APS solar interconnection in Arizona can look like one utility application. It is really a chain of records. The Arizona Corporation Commission (ACC) track, PowerClerk application, approved drawings, installed equipment, rate rider, meter work, and permission to operate must all describe the same project.
Direct answer. An APS solar interconnection starts in PowerClerk, but the correct path depends on maximum alternating-current capacity, screening results, and operating mode. The installer submits project data and drawings. APS reviews the application, the authority having jurisdiction inspects the installation, and APS completes final review and meter work. APS then issues permission to operate.
This guide is for Arizona solar installers, permit coordinators, and commercial project teams. It explains how to select the route and keep the application package coordinated. The broader Arizona solar permit guide covers local building permits and structural review. This page stays with Arizona Public Service Company (APS) interconnection.
Date check. This guide reflects APS and ACC documents available on September 26, 2026. Confirm the current manual, tariff, forms, and equipment list before each submission.
Which approvals does APS solar interconnection in Arizona require?
An APS solar project normally needs separate approval from the local authority having jurisdiction (AHJ) and APS. The AHJ covers the building and electrical permit. APS covers connection to its distribution system, metering, and authorization to operate in parallel.
These reviews touch the same equipment but answer different questions. A city permit does not authorize parallel operation. APS initial approval does not replace the construction permit or final inspection.
The current APS Interconnection Application Process Guide, dated October 2021 and still linked by APS, lays out five broad stages:
- The installer submits the PowerClerk application and required documents.
- APS reviews the package, requests corrections, or approves construction.
- The installer builds the system and uploads final documents.
- APS reviews the final record and requests inspection or meter work.
- APS issues permission to operate (PTO) or records field corrections.
The sequence means that permit work and utility work must stay coordinated. A module change accepted by the AHJ can still require an APS record update. A one-line accepted by APS can still receive a local code comment.
| Decision | AHJ record | APS record | Project control |
|---|---|---|---|
| System location and access | Site plan, setbacks, equipment layout | Site plan, meter and disconnect locations | Use one coordinated base plan |
| Electrical design | Permit one-line or three-line, calculations, labels | Interconnection drawing and equipment data | Match ratings and model numbers |
| Construction acceptance | Final inspection or permit closeout | Final documents and inspection evidence | Upload the accepted record APS requests |
| Parallel operation | Not granted by a building permit | APS meter work and PTO | Do not energize in parallel before PTO |
The solar interconnection application guide covers the national handoff between design, utility review, and construction. APS adds its own portal fields, track rules, and technical manual.
Which ACC interconnection track applies to the project?
Arizona uses several review tracks. Maximum AC capacity, inverter certification, export behavior, and screen results decide the starting route. A project does not choose a faster track because its construction schedule is tight.
The APS Interconnection Requirements for Distributed Generation, Revision 10.0 maps APS projects to ACC Article 26. The manual applies to interconnections on the APS distribution system below 69 kV. Transmission and resale cases can follow different federal procedures.
APS Interconnection Routing Matrix
The matrix below is a routing aid, not an approval decision. APS determines the applicable route from the submitted facts and screening results.
| Project condition | ACC route | Main threshold or trigger | PowerClerk and design focus | What can change the route |
|---|---|---|---|---|
| Certified inverter-based system | Level 1 Super Fast Track | Maximum capacity of 20 kW or less | Certified equipment, AC capacity, drawings, operating mode | Ineligible equipment or a failed requirement |
| System below 2 MW that is not Level 1 | Level 2 Fast Track | Below 2 MW | Screen data, point of common coupling, protection, export behavior | Failed fast-track or supplemental screens |
| Large or screen-failing system | Level 3 Study Track | 2 MW or greater, or failed lower-track screens | Study data, system impacts, protection, facilities | Study findings and required upgrades |
| Project needing added screening | Supplemental Review | Failed initial screens or applicant request where allowed | Data needed to resolve the failed screen | Supplemental result |
| Qualifying non-export storage or inadvertent-export system | Expedited Track | Maximum capacity of 20 kW or less, subject to rule conditions | Power control, operating mode, certified equipment | Export capability or failure to meet rule conditions |
| Specified non-FERC generation | Service Schedule 6 route may apply | Tariff scope, voltage, purpose, and facility type control | Study deposits, facilities, ownership, operating arrangement | A retail load-side exclusion or federal jurisdiction |
| Transmission or resale project | Separate federal route may apply | Connection purpose and voltage | APS transmission procedures and applicable agreements | Jurisdiction and transaction structure |
Article 26 sets review periods after the utility finds an application complete. Arizona Administrative Code R14-2-2617 states 14 calendar days for Level 1 review. R14-2-2618 states 21 calendar days for Level 2 review.
