Appendices

These appendices provide practical checklists and templates to support the workstreams in the playbook. They are intended as management tools for structuring discussions, documenting assumptions, and preparing decisions.

Appendix A. Executive Power Access Diagnostic Checklist 

Use this checklist during the first 30 days after learning that full utility service may be delayed. The purpose is to establish facts, ownership, and decision momentum before the project loses time.

• Business impact: Confirm launch date, revenue at risk, customer commitments, penalties, tax incentive deadlines, workforce implications, and the estimated cost of delay.
• Utility position: Request written confirmation of available capacity, delayed capacity, required studies, upgrade assumptions, deposits, and likely energization date.
• Load baseline: Build an initial view of connected load, expected load, peak demand, base load, critical load, flexible load, day-one load, and full-build load.
• Minimum viable operation: Define the smallest operating configuration that creates meaningful value while remaining safe, compliant, and customer-relevant.
• Immediate levers: Screen peak reduction, phased ramp-up, managed charging, operating windows, temporary generation, batteries, solar, fuel cells, neighbor power, and demand response.
• Governance: Name an executive sponsor, program owner, utility contact, finance lead, legal lead, engineering lead, and workstream owners.
• Decision roadmap: Identify the decisions required in the next 30, 60, and 90 days, including utility resubmission, bridge power, permits, and vendor RFPs.
• Red flags: Escalate immediately if the site may be unusable, the utility cannot provide partial service, permits may exceed the bridge timeline, or customer commitments are at risk.
  
  

Appendix B. Utility Interconnection Readiness Checklist

Before submitting or revising a utility request, confirm that the package is complete, consistent, and controlled. A clean submission cannot guarantee speed, but it reduces avoidable friction.

• Service information: Site address, customer entity, requested service date, service voltage preference, metering location, ownership boundary, and primary contact.
• Load documentation: Phase-by-phase demand, peak demand, average demand, ramp-up schedule, major equipment list, expected power factor, and flexible-load assumptions.
• Engineering documents: Site plan, single-line diagram, transformer and switchgear assumptions, backup generation plans, solar or storage plans, and future expansion areas.
• Commercial readiness: Study deposits, customer contribution exposure, easements, credit support, tariff review, and internal approval authority.
• Operating flexibility: Identify partial service, curtailable load, interruptible load, off-peak operation, demand caps, and phased energization options.
• Communication control: Use one version of the load letter, one utility-facing owner, documented questions, and meeting notes after every utility interaction.
• Readiness evidence: Keep a dated record of submissions, utility responses, deposits paid, assumptions confirmed, and open technical issues.
  
  

Appendix C. Facility Load Data Request Template

Use this template to gather the information needed for a utility-grade load forecast. The request should go to engineering, operations, equipment vendors, construction, automation, IT, and facilities teams.

• Facility profile: Site use, operating hours, shifts, seasonal patterns, launch phases, expansion assumptions, and critical operations.
• Equipment inventory: Equipment name, quantity, voltage, rated kW or horsepower, expected operating load, duty cycle, startup behavior, vendor, and installation date.
• System categories: HVAC, refrigeration, process equipment, compressed air, pumps, fans, lighting, IT, data halls, automation, chargers, life safety, and future expansion.
• Operating data: Utility bills, interval data, submeter data, production volume, temperature records, maintenance logs, and commissioning schedules.
• Criticality inputs: Loads that are critical, essential, flexible, deferrable, curtailable, or noncritical during constrained operation.
• Assumption quality: Mark each input as final, vendor-confirmed, engineering estimate, historical proxy, or planning assumption.
• Open questions: Assign an owner and due date for missing data, unresolved vendor specifications, and future expansion assumptions.
• Data governance: Store the current equipment list, load model, assumptions log, and source documents in one controlled project folder.
  
  

Appendix D. Sample 8760 Load Forecast Output

An 8760 model shows expected facility demand for every hour of a non-leap year. The output should be simple enough for executives to interpret and detailed enough for utility and engineering review.

• Required fields: Date, hour, total load, critical load, flexible load, HVAC load, process load, charging load, solar production, battery dispatch, generator output, and net utility demand.
• Scenario fields: Commissioning, minimum viable operation, phase one, full buildout, curtailed operation, summer peak, winter peak, and outage mode.
• Decision outputs: Annual energy, monthly peak, highest hourly peak, number of hours above each demand cap, coincidence with utility peak, and storage or generator requirement.
• Interpretation: Identify whether the constraint is continuous baseload, seasonal cooling, short-duration spikes, charging behavior, startup events, or future expansion.
• Review questions: What creates the peak, how often does it occur, can it be shifted, and does the requested service reflect actual operations?
• Quality checks: Reconcile annual energy to expected operations, confirm that phase dates match the ramp-up plan, and flag assumptions that drive the peak.
  
  

Appendix E. Peak-Load Reduction Opportunity Checklist

Use this checklist to identify load reductions before resizing utility requests or bridge-power systems. The best measures reduce peak demand without reducing high-value output.

• Operations sequencing: Stagger equipment starts, shifts batch processes, separate charging from production peaks, and avoids simultaneous commissioning tests.
• Control changes: Add demand caps, alarms, automatic load shedding, managed charging, HVAC scheduling, refrigeration staging, and restart sequencing.
• Equipment improvements: Add variable frequency drives, correct power factor, repair compressed air leaks, tune chillers, optimize compressors, and right-size motors.
• Thermal flexibility: Use pre-cooling, chilled water, ice storage, refrigeration thermal mass, and safe temperature bands where product and comfort allow.
• Operating rules: Define who authorizes load reduction, what turns off first, how long the reduction lasts, and how loads restart without rebound peaks.
• Business trade-offs: Rank each measure by peak reduction, cost, speed, operating impact, customer impact, reliability risk, and utility relevance.
• Validation: Test priority measures with operators before committing them to the utility or relying on them to resize bridge power.
  
