What Is the Non-Domestic Renewable Heat Incentive
The UK Non-Domestic Renewable Heat Incentive (ND RHI) supported biomass boilers, heat pumps, and biomethane for businesses and public bodies for years—but it closed to new applicants on 31 March 2021. If you still operate an accredited installation, compliance and metering obligations continue, and payments remain subject to DESNZ rules. If you are planning new heat investment today, you must look at current capital grants, tax tools, and carbon reporting expectations informed by levy exemptions and Climate Change Committee pathways rather than the legacy tariff.
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Key takeaways
- No new ND RHI accreditations post-March 2021—budget business cases must use today’s instruments.
- Existing participants must maintain eligible heat uses, metering, and reporting or risk payment stops and clawback.
- Heat interacts with electricity strategy—coordinate with on-site HH metering if electrifying.
- Carbon budgets and CCC advice push industrial heat decarbonisation—track policy, not only retail gas tariffs.
- Ofgem administered aspects historically; current scheme administration sits with DESNZ—verify portals for your vintage.
What ND RHI did while open
The programme paid participants for qualifying renewable heat output over time, subject to efficiency tiers, sustainability criteria for biomass, and strict metering arrangements. That shifted lifetime economics for hotels, farms, and manufacturers willing to operate assets diligently. It also trained a generation of energy managers in heat metering discipline—skills that still matter under SECR-style reporting and net-zero roadmaps.
Because payments were tied to useful heat, accidental export of heat to ineligible loads or poor calibration could depress income. Many sites paired RHI thinking with demand-side measures first—insulation and controls still beat oversized boilers.
Operating a legacy accreditation responsibly
Keep meter certificates, maintenance logs, and fuel sustainability documentation where biomass applies. Map process changes: if production lines move off the heated zone, you might alter eligible load. Treat audits like tax inspections—prepared sites survive spot checks with minimal drama.
Electrification projects (heat pumps, electric steam) may interact with your electricity capacity agreements and maximum demand charges—model both fuels, not only kWh prices.
What replaces ND RHI for new capex (high level)
Government portfolios shift with budgets. Businesses today often stitch together enhanced capital allowances (where available), targeted public sector grants for specific sectors, and private finance for efficiency bundles. There is no single like-for-like ND RHI successor—procurement teams must stress-test IRR under multiple policy scenarios suggested in CCC progress reports to Parliament.
Gas markets still reference NBP and global LNG flows; National Grid ESO’s electricity balancing costs may rise if your electrified heat adds evening peaks. None of that negates decarbonisation—it just belongs in the business case.
Regulatory interfaces beyond DESNZ
Environmental permitting, local air quality rules, and planning can constrain biomass upgrades. Ofgem’s world is more about electricity/gas supply licences than heat equipment, but your retail contracts still price the commodity you burn or displace.
Legacy participant compliance checklist
| Control | Evidence | Cadence |
|---|---|---|
| Meter accuracy | Calibration certs | Annual review |
| Eligible heat use | Process diagrams | On plant change |
| Biomass sustainability | Fuel receipts + specs | Per delivery |
| Maintenance | Service tickets | OEM schedule |
| Reporting | Portal submissions | As mandated |
New-project planning prompts
- Model electricity import limits with your DNO before sizing electric heat.
- Align capex with SECR/ESOS cycles if your organisation qualifies.
- Track DESNZ guidance updates—heat policy moves faster than many assume.
- Benchmark gas retails using forward curves but stress-test carbon costs using CCC scenario language for boards.
Integrating legacy heat assets with today’s electricity strategy
RHI-era boilers and heat pumps were sized for past loads. Before electrifying further, update heat profiles using current production schedules. Coordinate with DNOs if new chillers or compressors will raise winter electricity peaks that offset gas savings.
Carbon reporting should treat legacy renewable heat and grid electricity consistently—avoid double-counting savings when exporting waste heat internally. Finance teams may want parallel models: commodity-only opex versus full lifecycle carbon costs suggested in CCC decarbonisation narratives.
Working with consultants and installers
Choose partners who can speak both RHI-era compliance and today’s heat pump quality schemes. Ask for references where they handled metering disputes or seasonal performance gaps—not only installation photos.
Contract split risk: separate payments for design, install, and commissioning so acceptance criteria are enforceable. Align warranty periods with expected run-hours and fuel types for biomass plants.
Closing practical notes
If you are unsure whether historic RHI paperwork matches today’s plant configuration, commission an independent compliance spot-check before regulators raise questions—proactive fixes cost less than interrupted payments.
If you are unsure whether historic RHI paperwork matches today’s plant, commission an independent compliance review before the next audit window—small paperwork gaps can become expensive interruptions.
Related guides
Read green tariffs for business and net-zero planning, or browse the energy hub.
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