Those periods are regulatory review steps, not project completion promises. Missing signatures, correction requests, study needs, construction, AHJ inspection, meter scheduling, and field corrections sit outside a simple initial-review count.
For aggregate systems at 500 kW AC or greater, the APS process guide highly recommends a pre-application report. ACC R14-2-2616 gives the utility 21 calendar days after a complete pre-application request. The report helps expose capacity and system conditions before the full application, but it does not reserve capacity or grant approval.
What if the site is served from an APS network or feeder-transfer arrangement?
Network configuration can change the technical review even when the generator looks small. APS Manual Revision 10.0 gives specific treatment to primary networks, secondary networks, and APS-owned feeder-transfer arrangements.
The manual states that systems above 10 kW on those arrangements require a detailed study at the customer’s expense. It also states that a spot-network system cannot backfeed the network. These are system-configuration limits, not a reason to guess the review outcome from the service voltage.
Ask APS to confirm the service configuration early when the site is in a dense commercial area or has unusual service equipment. The installer should not infer a radial circuit from the meter enclosure. The utility record controls that fact.
For a network-served project, collect the service diagram, transformer and meter information, existing-generation record, proposed operating mode, and control details before design release. Mark any unknown network fact in the design basis. Do not bury it in a generic note.
A non-export control can be relevant, but its label does not erase the network rule. APS still evaluates the equipment, control behavior, and circuit arrangement under the current manual. If the design depends on power control, show the sensing point, controlled devices, operating response, and applicable certification record.
This early check protects the proposal. It separates an ordinary plan-set scope from a project that may need study, added control design, or utility facilities.
What information does APS PowerClerk require?
APS PowerClerk requires more than a PDF plan set. The application records account data, project type, existing generation, operating mode, equipment, array geometry, rate-rider selection, documents, authorizations, and signatures.
The APS PowerClerk Applicant User Guide, dated August 23, 2024, organizes the application into five pages:
- Contact and site information.
- Technology and equipment.
- Rate-rider qualification.
- Document submission.
- Authorization and signatures.
The portal uses the APS account number and billing meter number to retrieve account-holder information. The applicant then identifies a residential or commercial project and discloses existing generation. The application also distinguishes parallel from non-parallel operation and exporting from non-exporting operation.
Equipment data reaches deeper than nameplate watts. PowerClerk asks for module, inverter, array, phase, tilt, azimuth, tracking, shading, disconnect, and installation information. The selected values must agree with the drawings and product records.
Record rule. Treat PowerClerk fields as part of the controlled design record. A correct drawing does not cure a different inverter, AC capacity, export mode, or meter number entered in the portal.
Required DocuSign signatures must be complete before submission. A successful submission creates a project number and places the project in Ready for Initial Review. Corrections can return under Application Corrections Needed or Engineer Review Corrections Needed.
Build a submission register before opening the portal. Record each field owner, source document, drawing location, and final checked value. That small discipline catches mismatches before APS has to find them.
Which drawings and documents should be in the initial package?
The initial package should give APS a single, consistent description of the proposed system. The APS process guide lists the site plan and three-line diagram among the core documents. It allows a one-line only for residential, single-phase, load-side connections.
