19/08/2026 in News, Views from Echelon
Planning permission does not build a wind farm, nor does a grid connection offer, a turbine order or a supportive minister. A wind farm gets built when a credit committee accepts that the project will earn enough, reliably, to repay debt over fifteen years or more. It is a harsh reality but explains more about Ireland’s renewable build rate than most of the public argument about it.
Wind generation is capital intensive and cheap to run. Almost all of the cost arrives before the first megawatt-hour is sold, which leaves these projects heavily dependent on debt, and lenders decide how much money to loan based on the worst-case year in the financial projections instead of the typical year.
Wind farms all produce power at the same time, when it’s windy, which floods the market with cheap electricity and crashes prices exactly when the wind farm has the most to sell, which is known as the cannibalisation effect. Wholesale prices, meanwhile, follow gas costs, and wind output fluctuates unpredictably. Relying on wholesale market sales alone means getting paid less per unit exactly when producing the most.
Research published this year by the Hertie School in Berlin modelling a decade of real operational data from 63 German onshore wind parks, found that under a conservative lending test most projects could support little or no debt at all if they relied on selling power at wholesale prices. The same study found that stable contracted revenues cut the cost of electricity by roughly 30 to 40 per cent. This is because predictable income lets projects swap expensive equity for cheaper debt Meaning whoever buys the power, and what they agree to pay, decides whether the project gets built at all.
What makes a buyer an anchor
Lenders are consistent about what they need from a power purchase agreement:
- a term that outlasts the debt, which in practice means fifteen years or more
- a counterparty whose credit survives a fifteen-year view
- a commitment to take, or pay for, a defined volume
- a price that is fixed, or floored
Demand that is long-term, creditworthy, high-volume and price-certain is rarer than it sounds. Most industrial load is cyclical. Most retail supply is short-term. Large data centres score unusually well on all four counts as they run at close to constant load, they are typically anchored by investment-grade hyperscale tenants, and they are planned in decades rather than seasons.
That is why the European market has tilted the way it has. Pexapark counts 18.8 GW of PPAs signed by data centre buyers in Europe between 2018 and May 2026, including 1.9 GW in Ireland, with the segment accounting for roughly a third of the European PPA market and 72 per cent of Europe’s grid-connected data centre capacity already contracted.
Until December 2025 this was a voluntary corporate choice but is now a condition of connection. The CRU’s Large Energy User connection policy requires data centres at or above 1 MVA to meet at least 80 per cent of annual electricity demand from additional renewable generation in Ireland, within six years of energisation. Generation already contracted under REFIT, RESS or ORESS cannot be counted towards it. The offtake has to underwrite something new.
The Large Energy User Action Plan published in January 2026 pushes the same logic further, committing to develop a corporate PPA route to market for the private procurement of offshore wind, and to plan-led green energy parks that co-locate large load with generation and storage.
The result is two parallel routes to market. RESS 6, with bids due in November, remains the state-backed route for onshore wind and solar. Private contracted demand is the other, and it is already carrying weight as two Phase 1 offshore projects that bid in ORESS 1, together representing more than a gigawatt, are progressing through planning while seeking a corporate PPA rather than a state contract.
Wind power doesn’t match when a data centre needs electricity hour by hour. Even if you match them annually, there’s a timing gap. Batteries narrow that gap, reduce the wind farm’s financial risk and make the whole package more bankable. This is why “green energy parks” exist, as they bundle wind, storage and demand together.
How much power a contract is worth depends on two things: the amount of power and where it’s located. Wind farms in Ireland get shut down 11.3% of the time when the grid is overloaded. In 2025, 11.3% of the electricity Irish wind farms could have produced went unused because the grid couldn’t take it. A power contract in an area where the grid is congested is worth less than the same contract where the grid can handle it.
Buying power from an existing wind farm doesn’t help the energy transition as under the new connection rules, only new generation counts so that data centre demand underwrites additional renewable capacity.
Big electricity demand isn’t a burden on the energy transition, it’s what makes new wind farms financeable. Companies signing long-term power contracts give lenders confidence to fund new wind farms. But this only works if: the contract is long-term, it is genuinely new generation and the grid can handle the output.
Echelon builds campuses designed to meet all three.
