Start here: a quick picture of the site and scope

• Tell me in one sentence what you are proposing to interconnect at this site
• Describe the asset mix and nameplate capacities you plan to install (PV kWdc, BESS kW / kWh, EV chargers count, CHP size)
• Summarize the proposed point of interconnection, including voltage level and whether it ties to a service lateral, distribution feeder, or substation Options: Service lateral (customer side), Distribution feeder (utility pole/transformer), Distribution substation, Transmission-level POI, Unknown / need help identifying
• How soon do you need permission to operate to preserve the project economics or contract deadlines Options: Within 4 weeks, Within 8 weeks, Within 3 months, Within 6 months, No firm deadline yet
• On average, how many interconnection projects is your team running in parallel right now Options: None, 1–2, 3–5, 6–10, More than 10

If the schedule slips, who pays the price

• If interconnection approval slips by 3 months, what is the first financial or contractual consequence you will see
• Identify the milestone that would force you to walk away from the project, for example a financing close date, PPA commercial operation date, or construction start window Options: Financing close, PPA commercial operation date, Construction mobilization, Utility study deadline, Other
• Who within your organization is responsible for holding the financing or offtake timeline, and how are they monitoring interconnection progress Options: Project manager, Director of development, Finance lead, Operations/facilities manager, External owner / investor
• Which delay outcome matters more to your decision makers, additional study costs or lost revenue from a late COD Options: Additional study/hardware costs, Lost revenue from late COD, Both equally, Unsure
• Name the single schedule risk that would most likely stop this project immediately (overloaded feeder, network upgrade cost, missed permit), and explain why

Where costs surprise teams most, and why it matters

• Which interconnection-related cost categories have surprised you on prior projects Options: Utility network upgrades, Protection and relays, Revenue-grade metering, Study fees, Service upgrades (transformer/line), Other
• Estimate how much you would tolerate in unplanned interconnection cost before the project stops being viable, as a percent of total project capex Options: <1%, 1–3%, 3–5%, 5–10%, >10%
• Have you received utility requests for additional protection or metering hardware on past projects that required a change order Options: Yes, often, Occasionally, Rarely, Never, Not applicable
• Describe a prior instance where a study result forced a redesign, what changed, and how much that cost in time or money
• Which single technical requirment would most increase your upfront budget if the utility enforces it (for example, customer-owned transformer, new relay, interposing CTs) Options: Customer-owned transformer, New protective relay, Revenue meter and CT/PT, Automatic reclosing or control equipment, Network upgrade

How the utility process behaves in practice

• Which step in the utility interconnection sequence has historically created the longest delay on your projects Options: Application intake and completeness review, Feasibility or initial review, System impact study, Study response time, Agreement negotiation, Witness testing / final approval
• When the utility requests additional data, how long does it typically take your team to assemble and resubmit that information Options: <1 week, 1–2 weeks, 2–4 weeks, More than 4 weeks, We need help gathering data
• Has your project ever been re-pooled or bumped in the queue, and what was the downstream impact on your timeline or cost Options: Yes, materially, Yes, minor impact, No
• If the utility requires a system impact study instead of a simplified review, how does that change your risk profile Options: Study cost and timeline become unacceptable, Manageable with contingency, Triggers design changes that delay COD, Unsure
• Who at the utility do you already have a working relationship with, and who would we need to meet to accelerate reviews

Decision makers, signers, and the people who can slow you down

• Who ultimately signs the interconnection agreement or permits the final authorization to operate for this site Options: Internal project sponsor, Finance/investor sign-off, Operations/facilities executive, Utility sign-off only, Other
• List the internal and external stakeholders who must approve changes to protection settings, metering, or point of interconnection
• How accessible are those approvers during the next 90 days for rapid decisions Options: Always available, Mostly available, Occasionally available, Hard to reach
• Who on your team will be the day-to-day contact for engineering questions and document approvals Options: Project manager, Lead engineer, Procurement, Third-party owner rep, Not assigned yet
• If a utility requires a change that increases project cost, who has authority to approve the additional spend Options: Project sponsor/owner, Finance lead, Procurement, No one assigned
• Which single approval bottleneck in your organization is most likely to delay an interconnection milestone Options: Budget approval, Technical sign-off, Vendor selection, Permitting, Other

