Corporate Wind Energy Projects in Ireland

Key takeaways

- A corporate wind energy project is a wind farm whose revenue rests mainly on a long-term contract with a company that uses electricity, not on a state support scheme.

- Three structures dominate: the sleeved PPA through a supplier, the virtual PPA settled as a contract for difference, and the on-site private wire project.

- The offtaker's credit quality, not the price, usually decides whether a deal gets funded. An unrated corporate will need credit support.

- Curtailment is the other deal-breaker. EirGrid and SONI reported all-island wind dispatch down to 14.0% of available wind energy in 2024, easing to 13.4% in 2025.

- Buying Guarantees of Origin is not the same thing as additionality, and buyers are increasingly asked to show both.

Wind supplied roughly a third of Ireland's electricity in 2025, with more than 5,000 MW of onshore capacity operating, according to Wind Energy Ireland's annual figures. The Central Statistics Office put data centre consumption at 22% of all metered electricity in 2024, rising to 23% in 2025. Demand is concentrated, supply is weather-driven, and the gap is where corporate wind procurement lives. Our commercial advisory and transaction work sits on both sides of these negotiations.

What is a corporate wind energy project?

A corporate wind energy project is a wind farm whose economics rest on a long-term electricity contract with a corporate buyer rather than on a government auction. The corporate commits to buy the output, or the financial value of it, for ten to fifteen years or longer. That contract is the asset the developer takes to lenders.

The electricity still flows into the national grid in almost every case. What changes is who carries price risk and who holds the environmental attributes. Matheson LLP signed a fifteen-year corporate PPA alongside Flogas Ireland for part of the output at Natural Forces' Tullyhaw project in Cavan, the rest of it supported under RESS 2.

Why are Irish corporates buying wind power directly?

Four forces are pushing the market: policy sets the direction, demand growth sets the urgency, corporate reporting sets the standard of proof, and grid constraint sets the timetable. None will ease before 2030.

The Climate Action Plan carries a target of 80% renewable electricity by 2030, supported by capacity goals of 9 GW onshore wind, 8 GW solar and at least 5 GW offshore wind. The CSO reported data centre consumption of 6,969 GWh in 2024, up 10% on 2023, equal to 22% of all metered electricity, rising to 23% in 2025. Companies in that bracket face connection scrutiny, planning scrutiny and board-level questions about where their power comes from. Microsoft signed two PPAs with Energia for onshore wind in Clare and Kerry in March 2025.

Vodafone Ireland contracted output from Derrynaflan in Mayo through Flogas.

Reporting is the third driver: CSRD-aligned disclosure and science-based targets push buyers from green tariffs towards contracts they can point to on a map. The fourth is price, since a long contract converts an unhedgeable exposure into a known cost.

What is a corporate PPA and how does it work in Ireland?

A corporate PPA is a long-term contract under which a company buys renewable electricity, or its financial equivalent, directly from a named generator at an agreed price. In Ireland, it sits on top of the Integrated Single Electricity Market, because the generator must still sell into I-SEM and the buyer must still take supply from a licensed supplier.

That architecture is why Irish corporate PPAs are rarely simple bilateral trades. The generator registers units with SEMO and is paid the market price for what it produces; the corporate buys from its supplier at the supplier's tariff. The PPA adjusts the net position, either by sleeving generation into the corporate's account or by financial settlement against a reference price. Our deeper piece on how corporate PPAs are structured in Ireland works through the mechanics.

What is the difference between a sleeved PPA, a virtual PPA and an on-site project?

A sleeved PPA moves physical electricity through a licensed supplier into the corporate's meter. A virtual PPA settles the difference between a fixed strike price and the market reference price in cash, with no physical delivery. An on-site project connects generation directly to the customer's load behind the meter.

