Guide for solar O&M and site survey teams · checked 6 November 2026
Field service software for solar O&M and site survey teams with technicians across many states
A solar O&M team is paid on availability. An inverter that trips on an isolation fault at 10 am is lost energy until someone with the right permit, the right spare and the right training reaches it, and every hour of that outage has to land in the right category on the owner's monthly report. Site survey teams have the opposite problem: hundreds of techs in dozens of states, each visit judged on whether the design team gets a busbar rating, rafter spacing and shade data it can build on. This guide covers NREL's O&M practices, availability guarantees, I-V curve tracing, inverter fault codes, NABCEP credentials, the 120% rule and what each record should hold.
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Short answer
Solar O&M providers usually run a monitoring platform plus an O&M work order tool: Power Factors Unity, Raptor Maps, 60Hertz and meteocontrol's VCOM CMMS are built for renewables. Survey teams often use photo-checklist tools like SiteCapture. What matters is an equipment register down to inverter and string, alarms that become tickets, permit-to-work before energized work, spares tracked across regional stores, outage hours logged by category for the availability guarantee, and survey forms that block a visit from closing without the panel label and rafter data. Fieldproxy is one option. Best for processes that don't fit a template, set up for you: it is built around your sites, your contract's availability terms, your stores and your survey checklist, with dispatch by state license.
$11/kWac-yr
Median utility-scale PV O&M cost in 2025 (about $7/MWh), across 173 utility-owned plants totaling 9.1 GWac
source: Berkeley Lab, Utility-Scale Solar 2026 Edition, briefing slides (O&M costs from FERC Form 1)
98% / 99%
Availability in NREL's example performance guarantee: 98% in year one, 99% in later years
10 days
NREL's typical contract response for non-safety corrective maintenance, 'or less'; safety faults are fixed as soon as possible
About 5%
Accuracy limit of a standard field I-V curve tracer, set by its irradiance, temperature and electrical sensors
How a job runs
One solar o&m and site surveys job, from first call to paid
The order the work really happens in, and what has to be written down at each step so nothing is argued about later.
- 1
The monitoring system raises an alarm
An inverter at a 20 MW site drops offline with a fault code. Codes are model-specific: on SolarEdge units, for example, an engineering services firm lists 18x37 and 18x38 for grid voltage out of range, 18x75 for over-temperature, 03x9a and 18x86 for isolation faults and 18xC for an arc fault. The ticket needs the code, the device, the time and the capacity behind it.
- 2
Triage: reset, batch or roll a truck
Grid voltage trips often clear; isolation and arc faults should not be reset remotely and need a qualified tech on site. NREL says contract response for non-safety corrective work is typically 10 days or less, that safety faults are fixed as soon as possible, and that small residential fleets often wait until enough work justifies a truck roll. The decision weighs lost revenue against the trip.
- 3
Issue the permit to work
Before anyone opens a combiner or an inverter cabinet, a permit to work names the equipment, isolation points, lockout and tag numbers, PPE and who holds the permit. NREL's model labor table expects arc-flash and lock-out/tag-out training for the electricians doing this work.
- 4
Diagnose the DC side
On site the tech reads the inverter's event log, then tests the strings behind it: open-circuit voltage, operating current and, where needed, an I-V curve trace. NREL notes field I-V tracers are accurate to about 5% and find defects that are already costing output, not latent hot spots. An infrared scan of combiner boxes finds hot terminals.
- 5
Draw the spare from the regional store
A fuse, a contactor, a fan or a whole inverter module comes from the nearest store. NREL describes regional clusters of sites sharing a warehouse, and gives a sizing formula: spares n = N x R^P / (1 - P) for N installed parts, failure probability P and target reliability R; above about 0.95 reliability it gets prohibitively expensive. The removed part goes on an RMA to the manufacturer.