The other options you are weighing

• Which alternatives are you currently considering for managing interconnection (select all that apply) Options: Keep it in-house with existing staff, Engage another external interconnection consultant, Use utility's recommended contractor, Delay project until grid conditions improve, Cancel the project, Other
• What would have to be true about your current approach for you to decide to keep it rather than partner with an outside firm Options: Clear internal expertise, Predictable, short timelines, Lower total cost, Strong relationships with the utility, No change needed
• Has anyone internally proposed solving interconnection without external help, and if so, who would lead that effort Options: Yes, engineering team, Yes, project management, Yes, procurement, No one has proposed it
• If you stayed with your current option, how would that decision affect your timeline or risk exposure compared with hiring external support Options: Shorter timeline, Same timeline, Longer timeline and higher risk, Unsure
• What single advantage would make you choose a specific external partner right now Options: Proven track record with our utility, Faster study management, Lower fee, Full end-to-end management, Better warranty or support

Operational readiness, data, and technical constraints

• Do you have an up-to-date single-line diagram and as-built electrical drawings available for this site Options: Yes, fully documented, Partially available, No, not available
• Which of the following data elements can your team provide within 5 business days Options: One-line diagram, Load profile or SCADA data, Existing relay settings, Metering point details, Historical outage records
• Who owns the system data and who can legally grant us access to submit it to the utility or third parties Options: Your organization, Third-party owner, Joint ownership, Unsure
• Are there regulatory, legal, or permit constraints we should know about that could block construction or testing windows Options: Yes, permits pending, Yes, regulatory approvals needed, No known constraints, Unsure
• Does your team have staff available to support study responses, witness tests, and field commissioning during the proposed timeline Options: Dedicated staff available, Limited availability, No internal support available
• Identify any physical access limits or site constraints that would prevent field crews from completing work within a 2-week mobilization window Options: Restricted hours or access permits, Safety or security clearance required, No crane or heavy equipment access, None of the above
• Would any single missing technical item prevent us from starting work within your desired schedule, for example missing one-line, missing load data, or unsigned data release Options: Yes, missing single-line, Yes, missing load/SCADA, Yes, lack of signed data release, No, nothing blocking

Standards, protection, and metering specifics we need to confirm

• Which interconnection standard governs this project or is the utility explicitly using (state rule, IEEE 1547, tariff) Options: State interconnection rule, IEEE 1547 referenced, Utility tariff-specific, Unknown
• Have you identified any protection or anti-islanding requirements the utility will mandate Options: Yes, detailed protection required, Utility gave high level only, No requirements shared yet
• Do you already own the relays and meters required, or will procurement be necessary Options: Owned and on hand, Owned but not commissioned, Need to procure, Unsure
• How flexible is your acceptance of specific relay models or metering vendors if the utility requires a particular spec Options: Very flexible, Somewhat flexible, Not flexible
• Which single protection or metering requirement would materially change the project's hardware budget Options: New relay model, Revenue-grade meter and CT/PT, Transformer change, SCADA integration, Other

Risk appetite and the decisive criteria to proceed

• Rank the factors that determine whether you sign a scope and schedule today, from most important to least (budget, schedule certainty, proven utility relationships, technical handoff) Options: Budget, Schedule certainty, Proven utility relationships, Technical execution plan, Post-commissioning support
• How much contingency are you willing to accept in schedule and cost to secure a faster utility review Options: No contingency, 5% cost / 2 weeks schedule, 10% cost / 1 month schedule, 15%+ or more
• If we can demonstrate a path to meet your required permission to operate date, what internal approvals would remain before you could sign a statement of work Options: Budget approval, Technical review, Executive sign-off, No further approvals
• Would a fixed-price study management milestone and acceptance criteria make it easier for you to decide today Options: Yes, Maybe, No
• If a short pilot or initial deliverable proved the timeline and cost assumptions, what would stop you from contracting the full engagement that week