  

Appendix F. Bridge Power Options Comparison Template

Compare bridge options using consistent criteria rather than vendor-specific claims. The template should show both the technical answer and the business consequence.

• Option description: Temporary generators, gas engines, batteries, solar-plus-storage, fuel cells, CHP, neighbor supply, co-location, or hybrid system.
• Power capability: MW available, MWh or duration, supported loads, redundancy level, ramping capability, and ability to support motor starts.
• Execution path: Equipment availability, permits, fuel, utility approval, construction requirements, commissioning, operator training, and earliest operating date.
• Commercial view: Capex, opex, fuel cost, rental cost, incentives, utility savings, avoided delay, residual value, and stranded-asset risk.
• Risk rating: Permitting, emissions, noise, safety, utility interface, fuel reliability, vendor performance, community acceptance, insurance, and exit complexity.
• Recommendation: State preferred option, fallback option, decision required, next gate, and assumptions that would change the answer.
• Exit plan: State whether the asset will be removed, retained, repurposed, sold, or integrated into the permanent power architecture.
  
  

Appendix G. Solar, Storage, and Generation Vendor RFP Template

A vendor RFP should create comparable bids and prevent scope gaps. It should be issued only after the owner has defined the use case, supported loads, and required operating modes.

• Project background: Facility description, power constraint, target service date, operating phases, load profile, and desired use cases.
• Technical scope: Required capacity, duration, operating modes, connection point, voltage, controls, protection, metering, fuel assumptions, and supported loads.
• Vendor response: Equipment proposed, delivery schedule, exclusions, site requirements, warranty, service model, safety certifications, references, and performance guarantees.
• Commercial response: Installed cost, rental cost, O&M cost, fuel assumptions, escalation, payment milestones, liquidated damages, and change-order process.
• Execution requirements: Permits, utility coordination, construction, commissioning, operator training, documentation, cybersecurity, and turnover materials.
• Evaluation criteria: Score technical fit, delivery certainty, total installed cost, integration risk, safety, warranty, service response, and contractual exceptions.
• Required attachments: Request equipment cut sheets, single-line markups, project schedule, permit assumptions, commissioning plan, insurance evidence, and reference projects.
  
  

Appendix H. Utility Meeting Agenda Template

Use a structured agenda to keep utility discussions factual and decision-oriented. Circulate materials in advance and send notes within 24 hours.

1. Project update: Confirm facility status, construction timing, requested service date, operating phases, and business criticality.
2. Load update: Review phase-by-phase demand, minimum viable load, flexible load, demand caps, and any revisions since the prior meeting.
3. Utility status: Review studies, capacity constraints, upgrade scope, cost estimate, deposits, required decisions, and expected dates.
4. Options discussion: Discuss partial service, phased service, alternate feeders, limited operating agreements, interruptible service, and customer-funded acceleration.
5. Open questions: Review technical questions, missing documents, decision owners, due dates, and dependencies on utility or customer teams.
6. Action log: Confirm next steps, next meeting, documents required, escalation items, and who will issue the meeting record.
7. Escalation items: Identify decisions that require senior utility, executive, regulatory, or commercial engagement before the next meeting.
   
   

Appendix I. Power Access Acceleration PMO Dashboard Template

The PMO dashboard should show executives what is blocking energization, what decisions are required, and whether the current plan still supports the business launch.

• Executive status: Overall status, target energization date, confidence level, decision required, and top three risks.
• Workstream status: Utility, load forecast, engineering, permitting, bridge power, gas supply, procurement, controls, finance, legal, and operations.
• Critical path: Next milestones, dependencies, delayed items, owner, due date, recovery action, and escalation need.
• Financial view: Approved spend, forecast spend, cost of delay, bridge-power burn rate, customer contribution, and pending commitments.
• Risk view: RAID log highlights, mitigation actions, unresolved assumptions, vendor risks, permit risks, utility risks, and upcoming stage gates.
• Decision log: Record what was decided, who approved it, why it was decided, and what follow-up is required.
• Cadence: Update the dashboard weekly during option development and more frequently when procurement, permitting, or energization is on the critical path.
  
  

Appendix J. Glossary of Common Power Access Terms

Bridge power: Interim power used until permanent utility service is available.

Connected load: Total rated capacity of installed or planned electrical equipment.

Critical load: Load that must remain powered to protect safety, product, data, compliance, or revenue.

Demand cap: Maximum demand the facility agrees or attempts to stay below.

Energization: Safe connection of the facility to live electrical service.

Firm load: Load expected to be served without planned interruption.

Interconnection: Technical and commercial process for connecting load or resources to the grid.

Load factor: Relationship between average demand and peak demand over time.

Microgrid: Local system of loads and energy resources that can operate with the grid or independently if designed for islanding.

Peak demand: Highest level of power draw during a defined period.

Point of interconnection: Location where the facility connects to the utility system.

Standby service: Utility capacity kept available when the customer uses on-site generation.

Demand response: Program or operating practice in which the facility reduces load during defined utility, market, or emergency events.

Limited operating agreement: Agreement that allows service under defined constraints, such as a demand cap, curtailment obligation, or seasonal limit.

Customer contribution: Payment by the customer toward utility facilities or upgrades needed to serve the load.

Utility queue: Process used by the utility to manage service requests, studies, and construction commitments.