- 6
Return to service and close the outage
The tech records the time the inverter is back in service, closes the permit and removes locks. The outage gets its start time, end time, kW affected and category. NREL's model availability terms use the IEC 63019 categories: full and partial capability, set points, out of environmental spec, requested shutdown, scheduled maintenance, planned corrective, forced outage, suspended and force majeure.
- 7
Run the preventive plan
NREL's model service schedule runs these yearly: visual inspection of the whole site, string Voc, current and I-V traces on a set percentage of strings, infrared scans of combiners with re-torque, sensor and pyranometer calibration checks, inverter filters, vents and heat sinks, roof penetration checks, an IR scan of a set percentage of modules, and washing once a year or per a soiling study.
- 8
Calculate availability the way the contract says
NREL's model formula is 1 minus the sum, over each incident, of unavailable hours times kW down, divided by sunlight hours in the period times plant nameplate kW. Events outside management control (OMC) are excluded, because operators should not be penalized for them. If the contract also guarantees a performance ratio, NREL's example liquidated damages are irradiation x nameplate x (expected PR minus actual PR) x the PPA rate.
- 9
Report to the owner and invoice
The month closes with availability against the guarantee, PR, tickets opened and closed with response times, PM tasks done, spares used and open RMAs. Corrective work outside the fixed fee is invoiced against the contract.
What to record
The fields every solar o&m and site surveys job should capture
Each site and its equipment
- Portfolio, site, owner, offtaker and PPA; nameplate kWdc and kWac; availability guarantee % by contract year and its exclusions
- Blocks > inverters (make, model, serial, firmware) > combiners > strings (module make, model, Wp, modules per string)
- Trackers, met station and sensors with calibration expiry dates; monitoring platform and device IDs
- Spare-parts list from the EPC handover, warranty terms per component, regional store that serves the site
Each ticket and visit
- Alarm source, fault code, device, time raised, capacity affected, safety flag (isolation, arc, ground fault)
- Permit to work: number, equipment, isolation points, lock and tag numbers, PPE, holder, issued and closed times
- Tests: string Voc and current, I-V trace file per string with irradiance and module temperature, IR images with max temperatures, torque values
- Parts used and removed with serials, RMA number; time back in service; outage category (forced, planned corrective, scheduled, grid, OMC)
Each site survey (rooftop and commercial)
- Main service panel: busbar rating, main breaker rating, open breaker positions, meter and service configuration, panel label photo cover on and off
- Attic: rafter or truss size and on-center spacing measured with a tape, signs of water damage, sag
- Each roof plane: azimuth, pitch, usable dimensions, roofing material, age and condition
- Shade: obstructions with photos and measurements; front, rear and side photos of the property
- Surveyor, state, license or certification held, time on site, QA result (pass, revisit, fix remotely)
Rules and standards
The rules that shape the work, with their sources
| Rule | What it means on the job |
|---|---|
| NREL O&M best practices: corrective response | Response time should be in the contract and is typically 10 days or less for non-safety corrective maintenance. Faults that create a safety problem are addressed as soon as possible even if little revenue is recovered. Response urgency should balance the cost of a truck roll against lost revenue. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| NREL model availability terms | Availability = 1 minus (sum of unavailable hours x kW down) / (theoretical production hours x nameplate kW). Production hours are when there is enough sun for inverters to reach operating voltage. Events outside management control are excluded. Categories follow IEC 63019, and the contract should list each inclusion and exclusion. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| NREL example performance guarantee | Expected PR = 82.8 x K x (1 minus degradation) x availability, with 0.5% degradation a year, availability 98% in year one and 99% after, and K = 1.3 for single-axis trackers. Shortfalls pay liquidated damages of irradiation x nameplate kWp x (expected PR minus actual PR) x the PPA rate per kWh. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| Availability plus response time as the O&M KPI | The Solar Energy Standardization Initiative's template O&M contract uses the availability guarantee, with response times where relevant, as the fairest indicator of the O&M provider's performance instead of PR, because availability is within the provider's control. A response time guarantee still obliges a fix on a failed inverter that barely dents plant output. source: PV Tech Power (2018), Towards a standardised contract for solar O&M (SESI template: availability guarantee plus response times) |