Practical next steps and document checklist

• Which of the following documents can you upload within 3 business days to start our evaluation Options: One-line diagram, Interconnection application file, Existing relay settings, Metering point data, Site single-point-of-contact
• Who should we add to the working group to reduce back-and-forth and accelerate approvals Options: Project manager, Lead engineer, Finance approver, Operations contact, Utility liaison
• Would you prefer a fixed-scope initial feasibility assessment or a time-and-materials rapid triage Options: Fixed-scope feasibility, Time-and-materials triage, Unsure, need guidance
• Select the preferred communication cadence for status updates during the next 90 days Options: Weekly written update, Weekly call, Biweekly call, Ad hoc as issues arise
• Provide a single readiness check: is there any non-negotiable constraint that would prevent you from starting the assessment within 10 business days Options: Yes, constraint exists, No, we can start within 10 business days

• Interconnection Plan Review

• Confirm the current state and its cost
• You confirm the proposed interconnection pathway and utility touchpoints match your project scope and constraints.
• Produce a detailed interconnection pathway diagram showing each utility touchpoint, expected study type and timeline, and preliminary cost drivers within 5 business days.
• You agree that the shown schedule and cost estimates are sufficient to support your go/no-go financing decision or identify what additional evidence is required.
• Walk the proposed interconnection pathway
• Provide the latest single-line diagram, site plan, and any prior utility study reports or application correspondence before the follow-up session.
• You select one mitigation approach to pursue next and approve a timeline for the seller to deliver the detailed pathway diagram and cost breakdown.
• Map technical steps to schedule and cost impacts
• Confirm the project's target go/no-go decision date tied to financing milestones so the schedule can be aligned to that deadline.
• Review mitigation options and trade-offs
• Prepare a brief comparison of two mitigation options with their schedule and cost trade-offs for the next review (seller deliverable).
• Validation, is this what you meant when you said interconnection delays threaten your financing and you need a fixed schedule and costs?

• Interconnection Plan Review, Solution Experience
• Interconnection Plan Review Deck
• Interconnection Plan Brief

• meeting
• slides
• document

• Prepare and Submit Interconnection Application
• Manage Utility Review and Response Process
• Manage System Impact Study Process
• Perform Power System Studies (Load Flow & Short Circuit)
• Design Protection, Control, and Relay Settings
• Develop Metering Design and Revenue Metering Plans
• Draft Interconnection Agreement Exhibits and Terms
• Provide Relay Programming and Functional Testing Support
• Coordinate Utility Witness Testing and Final Authorization
• Provide Construction-Phase Commissioning Support
• Deliver As-Built Protection, Control, and Metering Documentation
• Prepare Incentive and Financing Qualification Package

Prepare and Submit Interconnection Application

• Provide the interconnection application ID if already filed, or state 'Not filed'.
• Which utility interconnection queue/regime applies for this site (example choices: fast track, supplemental study, screen-out study, state tariff reference)? Options: Fast track / expedited screens, Study queue / supplemental study likely, Transmission-level review required, Uncertain / need assessment
• Do you have a stamped single-line diagram (SLD) and site plan that meet the utility's minimum submission requirements? Options: Yes, SLD and site plan ready, Partially (SLD draft only), No, we need help producing them
• Specify the proposed DER type(s) and nameplate capacities (kW/kVA) per point of interconnection and whether you plan co-located PV and battery inverter export.
• When does interconnection approval need to be in place to meet your financing or offtake milestone (target completion date)?
• List the documents you can provide at submission (for example: equipment cut sheets, inverter anti-islanding spec, PVSyst output, protection one-line).
• Identify who will be your authorized signer for the utility application and who provides utility account details (account number, meter ID).

