Cable decides when people are needed offshore, and cable is now ordered three to four years ahead. When a slot moves, the commissioning hiring window moves with it, and the teams you release are not the teams you can get back.
Key Takeaways
- HVDC export cable orders face lead times of 36 to 48 months. Prysmian held about €17bn of transmission backlog at 30 June 2026 and NKT €13.0bn at the end of Q2 2026, so an order placed in 2027 delivers around 2030.
- Eastern Green Link 1, the 2GW link from Torness to Hawthorn Pit, is now expected in April 2029, 16 months later than required. Its developers sought a 480-day Ofgem penalty exemption citing global supply chain capacity.
- New cable-lay vessel capacity arrives in 2029, not 2027. Boskalis has ordered a 24,000-tonne vessel with two 12,000-tonne carousels entering service that year.
- Each day of export cable outage costs roughly $167,000 to $500,000 on Lloyd Warwick’s published loss range. Holding a 12-person HV commissioning team on standby costs about £50,400 a week on LSP’s own workings.
- Offshore HV commissioning, SAP and energisation teams are the ones released when a cable slot slips. Onshore civils, cable duct and landfall crews are usually held, because their work precedes cable pull in.
Cable Lead Times Are Now Longer Than Most Hiring Plans
The constraint is manufacturing capacity, and the evidence for it sits in company results rather than commentary. Prysmian reported a transmission backlog of about €17bn at 30 June 2026, with a further €2bn awarded but not yet booked. NKT’s transmission backlog stood at €13.0bn at the end of Q2 2026, down from €13.5bn at Q1. Hellenic Cables reached a record €3.4bn backlog at 30 June 2026, having been sole inter-array supplier across all three Dogger Bank phases and holding an HVDC framework with National Grid, though that figure reached us through Green Stocks Research rather than from Cenergy’s own results and should be confirmed there.
Those backlogs translate into order to delivery of 36 to 48 months on new HVDC export cable. The trade analysis site Offshore Industry reported in May 2026 that “projects sanctioning in 2026-2027 have effectively committed cable supply through 2030 and beyond”. That is a trade source rather than a manufacturer statement, so treat the 2030 figure as directional. The company backlogs behind it are audited.
Vessels are the second gate and they open later. Nexans took handover of Electra on 18 May 2026 and Jan De Nul’s Fleeming Jenkin was due in the same year. NKT began building harbour facilities for a second vessel, NKT Eleonora. But the next significant step change in capacity is Boskalis’s 24,000-tonne newbuild, which enters service in 2029. Market research from Persistence expects nine newbuilds to expand the fleet by the end of 2026 with no significant orders visible beyond that, and Dataintelo reports cable-lay day rates rising from $320,000 to $380,000 in 2023 to $480,000 to $620,000 by May 2026 against roughly 85 vessels and peak demand for 120. Both are market research publications rather than primary sources. The direction is consistent with everything else here, the precise numbers should not be quoted as fact.
Nothing in this research forecast easing in 2027. NKT’s own 2025 annual report treats delivering its backlog across “2026 and 2027” as a prerequisite rather than an ambition. The capital driving the demand is set out in the UK grid investment pipeline under RIIO-T3.
The Delays Already on the Record
Eastern Green Link 1 is the clearest UK case. Ofgem described it in April 2025 as “a c176km, 525 kilovolt (KV), two gigawatt (GW) High Voltage Direct Current (HDVC) marine cable” running from Torness to Hawthorn Pit, delivered by SP Energy Networks and National Grid Electricity Transmission. Reuters reported Ofgem’s assessment that the link is “now expected to be delivered in April 2029, 16 months later than required”.
What makes it instructive for hiring is the reason given. The developers requested a 480-day Penalty Exemption Period citing “unavailability of equipment or capacity globally in supply chain”, and Ofgem consulted on rejecting it. An offshore start originally set for summer 2025 moved to cable installation across 2027 and 2028. Every offshore commissioning and energisation role on that project moved with it.
Hornsea 3 shows the same effect from the onshore end. Ørsted reported a National Grid connection delay of up to two months in May 2025, and by its H1 2026 results the 2.9GW project was around 30% complete with commissioning targeted for Q4 2027 or Q1 2028. Rasmus Errboe, Ørsted’s Chief Executive, was candid about what that does to planning. “We have been informed by National Grid that the connection onshore will be delayed [by] up to two months... and as a consequence of that, we have to be cautious,” he said.
One case that is often cited in this context does not belong in it, and saying so matters more than adding a third example. Neart na Gaoithe slipped from an original 2023 completion to summer 2024 and then summer 2025, and ESB’s annual report assessed “the expected credit loss … as €134.6 million as at 31 December 2024” on top of over €150m of impairments in 2021. But ESB attributed the delay to “delivery issues on the foundation package and construction delays as a result of COVID-19 impacts”, not to cable, and its H1 2025 results confirm the 448MW wind farm became fully operational in that period. A foundations delay resets a hiring window just as hard as a cable delay, and conflating the two leads to watching the wrong supplier.
Equally worth stating plainly, no documented cable or vessel delays were found for Sofia, Moray West or Dogger Bank A to C in this research. Dogger Bank South’s 2026 delay was a Development Consent Order matter rather than a cable matter. Those projects should not be described as cable-delayed without separate verification.
Which Teams Get Released and Which Get Held
This section is LSP’s inference from the project sequence rather than a published finding, and it is the part clients ask about most.