| NREL model PM schedule (annual items) | Visual inspection of site, arrays, equipment, racking, fence, vegetation and erosion; string Voc, current and I-V traces on a stated % of strings; switch and disconnect tests; IR scans and re-torque on combiners; sensor calibration; communications and battery backup checks; inverter vents, filters and heat sinks; roof penetrations; module IR scan on a stated %; washing yearly or per study. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| Field I-V curve tracing limits | Manual electrical testing such as Voc, operating current or I-V tracing finds DC faults monitoring misses. Standard field tracers are accurate to about 5%, and testing reveals defects that are already causing significant module failure, not hot spots that are not yet degrading output. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| Inverter fault codes: reset or send a tech | Codes are model-specific. For SolarEdge, one engineering services firm lists isolation faults (03x9a, 18x86), ground current (18x3D) and arc faults (18xC) as do-not-reset codes for a professional, grid voltage high or low (18x37, 18x38) as usually safe to reset, and over-temperature (18x75) as reset only after cooling. source: GreenLancer, SolarEdge inverter troubleshooting (error codes and when not to reset) |
| Spares sizing and regional stores | NREL gives n = N x R^P / (1 - P) for spares to stock, and says stocking above about 0.95 reliability is prohibitively expensive. It suggests regional clusters of systems sharing a warehouse, and notes the higher the contracted availability, the more spares must be held. source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018) |
| SolarPower Europe O&M Best Practice Guidelines, Version 6.0 (Feb 2025) | The sixth edition since 2016 updates chapters on plant maintenance and data management and adds new chapters on electrical safety and on common tests and inspections. source: SolarQuarter (19 Feb 2025), SolarPower Europe updates O&M Best Practice Guidelines (Version 6.0) |
| IEC 62446-1: commissioning and handover records | Defines the documentation handed to the customer and the commissioning tests, inspection criteria and documentation that verify a grid-connected PV system is safe and working. The 2016 edition widened the test and inspection regimes for larger, more complex systems. The handover pack is the baseline O&M tests are compared against. source: IEC webstore, IEC 62446-1: PV systems, requirements for testing, documentation and maintenance, grid connected systems |
| NABCEP PV Commissioning and Maintenance Specialist (PVCMS) | 24 hours of advanced training (18 on the PVCMS job task analysis, 6 on the NEC), OSHA 30 or the provincial equivalent, and 12 project credits (2 per 1 to 999 kW system, 3 per system of 1 MW or more). The exam is 70 multiple-choice questions, 60 scored. source: Midwest Renewable Energy Association, NABCEP PV Commissioning and Maintenance Specialist (PVCMS) requirements |
| NABCEP Operations and Maintenance Associate Technician (OMAT) | Entry-level O&M credential. Eligibility: a course from an associate registered training provider, or 6 months or more working for a solar company confirmed by a supervisor. Exam domains: safety 20%, core knowledge 30%, existing system infrastructure 28.3%, O&M 21.7%. 12 contact hours of continuing education per 3-year period. source: NABCEP, Operations and Maintenance Associate Technician credential (OMAT) |
| NABCEP credential ladder in 2026 | OMAT was announced in April 2026 as the associate-level entry point into the O&M career path. The existing PVCMS stays the demanding specialist credential, closer in difficulty to the PV Installation Professional (PVIP) than to the PV Associate. source: HeatSpring, What's new with NABCEP credentials in 2026 |