Manage Utility Review and Response Process

• Indicate the utility's typical data request cadence you expect based on past projects (one round, multiple rounds, frequent clarifications). Options: One round of data requests, Two rounds typical, Multiple iterative requests expected, Unknown
• Do you have prior correspondence or redlines from the utility (for example: a technical deficiency letter or study scoping note)? Options: Yes, we have utility correspondence, No, none yet
• Describe which party will manage regular utility communications, meeting scheduling, and technical clarifications (we can manage / you manage / shared). Options: We manage full communications, You manage and we support, Shared responsibilities (specify)
• Specify the expected response SLA the utility requires for formal submissions or data requests (e.g., 7 days, 14 days). Options: 7 days, 14 days, 30 days, Custom - specify
• Identify any prior utility study numbers or queue positions that affect priority (provide study ID or 'none').
• List any planned meetings or workshops with the utility (technical conference, interconnection study kick-off) and preferred attendees (protection engineer, developer PM).

Manage System Impact Study Process

• Which study deliverables does your project require from the utility or from us (feeder impact memo, thermal/voltage sensitivity, protection coordination report)? Options: Feeder thermal/voltage impact memo, Protection coordination analysis, Fault contribution and device ratings, Other / custom deliverable
• Do you expect a utility full system impact study or only a supplemental study based on initial screens? Options: Full system impact study likely, Supplemental study expected, Study requirement unknown
• Provide any known study inputs from the utility such as short-circuit levels, existing relay settings, feeder impedance, or hosting capacity values.
• How will study coordination be handled for site-specific equipment outages, temporary ratings, or switching windows required by the utility? (we coordinate windows / you coordinate / joint) Options: We coordinate switching windows, You coordinate switching windows, Joint coordination
• Estimate the tolerance for schedule slip on study completion before financing is at risk (days). Options: <30 days, 30-60 days, 60-90 days, >90 days
• Identify any additional parties that must be included in study review (e.g., transmission operator, third-party protection vendor).

Perform Power System Studies (Load Flow & Short Circuit)

• Specify modeling data you can provide for load-flow and short-circuit studies (one-line SLD, equipment impedance, inverter fault current profile, protection models).
• Are IEEE 1547 inverter ride-through and dynamic response settings already defined in your equipment spec, or do you need us to propose settings? Options: Settings provided by equipment spec, We need proposed IEEE 1547 settings, Partially provided
• Which study cases must be run (for example: peak load, minimum load, N-1 contingency, worst-case exporting scenario)? Options: Peak load, Minimum load, N-1 contingency, Worst-case export
• Identify the power system analysis tools preferred or required for deliverables (e.g., PSS/E, CYME, OpenDSS) or leave blank for our recommendation. Options: PSS/E, CYME, OpenDSS, No preference / recommend
• List the acceptance thresholds for thermal and voltage results that will trigger design changes (for example: voltage deviation >3%, thermal overload >100%).
• Indicate whether duty-cycle and inverter short-circuit contribution data are available from the inverter manufacturer for fault current analysis. Options: Manufacturer fault current data provided, Manufacturer data not provided, Unknown

Design Protection, Control, and Relay Settings

• Describe the existing protection scheme at the POI (point of interconnection) including device types: recloser, SEL relay model, substation breaker, fused tie) and whether settings are available.
• Do you require coordination to a specific utility relay setting standard or a regulator order (for example: IEEE 1547 compliance plus utility-provided relay templates)? Options: Yes, must match utility templates, No, follow IEEE 1547 and best practice, Custom coordination required
• Specify CT/PT ratios, metering points, and relay communication method (fiber, SEL-FTP, DNP3 over serial/Ethernet) that apply to the site.
• List the protective functions to be delivered (for example: anti-islanding, frequency trip, voltage trip, rate-of-change, negative-sequence protection). Options: Anti-islanding, Over/under voltage, Over/under frequency, Rate-of-change of frequency, Negative-sequence
• Identify whether vendor relay models and sources for test files (e.g., SEL, GE, ABB) will be provided or need to be procured. Options: Provided by you, We procure/provide relay models, Mixed / partial
• Confirm any required sign-offs for protection design (for example: utility protection engineer approval, stamped engineer deliverable). Options: Utility protection sign-off required, Engineered stamped deliverable required, Both required, None required

