Solar projects fail compliance at every stage — not just at the permit desk. A permit rejection at week four costs far less than a failed utility interconnection at week twelve, which in turn costs far less than a post-commissioning enforcement notice. The damage compounds with each stage. A structured, stage-by-stage checklist prevents that compounding.
This guide covers all six compliance phases — pre-design, design, permitting, installation, commissioning, and post-commissioning — with a universal checklist applicable to any market. The second half provides market-specific checklists for the USA, Australia, UK, India, and Singapore. Use the universal checklist on every project, then layer on the market-specific items that apply to your installation country.
This Checklist Covers Universal Requirements
Always supplement with the country-specific compliance guide for your market. Use the market-specific sections below for USA, Australia, UK, India, and Singapore — and link through to the full country guides for complete regulatory detail.
Universal Compliance Checklist
The items below apply regardless of market. Every phase must be completed in sequence — skipping pre-design compliance work to save time reliably produces rework in later phases.
Phase 1: Pre-Design
- Identify the applicable electrical installation standard for the project location (NEC, AS/NZS 5033, BS 7671, CEA, IEC 62548)
- Identify the applicable grid connection standard (G98/G99, VDE-AR-N 4105, AS 4777.2, EMA Rules)
- Confirm whether the net metering or FiT scheme is currently open and the current export rate
- Verify installer certification requirements for this market and confirm all certifications are current and not expired
- Confirm AHJ or DNSP/DSO requirements specific to this site, including any local amendments to national standards
Phase 2: Design
- String voltage calculation completed within limits (NEC 690.7, IEC 62548, AS/NZS 5033 Section 3) using the minimum expected temperature at the site
- Overcurrent protection sizing verified (NEC 690.9 or local equivalent)
- Conductor ampacity verified with all applicable derating factors applied (NEC 310 or local equivalent)
- Shading analysis completed for all orientations and seasons
- All selected equipment is on the applicable approved product list (ALMM India, CEC approved products AU, ENA/G98 inverter list UK)
- Fire safety setbacks and access aisle requirements met (SCDF Singapore, IFC USA, or local code)
- Structural load calculation completed and stamped where required by the AHJ or DNSP
Phase 3: Permitting
- Building or electrical permit application submitted, or notification filed per market requirements
- Grid connection or export registration application submitted to the relevant utility or DSO
- All required drawings prepared: single-line diagram, site plan, equipment schedules, mounting detail drawings
- Correct submission format confirmed for the relevant AHJ (PDF, DWG, SolarAPP+ portal, or local portal)
Phase 4: Installation
- Installed equipment matches the specifications in the approved permit documents
- Labeling and signage installed per applicable standard (NEC Article 690 Part VI, AS/NZS 5033 Clause 5, or local equivalent)
- Rapid shutdown device installed where required (NEC 690.12 — USA building-mounted systems)
- Conduit fill and wiring methods confirmed compliant with the applicable standard
- Earth and grounding system installed correctly per applicable standard
Phase 5: Commissioning
- Licensed Electrical Worker, CEC accredited installer, or MCS-certified installer sign-off obtained as applicable to the market
- All protection relay settings tested against the applicable grid connection standard (G99 UK, AS 4777.2 AU, VDE-AR-N 4105 DE)
- Export meter or smart meter installed and tested
- Grid export formally registered with the utility or DSO
Phase 6: Post-Commissioning
- National registry registration completed where required (MaStR Germany, MCS Certificates UK, Clean Energy Regulator STC registration AU)
- Permit closed out with the AHJ
- FiT, net metering, or export scheme enrollment confirmed in writing
- O&M documentation and all warranty documentation handed to the client
Common Failure Points
The table below identifies the checklist items most often skipped, the consequence of skipping them, and the markets where this failure is most common.