| NEC 705.12(B)(2) 120% rule on surveys | For a load-side connection, each panelboard with two sources must meet an approved method: 100% rule, 120% rule, sum of breakers, or a power control system. The 120% rule applies where the sources sit at opposite ends of a busbar with loads: main breaker plus solar breaker may not exceed 120% of the busbar rating. That is why a survey must record the busbar rating, not just the main. source: SolarAPP+ help center, Point of interconnection compliance methods (100%, 120%, sum of breakers, PCS) |
| What a site survey must capture | Busbar rating, main breaker size and available capacity; rafter or truss size and spacing; roof type, pitch and usable dimensions; shading across the year and obstructions; photos of every side of the property, each roof plane, the panel labels and the meter. Weak surveys force redesigns, delay permits and can fail inspection. source: GreenLancer, Solar site survey: what to capture |
| State contractor licensing (California example) | California's C-46 Solar Contractor installs, modifies, maintains and repairs thermal and PV solar energy systems, and may not take general building work except what the solar install needs. Each state has its own license and AHJ rules, so a multi-state roster tracks licenses per tech and per state. source: California CSLB, C-46 Solar Contractor classification |
| What O&M cost benchmarks include | Berkeley Lab's O&M figures come from FERC Form 1 filings by regulated utilities: supervision and engineering, maintenance, rents and training. They exclude property taxes, insurance, land royalties, performance bonds, administrative fees and overhead, so they are one part of total operating expense. source: Berkeley Lab, Utility-Scale Solar 2026 Edition, briefing slides (O&M costs from FERC Form 1) |
Rules vary by state, council and contract. Checked 6 November 2026; confirm against the source for your area before relying on it.
Numbers
Solar O&M benchmarks from NREL and Berkeley Lab
Costs are Berkeley Lab's 2025 medians for utility-owned plants over 5 MWac. Labor rates and the availability and degradation terms are inputs to NREL's 2018 O&M cost model and model contract, not market wages or industry norms. Use them to frame a contract and a crew, not to price one.
| Item | Figure | Source |
|---|---|---|
| Median PV O&M cost, 2025 | About $11 per kWac-year | Berkeley Lab 2026 edition |
| Same, per unit of energy | About $7 per MWh | Berkeley Lab 2026 edition |
| Sample behind the median | 173 projects, 9.1 GWac | Berkeley Lab 2026 edition |
| Example availability guarantee | 98% year 1, 99% later years | NREL model guarantee |
| Example module degradation in the guarantee | 0.5% per year | NREL model guarantee |
| Typical non-safety corrective response | 10 days or less | NREL best practices |
| Field I-V tracer accuracy | About 5% | NREL best practices |
| Inspector, loaded rate | $33.12 per hour | NREL cost model, 2018 |
| Inverter specialist, loaded rate | $33.17 per hour | NREL cost model, 2018 |
| Master electrician, loaded rate | $32.01 per hour | NREL cost model, 2018 |
| Network and monitoring tech, loaded rate | $45.89 per hour | NREL cost model, 2018 |
| Array cleaner, loaded rate | $14.74 per hour | NREL cost model, 2018 |
source: Berkeley Lab, Utility-Scale Solar 2026 Edition, briefing slides (O&M costs from FERC Form 1)source: Berkeley Lab, U.S. Utility-Scale Solar, 2026 Edition (1,989 projects over 5 MWac installed through 2025)source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018)
Where it breaks
Where spreadsheets and generic software fall over
Monitoring alarm emails land in a shared inbox. One inverter sends the same fault dozens of times overnight, a second inverter's arc fault is buried under them, and nobody can say when the outage started.
Each alarm becomes one ticket per device and fault, with repeats added as events. Safety codes are flagged red and cannot be closed by a remote reset.
Availability is rebuilt in a spreadsheet at month end from memory and inverter logs, and the owner disputes which hours were grid outages and which were the operator's.
Every ticket carries outage start, end, kW affected and a category from the contract. Availability is calculated from those records with the contract's own exclusions, and the owner sees the same list.
A renewable operator with 16 or 17 sites and planned regional stores worried about parts requested for jobs that never physically arrived or got fitted.
