IN Brief:
- Five Irish wind developments totalling 311MW secured planning approval during Q2 2026.
- Forty-eight projects representing 2,668MW remain in the planning queue, with more than 1GW waiting over a year.
- Planning throughput must align with grid, procurement, and construction capacity for the 2030 build programme.
Wind Energy Ireland recorded five wind projects with a combined capacity of 311MW gaining planning approval during the second quarter of 2026, the strongest quarterly result since the first quarter of 2025. One project was refused, while the volume of capacity waiting for a decision continued to increase.
The 311MW approved during the quarter follows an opening three months of 2026 in which no new wind farms received planning approval. The recovery adds meaningful capacity to Ireland’s development pipeline, but the same dataset shows that the queue of unresolved projects is expanding faster than recent decisions have reduced it.
Forty-eight projects representing 2,668MW are now awaiting decisions from An Coimisiún Pleanála, compared with 31 projects totalling 1,643MW in the second quarter of 2025 and 28 projects representing 1,683MW two years earlier. More than 1GW across 18 projects has been waiting for a decision for over a year, including 277MW across five projects that has spent more than two years in the process.
Planning approval is only the first major gate in a long delivery sequence. A consented wind farm still needs a viable grid connection, project finance, turbine and balance-of-plant procurement, civil works, electrical infrastructure and commissioning. Long waits early in the programme compress the period available for those later activities even when consent is eventually granted.
Ireland is targeting around 9GW of onshore wind by 2030, against an installed fleet that passed 5GW during 2025. Closing the remaining gap requires a consistent flow of projects from planning through grid connection and construction rather than occasional quarters of high approvals followed by long pauses.
The backlog also creates procurement uncertainty. Turbine supply, heavy transport, cranes, substations and grid works all require forward scheduling, and developers are competing for much of the same equipment and specialist labour. A planning decision that lands later than expected can force changes to delivery slots, financing assumptions or construction windows, particularly where turbine models or supplier availability have changed during the wait.
Modern onshore turbines add another logistical constraint. Larger rotors and taller towers can improve energy yield, but blades, nacelles and tower sections require more demanding transport routes, lifting plans and site preparation. Those activities cannot be compressed indefinitely simply because the administrative stage has taken longer than forecast.
The planning figures arrive as wind already supplies a large share of Irish electricity. Wind farms produced 763GWh during July and met 23% of demand, according to Wind Energy Ireland. Additional capacity will increase the need for network investment and system flexibility if new generation is to be accommodated without pushing constraint and curtailment higher.
Grid connection therefore runs in parallel with consenting rather than following it as a secondary issue. Substations, circuits and transmission reinforcement must be available when projects are ready to energise, while system operators need enough reserve, storage, interconnection and controllable demand to manage periods of high instantaneous renewable output.
The same sequencing challenge applies to Ireland’s wider 2030 electricity programme. Wind expansion is being pursued alongside solar, offshore wind, storage and major grid investment. Each technology has its own planning and construction timetable, but the power system only gains value when generation, networks and flexibility arrive in compatible quantities.
A faster planning process would not remove every bottleneck. Grid works can still take years, turbine supply can tighten, financing can move with interest rates and project economics, and local construction constraints can delay a consented development. The current queue nevertheless shows that planning remains one of the first points at which the delivery timetable can be lost.
The age of the queue is as important as its headline capacity. Projects waiting more than a year can face changed turbine pricing, updated grid studies, revised construction costs and expiring commercial assumptions before a planning decision arrives. Each change can trigger another round of engineering or financial work, so administrative delay can continue to consume project time even after the original application is complete.
Five approvals and 311MW of capacity make the second quarter a clear improvement on the start of 2026. The harder number remains the 2,668MW waiting for decisions. Unless that queue begins to fall in absolute terms, stronger individual quarters will amount to improved throughput rather than a cleared bottleneck, leaving developers with less time to turn paper capacity into operating turbines before the end of the decade.