| Checklist Item Skipped | Consequence | Most Common Market |
|---|---|---|
| Pre-design: minimum temperature for string voltage calculation | String voltage exceeds 600 V residential limit; plan rejection, redesign required | USA (NEC 690.7), Australia (AS/NZS 5033) |
| Pre-design: export scheme availability check | System designed for net metering in a market with a closed or capacity-capped scheme; business case collapses | UK (G98 queue), India (state DISCOM caps) |
| Design: equipment on approved product list | ALMM non-compliance disqualifies subsidy claim; CEC list mismatch fails DNSP notification | India (ALMM), Australia (CEC list) |
| Permitting: grid connection application timing | Critical path extends by 30–180 days waiting for utility review | USA (interconnection queue), Japan, Brazil |
| Installation: labeling and signage | AHJ fails inspection; reinspection fee and project delay | USA, Australia |
| Installation: rapid shutdown | Fails inspection; NEC 690.12 requirement missed entirely for building-mounted systems | USA |
| Commissioning: protection relay testing | System connected without relay verification; DNSP can disconnect and impose reconnection fees | UK (G99), Australia (DNSP rules) |
| Post-commissioning: STC registration deadline | 12-month deadline missed; STCs become ineligible | Australia (CER) |
| Post-commissioning: MaStR registration | Fine up to €5,000 for failure to register within one month of commissioning | Germany |
Design Systems That Pass Compliance First Time
SurgePV calculates string voltage to NEC 690.7, AS/NZS 5033, and IEC 62548 automatically, runs shading analysis, and exports a complete permit package — single-line diagram, site plan, and equipment schedules.
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Step-by-Step: How to Use This Checklist
Start with the pre-design compliance check before touching design software
Before opening solar design software, identify: the applicable electrical standard, the grid connection standard, whether the export scheme is open, and what installer certification is required. Getting these wrong forces complete redesign after permit submission. Five minutes at this stage prevents five days of rework at the permitting stage.
Run string voltage calculations before finalising equipment selection
String voltage must comply with both the maximum system voltage (1000 V NEC / 1500 V for utility scale; 600 V for some older AHJs) and the minimum start voltage for the inverter. Calculate using the lowest expected temperature at the site — not standard test conditions. Solar software that auto-calculates to NEC 690.7, AS/NZS 5033, or IEC 62548 eliminates this error. Run the calculation before ordering equipment, not after.
Submit the grid connection application as early as possible
In markets with long utility interconnection queues — USA: 30–180 days; Japan: 60–120 days; Brazil: 30–90 days — the utility application is the critical path, not the building permit. The building permit can often be obtained while the utility application is in review. The reverse is not possible. Submit the grid connection application immediately after the design is confirmed.
Match commissioning sign-off requirements to the market before scheduling the commissioning visit
Commissioning requirements vary significantly by market. G99 UK systems need protection relay testing by a qualified engineer — this cannot be done by the installation crew. CEC AU installers must complete a compliance declaration before STC registration. Singapore LEW must physically sign off on the installation. India DISCOM inspectors may visit the site. Booking the commissioning visit without confirming these requirements creates avoidable delays. Use the market-specific checklists below.
USA-Specific Checklist
For full detail see the USA solar compliance guide.
Pre-Design:
- Confirm local AHJ has adopted NEC 2017, 2020, or 2023 — do not assume the current edition applies
- Confirm whether the AHJ uses SolarAPP+ or a manual plan review process
- Verify installer holds required state electrical contractor licence or NABCEP certification
- Confirm whether the utility’s interconnection queue is open and its current review timeline
Design:
- Maximum system voltage calculated per NEC 690.7 using ASHRAE extreme minimum temperature for the location
- Overcurrent protection sized per NEC 690.9 (minimum 125% of Isc, DC-rated devices)
- Conductor sizing and derating per NEC 690.8 and NEC Table 310.16 (add 22°C for rooftop conduit)
- Rapid shutdown system designed per NEC 690.12 for all building-mounted systems
Permitting:
- Submit interconnection application to the utility (Form varies by state — check utility tariff)
- For SolarAPP+ jurisdictions: upload design to solarapp.nrel.gov for automated permit review
- Required drawing set: single-line diagram, site plan with setbacks, equipment schedules, NEC label plan
Installation:
- Rapid shutdown initiator labelled per NEC 690.56
- All DC overcurrent devices are DC-rated at the system voltage
Commissioning:
- Utility inspection completed; Permission to Operate (PTO) issued in writing
- Federal ITC documentation prepared (Form 3468 for commercial, Schedule 3 for residential)
Post-Commissioning:
- Permit closed out with AHJ
- ITC claim filed with applicable tax return
Critical USA Step: Interconnection Application Timing
FERC Order 2023 (effective 2025) reformed the federal interconnection queue, but many utility interconnection timelines remain 60–180 days for residential projects. Submit the interconnection application to the utility the same week the design is finalised. Do not wait for the building permit to be issued first.
Australia-Specific Checklist
For full detail see the Australia solar compliance guide.
