Quick site snapshot

• What is the site's physical address or parcel ID and its primary operating function?
• Give a concise summary of the existing electrical service configuration you have today, including service voltage, number of meters, and any on-site transformers or substations.
• When did the existing service capacity last change, and what drove that change? Options: Within 12 months, 1-3 years ago, 3-7 years ago, More than 7 years ago, Unknown
• Who on your team owns the utility relationship and who will be the single point of contact for service applications? Options: Facility engineer, Director of construction, Energy manager, Procurement, External consultant, Other
• How confident are you in the accuracy of your recorded site load and diversity factors? Options: Very confident, Somewhat confident, Uncertain, We need to validate
• Tell us about any site constraints we should see on arrival, such as limited easement access, protected areas, or space limits for switchgear.

Where the timeline really breaks

• What single permit or utility milestone, if delayed, would stop your entire project immediately?
• If that milestone slipped by three months, what would the financial or schedule consequence be for your overall program? Options: Minor re-sequencing cost (<5%), Moderate cost and delay (5-15%), Major cost and delay (>15%), Project would pause
• Describe the longest lead item you are already tracking for this site and the current delivery date.
• In the last similar project your team ran, which utility step took the most calendar time and who was responsible for follow up?
• Who are the named approvers at the utility and the local authority having jurisdiction you need to engage with for this project?
• Estimate a realistic earliest energization date you could accept, and the latest acceptable date before the project becomes unviable.

Capacity gaps and hidden technical surprises

• How would an unexpected 20 percent increase in load at go live change the equipment or timeline you would need?
• List the major electrical equipment you expect to specify or reuse on site, including switchgear, transformers, and metering. Options: New substation or switchgear, Pad-mounted transformer, Existing transformer reuse, New metering, Portable generator, Other
• Which protection settings or relay vendor standards does your operations team require us to match or hand over? Options: We have internal relay settings, We will accept vendor defaults with review, Utility requires specific settings, Don't know yet
• Has the site undergone a formal short circuit and coordination study within the past 12 months? Options: Yes, within 3 months, Yes, 3-12 months ago, No, older than 12 months, No study available
• Walk me through a recent site condition that increased costs unexpectedly and how your team responded.
• Identify the single site characteristic that would make a utility require a higher level of review or additional studies.

Permits, utilities, and external gateways

• Tell us which critical permit or utility approval you expect us to chase, and why it could still be at risk.
• Provide the utility application IDs, current review status, and any outstanding information requests we should expect to resolve.
• Name the person on your team authorized to sign permits and site access agreements, and describe any legal hold points.
• Are there municipal review cycles or single weekly intake days that typically add wait time in your jurisdiction? Options: Yes, regular cycles, Occasional cycles, No fixed cycles, Unknown
• If the utility requests additional load ownership proof or future expansion plans, do you have documentation ready and who will provide it? Options: We have full documentation, Partial documentation, Need to assemble, Unknown
• Which external stakeholders, such as neighboring property owners or railroads, require outreach before excavation or new service routing? Options: Adjacent property owners, Railroad or transit authority, Local utilities other than primary, Environmental agencies, None, Other

Operational readiness and hard constraints

• Are there headcount, tooling, or safety training gaps on your side that could block parallel work during electrical construction? Options: Yes, critical gaps, Minor gaps that can be filled, No gaps identified, Unknown
• Quantify the number of full time staff available for coordination and the hours per week they can commit. Options: 0-5 hours per week, 5-15 hours per week, 15-30 hours per week, 30+ hours per week
• List the internal systems that must receive metering data and the required delivery format for each. Options: SCADA or EMS, Facility CMMS, Energy management platform, Billing or chargeback system, CSV or API export, Other
• Has your team budgeted for utility-approved equipment changes or unforeseen remediation work on site? Options: Budgeted and approved, Budgeted but not approved, No budget yet, Unknown
• Identify the decision owner in procurement or finance and the approval threshold that would trigger escalated funding.
• Map any contractual obligations with current vendors that could restrict schedule or equipment choices, such as exclusive supply or site access windows.