Feature	Sleeved (physical) PPA	Virtual (financial) PPA	On-site/private wire
Physical delivery	Yes, via a licensed supplier	No, cash settled	Yes, direct to the load
Shape and imbalance managed by	The supplier, for a fee	Existing supplier, unchanged	The site, plus backup supply
Accounting treatment	Normally a supply contract	Often a derivative under IFRS 9	Supply or lease arrangement
Guarantees of Origin	Transferred with the volume	Transferred separately by contract	Transfer with the volume
Capture rate risk	Shared, depends on drafting	Corporate, unless shaped	Minimal, limited by on-site load
Main friction point	Sleeving fees, supplier credit	Derivative accounting, basis risk	Planning, land, matching output to load

On-site projects are the smallest category and the most intuitive commercially. The limiting factor is load profile: a turbine producing at three in the morning is worth little to a factory running one day shift. Multi-buyer structures are a fourth option. Flogas and Ørsted launched a model in August 2025 letting medium-sized companies take a slice of a wind farm's output rather than the whole site.

How long are corporate wind PPAs and how is the price set?

Irish corporate wind PPAs typically run 10 to 15 years, occasionally longer when the buyer is strongly rated. Buyers negotiate the price against the forward curve, the project's cost of capital, and the buyer's credit, not a published index. Most deals use a fixed EUR/MWh price with annual indexation.

A fixed price gives a flat EUR/MWh for the term: lenders like it, but both sides risk being wrong about inflation. An indexed price escalates a base price by HICP or a set percentage, and dominates at longer tenors because it protects the developer's real return. A collar sets a floor and a cap, giving the corporate upside participation and the developer a bankable floor. Floor only means the corporate guarantees a minimum, and the generator sells merchant above it, still enough to support debt at lower gearing.

Shape risk and volume risk

Shape risk is the gap between the average market price and the price wind actually captures, because wind farms produce most when wind is widespread, and prices are depressed. That ratio is the capture rate, and it has trended down across European markets as renewable penetration has risen. Volume risk is that the wind does not blow as forecast.

Pay-as-produced contracts leave volume risk with the buyer. Baseload or pay-as-nominated contracts shift it to the generator, who must buy from the market to cover shortfalls, and price accordingly. Most Irish deals land on pay-as-produced with a defined availability obligation.

What does a corporate need to qualify as an offtaker?

Credit is the gate. A lender underwriting a fifteen-year project loan is, in substance, underwriting the offtaker's ability to pay for fifteen years. Most Irish project lenders want an investment-grade rating or an equivalent internal assessment, and an unrated corporate will need credit support before the conversation progresses.

This is the most common reason a well-intentioned corporate PPA never reaches signature. The buyer has the demand, the mandate and the budget, but no public rating and a balance sheet that does not survive a fifteen-year stress case. The workarounds are established:

• Parent company guarantee. Works where the group parent is rated. Lenders want a direct guarantee, not a comfort letter, and will test enforceability in the parent's jurisdiction.

• Letter of credit or bank guarantee. Usually sized at six to twelve months of contract value, rolling. It costs real money in facility fees and consumes banking lines.

• Shorter tenor with a merchant tail. Debt is sized against ten years of contracted revenue plus a conservative merchant assumption. Gearing falls, but the deal closes.

• Volume staging. Start smaller, build a payment history, then expand.

Run the credit test before a term sheet is drafted. It decides whether the project is financeable.

How does a corporate PPA compare with RESS for a developer?

RESS gives a developer a state-backed two-way CfD with high certainty and low flexibility. A corporate PPA gives a negotiated price, counterparty risk, and control over timing. Merchant exposure gives full upside and no bankability. Most Irish portfolios now blend all three.