Spares are issued against a ticket, the new part's serial is scanned on install, the removed part's serial and a photo are captured, and anything issued but not fitted shows on the store's reconciliation list.
A survey tech in another state leaves without the panel label photo or the rafter spacing. The design team finds out two days later, and the revisit costs another trip.
The survey cannot be submitted until required photos and fields are present, and the panel label is read on site to check the busbar and main breaker numbers before the tech drives away.
A firm with hundreds of survey techs across 46 states schedules from a spreadsheet of names and ZIP codes. A surveyor without the right state credential gets sent, or two techs drive past each other.
Each tech has states, licenses and credentials with expiry dates, home base and capacity. Orders are matched to eligible techs by distance and calendar, and expiring licenses are flagged weeks ahead.
Entry-level technicians see an unfamiliar inverter code, reset it, and the fault comes back worse. The manual is a long PDF on someone's laptop.
A fault code library per inverter model holds the meaning, a do-not-reset flag and the steps, and the manual is attached to the inverter record so the answer is on the job.
Checklist
The solar o&m and site surveys operations checklist
Print it, or hand it to whoever runs the office side.
- Equipment register down to inverter, combiner and string at every site
- Availability guarantee, exclusions and response times from each contract stored on the site
- Alarms become one ticket per device and fault, with safety codes flagged
- Permit to work and lockout recorded before any energized or DC work
- Outage start, end, kW and category logged on every ticket
- Annual PM list per site, including I-V traces on a set % of strings and IR scans
- I-V trace files, irradiance and module temperature attached per string
- Spares issued against tickets with serials in and out; RMAs tracked to credit
- Sensor and pyranometer calibration expiry tracked
- NABCEP, OSHA and state license expiry tracked per tech
- Survey form blocks submission without panel label, rafter and roof plane data
- Survey QA result and revisit rate per surveyor
- Monthly owner report: availability vs guarantee, PR, tickets, PM done, spares
Software options
What software solar O&M and site survey teams actually use
Judge each one on whether it fits the way your jobs run, not on the feature list. Bring a real job to every demo.
Power Factors (Unity)
Owners and operators of large solar, storage and wind fleets
Renewable energy management suite: SCADA and monitoring, asset performance management, and a field service management module for work orders, scheduling, inventory and maintenance KPIs. Lists 600+ customers. Suits fleets that want monitoring and work orders in one vendor.
Raptor Maps
Solar owners, O&M providers, EPCs and IPPs
Map-based digital twin of each plant, image analytics for defects, the Solar Sentry inspection drone, and an RS Mobile App that gives techs checklist tasks and works without signal. Strong on inspection data at plant scale.
60Hertz
Solar, storage and wind operators at distributed or utility scale
O&M platform with preventive schedules built from OEM manuals, correctives, an offline mobile app with QR asset access, and an inventory tool. Built by renewable energy professionals for this work.
meteocontrol VCOM CMMS
Operators already monitoring sites in VCOM Cloud
Maintenance module inside VCOM: work orders, recurring tasks, custom form templates, service reports in your design, and a technician app with location, safety instructions and checklists.
SiteCapture
Solar installers and survey teams, including subcontracted surveyors
Guided field reporting from site survey through install and O&M, with AI checks that jobsite photos meet your requirements, work orders for teams or subcontractors, and PDF reports. Ask how it handles multi-state dispatch and licensing.
Questions to ask any vendor
- Can the register go down to inverter, combiner and string, with the contract's availability guarantee on the site?
- How do monitoring alarms become tickets, and how are repeat alarms on the same device handled?
- Does every ticket log outage start, end, kW affected and an outage category, and can availability be calculated from them with our contract's exclusions?
- Can a permit to work block a job from starting until it is approved?
- Are spares tracked by store and by serial, with removed parts and RMAs?
- For surveys: can a submission be blocked until required photos and panel data exist, and can dispatch filter techs by state license?