The other paths you are weighing

• Why would you keep the incumbent or your current approach instead of switching to an external engineering and construction partner?
• Describe any internal proposal to do this work without an outside partner and what gaps you see in that plan.
• Have you formally issued a request for proposals or quotes to other vendors, and if so, how many bids did you receive? Options: No RFP issued, RFP issued, 1 bid, RFP issued, 2-3 bids, RFP issued, more than 3 bids
• Name the incumbent provider if there is one and the primary reason you are considering a change.
• Under what conditions would your team choose to stay with the current approach rather than change vendors? Options: Current schedule guaranteed, Lower cost by a set percent, Improved utility relationships, No internal resource gap, Other
• Would a guaranteed energization date in writing from a partner be decisive in choosing them, and what penalties or remedies would be acceptable? Options: Yes, decisive with liquidated damages, Yes, decisive with milestone credits, Helpful but not decisive, Not important

Decision gates and next steps

• Imagine the pilot or initial phase proves the forecasted load and timelines, what would stop you from issuing a purchase order that same week?
• Confirm the internal approvals needed to move to commitment, including roles, approval levels, and typical review lead time.
• Provide the key dates you need to lock for procurement, site access, and energization.
• Select the typical elapsed time your finance team requires to approve a capital release after contract signing. Options: Immediate (≤7 days), 2-4 weeks, 1-2 months, More than 2 months, Unsure
• Rate the importance of utility relationship depth versus price in your procurement decision. Options: Utility relationships are far more important, Slightly more important than price, Price and relationships equal, Price is slightly more important, Price is far more important
• Please attach or paste your most recent single line diagram or an equipment list we should review.

• Solution Experience Session

• Confirm the current state and its cost to your project
• You confirm the demonstrated solution eliminates the schedule risk caused by uncertain utility lead times.
• Deliver a detailed utility engagement timeline and a one-page reference project timeline mapped to your target energization date.
• Map the proposed design to your site constraints
• You agree the acceptance criteria and milestones are measurable and sufficient to lock the construction schedule.
• Provide a preliminary equipment and procurement lead-time matrix aligned to the agreed milestones.
• Show the utility engagement and permitting plan with a reference timeline
• Share the latest single-line diagram, target installation window, and list of utility and AHJ contacts.
• You identify the remaining evidence required from reference projects and the utility before a procurement and schedule commitment can be made.
• Confirm your internal decision date and the owner of the capital approval for the electrical scope.
• Confirm measurable acceptance criteria and gates
• Validation question, confirm this maps to your requirement
• Agree remaining evidence and next steps toward decision

• Solution Experience Session
• Solution Experience Deck
• Solution Brief

• meeting
• slides
• document

• File utility interconnection application
• Prepare and submit permitting packages
• Construct substation and set equipment
• Supply and install switchgear
• Procure and install power transformers
• Install underground conduit and power cables
• Install equipment foundations and cable trenches
• Supply and install metering equipment
• Protection coordination and relay commissioning
• Medium and low-voltage termination and testing
• Utility acceptance testing and energization
• As-built drawings and O&M handover
• Incentives and financing qualification

File utility interconnection application

• Provide the utility service territory and interconnection application ID or queue number if already filed
• Upload or name the application form type submitted (new service, service upgrade, point of interconnection)
• Which nominal service voltage and phasing are requested on the application (for example 480 V three-phase, 12.47 kV) Options: 480 V three-phase, 4.16 kV, 12.47 kV, Other
• Do you have a signed single-line diagram (SLD) showing the proposed point of interconnection and protective devices to attach to the utility filing? Options: Yes, No
• Identify the load profile submitted with the application (peak kW, continuous kW, kVA, motor-starting kW) and attach the schedule if available
• List any utility-requested studies (for example short-circuit, load-flow, protection coordination) and whether study deposits or study scopes were accepted Options: Short-circuit study, Load-flow study, Protection coordination study, None, Other

Prepare and submit permitting packages

• Provide the Authority Having Jurisdiction (AHJ) name and application reference numbers for electrical, civil, and building permits
• Upload or confirm the required permit package checklist items (site plan, SLD, equipment cut-sheets, civil grading plan) you will submit
• Which environmental or site surveys are required for permits on this site (for example wetlands, archaeological, geotechnical)? Options: Geotechnical report, Wetlands survey, Archaeological survey, None known, Other
• Do you have existing civil or site plans showing property lines, easements, and proposed equipment locations to include in the permit package? Options: Yes, No
• Identify local permit review timelines or estimated review cycles provided by the AHJ (for example 4-6 weeks, 8-12 weeks) Options: 2-4 weeks, 4-8 weeks, 8-12 weeks, More than 12 weeks, Unknown
• List any required third-party approvals that must be bundled with the permit package (for example railroad crossing, DOT encroachment, environmental agency)