When an export cable or vessel slot slips, the roles released or deferred are the ones whose work starts at or after cable pull in. Offshore HV commissioning engineers, Senior Authorised Persons, energisation teams and control systems engineers sit in that group. Their mobilisation date is pinned to the cable, not to the programme start.
The roles usually held are the ones whose work precedes it. Onshore substation civils, cable duct and landfall crews, and turbine installation crews carry on, because their output is a prerequisite for the cable rather than dependent on it. East Anglia TWO completing two cable ducts beneath the Suffolk coast in October 2026 is that pattern in practice, with onshore enabling work progressing against an offshore schedule that may still move.
The cost of getting the released group back is the number nobody publishes. No UK figure exists for demobilising and remobilising a commissioning team, or for how far ahead HV teams are typically secured, so the following is built from 2026 advertised day rates and is our own calculation.
A senior HVDC project manager advertised at £650 to £750 per day through Turner and Lovell in October 2026. An offshore and onshore renewables control systems engineer advertised at £600 to £650 per day through ERSG. A competent offshore wind turbine technician advertised at £500 to £550 per day through Kinekta in Lowestoft. On a blended £600 per day, a 12-person HV commissioning team costs £7,200 a day, £50,400 for a seven-day week, or roughly £216,000 a month held on standby. SSEN advertised a 400kV lead commissioning engineer on a 12-month outside IR35 day rate in September 2026, and how that determination is reached is covered in the IR35 status model in renewable energy contracting.
Set that against the alternative. Ofgem’s ASTI Output Delivery Incentive penalises late transmission delivery financially, which is precisely why EGL1’s developers sought a 480-day exemption. The published proxy for the cost of offshore delay comes from Lloyd Warwick’s export cable loss range of $10m to $30m over roughly 60 days of downtime, cited by DNV, which works out at about $167,000 to $500,000 per day. On those numbers a month of standby at £216,000 is cheaper than a fortnight of outage, which is the commercial case for retaining rather than releasing. Comparable rates at project leadership level appear in offshore wind project manager day rates, and the equivalent transmission bands in transmission project director and senior project manager pay.
Failure Creates Demand Nobody Planned For
Planned delay is only half the picture. University of Strathclyde research from 2019 found about 0.003 cable failures per km per year, which gives a 100km system roughly a 30% chance of a failure in any given year. Array cable repairs average about 40 days of downtime and export cable repairs about 60, with a UK average of 62 days.
ORE Catapult attributes 46% of failures to installation damage, 31% to manufacturing, 15% to design and 8% to external causes. The financial concentration is in export cables, which AXIS Capital found represent only 6% of claims by count but carry the highest average claim at $18.8m. Array cable damage runs $1.8m to $12m and export damage $10m to $30m on Lloyd Warwick’s figures. Beatrice illustrates how repair duration understates disruption, where a 38-day repair sat inside an outage of around three months.
Neil Gordon, Chief Executive of the Global Underwater Hub, has cited the headline figure the sector works to. “It’s estimated that around 85% of the total value of offshore wind insurance claims relate to subsea cables,” he said. That estimate traces back to Carbon Trust report CTC835 from February 2015 and rests on broker information, so it is a long-standing industry reference rather than a current measurement.
What it means for hiring is that cable jointers and HV repair specialists are needed at short notice, repeatedly, on no plan. At $167,000 to $500,000 per outage day, a standby retainer for repair capability is cheaper than sourcing it cold, and that is the argument for holding a relationship with the market rather than a vacancy.
Frequently Asked Questions
How long does it take to get a subsea HVDC cable?
New HVDC export cable orders face lead times of 36 to 48 months according to trade analysis from Offshore Industry in May 2026. Prysmian held about €17bn and NKT €13.0bn of transmission backlog at 30 June 2026, both from company results, so an order placed in 2027 delivers around 2030.
Which UK projects have been delayed by cable supply?
Eastern Green Link 1, a 2GW HVDC link from Torness to Hawthorn Pit, is now expected in April 2029, 16 months later than required. Its developers sought a 480-day Ofgem penalty exemption citing global supply chain capacity. Hornsea 3 now targets commissioning in Q4 2027 or Q1 2028 following an onshore connection delay.
How often do offshore wind cables fail?
University of Strathclyde research from 2019 found about 0.003 failures per km per year, giving a 100km system roughly a 30% annual chance of failure. Array repairs average about 40 days and export repairs about 60. ORE Catapult attributes 46% of failures to installation damage.
What does an offshore cable delay cost?
Lloyd Warwick, cited by DNV, puts export cable losses at $10m to $30m over about 60 days of downtime, roughly $167,000 to $500,000 per day. AXIS Capital found export cables average $18.8m per claim. Holding a 12-person commissioning team on standby costs about £50,400 a week on LSP’s own workings.
Will cable supply ease in 2027?
Unlikely. NKT’s 2025 annual report treats delivering its backlog across 2026 and 2027 as a prerequisite, and the next significant vessel capacity, Boskalis’s 24,000-tonne newbuild, arrives in 2029. No source found in this research forecasts easing in 2027.
Plan your commissioning hire against the cable date
Tell us the energisation window you are working to and we will map the HV commissioning, SAP and control systems market behind it, including who is available on standby terms rather than only on start dates. Our offshore wind recruitment desk tracks mobilisation against project schedules rather than calendar quarters.
