Behind-the-Meter Generation or Microgrid Deployment Program
Interconnection queues and distribution capacity constraints have made grid power a scheduling problem rather than a procurement one, and the organizations that cannot wait are generating their own. Behind-the-meter projects are not solar arrays bolted onto a roof. A facility that intends to operate through a grid outage needs islanding capability, which means protective relaying, automatic transfer, a microgrid controller that can balance generation against load in real time, and switchgear designed for the transition. It needs permits that most energy projects do not: air permits for engines or turbines, fire code approval for battery energy storage with its own separation, ventilation, and suppression requirements, and electrical and structural permits for equipment that did not exist on the site plan. It needs a utility arrangement covering interconnection, standby charges, and export, and it needs an operating model, because generation assets fail differently than utility service does. Avina detects interconnection and distributed generation filings, storage and emission permits, financing and offtake announcements, and the energy management and controls hiring that marks a committed program.
Why On-Site Generation Is a Buying Signal for Sales Teams
On-site generation used to be a sustainability program. It is now a capacity and continuity program, and that change is what makes this signal commercially useful, because continuity projects get funded on a schedule and sustainability projects frequently do not. The driver is usually that the grid cannot deliver in time. Large new loads, whether a data center, an electrified manufacturing process, or a fleet charging depot, are facing interconnection studies and distribution upgrades measured in years. An organization with a facility to open cannot absorb that delay, so it builds generation to bridge or replace the shortfall. That reframes the project from discretionary to schedule-critical, and schedule-critical projects buy quickly. Islanding is where the engineering cost lives. A generator that runs when the grid is down is a familiar backup arrangement. A microgrid that detects a disturbance, separates from the grid, continues serving critical load from a mix of sources, and then resynchronizes without an outage is a controls and protection problem. It needs relaying and automatic transfer equipment, a controller capable of real-time dispatch across generation, storage, and load, and a tested sequence of operations. This is the single largest technical purchase in the program and the one most often underestimated. The permitting path is unusually broad. Engines, turbines, and fuel cells are emission sources requiring air permits, with limits on operating hours that constrain how the asset can be dispatched. Battery energy storage triggers fire code requirements including hazard mitigation analysis, separation distances, ventilation and deflagration provisions, and suppression, with an authority having jurisdiction that may have limited experience approving these systems. Medium-voltage equipment requires electrical and structural permits and often a utility witness test. Fuel storage carries its own approvals. Any one of these can become the critical path. The utility arrangement is a negotiation, not a form. Interconnection of generation behind the meter requires an application, a study, and an agreement, with upgrade costs that may be allocated to the customer. Standby and backup tariffs price the utility's obligation to serve a customer who mostly self-supplies, and those charges can determine whether the project pencils. Export arrangements, if any, have their own rules. Organizations routinely need regulatory and tariff expertise they do not have in-house. Financing structures bring their own advisors. Many of these projects are delivered as a power purchase agreement or energy-as-a-service arrangement so the host avoids capital outlay, which means a developer, a financier, measurement and verification, and an operating agreement. Tax credit monetization through transfer or tax equity adds structuring and compliance work, and credit eligibility carries construction start and in-service deadlines that drive the schedule hard. Operations are a new competency. A facility that owns generation has to maintain it, test it under load, keep fuel available, manage dispatch against tariffs and emissions limits, and respond when it fails. That produces purchases in asset performance management, service contracts, submetering, and dispatch optimization, and it produces hiring, because most facilities teams have never run a generation asset. Security becomes a real exposure. A microgrid controller is an operational technology system with authority over the facility's power, networked for remote monitoring and often vendor-accessed. Organizations that think carefully about this buy operational technology segmentation, monitoring, and access control alongside the project. Organizations that do not are a different kind of opportunity. And the resiliency case is increasingly mandated rather than chosen. Critical facility designations, state resiliency programs, and institutional requirements for hospitals, water systems, and emergency facilities put backup and islanding capability into obligations with dates, and grant funding frequently comes attached.
How Does Avina Detect Microgrid and On-Site Generation Programs?