Construct substation and set equipment

• Provide the planned substation layout and approximate footprint dimensions for foundation and fence work
• Which equipment will be set inside the substation yard (transformer types, switchgear, capacitor banks) and what are their approximate weights and dimensions?
• Identify required crane lift plans, ground-bearing capacity, and any traffic control permits needed for equipment setting
• Estimate foundation cure and hold times the schedule must respect before equipment can be placed (for example 7 days, 14 days) Options: 3-7 days, 7-10 days, 10-14 days, More than 14 days
• Confirm whether site access restrictions or insurance requirements (for example bonded subcontractors, site-specific safety orientation) apply to heavy lifts Options: Yes, No
• List any on-site utilities or buried conflicts to avoid during setting (gas mains, telecom ducts, storm drains) and provide as-built references if available

Supply and install switchgear

• Specify the switchgear functional requirements: voltage class, maximum continuous current rating, fault interrupting rating (kA RMS)
• Provide preferred switchgear auxiliary systems and options (for example remote racking, local HMI, battery-backed controls) Options: Remote racking, Local HMI, Battery-backed controls, Basic controls only, Other
• Which enclosure environmental rating is required by site conditions (for example NEMA 3R, NEMA 4X)? Options: NEMA 1, NEMA 3R, NEMA 4, NEMA 4X, Other
• Do you require factory witness tests or FAT (factory acceptance test) packets prior to shipment of switchgear? Options: Yes, witness preferred, Yes, documented FAT only, No
• Identify switchgear protection/control interface points that must integrate with site SCADA or relay systems (for example RS-485, Ethernet, Modbus TCP)
• List spare parts and recommended maintenance items to be supplied with the switchgear (for example spare fuses, control boards, breakers)

Procure and install power transformers

• Specify transformer rating and cooling class required (kVA, delta/wye, ONAN/ONAF) along with impedance and vector group preferences
• Provide site transformer pad or pit dimensions and weight capacity or upload civil drawings if already available
• Which secondary termination arrangement and bushing types are required for field cabling compatibility? Options: Bottom bushing, Top bushing, Through-bus, Other
• Identify inrush and short-circuit contribution assumptions to verify transformer kVA and system protection settings
• Do you require oil handling, testing, and transformer preservation services on delivery (for example oil sampling, vacuum filling)? Options: Yes, No
• List any factory lead-time constraints or delivery windows that the procurement must meet

Install underground conduit and power cables

• Provide proposed conduit routes and approximate run lengths for primary and secondary power cables
• Specify cable types and ratings required (for example XLP insulated medium-voltage, copper or aluminum, insulation class)
• Which minimum burial depth, warning tape, and separation from other utilities does the local code or utility require at this site?
• Identify required pull boxes, splice vaults, and handhole locations with access requirements
• Confirm if live-line work or temporary shutdowns for pulling and splicing will be permitted by the utility and AHJ Options: Live-line permitted, Shutdown windows required, Not permitted/unknown
• List trenching or dewatering constraints (for example high groundwater, rock excavation, traffic control) that affect cable installation

Install equipment foundations and cable trenches

• Provide geotechnical recommendations or soil-bearing capacity values for foundation design
• Which foundation type do you prefer for major equipment (cast-in-place concrete pad, precast pad, pile foundations)? Options: Cast-in-place concrete, Precast pad, Pile foundations, Other
• Identify seismic, wind, or flood elevation requirements that the foundation design must meet
• Specify required concrete strength and anchor bolt patterns for equipment setting
• List required trench backfill compaction criteria and surface restoration standards
• Confirm whether temporary access roads or laydown areas are available for foundation construction equipment Options: Yes, No

Supply and install metering equipment

• Specify required metering accuracy class, metering point (utility-side or customer-side), and CT/PT ratios
• Which metering enclosure and access requirements are mandated by the utility (for example meter socket type, remote reading interface)?
• Do you require revenue-grade metering and utility witnessing at installation and testing? Options: Yes, revenue-grade with witness, Revenue-grade without witness, Standard metering only
• Identify data telemetry requirements from the meter (for example 4-20 mA, Modbus, DNP3 over serial or Ethernet) Options: Modbus RTU/ASCII, Modbus TCP, DNP3, 4-20 mA, Other
• List required metering deliverables at handover (calibration certificate, meter settings report, wiring diagram)
• Provide meter installation window constraints that the utility or site operations require

Protection coordination and relay commissioning

• Provide existing protective device settings and relay models or attach relay setting export files where available
• Which coordination studies are required (time-current coordination, breaker damage curve check, arc-flash study)? Options: Time-current coordination, Breaker damage check, Arc-flash study, None, Other
• Identify planned communications and telemetry between protective relays and site control (for example fiber, serial RTU, Ethernet) and existing SCADA points
• Specify the relay test deliverables you expect at commissioning (control wiring verification, secondary injection test reports, event playback)
• Confirm whether on-site utility protection witness testing is required and any scheduling constraints for utility witness windows Options: Utility witness required, Utility witness optional, Not required/unknown
• What signed evidence will validate relay commissioning acceptance (for example signed secondary injection test report and protection settings checklist)?

