UK commercial solar grants — questions we get most.

Grants and tax benefits typically cover 20–50% of installation costs. Examples: a £400,000 IETF-funded project effectively reduces to £280,000 net of grant, then £210,000 net of Full Expensing. A £100,000 system using Full Expensing alone effectively costs £75,000. PSDS-funded public sector projects can be 100% covered. We model exact figures during the free funding review.

Most commercial installations take 1–3 weeks of on-site work depending on system size. A typical 100 kWp system takes 5–7 working days; larger systems (500 kWp+) typically 2–3 weeks. We schedule around your operations to minimise disruption — most work is on the roof with brief electrical shutdowns (1–4 hours) at convenient times.

Minimal disruption. Most work is on the roof and doesn't affect operations below. Electrical shutdowns are brief (1–4 hours) and scheduled at convenient times, often evenings or weekends. Most clients report barely noticing the installation process beyond the rooftop activity.

Structural surveys identify any required works before installation. Roof remediation can be included in the project scope and costs may be partially covered by some grants (PSDS allows roof remediation when it's part of an integrated decarbonisation package; private-sector grants typically don't). Modern panels are lighter than older systems and most commercial roofs built post-1990 take PV without reinforcement.

Tier 1 modules carry 25–30 year linear performance warranties. In practice good systems are still producing 85% of nameplate output at year 30. Inverters last 10–15 years and are replaced once during the system lifetime (typically year 12–15). The financial model treats panels as a 25-year asset with ~0.5% annual degradation.

Annual visual inspection, electrical test every 3 years, occasional cleaning (rain naturally cleans panels in most cases). Inverter replacement at year 12–15. Budget £8–£15/kWp/year for full O&M with monitoring. Most projects bundle 2 years of O&M into the install contract.

Roughly 5–6 square metres per kWp installed. A 100 kWp system needs around 550 m² of usable roof; a 500 kWp system needs 2,800 m². Roof should be in reasonable condition, relatively unshaded, ideally south, east or west facing. We assess feasibility during free site surveys.

Alternatives exist — ground-mounted systems on adjacent land, solar canopies on car parks, wall-mounted installations, or sleeved off-site PPAs (where solar is generated remotely and contractually allocated to your supply). We explore all options during the assessment. Sometimes multiple smaller installations across different buildings work better than one large array.

Most commercial solar installations are permitted development and don't need full planning permission. Exceptions include listed buildings, conservation areas, systems facing highways, sites near airports (glint and glare assessment), and ground-mount installations above 1 MW. We handle all permissions and work with local authorities on your behalf.

Ownership is ideal but not essential. Long-term leases (15+ years remaining) work for most PPA structures. Some landlords welcome solar as it increases property value — landlord-funded structures with the tenant signing a long-term off-take agreement are increasingly common. We can help negotiate agreements that benefit both parties.

Yes. Commercial properties with solar typically see 3–5% value increases and are more attractive to buyers and tenants. Solar demonstrates environmental commitment, reduces operating costs for the next occupant, and supports certifications (BREEAM, Net Zero Carbon Buildings Standard) that command rental premiums.

A typical 100 kWp system offsets 40–50 tonnes of CO2 annually, equivalent to planting 2,000+ trees each year. Over 25 years, that's 1,000–1,250 tonnes of CO2 prevented. Larger systems achieve proportionally greater environmental impact. Solar is one of the most effective ways to reduce Scope 2 (purchased electricity) emissions.

Yes — modern Tier 1 panels are 95%+ recyclable. Most manufacturers operate take-back schemes. The aluminium frames, glass, copper and silicon can all be recycled. The UK solar industry has robust end-of-life recycling infrastructure in place.

Yes. £820m+ is live across IETF Phase 3 (£185m), Salix PSDS Phase 4 (£530m for public sector), the Rural England Prosperity Fund (£110m), plus devolved equivalents in Scotland, Wales and Northern Ireland. Outside grants, Full Expensing reimburses 25% of solar capex via corporation tax for any UK incorporated business — that often beats a grant on net economics.