Other initial records can include an executed contract, disclaimer, consumer acknowledgement, authorization form, and interconnection agreement. Applicability depends on project type and current portal prompts. Use the current APS checklist rather than a recycled file list.
| Package item | What APS needs to reconcile | Frequent mismatch to prevent |
|---|---|---|
| Account and meter record | Customer, service address, billing meter | Wrong meter or account holder |
| Site plan | Service point, meter, disconnects, generation equipment, access | Equipment moved after drawing issue |
| One-line or three-line diagram | Source, conductors, protection, disconnects, point of common coupling | Rating differs from portal entry |
| Equipment data | Exact manufacturer and model, AC and DC ratings, certification | Substitute model entered in only one place |
| Existing-generation record | Existing capacity and equipment | Addition treated as a new standalone system |
| Operating-mode record | Exporting, non-exporting, or inadvertent export | Control narrative conflicts with selection |
| Authorization and agreement | Customer and applicant authority | Missing or incomplete DocuSign record |
| Rate-rider selection | Requested billing treatment and qualification | Tariff choice mistaken for review track |
The APS process guide states that commercial one-line and three-line drawings require an Arizona-registered electrical professional engineer. That requirement needs qualified project review. It does not support an assumption about who provides the seal or whether another document also needs professional responsibility.
The three-phase commercial solar interconnection guide explains phase data, transformer context, fault information, and protection coordination for larger projects. The solar permit plan-set contents guide shows where the same equipment data appears across a permit package.
For each issue, search the complete package for old model numbers and ratings. Then compare the portal export with the current drawings. A drawing checker can miss a portal field, and a portal checker can miss a note hidden on a detail sheet.
What should the APS pre-submission check include?
The pre-submission check should compare source records, not rely on memory. Complete it after the drawings and PowerClerk draft are ready, but before the applicant requests signatures. A late correction is easier than a signed application built on the wrong service record.
Start with the service identity. Compare the legal account-holder name, service address, account number, and billing meter number against the current APS bill. Confirm that the PowerClerk project address and the drawing title block use the same site identity.
Next, reconcile system capacity. Record module quantity and wattage, inverter quantity, continuous AC output, maximum AC capacity, storage power, and existing generation. The portal, equipment schedule, diagram, and contract should use the same basis.
| Check point | Primary record | Compare against | Stop condition |
|---|---|---|---|
| Customer and service | Current APS bill | PowerClerk contacts, site plan, agreement | Account holder, address, or meter differs |
| Project type | Contract and design basis | Residential or commercial portal selection | Classification is unresolved |
| Existing generation | Site survey and APS account record | Portal disclosure and diagram | Existing system is missing |
| PV capacity | Equipment schedule | Portal, diagram, contract, site plan | Module or inverter basis differs |
| Operating mode | Control design | Portal selection, diagram, narrative, settings | Export behavior is not proved |
| Point of connection | Electrical design | Site plan, diagram, service equipment record | Connection method or location differs |
| Equipment certification | Current APS list and manufacturer record | Portal models and cut sheets | Exact model cannot be verified |
| Rate rider | Customer decision and tariff eligibility | PowerClerk rate page | Choice or qualification is unresolved |
| Signatures | Current APS workflow | DocuSign status and authorization | Required signature is incomplete |
Then inspect topology. Follow power from the array or storage system to the point of common coupling. Confirm conductor paths, protective devices, disconnects, meters, power control equipment, phase, and equipment locations. A diagram can be electrically correct and still conflict with the site plan.
Finish with document control. Each file should carry a clear issue date and revision. Remove superseded drafts from the upload folder. Confirm that every cut sheet belongs to an exact submitted model, not a similar product family.
The checker should record each exception, owner, and resolution. Do not fix a conflict silently in PowerClerk while leaving the drawing unchanged. The final check is complete only when the source record and every dependent record agree.
How do exporting, non-exporting, and inadvertent-export modes differ?
The three operating modes describe power behavior at the point of common coupling. They are technical classifications, not alternative names for an APS billing rider. The selected mode must match the controls, drawings, equipment capability, and intended operation.
ACC Article 26 defines conditions for exporting, non-exporting, and inadvertent-export systems. A non-export label alone is not evidence that a project meets the applicable rule. APS needs the control method and project facts required for the selected route.
| Operating mode | Practical meaning | Design evidence to coordinate | Common error |
|---|---|---|---|
| Exporting | The system is designed to deliver energy to the APS grid under the approved arrangement | Export capacity, inverter settings, protection, meter and tariff record | Treating the billing rider as the operating mode |
| Non-exporting | The system uses an eligible method to prevent export under the rule and APS requirements | Power control system, sensing point, control logic, fail response, certified equipment | Writing zero export without a technical basis |
| Inadvertent export | Limited unintended export is handled under the defined regulatory conditions | Capacity, controls, duration or magnitude conditions, equipment and monitoring | Assuming any export-control system qualifies |
The IEEE 1547-2018 solar interconnection guide explains the performance framework behind modern distributed-energy-resource behavior. The IEEE 1547 glossary entry provides a shorter definition.