Medium and low-voltage termination and testing

• Specify torque and termination standards to be followed for LV and MV cable terminations (for example manufacturer's torque table, industry standard)
• Which insulation test and megger thresholds must be met for MV and LV cables prior to energization (for example >1 GΩ at 500 V)?
• Provide the expected cable joint types and whether factory-made joints or field joints will be used Options: Factory-made joints, Field joints, Mix
• Identify acceptance criteria for terminations and phasing verification (for example phase-to-phase continuity, phase rotation confirmation)
• List required test reports to be delivered (tan-delta, insulation resistance, hipot, continuity) and preferred report formats
• Confirm whether temporary power or protective grounding is required during termination and testing activities Options: Temporary power provided, Protective grounding required, Not required/unknown

• Master Services Agreement (MSA)
• Statement of Work (SOW)
• Equipment Purchase Agreement
• Order Confirmation / Purchase Order
• Payment Schedule and Milestone Payment Agreement
• Change Order Agreement
• Acceptance & Commissioning Certificate
• Procurement Lead-Time and Delivery Schedule Acknowledgement
• Authorization to Act for Utility Filings
• Schedule Commitment & Delay Remedies
• Warranty & Maintenance Agreement
• Insurance, Indemnity & Performance Security Requirements

• Go-live Health Check (weeks 1-4)
• First Measurement Review (weeks 4-10)
• Acceptance Gate Review (around day 90)
• Quarterly Operational Review

• Close resolved tickets and archive evidence of resolution in the shared channel.
• Produce a documented acceptance decision for the installed infrastructure against the Solution Scope criteria.
• Deliver complete as-built documentation and the maintenance plan into the shared workspace.
• Agree remediation items, retest plan, and deadlines for any conditional or failed criteria.
• Publish the formal acceptance decision and archive it in the project folder.
• Upload the final as-built drawings, equipment logs, and the maintenance plan to the shared repository.
• Open remediation tickets for any conditional passes with retest dates and verification requirements.
• Schedule and publish training or handover sessions for the buyer's operations and maintenance teams.
• Operational metrics and trend review
• Confirm whether operational metrics meet the targets recorded in Solution Scope or identify where remediation is required.
• Close resolved issues and update remediation timelines for outstanding items.
• Agree the schedule for preventive maintenance windows and any required coordination actions.
• Publish the quarterly operational summary and metric dashboard to the shared workspace.
• Update the preventive maintenance schedule and notify affected parties of upcoming windows.
• Create or update tickets for enhancement requests with prioritization and tentative scheduling.
• Reconfirm acceptance criteria and owners
• Confirm that core commissioning tasks completed and are documented in the commissioning report.
• Agree a prioritized list of open punch-list items with owners and due dates.
• Establish a persistent shared channel for issues and enhancement requests and confirm escalation path.
• Publish the initial commissioning report and upload it to the shared workspace.
• Upload available as-built drawings and equipment serial records to the as-built repository.
• Create the shared issue channel and document the escalation path and response SLAs.
• Present first operational data
• Determine whether commissioning test pass rate and punch-list closure trend toward the targets recorded in Solution Scope.
• Agree a prioritized remediation plan with specific tasks and completion dates to close gaps before the acceptance gate.
• Confirm the updated acceptance gate date or criteria for a gated retest.
• Open remediation tickets for failed commissioning tests with retest criteria and target dates.
• Close high-priority punch-list items and publish evidence for verification.
• Publish an updated timeline to the shared workspace showing path to Acceptance Gate.
• Restate acceptance criteria and numeric targets
• Present outcome data against each criterion
• Open issues and remediation status
• Deployment and commissioning validation
• Root-cause diagnosis for gaps
• Document pass/fail per criterion and formal acceptance decision
• Early operational signals and usage
• Preventive maintenance and upcoming windows
• Agree corrective actions and timelines
• Open punch-list and blockers review
• Agree remediation and retest plan for any failed or conditional items
• Confirm timeline to the Acceptance Gate
• Enhancement requests triage
• Establish shared issue channel and immediate remediations
• Quarterly action rundown
• Handover deliverables and closeout logistics