Solar Photovoltaic Systems Inspection

Per CSA C22.1 Section 64 and provincial electrical safety authority requirements, all solar PV installations require an electrical permit and must comply with the Canadian Electrical Code. System design documents must include single-line diagrams, equipment specifications, structural load calculations per NBC Part 4, and confirmation that the installation meets local utility interconnection requirements for microFIT or net metering programmes.

1. Verify that a valid electrical permit has been issued by the provincial electrical safety authority (e.g., ESA in Ontario)

2. Confirm single-line diagram matches the installed system configuration, including module count, string layout, and inverter sizing

3. Review structural engineering assessment confirming the roof can support additional dead and live loads per NBC Part 4

4. Check that equipment is listed and labelled to applicable CSA standards (modules to CSA C22.2 No. 330, inverters to CSA C22.2 No. 107.1)

5. Verify utility interconnection application approval and compliance with provincial net metering or microFIT programme requirements

- Installation commenced without obtaining the required electrical permit

- System design documents not matching as-built conditions on site

- Structural assessment not performed for roof-mounted arrays, risking overloading

- Equipment not certified to applicable CSA standards

Per CSA C22.1 Section 64 and NBC Part 4, PV modules must be securely mounted using racking systems designed for Canadian wind and snow loads. Roof penetrations must be properly flashed and sealed to maintain the building envelope. Mounting hardware must be corrosion-resistant and compatible with the roofing material. Setback distances from roof edges must comply with local fire code requirements for firefighter access.

1. Verify racking system is installed per manufacturer's specifications with correct bolt torque values and spacing

2. Confirm all roof penetrations are properly flashed, sealed with compatible sealant, and do not compromise roofing warranty

3. Check module setback distances from roof edges, ridges, and valleys per local fire code requirements (typically 0.9 m minimum)

4. Verify mounting hardware is stainless steel or otherwise rated for the corrosion exposure class

5. Confirm modules are oriented and tilted per design documents, with adequate spacing for snow shedding

- Roof penetrations improperly sealed leading to water ingress

- Racking not designed for local snow and wind loads per NBC Part 4

- Insufficient setback distances compromising firefighter roof access

- Dissimilar metals in mounting hardware causing galvanic corrosion

Per CSA C22.1 Section 64, DC wiring for PV systems must use photovoltaic wire (PV wire) or other approved cable types rated for the maximum system voltage and current. All DC conductors must be routed in approved raceways or secured with appropriate cable management. String voltages must not exceed inverter maximum input voltage at the lowest expected ambient temperature. Connectors must be mating pairs from the same manufacturer.

1. Verify all DC conductors are PV wire or approved type, properly sized for the string current with applicable correction factors per CSA C22.1 Table 2

2. Confirm string open-circuit voltages at lowest expected temperature do not exceed inverter maximum DC input voltage

3. Check that all MC4 or equivalent connectors are from the same manufacturer (no cross-brand mating) and properly latched

4. Verify DC conductors are secured, supported, and protected from physical damage per CSA C22.1 Section 12

5. Confirm polarity is correct at all string connections and combiner boxes

- Mismatched connector brands creating unreliable connections and fire risk

- DC string voltage exceeding inverter maximum at low winter temperatures

- Conductors not properly supported or protected from UV exposure

- Polarity reversal at combiner box or inverter input terminals

Per CSA C22.1 Section 64 and CSA C22.2 No. 107.1, inverters must be listed and labelled for the application. The AC output connection must comply with CEC requirements for overcurrent protection, grounding, and disconnection means. The inverter must be installed per manufacturer's specifications with adequate ventilation clearances. Anti-islanding protection must function per CSA C22.2 No. 330 to disconnect from the grid during a utility outage.

1. Verify inverter is CSA-listed and the nameplate rating matches design specifications

2. Confirm AC overcurrent protection is sized per CSA C22.1 Section 64 (typically 125% of continuous output current)

3. Check that a visible, lockable AC disconnect switch is installed between the inverter and the utility connection point

4. Verify inverter mounting provides required manufacturer clearances for cooling airflow

5. Confirm anti-islanding protection settings comply with CSA C22.2 No. 330 and local utility requirements

- AC overcurrent protection incorrectly sized for the inverter output

- Missing or inaccessible AC disconnect switch for utility workers

- Inverter installed without adequate ventilation clearances causing overheating

- Anti-islanding settings not configured to local utility specifications

Per CSA C22.1 Sections 10 and 64, all exposed metal components of a PV system must be bonded to the equipment grounding conductor. The grounding electrode system must comply with CEC Section 10. Module frames, racking, junction boxes, and inverter enclosures must be bonded using listed grounding devices. Ground fault protection must be provided for the DC system per Section 64.

1. Verify all module frames are bonded to the equipment grounding conductor using listed lay-in lugs or grounding clips per manufacturer's instructions

2. Confirm racking system bonding continuity from all rails and supports back to the grounding electrode conductor

3. Check that the grounding electrode conductor is connected to the building grounding electrode system per CSA C22.1 Section 10

4. Verify DC ground fault protection device is present and functional per CSA C22.1 Section 64

5. Test bonding continuity with a low-resistance ohmmeter to confirm all connections are below 1 ohm

- Module frame grounding clips missing or improperly installed

- Racking bonding jumpers omitted at splice points between rail sections

- Grounding electrode conductor undersized for the system

- DC ground fault detection not operational or not tested during commissioning

Per CSA C22.1 Section 64, PV systems require specific warning labels and identification at all disconnects, junction boxes, and the main electrical panel. Labels must indicate the presence of multiple power sources, maximum voltage, and the location of disconnecting means. Commissioning must include functional testing of all protective devices and performance verification per the design specifications.

1. Verify warning labels are present at the main service panel indicating a secondary power source per CSA C22.1 Section 64

2. Confirm all DC and AC disconnects are labelled with system voltage, current, and the "SOLAR PV" designation

3. Check that a permanent plaque or directory is posted near the main panel listing the location of all PV disconnecting means

4. Review commissioning test records including insulation resistance, open-circuit voltage, short-circuit current, and inverter functional tests

5. Verify that as-built drawings and the operation and maintenance manual have been provided to the building owner

- Missing or illegible warning labels at the main electrical panel

- DC disconnect not labelled with maximum system voltage

- Commissioning tests not performed or records not retained

- As-built documentation not provided to the building owner or authority having jurisdiction