Develop Metering Design and Revenue Metering Plans

• Which metering standard will govern revenue metering and telemetry (for example: ANSI class, utility-specific meter spec, NERC/WECC criteria)? Options: Utility-specific meter spec, ANSI class reference, NERC-related requirement, Unknown
• Do you require revenue meter selection, CT/PT sizing verification, and meter socket location design as part of scope? Options: Full revenue metering design, CT/PT sizing only, No metering design required
• Provide the required telemetry points and SCADA mapping (for example: real power, reactive power, status, analog points) that must be submitted to the utility.
• List the acceptable meter manufacturers or metering protocols if constrained (for example: Modbus, DNP3).
• Indicate whether metering will be used for billing, settlement, or only for operational visibility. Options: Billing / settlement use, Operational visibility only, Both
• Are there special accuracy classes or CT saturation concerns at high fault current levels that must be addressed in the metering design? Options: Yes - accuracy / saturation concern, No special concerns, Unknown - need verification

Draft Interconnection Agreement Exhibits and Terms

• Specify the contract exhibits required by the utility interconnection agreement (for example: Exhibit A one-line, Exhibit B technical requirements, Exhibit C meter specs).
• Do you have preferred commercial terms that must be reflected in the exhibits (for example: limitation of liability clauses tied to commissioning date)? Options: Yes - provide terms, No - use standard terms
• List which payment or milestone triggers the interconnection exhibit must align to (for example: Lender acceptance, commercial operation date, energization).
• Identify any required insurance, security, or performance guarantees called out in the IA exhibits that affect engineering deliverables.
• Indicate whether you need negotiation support with the utility on technical exhibits or only a redline-ready exhibit package. Options: Negotiation support required, Redline-ready exhibit package only, Both
• How many rounds of exhibit revisions should be budgeted into scope before additional change orders are required? Options: 1 round, 2 rounds, 3+ rounds

Provide Relay Programming and Functional Testing Support

• Which relay families and firmware versions will be programmed on site (for example: SEL-451, SEL-351S, Siemens SIPROTEC)?
• Do you require delivery of relay setting files in vendor format, and do you require test-ready COMTRADE/test switch test scripts? Options: Provide vendor-format setting files, Provide COMTRADE and test scripts, Both, None
• Describe whether on-site functional testing will require a relay test set, portable CT injection, or integrated relay simulator and who will provide test equipment. Options: We provide test equipment, You provide test equipment, Shared / coordinate
• List the functional test sequences you expect (for example: loss-of-grid, anti-islanding, breaker failure, sync-check).
• Identify the expected duration and working window for relay programming and functional verification at site (hours/days). Options: <1 day, 1 day, 2 days, 3+ days
• Are factory acceptance tests (FAT) required for protection firmware/logic prior to field deployment? Options: FAT required, FAT optional, No FAT required

Coordinate Utility Witness Testing and Final Authorization

• Indicate whether the utility requires witness testing for protection, commissioning, or metering accuracy before final authorization to operate (ATO). Options: Protection witness testing, Metering witness testing, Both, No witness testing
• Specify preferred witness-test windows and any blackout dates for the site that affect utility scheduling.
• Who will be the on-site owner of witness-test coordination and gatekeeping (we coordinate / you coordinate / third party)? Options: We coordinate, You coordinate, Third-party coordinator
• List the pieces of evidence the utility requires at witness testing (for example: relay settings printout, CT ratio verification, meter calibration certificate).
• Identify any utility access or badging requirements for personnel attending witness testing.
• Estimate the number of utility witness sessions anticipated (initial, re-test, final acceptance). Options: One session, Two sessions, Three or more