Do not choose non-exporting operation merely to avoid a study. A control design can add equipment, commissioning steps, failure states, and documentation. It also must match how the owner plans to use storage and generation.
The useful question is not, “Which box looks fastest?” Ask which operating mode the installed system implements. Then ask whether the project record proves it.
What changed in APS inverter requirements in 2026?
APS updated its distributed-generation manual and published current default settings in 2026. Equipment selection and commissioning records should reflect UL 1741 SB certification and the APS advanced-inverter settings that apply to the project.
The APS 2026 Distributed Resources Engineering forum states that Interconnection Requirements Manual Revision 10.0 became effective May 11, 2026. It also states that UL 1741 SB is required under the current manual and that approved equipment must not be field modified.
APS identifies normal performance Category B and abnormal performance Category III as current defaults, including IEEE 1547A-2020. APS also moved its default direction from fixed power factor toward Volt/VAR operation.
The APS Default DER Settings for systems below 10 MW is dated April 27, 2026. It shows the following high-level mode status:
| Function | APS default for DER below 10 MW | Record to verify |
|---|---|---|
| Constant power factor | Disabled | Commissioning or settings report |
| Constant reactive power | Disabled | Commissioning or settings report |
| Volt/VAR | Enabled | Curve and device settings |
| Volt/Watt | Enabled | Curve and device settings |
| Enter service | Enabled | Reconnection settings |
The source contains the complete values. Use that document and the current approved-equipment record during commissioning. Copying every register into a plan note creates another stale record when APS updates the settings.
The UL inverter compliance guide separates certification, listing, field configuration, and utility settings. The UL 1741 SB glossary entry explains the certification supplement in plain language.
Advanced functions do not mean every possible function is active. ACC R14-2-2625 lists capabilities such as Volt/VAR, Volt/Watt, fixed power factor, ride-through, soft-start reconnection, and frequency-watt. Some settings depend on utility and customer agreement. Use the APS project record rather than a generic inverter profile.
How do RCP and EPR-2 relate to interconnection?
Resource Comparison Proxy (RCP) and EPR-2 are tariff choices with separate qualifications. They do not replace the ACC review track or the technical operating-mode decision. A project can have a correct track and still carry the wrong rider selection.
The current APS RCP tariff, A.C.C. No. 6248, Revision 11, became effective September 1, 2026 under Decision No. 82122. It applies to qualifying residential on-site solar partial-requirements customers.
For the tranche from September 1, 2026 through August 31, 2027, the tariff lists $0.05554 per kWh. The initial rate generally applies for ten years, subject to the tariff conditions. This figure is volatile and needs a same-day tariff check before publication or customer use.
The current APS EPR-2 tariff, A.C.C. No. 6214, Revision 21, became effective March 8, 2024 under Decision No. 79293. It applies to qualifying facilities of 100 kW AC or less.
| Tariff record | Published scope | Current published non-firm energy values | Do not infer |
|---|---|---|---|
| RCP Revision 11 | Qualifying residential on-site solar partial-requirements customers | $0.05554 per kWh for the 2026 tranche | That every residential project qualifies or keeps the rate after a material change |
| EPR-2 Revision 21 | Qualifying facilities at 100 kW AC or less | Summer on-peak $0.02989, summer off-peak $0.02897, winter on-peak $0.03040, winter off-peak $0.02831 per kWh | That EPR-2 is the same product as RCP |
The RCP tariff defines a material increase as 10 percent or 1 kW AC, whichever is greater. That threshold matters when adding capacity to an existing system. It should not be generalized to every equipment substitution or every interconnection decision.
Rate advice has financial consequences. Confirm eligibility and billing treatment with APS and the current tariff. Keep tariff analysis separate from the engineering route.
Which APS interconnection fees actually apply?
APS does not publish one universal fee that can be copied into every residential quote. Service Schedule 6 lists study charges for a defined group of non-FERC generation facilities, and it also contains a major retail load-side exclusion.
