anyone weighing whether the UK remains an attractive destination for international solar capital, the AR7 figures suggest the enabling conditions are structural and repeatable, not a one-off window that happened to catch Gülermak at the right moment.

Financing risks the deal does not resolve

The bankable template is real, but it does not eliminate risk. It relocates it. Three tensions sit beneath the announcement.

• Strike price tightness leaving little room for cost overruns
• A revenue cap that limits upside across the 20-year term
• Grid connection and curtailment pressure across the wider pipeline

Strike price and revenue ceiling

The AR7 solar strike price of £65.23/MWh (2024 prices) cleared roughly 13% below the auction ceiling. That margin is a proxy for how hard developers competed, and it signals how little headroom is left.

For a developer new to UK project delivery, that tightness concentrates the pressure squarely on execution. There is limited slack to absorb construction cost inflation, supply chain delays, or contractor disputes before equity returns start to compress.

The strike price tightness visible in AR7 solar mirrors pressures documented across UK renewable project financing costs more broadly, with offshore wind providing a parallel case where record capacity awards have coincided with rising construction cost pressure and thin margin buffers for developers.

The CfD also cuts both ways. It protects Gülermak from wholesale prices falling below the strike, but it caps revenue at that strike across the full 20-year term. During periods of high wholesale prices, the project cannot capture the upside.

What that means for you as an observer is a clear reframing of where the returns come from. Hanningfield’s economics are driven almost entirely by construction cost discipline and hitting the August 2027 operations date, not by electricity market conditions. The risk lives in delivery, not in price.

Grid and delivery risks

Then there is the network. The full 6.2 GW of Pot 1 capacity, most of it solar, is now competing for connections in a system already showing regional bottlenecks.

Rapid build-out into constrained parts of the grid raises the prospect of connection delays and curtailment, where output is dialled back because the network cannot absorb it. For a developer less familiar with UK network processes, that is a live consideration for a 2027 delivery target.

None of this undoes the deal’s logic. It qualifies it.

What Gülermak’s first UK deal signals for international solar developers

Consider the timeline. Gülermak Renewables was established in 2023 and closed its first UK project financing on 25 September 2026, roughly three years from company formation to a signed construction loan.

That speed is the signal, and it says more about the market than about the developer.

Gülermak’s move into the UK reflects a pattern visible across global solar investment trends in 2026, where international capital is following standardised financing templates into markets with government-backed revenue certainty rather than concentrating in home jurisdictions.

Two conditions made it possible. The first is the standardised CfD-backed financing template that AR7’s scale has entrenched. The second is the mature ecosystem of UK advisers and service providers that surrounds any deal like this: TLT LLP and Hunton Andrews Kurth LLP on the legal side, Natural Power on technical, and ElectroRoute providing the route-to-market layer.

That infrastructure is what a new entrant plugs into. A first-time developer does not need decades of UK experience if it can retain advisers who have run the structure many times before.

For an international developer watching this transaction, the takeaway is specific. The UK’s combination of government-backed revenue certainty and a deep adviser ecosystem has made first-project financing achievable within a three-year establishment window.

That lowers the perceived barrier to entry. A milestone that might once have implied a long, uncertain build-up now looks like a repeatable process for anyone who can win an AR7 CfD and assemble the right advisers.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions.

Forward-looking statements regarding delivery timelines and pipeline plans are speculative and subject to change based on market developments and project performance.

A replicable template in a maturing market

The Hanningfield financing matters less for its size than for what its structure reveals. A sub-100 MW solar farm from a three-year-old developer is not a landmark on its own. The way it was financed is.

The three-layer logic holds the story together. The AR7 CfD supplies revenue certainty, the ElectroRoute PPA supplies operational bankability, and the NORD/LB construction loan closes the capital stack. Together they form a template that 157 AR7 solar projects have already validated.

The stacked-contract logic that NORD/LB required at Hanningfield is not unique to the UK market; solar financing structures in other jurisdictions are converging on similar layered approaches, combining offtake certainty with operational risk management tools before senior debt can be committed.

Two indicators will test whether this first deal becomes a lasting UK presence: whether Gülermak Renewables meets its August 2027 commercial operations target, and whether it announces further UK pipeline activity. Those are the markers to watch.

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