Pre-Design:
- Confirm the CEC accreditation of the installing electrician is current (check CEC public register)
- Confirm DNSP notification requirements for the site (varies by network area)
- Confirm whether the applicable DNSP has export limits or local rules beyond AS 4777.2
Design:
- String voltage and configuration compliant with AS/NZS 5033:2021 Section 3
- Inverter on CEC approved product list (check cleanenergycouncil.org.au)
- Modules on CEC approved module list
- Anti-islanding and protection settings compliant with AS 4777.2
Permitting:
- DNSP notification submitted (for systems within the standard size limits under the simplified notification process)
- Required documents: single-line diagram, site plan, inverter data sheet, module data sheet
Installation:
- AS/NZS 5033:2021 labelling requirements met on all switch and isolator labels
Commissioning:
- CEC compliance declaration completed
- DNSP notified of commissioning date (where required by network)
Post-Commissioning:
- STC registration submitted to the Clean Energy Regulator within 12 months of installation
- Feed-in tariff enrolment confirmed with electricity retailer
Critical Australia Step: STC Registration Deadline
Small-scale Technology Certificates must be registered with the Clean Energy Regulator within 12 months of installation. Missing this deadline makes the entire STC entitlement ineligible. Register through the REC Registry as soon as commissioning is complete — do not batch these at the end of a quarter.
UK-Specific Checklist
For full detail see the UK solar compliance guide.
Pre-Design:
- Determine whether the system falls under G98 (fit-and-inform, up to 3.68 kVA per phase) or G99 (pre-approval required, above 3.68 kVA per phase)
- Confirm whether the installer holds MCS certification — required for Smart Export Guarantee (SEG) eligibility
- Check DNO-specific requirements for the network area (Electricity North West, UK Power Networks, SP Energy Networks, etc.)
Design:
- Electrical installation designed to BS 7671:2018 (18th Edition) including Amendment 2 (2022)
- Inverter on the ENA/G98 type-tested list (for G98 systems)
- For G99 systems: protection relay settings confirmed with DNO before equipment ordering
Permitting:
- G98: submit fit-and-inform notification to DNO within 28 days of commissioning
- G99: submit full application to DNO and receive approval before commencing installation
- Planning permitted development rules confirmed (or full planning application submitted where required)
Commissioning:
- BS 7671 18th Edition electrical installation certificate completed
- For G99 systems: protection relay testing completed by a qualified engineer; DNO commissioning witnessed
Post-Commissioning:
- MCS Installation Certificate issued to customer (required for SEG eligibility)
- SEG application submitted to the customer’s chosen SEG licensee
- G98 notification confirmed received by DNO
Critical UK Step: G98 vs G99 Threshold
The 3.68 kVA per phase threshold is commonly misapplied. A single-phase system above 3.68 kVA requires G99 pre-approval — not G98 fit-and-inform. G99 pre-approval adds 6–12 weeks to the programme. Determine the applicable procedure before site survey, not after equipment selection.
India-Specific Checklist
For full detail see the India solar compliance guide.
Pre-Design:
- Confirm the applicable state SERC net metering order and current export rate (APPC or state-specific rate)
- Confirm whether the DISCOM’s net metering capacity allocation for the area is open
- Verify vendor is registered on the PM Surya Ghar portal (pmsuryaghar.gov.in) if claiming central subsidy
Design:
- Modules on MNRE ALMM List I (mandatory for subsidised residential installations)
- Inverters on MNRE ALMM List II (mandatory for subsidised installations)
- System designed to CEA Technical Standards for Connectivity of Distributed Generation Resources 2022
- BIS-certified modules and inverters confirmed
Permitting:
- DISCOM interconnection application submitted with: load sanction letter, site plan, single-line diagram, ALMM compliance declaration, inverter and module spec sheets
- PM Surya Ghar application submitted on national portal if claiming central financial assistance
Installation:
- ALMM-listed and BIS-certified equipment confirmed on site before installation commences
- Net metering meter installation coordinated with DISCOM
Commissioning:
- DISCOM inspection completed and commissioning certificate issued
- Subsidy disbursement triggered via PM Surya Ghar portal
Post-Commissioning:
- Net metering agreement signed with DISCOM
- First net metering bill reviewed for correctness
Critical India Step: ALMM Compliance Before Procurement
Sourcing modules or inverters not on the ALMM list before confirming eligibility is the most common and most costly mistake in India. The customer loses the PM Surya Ghar central financial assistance — up to Rs. 78,000 for a 3 kW residential system — and the project cannot be retrofitted with compliant equipment without removing and replacing installed kit. Always verify the specific model is on the current ALMM list, not just the brand name.
Singapore-Specific Checklist
For full detail see the Singapore solar compliance guide.