	RESS	Corporate PPA	Merchant
Counterparty	State-backed, via the scheme	Corporate offtaker	I-SEM market
Price certainty	High, fixed strike with indexation	High during term, negotiated	None
Tenor	Scheme support period	Typically 10 to 15 years	Not applicable
Credit risk	Minimal	Central issue, drives the structure	Market and settlement risk
Gearing achievable	Highest	Slightly lower, covenant-dependent	Low
Flexibility on timing	Low, tied to auction and longstop dates	High, sign when ready	High
Community benefit	Mandatory, minimum EUR 2/MWh	Negotiated, increasingly expected	None imposed

EirGrid's provisional RESS 5 results, published in September 2025, showed an average strike price of EUR 98.81/MWh across provisional winners, with onshore wind averaging EUR 96.56/MWh against EUR 90.47/MWh for wind in RESS 4. Corporate PPA prices are not published, but the auction clearing level is where every negotiation starts. Our analysis of how the RESS auction rounds have evolved covers the scheme mechanics.

RESS suits projects that are consented, grid-connected, and able to meet a longstop date. Corporate PPAs suit projects that missed an auction or want to avoid the all-or-nothing outcome of a single round.

What are the main risks for the corporate buyer?

Price, volume, delivery and accounting. Price risk is that wholesale prices fall below the strike for a sustained period, leaving the corporate paying above market for a decade. That exposure should be modelled, not waved away with a sustainability argument.

Volume risk under pay-as-produced means the corporate receives less than forecast in a poor wind year and buys the shortfall at spot. Delivery risk is that the project is delayed or never built, which is why buyers should insist on milestone conditions, longstop dates and termination rights. Accounting catches people out too: a virtual PPA is often classified as a derivative under IFRS 9, with mark-to-market movements running through the income statement.

What are the main risks for the developer?

The developer's primary risk is the mirror image: the offtaker fails or deteriorates, and the project loses its revenue contract mid-life with debt outstanding. Change in law and basis risk between the contract reference price and the price actually received sit in the next tier.

Curtailment is the exposure that most often gets underpriced. If the contract obliges delivery of volume and the system operator instructs the farm down, the developer buys replacement energy at market prices for output it could have generated. Deemed generation provisions, treating curtailed output as delivered, are the standard answer and worth fighting for. We map the full set in our review of the risks that recur across Irish renewable projects.

How does additionality work and why do buyers care?

Additionality means the corporate's contract caused new renewable capacity to exist that would not otherwise have been built. A PPA signed with a project before financial close, where that contract enabled the investment decision, is additional. Buying certificates from a wind farm commissioned in 2009 is not.

Signing with a pre-construction project carries development risk, which is precisely why it demonstrates additionality. Signing with an operating asset is cheaper and remains credible under market-based GHG accounting, but it adds nothing to the Irish system. The practical test: was the PPA a condition precedent to financial close? Buyers should also look at hourly matching, where consumption is matched to generation within the same hour rather than netted across a year.

What is the role of Guarantees of Origin?

A Guarantee of Origin is an electronic certificate proving one MWh was generated from a renewable source. In Ireland, SEMO acts as the issuing body for electricity GOs, and the CRU sets the framework for fuel mix disclosure and GO use. One GO equals one MWh, and it is cancelled when claimed.

GOs are how a corporate entity substantiates a renewable claim in its disclosures. They are also tradeable independently of the power itself, which is the source of most confusion. A company can buy unbundled GOs from elsewhere in the European system, retire them and report zero-carbon electricity, without a single new turbine being erected. That is legitimate, but it is not procurement. State in the PPA who owns the GOs and when they transfer.

Grid: the issue that sets the timetable

Grid access determines whether a corporate wind project happens in 2028 or 2033. The project needs a connection offer under the Enduring Connection Policy process run by EirGrid and ESB Networks, and the buyer's own site needs sufficient Maximum Import Capacity for any on-site arrangement. MIC is a hard constraint for large energy users, and raising it is a formal application with cost and lead time attached.

Curtailment is the live commercial issue. EirGrid and SONI reported all-island wind dispatch down at 14.0% of available wind energy in 2024, falling to 13.4% in 2025. Some is system-wide curtailment, some local network constraint, and the two are treated differently under compensation arrangements. The PPA must say who carries each. Our guide to securing and managing a grid connection in Ireland covers the pinch points.