For direct cash grants, only if you are in manufacturing, food production, data centres or chemicals — that is who IETF covers. For everyone else, Full Expensing (100% first-year tax relief) acts as the de facto grant; rural businesses can also access REPF; and PPA structures provide third-party-funded solar with no grant needed. Most non-industrial commercial sites end up on a Full Expensing + PPA stack.

No. The funder requirement is that the project is delivered in the UK and the applicant is UK-registered (a UK company or branch). Foreign-parented UK subsidiaries qualify for IETF, PSDS contractor work and Full Expensing.

They are eligible for Annual Investment Allowance and REPF, but not for Full Expensing (which is corporation-tax-only). For grant purposes, partnerships often need to demonstrate that the project entity has separate accounts. Sole traders rarely have the project size needed for IETF.

They face the same eligibility, but PPA structures need careful IFRS 16 review — some PPAs are now treated as right-of-use assets and brought back on balance sheet. The funding mechanism matters less to listed companies than the accounting treatment.

Most charity-led commercial solar projects do not qualify for IETF (sector-restricted) or PSDS (public sector only). REPF is open to charities operating in rural areas. Tax allowances do not apply (no corporation tax). The right answer for most charities is normally a PPA or grant funding from charitable foundations.

Generally no. Housing associations sit outside PSDS eligibility and IETF sector restrictions. They have separate routes via the Social Housing Decarbonisation Fund (SHDF) which is residential-focused and not directly comparable to commercial solar grants. We can advise on commercial properties held by housing associations (offices, depots) but not residential stock.

The Industrial Energy Transformation Fund is a DESNZ programme funding decarbonisation in energy-intensive industries. Solar is eligible as part of an integrated decarbonisation package — standalone solar applications rarely score competitively. Phase 3 runs to 2028 with £185m allocated.

Capex typically £250k–£14m. Below £250k the application overhead rarely pays off; above £14m sits with separate Net Zero Innovation Portfolio routes. The sweet spot is £500k–£3m, where IETF has historically funded 60% of applications.

Yes, when it materially improves carbon performance — e.g. firming up solar self-consumption, displacing diesel backup, or supporting grid-edge frequency response. Pure arbitrage batteries are not eligible.

Yes, across different phases or windows, but each application must be a distinct project. You cannot submit the same project to multiple windows hoping for better treatment.

NHS trusts, local authorities (district, county, unitary, combined), state-funded schools and academies, FE colleges, central government departments and arms-length bodies, fire and police services. Universities are mostly outside (they have their own LCSF route). Charities and housing associations are not eligible.

PSDS scores integrated retrofits, not individual measures. The HDP is the document that proves your solar PV fits inside a credible whole-estate plan to remove fossil heat. Solar without an HDP almost always loses scoring.

4–6 weeks after window close in normal cycles. Phase 4 has been running on time. Awards are typically announced as a batch — be ready to draw down within 3 months of award.

Yes, that is how almost all PSDS work is delivered. The applicant is the public sector body but procurement runs to standard public-sector frameworks (Crown Commercial Service, ESPO, NEPO).

The Rural England Prosperity Fund is a DEFRA programme delivered through local councils. It covers up to 40% of capex on rural enterprise capital projects including solar PV. Each council has its own allocation and scoring weightings. Application narratives that anchor on rural growth outcomes (jobs, contract revenue, GVA) score better than pure decarbonisation pitches.

No. Scotland has its own Scottish IETF (SIETF) administered by the Scottish Government. Wales has the Welsh Industrial Decarbonisation Fund. Northern Ireland operates separate routes through the Department for the Economy. The eligibility criteria are similar but the application processes and timetables differ.

Full Expensing gives you 100% first-year capital allowances on qualifying plant, including solar PV and battery storage. For a company paying main-rate corporation tax (25%), that means 25p back on every £1 of capex — claimed on the corporation tax return for the period the capex is incurred. A £400k system saves you £100k in corporation tax.

Solar PV plant is main pool plant. Some integrated building items may end up special rate — but the panel array, inverters, mounting and DC infrastructure all qualify for main pool treatment, which means full Writing Down Allowance under AIA after Year 1 if you don't use Full Expensing.