Bring one real solar o&m and site surveys job. We show it running in Fieldproxy.
Get DemoHow Fieldproxy is set up for this
Solar O&M and site surveys on Fieldproxy: built around how you already work
A Fieldproxy setup for solar O&M is built around the site's contract and its equipment: every inverter and string is a record, every alarm is a ticket with an outage category, and availability is calculated the way your PPA or O&M agreement defines it. For survey teams, the same setup runs a multi-state roster with licenses per tech and a survey form that will not submit until the design team has what it needs.
Module 1
Portfolio and equipment register
Tickets, PM, spares and availability all hang off a device, and the owner asks about inverter 7 in block B.
- Records: Portfolio > Site > Block > Inverter > Combiner > String; plus trackers, met station, sensors, transformers, BESS if present
- Site fields: owner, offtaker, PPA, nameplate kWdc and kWac, availability guarantee by contract year, exclusions, response times, store that serves it
- Device fields: make, model, serial, firmware, warranty end, manual attached, monitoring device ID
- Sensor calibration expiry dates with reminders
Module 2
Alarm intake and fault code library
Alarms are the start of most corrective work, and the code decides who goes and how fast.
- Alarm emails or a feed through the open API become tickets: site, device, code, time raised, kW behind it
- Repeats on the same device and code attach to the open ticket instead of creating new ones
- Fault code library per inverter model: meaning, safety flag (isolation, arc, ground fault), do-not-reset flag, first steps
- Statuses: New, Triaged, Remote reset, Truck roll, Waiting on parts, Waiting on OEM, Back in service, Closed
Module 3
Permit to work and lockout
No one should open a combiner or inverter without a permit and locks recorded.
- Permit record: equipment, isolation points, lock and tag numbers, PPE level, holder, approver, issued and closed times
- A ticket marked energized or DC work cannot move to In progress until its permit is approved
- Holder must have the required training on file (e.g. arc flash, lockout)
- Permit closes only after back-in-service time is recorded and locks are removed
Module 4
Preventive maintenance plan per site
The O&M agreement lists the tasks and frequencies; the plan should match it line for line.
- Task templates from your agreement, e.g. NREL's annual list: site visual, string Voc and current, I-V on a stated % of strings, combiner IR and re-torque, inverter vents, filters and heat sinks, module IR on a stated %, washing per soiling study
- Visits generated per site per month, grouped by region for crew travel
- PM completion % per site per month for the owner report
Module 5
Field test forms
I-V curves and IR images are only useful if they are tied to the string and the conditions they were taken in.
- String test form: Voc, Isc or operating current, irradiance, module temperature, I-V trace file attached, pass or investigate
- IR form: device, max temperature, delta to reference, image, re-torque value
- Offline in the field; syncs back when the tech has signal
- Results stored on the string or combiner so the next test compares against the last
Module 6
Spares, regional stores and RMAs
Contracted availability sets how many spares you hold, and every part has to be accounted for.
- Stores (e.g. North and South) and van stock; min levels per part per store
- Issue against a ticket only; scan the new part's serial on install, capture the removed part's serial and photo
- Reconciliation list: issued but not fitted, fitted but not issued
- RMA record per failed part: manufacturer case number, ship date, credit or replacement received
Module 7
Availability and outage ledger
This is the number the contract is judged on, so it should come from tickets, not a month-end spreadsheet.
- Outage event on each ticket: start, end, kW affected, category (forced, planned corrective, scheduled, grid, curtailment, force majeure, OMC)
- Availability calculated per site with the contract's formula and exclusions; running month-to-date figure
- PR and expected PR by month where the contract guarantees it
- Owner can see and comment on each event's category before the month closes
Module 8
Site survey program
A survey is only done when the design team can design from it.