The APS Service Schedule 6, A.C.C. No. 6220, Revision 5, became effective March 8, 2024 under Decision No. 79293. The schedule states that it does not apply to a load-side facility below 1 MW that primarily serves a retail customer’s load.
That exclusion is why a $5,000 study charge should not appear automatically in an ordinary residential proposal.
| Schedule 6 study item | Published amount | Scope warning |
|---|---|---|
| Feasibility study below 69 kV | $5,000, non-refundable | Only when Schedule 6 applies |
| System-impact study below 69 kV | $15,000, or $10,000 after an APS feasibility study | Only when Schedule 6 applies |
| Facilities study below 69 kV | Actual cost | Project-specific scope |
| Feasibility-study deposit at 69 kV and above | $20,000 | High-voltage Schedule 6 case |
| System-impact-study deposit at 69 kV and above | $40,000 | High-voltage Schedule 6 case |
| Facilities-study deposit at 69 kV and above | $55,000 | High-voltage Schedule 6 case |
Project-specific upgrades, meters, protection, facilities, or studies can still create costs under the applicable route. The safe estimating process is to classify the facility first, then read the tariff and utility response that governs that project.
Estimating rule. Label unknown utility upgrade and study costs as pending APS review. Do not turn a scoped tariff charge into a flat residential application fee.
What happens after APS grants initial approval?
Initial approval releases the project for construction under the accepted record. It is not PTO. The installer must build the approved design, complete the AHJ process, upload final documents, resolve final review, and complete required meter work.
The APS PowerClerk guide moves a complete final upload to Final Review Ready. APS then reviews the final record and requests inspection or meter set as applicable. A field problem can return under Inspection/Meter Set Corrections Needed.
Use a four-record reconciliation before final upload:
- Approved application. Confirm capacity, equipment, operating mode, rate rider, and project contacts.
- Approved drawings. Confirm model numbers, ratings, protection, disconnects, meter location, and point of common coupling.
- Installed system. Compare nameplates, conductor and device records, controls, labels, and physical locations.
- AHJ closeout. Upload the inspection evidence and final documents that APS currently requests.
The 2026 APS year-in-review material states that an approved application has 180 days to interconnect. It also describes a self-service request for one 90-day extension. Treat both as dated portal rules and confirm them in the live project before relying on an extension.
PTO comes after successful meter work and the APS completion notice. Keep that notice with the approved drawings and commissioning record. The AHJ glossary definition helps teams explain why the local inspection and utility authorization remain separate.
Which APS correction loops cause the most rework?
Most avoidable correction loops are record conflicts. The portal, drawings, equipment data, field installation, and tariff selection describe different versions of the project. A complete package can still fail if it is not internally consistent.
The interconnection rejection-reasons guide covers recurring national issues. APS projects deserve extra checks in six places:
| Correction loop | Why it occurs | Pre-submission control |
|---|---|---|
| Account mismatch | Wrong service address, customer, or billing meter | Confirm against the current APS bill |
| Capacity mismatch | DC size, inverter AC output, or existing generation differs | Use one capacity register across portal and drawings |
| Equipment mismatch | Model changed after application or construction approval | Freeze procurement models and run change control |
| Diagram mismatch | One-line or three-line differs from site plan or field work | Cross-check device tags, ratings, and locations |
| Operating-mode mismatch | Export selection conflicts with PCS design or narrative | Review controls and portal answer together |
| Final-record mismatch | Installed work differs from the approved package | Perform a field-to-record reconciliation before upload |
Equipment changes need their own route. The current APS solar page states that an increase greater than 1 kW or 10 percent, whichever is greater, requires a new application. Changes up to that threshold use an equipment amendment request through APS, subject to current instructions.
The PowerClerk guide calls the approved-project workflow Equipment Addendum Request. It asks for updated equipment data plus revised diagrams and site plan. The threshold does not mean every smaller change is automatically accepted. It identifies the requested route.
The PE stamp revision after an equipment swap guide explains how to compare changed electrical, structural, and document inputs without making an unauthorized professional decision.
The APS Record Reconciliation Check
The APS Record Reconciliation Check is a project-control method for comparing the six records that can drift during interconnection. It does not replace APS review. It gives the installer one repeatable check before each status change.