Not on the same asset. AIA covers the first £1m of plant per group; Full Expensing covers the rest. Most companies use AIA on smaller items where they need 100% relief and Full Expensing on the major plant. We model both routes side by side.

A balancing charge — broadly the lower of (sale price) or (original Full Expensing claimed) gets added back to taxable profits in the year of sale. For solar this rarely matters; PV is sold as part of a building sale, where capital allowances transfer to the buyer.

A third-party investor pays for and owns the solar PV asset. You, the site host, sign a long-term contract (15–25 years) to buy electricity from them at a fixed pence/kWh rate. The PPA rate sits 6–9p/kWh below grid prices for typical UK commercial sites in 2026.

Two things. First, the rate escalator — most PPAs include 1.5–3% annual escalation, often linked to RPI or CPI. Over 25 years that adds up. Second, the exit terms. Selling the building or vacating the site mid-PPA typically triggers a buyout — make sure the buyout schedule is in your favour from year 7 onward.

Yes. The PPA funder can take the grant on your behalf and pass through a lower headline tariff. This is common on IETF-funded projects where the host doesn't want capex but does want the grant value.

Most PPAs include a buyout schedule from year 7 or 10. Typical buyout values are 75–85% of fair market value at the buyout date. We always negotiate caps on the buyout multiple.

Allow 6–10 weeks of effort for an IETF or PSDS application, of which roughly half is energy data and modelling. The funder then takes 8–12 weeks to score. Total from kickoff to grant decision: 16–22 weeks.

Yes, and it usually is. The application requires a detailed design, supplier quotes and financial model — those documents are also what the installer needs. We sequence the work so the same outputs feed both streams.

Rejection feedback usually identifies one or two scoring weaknesses. Depending on the funder, you can resubmit in the next window with a strengthened application. About 40% of our rejected-then-resubmitted IETF applications succeed on second attempt.

No. All UK solar grants require the project to be unstarted on the day the application is submitted. Spend incurred before that date is not eligible. This is a hard rule and is the most common reason grants are clawed back.

A Heat Decarbonisation Plan (HDP) is required for most PSDS Phase 4 applications. It is a structured technical assessment of how an estate will move off fossil heat. Typical HDP development is 4-8 weeks per estate, including Stage 4 RIBA-equivalent surveys, IES VE-equivalent modelling, and phased capex scheduling.

12-16 weeks for sub-1MW commercial rooftop projects. Larger projects (1MW+ or ground-mount) typically take 16-24 weeks. The DNO connection is usually the long pole — G99 turnaround is 60-110 working days depending on region. Most IETF and PSDS awards have 12-month milestone schedules giving comfortable timeline headroom.

Probably yes, but more slowly. Most commercial PV models assume 6–9% wholesale energy inflation; if grid prices flatline at £160/MWh for the next decade, payback periods extend by 12–18 months. With Full Expensing or a grant, the project still beats most other capex options on IRR.

You contact a SEG-licensed supplier (Octopus, EDF, E.ON Next, Scottish Power, etc.), provide your MCS certificate and meter point details, and switch your export contract. Payments come monthly or quarterly against your half-hourly export readings. You can hold import with one supplier and export with another.

Yes — annual visual inspection, electrical test every 3 years, inverter replacement at year 12–15. Budget £8–£15/kWp/year for full O&M with monitoring. Most projects bundle 2 years of O&M into the install contract.

Tier 1 modules carry 25–30 year linear performance warranties; in practice good systems are still producing 85% of nameplate output at year 30. The financial model treats panels as a 25-year asset with ~0.5% per annum degradation.

Three things: contractor's all-risk during install (provided by installer), insurance-backed warranty for the post-install period (provided through MCS-aligned schemes), and your standard property insurance updated to declare the asset. Insurance-backed warranty is non-negotiable for grant-funded projects.

Yes — the UK Subsidy Control Act 2022 replaced EU state aid. For solar grants the practical rule is "no double-funding". You cannot stack two grants from different government programmes for the same plant. You can stack a grant with tax allowances and SEG.

Clawback. The funder can demand return of the grant plus, in some cases, interest. Common breach causes: project not completed on time, asset sold within the qualifying period, monitoring data not provided. We build the grant compliance schedule into the project plan from day one.