- Survey orders from your sales or design system, or emailed by installer clients
- Survey form: busbar rating, main breaker, open positions, 120% check, rafter size and spacing, roof planes (azimuth, pitch, dimensions, material, age), attic condition, shade
- Required photo list (panel cover on and off, label close-up, meter, each roof plane, each side of the house); submit blocked until complete
- QA review: pass, fix remotely, or revisit, with reason codes and revisit rate per surveyor
Module 9
Multi-state roster and dispatch
With techs and subcontracted surveyors in dozens of states, the right person is the one licensed there and nearby.
- Tech profile: home base, states covered, state licenses and expiry, NABCEP credential (PVCMS, OMAT, PVIP), OSHA 10 or 30, equipment (I-V tracer, IR camera, drone)
- Dispatch filters by state and credential, then distance and calendar; subcontractors see only their own orders
- Expiring licenses and credentials flagged e.g. 30 days ahead
Module 10
Owner reports and portal
Asset owners and offtakers want the month in one place, with the evidence behind it.
- Monthly report per site: availability vs guarantee, PR, tickets and response times, PM done, spares used, open RMAs
- Portal per owner: sites, open tickets, outage events and categories, PM records, test files
- Invoices for out-of-scope corrective work synced to QuickBooks or Xero
The AI agents, set up for solar O&M and site survey teams
| Agent | When | What it does | What you get |
|---|---|---|---|
| Watcher agent | A ticket passes its contract response time, a safety-flagged code is reset remotely, or month-to-date availability at a site drops below its guarantee | Checks the ticket against the site's contract terms and the outage ledger | An alert to the O&M manager naming the site, device, hours lost and the next action |
| Knowledge agent | A technician asks on site what a code means on that inverter, e.g. 'what is 18x86 and can I reset it?' | Searches the fault code library, the inverter manual attached to the record and that device's past tickets | The meaning, the do-not-reset warning if it applies, the first steps and the manual page |
| Dispatch agent | New survey orders or truck-roll tickets are ready to assign | Filters techs by state license and credential, then ranks by distance, calendar and test equipment carried | Assigned tech and a route for the day, with unassignable orders listed with the reason |
| Vision agent | A surveyor photographs the main panel label or an inverter nameplate | Reads busbar rating and main breaker, or make, model and serial, and runs the 120% check | Survey or equipment fields filled, with a flag if the label is unreadable or the numbers fail the check |
| Document intelligence agent | An installer client emails a survey request PDF or spreadsheet of addresses | Reads addresses, homeowner contacts, requested dates and special notes | Survey orders created in the right state queue, duplicates flagged |
| Scheduler agent | The 2nd of each month at 7 am | Totals last month's availability vs guarantee, PR, tickets and response times, PM completion, spares and RMAs per site | An owner report per site and a portfolio summary emailed to the O&M head |
Straight answers
Solar O&M and site surveys: FAQ
What software do solar O&M and site survey teams use?
O&M providers use renewable-specific tools such as Power Factors Unity, Raptor Maps, 60Hertz and meteocontrol's VCOM CMMS alongside their monitoring platform. Survey teams often use photo checklist tools like SiteCapture. What matters is an equipment register down to the string, alarms that become tickets, outage hours logged by category for the availability guarantee, spares by store, and survey forms that cannot submit incomplete. Fieldproxy is set up around your own contracts, stores and survey checklist.
What is the best field service software for solar technicians across many states?
Look for dispatch that filters by state license and credential before distance, tech profiles with license expiry dates, an offline mobile app, subcontractor access limited to their own orders, and forms that block submission without required photos. Then check reporting by state and by tech: revisit rate, time on site and QA pass rate.
What is an availability guarantee in a solar PPA or O&M contract?
A promise that the plant is available to produce for a set share of sunlight hours, with liquidated damages or bonuses around it. NREL's model terms calculate it as 1 minus unavailable hours times kW down, divided by production hours times nameplate kW, excluding events outside the operator's control. NREL's example guarantee uses 98% in year one and 99% after.