Provide Construction-Phase Commissioning Support

• Describe the construction-stage deliverables you expect (as-built one-line updates, relay setting uploads, meter installation oversight, punchlist management).
• Do you require a named commissioning manager on-site for turnover and coordination during the energization window? Options: Yes - named manager required, No - remote coordination ok
• Identify any LOTO (lockout/tagout), PPE, or site safety qualifications our staff must meet to access the electrical equipment.
• List handover items you require for construction acceptance (for example: labeled schematics, test reports, vendor certificates).
• Indicate whether your contractor will install equipment to vendor cut-sheet tolerances or whether we should include shop-drawings review in scope. Options: Contractor installs to cut sheets, We review shop drawings, Both

• Master Services Agreement (MSA)
• Statement of Work (SOW)
• Authorization to Proceed (Notice to Proceed)
• Payment Schedule & Fee Terms
• Data Access Authorization
• Utility Filing & Agent Authorization
• Data Processing Agreement (DPA)
• Change Order Agreement
• Acceptance & Milestone Sign-Off

• Go-live Health Check (week 1-4)
• First Measurement Review (weeks 4-10)
• Acceptance Gate — 90-Day Operational Acceptance
• Quarterly Post-Commissioning Operational Review

• Publish the quarterly performance snapshot and scheduled maintenance calendar for operational teams.
• Publish a short performance report summarizing measured vs modeled kWh and uptime for stakeholder review.
• Restate acceptance criteria and numeric targets
• Produce a documented acceptance outcome that records pass/fail per criterion and the acceptance decision.
• For any failed or conditional criteria, agree remediation steps with owners and firm resolution dates.
• Confirm whether final permission to operate status is achieved or what remains to secure it.
• Publish the acceptance report that lists pass/fail decisions, remediation items, and the recorded acceptance decision.
• Execute the remediation plan for conditional items and schedule targeted re-validation tests before the agreed deadline.
• Update the project's operational runbook and handover artifacts to reflect acceptance outcomes.
• Quarterly performance against forecast
• Confirm quarterly kWh production remains within acceptable variance of the modeled forecast or identify required corrective programs.
• Ensure interconnection and monitoring uptime meets agreed thresholds and that incident closures are on schedule.
• Prioritize enhancement requests and assign next actions without reopening the acceptance decision.
• Assign owners and target dates for the top-priority enhancement requests and add them to the backlog with agreed prioritization criteria.
• Close out all incidents older than 30 days or provide an extended remediation plan for unresolved items.
• Re-confirm success criteria and owners
• Confirm monitoring is capturing live site telemetry at the agreed sample rate and is visible to operations.
• Document top 3 go-live blockers with owners and target resolution dates.
• Agree date and deliverables for the first measurement meeting.
• Enable or repair telemetry feed so that full SCADA data reaches the monitoring dashboard within 72 hours.
• Resolve highest-priority field defect or access constraint and confirm completion in the project tracker.
• Distribute the post-go-live checklist and owners to all participants for asynchronous confirmation.
• Present first-period production vs model
• Establish whether measured kWh production is tracking toward the modeled forecast and quantify the deviation.
• Confirm interconnection and monitoring uptime percentage and list required steps to reach the target uptime.
• Assign owners and dates for all corrective actions required before the 90-day acceptance gate.
• Open tickets for each identified root cause, assign an owner, and set target resolution dates aligned to the acceptance gate.
• Schedule re-test or re-commissioning activities for any adjusted protection or metering settings.
• Present outcome data against each criterion
• Interconnection and monitoring reliability
• Deployment and system validation
• Interconnection and monitoring uptime review
• Document pass/fail for each acceptance item
• Telemetry and monitoring check
• Post-commissioning issues and ticket burn-down
• Root-cause analysis for any shortfalls
• Early adoption and operations signals
• Agree corrective actions and owners
• Enhancement requests and prioritization
• Formal acceptance decision and signatory capture when applicable
• Open issues and remediation plan
• Agree remediation and closure plan for conditional items
• Next-quarter operational calendar and maintenance windows