Planning: An Coimisiún Pleanála, SID and community benefit

Larger Irish wind farms are typically consented through the Strategic Infrastructure Development route, with the application going directly to An Coimisiún Pleanála rather than the local authority. Qualification is decided case by case under the Planning and Development Act 2000 as amended, based on whether the project is energy infrastructure of strategic importance, not by a fixed megawatt threshold. Smaller schemes go to the local authority with an appeal route to the Commission. Either way, an Environmental Impact Assessment Report and Appropriate Assessment screening will be required at scale.

Under RESS terms, generators must establish a community benefit fund contributing a minimum of EUR 2/MWh generated, governed by a binding rulebook published in 2025 with annual reporting to the SEAI. Projects outside RESS are not bound by that figure, but most developers adopt an equivalent commitment.

How do you actually get a corporate wind project financed?

You get it financed by presenting a lender with a contracted revenue stream from a creditworthy counterparty, a project that is consented and grid-connected, and a financial model that holds up under stress. The rest is detail.

A typical Irish onshore wind structure uses a special purpose vehicle holding the asset, non-recourse senior debt secured over the SPV's shares and assets, and a cash waterfall paying operating costs, then debt service, then reserve accounts, then equity. Gearing follows revenue certainty. Lenders test the model against a debt service cover ratio, at base case and under downside sensitivities covering low wind years, curtailment, price and availability. The ratio must hold in the downside case, and a credit committee must be able to trace every number. We have written separately on building a wind financial model that survives lender scrutiny.

Tenor mismatch deserves attention. If the PPA runs fifteen years and the debt eighteen, the lender takes merchant risk for the final three and sizes accordingly, usually with a cash sweep in the tail. Some lenders will not go beyond the PPA term at all.

Frequently asked questions

What is a corporate PPA in Ireland?

A long-term contract under which an Irish company buys renewable electricity, or its financial value, directly from a named generator at an agreed price. The power still flows through I-SEM and a licensed supplier, with the PPA adjusting the commercial outcome between the parties.

How long does a corporate wind PPA last?

Most run ten to fifteen years. Shorter terms of five to seven years exist for operating assets with lower financing needs. Longer terms are possible where the offtaker is strongly rated, and the developer wants maximum gearing on a new-build project.

Does my company need a credit rating to sign a wind PPA?

Not strictly, but an unrated corporate will almost always need credit support before a lender accepts the contract. That usually means a parent company guarantee or a rolling letter of credit sized at six to twelve months of contract value.

What is the difference between a sleeved PPA and a virtual PPA?

A sleeved PPA delivers physical electricity to your meter through a licensed supplier, who manages imbalance and shape for a fee. A virtual PPA involves no physical delivery: it settles the difference between a fixed strike and a market reference price in cash.

Are Guarantees of Origin enough to claim renewable electricity?

GOs support a market-based renewable claim under current accounting rules, and SEMO is the issuing body for electricity GOs in Ireland. They do not demonstrate additionality on their own. For that, you need a PPA with a project that reached financial close because of it.

Who bears curtailment risk in an Irish corporate PPA?

It is negotiated. Deemed generation provisions, which treat curtailed output as if delivered, place the risk with the buyer. Without them, it sits with the developer. EirGrid and SONI reported all-island wind dispatch down of 13.4% in 2025, so the clause carries real value.

Can a corporate PPA and RESS support the same project?

Yes, in the sense that one site can split capacity between the two, as Natural Forces did at Tullyhaw in Cavan, where part of the output is supported under RESS 2 and part sits under a corporate PPA. A single MWh cannot be supported twice.

What size does a corporate need to be to buy wind power directly?

The market historically started around 10 GWh a year of consumption. Multi-buyer structures launched in 2025, including the model Flogas brought to market with Ørsted, now let medium-sized companies take a share of a wind farm's output instead.

If you are weighing a corporate PPA, a route-to-market decision, or the financing behind a wind project, start a conversation with us about where your project sits.

Sources: EirGrid, Wind Energy Ireland, SEAI, CRU, SEMO Guarantees of Origin, gov.ie.