- Identity. Match customer, service address, APS account, billing meter, project number, and applicant authority.
- Capacity. Match module count, DC rating, inverter count, maximum AC capacity, existing generation, and storage power.
- Topology. Match phase, point of common coupling, connection method, protection, disconnects, meter arrangement, and control equipment.
- Operating mode. Match exporting, non-exporting, or inadvertent-export selection to the control narrative and settings.
- Commercial record. Match the requested rate rider to current eligibility and customer choice without changing the engineering track.
- Field closeout. Match installed nameplates, locations, settings, AHJ evidence, final drawings, meter work, and PTO notice.
Assign one owner to sign each check. A designer can own drawing coordination. The installer can own field verification. The account holder can own tariff selection. APS owns the utility decision.
Release rule. Do not advance a project because one record is correct. Advance it when all six records agree or the difference has a documented owner and resolution.
This check gives permit coordinators a useful stop point before initial submission, construction release, final upload, and energization. It also makes correction ownership visible.
How can Heaven Designs support an APS drawing package?
Heaven Designs can support the coordinated drawing record for APS and the local permit process. The useful scope is not a generic utility template. It is a project-specific plan set whose equipment, capacity, topology, and site information agree with the application basis.
The solar permit design service covers US permit plan-set support. For an APS project, the drawing intake should include the utility bill, site information, equipment schedule, proposed operating mode, interconnection concept, and current APS requirements.
Commercial drawings and any work under professional responsibility require qualified project review. Heaven Designs does not claim in-house Arizona licensure or approval authority. APS and the AHJ make their own decisions.
A useful handoff package includes:
- Controlled site plan and electrical diagrams.
- Exact equipment schedules and current cut sheets.
- Portal-to-drawing data register.
- Revision record for equipment or field changes.
- Final drawing set aligned with the installed system.
If your team needs drawing support for an active APS project, send the service address, system type, capacity, and current project status. The team can review the requested drawing scope without promising APS approval or a utility timeline.
FAQ
Can construction start after an APS application is submitted?
Submission alone is not construction approval. The APS process guide places utility review before approval for installation. The project also needs the local permit path required by the AHJ. Wait for the applicable written approvals and confirm that procurement still matches the accepted equipment record.
Does an APS Level 1 project receive PTO within 14 days?
No. ACC R14-2-2617 gives a 14-calendar-day Level 1 review period after the completeness notice. That period does not include every correction, permit, construction, inspection, meter, or field step. It should not be marketed as a 14-day PTO promise.
Is APS RCP the same as net metering?
No. The current RCP tariff is a specific APS export-credit rider for qualifying residential partial-requirements customers. Use the tariff name and current terms. Do not replace it with a broad net-metering label, because that can hide eligibility, tranche, and material-increase conditions.
Can a non-export system skip APS interconnection review?
Do not assume so. ACC Article 26 includes technical conditions for non-export and inadvertent-export projects. APS has an expedited route for certain systems at 20 kW or less. The control design, certified equipment, capacity, and application still need the route that fits the project.
Does APS accept a one-line diagram for every solar project?
No. The APS process guide allows a one-line for residential, single-phase, load-side connections. It calls for a three-line in other cases. Commercial one-line and three-line drawings also carry the Arizona-registered electrical PE requirement stated in that guide.
What happens if approved equipment changes before installation?
Compare the exact old and new equipment first. APS states that an increase greater than 1 kW or 10 percent, whichever is greater, requires a new application. Changes up to that threshold follow the current equipment-amendment process, with revised project data and drawings.
Does PTO from the AHJ allow parallel operation with APS?
The AHJ does not issue APS PTO. The local authority completes its permit and inspection role. APS completes final review, meter work, and its own permission-to-operate notice. Keep both approvals in the project closeout record.
Final decision for an APS interconnection package
The fastest defensible APS submission is not the shortest PDF. It is the application with the fewest disagreements between its records.
Select the ACC track from capacity and screening facts. Select the operating mode from the actual control design. Select the tariff from current eligibility. Then reconcile PowerClerk, drawings, equipment, field work, inspection evidence, meter work, and PTO.
That approach also makes revisions easier. When a model, capacity, or field location changes, the team can identify every affected record before APS or the AHJ finds the mismatch.