Pre-Design:
- Determine system capacity relative to the 1 MWac EMA Generation Licence threshold
- Confirm export scheme: SCT (fixed rate, approximately S$0.20/kWh via SP Services) or ECIS (USEP-based market rate, capped at 10 MWac)
- Confirm whether the building is a JTC-leased property and whether JTC written consent is required before any rooftop works
- Identify whether SCDF Fire Code Clause 10.2 clearance is required for the installation
Design:
- Electrical design compliant with the Singapore Electricity Act and EMA regulatory requirements
- BCA structural assessment confirmed (required if roof strengthening, mounting platforms above 2.5 m, or panel array acting as roof shelter above 10 sqm)
- Inverter and module specifications prepared for SP Services export registration
Permitting:
- BCA CORENET building plan application submitted where required
- SCDF clearance obtained where Fire Code Clause 10.2 applies
- JTC written consent obtained for JTC-leased buildings
Installation:
- Licensed Electrical Worker (LEW) engaged and supervising all electrical works
- Metering arrangement prepared per SP Services export registration requirements
Commissioning:
- LEW provides commissioning sign-off and signs the Electrical Installation Licence (EIL)
- SP Services Export Registration Form completed; export meter installed
Post-Commissioning:
- For systems at or above 1 MWac: EMA Generation Licence in place before grid connection; EMC Market Participant registration completed
- ELISE portal notification submitted for systems at or above 1 MWac
- First SP Services export credit invoice reviewed
Critical Singapore Step: LEW Engagement and JTC Consent
Two parallel sign-offs are required before any physical work begins on a Singapore rooftop installation: the LEW engagement (mandatory for any grid-connected electrical works under the Electricity Act) and, for JTC-leased buildings, JTC Corporation’s written consent. Neither can be obtained after works have commenced. Installing before obtaining JTC consent can constitute a breach of the lease.
Using Solar Design Software for Compliance
Solar design software eliminates the most common design-phase compliance errors. The string voltage calculation error (wrong minimum temperature, or wrong voltage limit for the jurisdiction) is the leading cause of plan review rejections globally. Automated calculation against the applicable standard — NEC 690.7, AS/NZS 5033 Section 3, or IEC 62548 — removes the manual step where the error occurs.
Beyond string voltage, compliant solar software handles:
- Shading analysis across all orientations and seasons, supporting both the design and the permit package
- Single-line diagram generation to the required format for the applicable AHJ
- Equipment schedules that match the spec sheets for permit submission
- Generation and financial reports that support interconnection applications and customer proposals
See the solar compliance hub for country-specific guides covering the full regulatory stack for each market.
Frequently Asked Questions
What documents are required in every solar permit application?
Regardless of market, most permit applications require: (1) a single-line electrical diagram, (2) a site plan showing panel layout and setbacks, (3) equipment specification sheets for panels, inverter, and mounting system, and (4) installer licence or certification details. Some markets — USA AHJs using SolarAPP+, India DISCOM portals — have specific digital format requirements for submissions.
What is the most common reason solar permits get rejected?
Documentation mismatches and non-compliant electrical calculations are the top two rejection causes globally. Specifically: string voltage calculations that don’t account for the correct minimum temperature (NEC 690.7 in the USA), single-line diagrams that don’t match actual equipment specs, and missing equipment approvals (ALMM list in India, CEC approved product list in Australia). These are all preventable with a pre-submission check against this checklist.
Is a structural engineer’s stamp required for rooftop solar?
In most markets, a structural engineer (PE in USA, structural engineer in UK, BCA-registered PE in Singapore) is only required when: (1) structural modifications are needed, (2) the roof cannot be verified as compliant with standard load tables, or (3) the system exceeds a size threshold — typically above 30 kW or 10 kWp in some markets. Standard flush-mounted residential systems on conventional tiled or metal sheet roofs typically do not require a structural PE stamp. The exception is where the AHJ has adopted a local rule requiring PE stamps on all solar installations — confirm this at the pre-design stage.
How long should solar compliance documentation be retained?
USA: IRS requires documentation for at least 3 years for ITC claims, longer where property depreciation applies. Australia: Clean Energy Regulator requires STC records for 5 years. UK: MCS certificate records must be kept for 15 years. Singapore: EMA requires electrical installation records for the life of the installation. The safest approach globally is to retain all permits, commissioning reports, and equipment certifications permanently. Digital storage costs nothing compared to the cost of reconstructing records for an audit or warranty dispute.