How is solar plant availability calculated?
Under NREL's model terms: availability = 1 minus (sum of each incident's unavailable hours x kW down) / (sunlight hours in the period x plant nameplate kW). The contract lists which outage categories count. NREL draws them from IEC 63019, including scheduled maintenance, forced outages, requested shutdowns and force majeure.
How often should solar strings get I-V curve tracing?
NREL's model service schedule lists string Voc, current tests and I-V curve traces once a year on a percentage of strings set in the contract, plus traces when monitoring points to a problem. Field tracers are accurate to about 5%, so record irradiance and module temperature with each trace.
Should technicians reset inverter fault codes?
Grid voltage and over-temperature trips often clear on their own or after a reset. Isolation, ground fault and arc fault codes should not be reset without a qualified technician finding the cause; on SolarEdge units an engineering services firm lists 03x9a and 18x86 as isolation and 18xC as arc faults. Codes differ by model, so keep a library per inverter.
What NABCEP certification do solar O&M technicians need?
NABCEP credentials are certifications, not state licenses, but O&M contracts and employers often ask for them. The PV Commissioning and Maintenance Specialist (PVCMS) needs 24 hours of advanced training, OSHA 30 and 12 project credits. NABCEP added the entry-level Operations and Maintenance Associate Technician (OMAT) in 2026, open after an approved course or 6 months working for a solar company.
What should a solar site survey capture?
Main panel busbar rating, main breaker size and open positions; rafter or truss size and spacing measured in the attic; each roof plane's azimuth, pitch, dimensions, material and age; shade and obstructions; and photos of each side, each roof plane, the panel labels and the meter. Missing items force redesigns and revisits.
Why does a survey need the busbar rating and not just the main breaker?
Because the NEC 120% rule (705.12(B)(2), as SolarAPP+ cites it) limits main breaker plus solar breaker to 120% of the busbar rating when they sit at opposite ends of the bus. A 200 A bus with a 200 A main leaves room for a 40 A solar breaker. Without the bus rating, the design team cannot choose the interconnection method.
What does solar O&M cost?
Berkeley Lab's 2026 edition puts the median O&M cost for utility-owned PV plants at about $11 per kWac-year, or $7 per MWh, in 2025, across 173 plants totaling 9.1 GWac. That covers supervision, engineering, maintenance, rents and training, and excludes property taxes, insurance, land royalties and bonds.
Related guides
All sources on this page (24)
- source: Berkeley Lab, Utility-Scale Solar 2026 Edition, briefing slides (O&M costs from FERC Form 1)
- source: NREL, Sandia and SunSpec Alliance, Best Practices for Operation and Maintenance of Photovoltaic and Energy Storage Systems, 3rd ed. (NREL/TP-7A40-73822, Dec 2018)
- source: PV Tech Power (2018), Towards a standardised contract for solar O&M (SESI template: availability guarantee plus response times)
- source: GreenLancer, SolarEdge inverter troubleshooting (error codes and when not to reset)
- source: SolarQuarter (19 Feb 2025), SolarPower Europe updates O&M Best Practice Guidelines (Version 6.0)
- source: IEC webstore, IEC 62446-1: PV systems, requirements for testing, documentation and maintenance, grid connected systems
- source: Midwest Renewable Energy Association, NABCEP PV Commissioning and Maintenance Specialist (PVCMS) requirements
- source: NABCEP, Operations and Maintenance Associate Technician credential (OMAT)
- source: HeatSpring, What's new with NABCEP credentials in 2026
- source: SolarAPP+ help center, Point of interconnection compliance methods (100%, 120%, sum of breakers, PCS)
- source: GreenLancer, Solar site survey: what to capture
- source: California CSLB, C-46 Solar Contractor classification
- source: Berkeley Lab, U.S. Utility-Scale Solar, 2026 Edition (1,989 projects over 5 MWac installed through 2025)
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