Smart Grid and Advanced Metering Infrastructure Rollout Plan

Role: Principal Energy Infrastructure Program Director

Context

• Electric distribution company: {{energy_distributor}}
• Geographic coverage and customer density: {{service_territory}}
• Existing metering fleet: {{legacy_meter_footprint}}
• Total approved capital envelope: {{capital_budget_allocation}}
• Distribution automation objectives: {{substation_automation_targets}}
• Program duration: {{deployment_timeline_months}}

Task

Produce an enterprise-grade capital deployment and operations plan for {{energy_distributor}} to replace {{legacy_meter_footprint}} with smart grid infrastructure and execute {{substation_automation_targets}} within {{capital_budget_allocation}} across a {{deployment_timeline_months}} schedule.

Method

1. Establish the geographical wave schedule based on substation feeder topologies, communication backhaul availability, and density in {{service_territory}}.
2. Design the RF mesh and cellular backhaul architecture required for bi-directional smart meter telemetry.
3. Formulate the field logistics workflow: inventory staging, field technician routing, legacy meter recycling, and safety protocols.
4. Define meter data management system (MDMS) and customer billing integration pathways to prevent billing cutover errors.
5. Detail the distribution automation roadmap to achieve {{substation_automation_targets}} (FLISR, smart reclosers, volt-VAR optimization).
6. Establish customer communications, notification sequences, access issue resolutions, and opt-out management protocols.
7. Structure a cybersecurity and operational technology resilience plan meeting NERC CIP and regional utility cybersecurity standards.
8. Build the program governance framework covering contractor SLA oversight, variance tracking, and regulatory audit reporting.

Constraints

• MUST stay within the total financial boundary of {{capital_budget_allocation}} without unallocated contingency.
• Field installation sequences MUST NOT exceed the window set by {{deployment_timeline_months}}.
• Customer notification protocols must define at least three touchpoints prior to physical meter exchange.
• Telemetry specifications must address dead zones and terrain anomalies in {{service_territory}}.

Output format

1. Program Governance & Architecture Blueprint (300 words)
2. Phased Deployment Schedule (table: Wave Number, Feeder Group, Meter Count, Start-End Months, Milestones)
3. Grid Modernization & Automation Framework (300-400 words detailing {{substation_automation_targets}})
4. Field Operations & Workforce Staging Plan (250-350 words)
5. Consumer Engagement & Exception Handling Protocol (process steps with timelines)
6. Capital Allocation & Cost Control Ledger (cost breakdown by technology, labor, contingency)

Self-review

• Ensure every phase aligns with the total scope of {{legacy_meter_footprint}}.
• Verify all cost line items aggregate precisely to {{capital_budget_allocation}}.
• Validate that backhaul and field routing reflect the distinct topography of {{service_territory}}.