Avina, an AI-powered GTM platform, reads interconnection filings, permits, and energy hiring together, because filings and permits establish a funded project with a schedule and hiring establishes who will operate it. Interconnection filings are the primary anchor. Distributed generation and behind-the-meter interconnection applications, queue positions, study results, and upgrade cost allocations are visible and dated, and they identify both the capacity involved and the stage of the process. Large load interconnection requests and capacity constraint disclosures identify the organizations most likely to self-generate next, which is the earliest entry point in this signal. Tariff activity reveals the economics. Standby, backup, and departing load tariff filings, exemption requests, net metering and export arrangements, and utility resiliency and distributed energy program participation establish whether a project is viable and which incentives are in play. Permits confirm physical commitment. Air permit applications for stationary engines, turbines, and fuel cells, battery energy storage permits with hazard mitigation analysis filings, electrical, structural, and building permits for generation and storage equipment, fuel storage approvals, and zoning and conditional use approvals establish that equipment has been selected and a construction schedule exists. Storage fire code filings in particular identify projects where approval is the critical path and specialist support is needed. Commercial and financing announcements show structure. Power purchase agreement, energy-as-a-service, and performance contract announcements, project announcements and groundbreakings, tax credit transfer and tax equity arrangements, resiliency and microgrid grant awards, and equipment orders establish who owns the asset and therefore who buys what. Operational pressure explains motivation. Outage, storm, and reliability disruption disclosures, demand charge and energy cost escalation commentary, business continuity and critical facility designations, load growth tied to electrification or compute expansion, and utility curtailment or service limitation notices identify organizations with a concrete reason to act now. Hiring shows the operating plan. Avina tracks listings for energy managers and directors of energy, controls and automation engineers naming microgrid or distributed energy, electrical engineers for medium-voltage and switchgear work, facilities and plant engineers naming cogeneration or standby generation, sustainability roles tied to on-site generation, operational technology security roles, and energy procurement and analytics roles. A first director of energy or a controls engineer posting naming microgrid work is a strong marker that a project has passed study and is being built. Technographic evidence maps what can operate the asset. Building and energy management, supervisory control and data acquisition, microgrid control and dispatch optimization, submetering, asset performance management, and operational technology security platform adoption shows whether an organization can monitor, dispatch, and protect generation with what it has, and a project with permitted storage and no visible controls or operational technology security footprint is the sharpest qualifier here. Each account is enriched with the interconnection filing and stage, tariff and incentive context, the permits and their status, the financing structure and counterparties, the operational pressure behind the project, the roles posted, and the current platform footprint, then matched against your ICP filters.
What Happens When an On-Site Generation Signal Fires?
Avina scores on schedule pressure, approval complexity, and operating gap. An organization with a filed interconnection application for behind-the-meter generation, permitted battery storage with a hazard mitigation analysis under review, a posted controls engineer naming microgrid work, a disclosed outage or load growth driver, and no visible microgrid control or operational technology security footprint scores at the top of the model, because the project is committed, the approvals are in motion, and neither the dispatch nor the security capability exists. An organization facing a long interconnection queue for a new large load scores highest on urgency, because the facility's opening date is at stake. An organization with a tax credit arrangement scores highly on schedule, because construction start and in-service deadlines are fixed. An organization under a critical facility or resiliency mandate scores highly on compliance-driven spend. An organization that has engaged a developer under an energy-as-a-service structure shifts the buyer to the developer for equipment and to the host for controls integration, submetering, and security. An organization with mature energy management and an existing cogeneration asset scores lower overall and higher on dispatch optimization and asset performance. Timing is set by queues, permits, and credit deadlines. Interconnection application and study milestones determine when equipment decisions are made and when upgrade costs become known. Fire code and hazard mitigation review for storage is frequently the longest approval and the one that slips. Air permit decisions determine allowable operating hours, which shapes the dispatch strategy and therefore the controls requirement. Tax credit construction start and placed-in-service deadlines are hard and drive procurement forward aggressively. Grant performance periods carry obligation dates. Equipment lead times for switchgear, transformers, turbines, and battery systems are long and have been the binding constraint on many projects, which means selection happens far ahead of construction. Commissioning and witness testing is when controls and protection gaps surface. Storm and peak season readiness dates drive backup capability deadlines at hospitals, water systems, and critical facilities. Utility rate case outcomes change standby charges and can re-open the economics. And capital budget approval cycles determine when the host-side controls, submetering, and security work is funded, often a cycle after the generation itself. Routing spans facilities, energy, finance, and security. The director of energy or chief sustainability officer owns the program where one exists and is the most receptive contact. The director of facilities or chief engineer owns installation, operation, and maintenance. The plant manager owns process continuity and the cost of an outage. The vice president of real estate or data center operations owns site capacity and the opening date. The electrical engineering lead owns protection, switchgear, and islanding design. The chief financial officer owns the financing structure, tax credit treatment, and the capital plan. The head of procurement owns energy supply, tariffs, and the developer or equipment contract. The head of operational technology or industrial security owns controller exposure and segmentation. The business continuity and risk leader owns the resiliency requirement. The regulatory affairs lead owns the interconnection agreement and tariff negotiation. And on the developer side, the director of development owns site selection and the project pipeline. Contacts are enriched with verified emails, phone numbers, and LinkedIn profiles through waterfall enrichment across energy management, facilities and engineering, operations, finance, procurement, security, and risk. Reps receive a Slack alert naming the organization and the site, the interconnection filing and stage, tariff and incentive context, the permits and their status, the financing structure, the driver behind the project, the roles posted, and the platforms already in place. Salesforce and HubSpot records carry interconnection milestones, permit review dates, tax credit deadlines, equipment lead times, and commissioning targets so outreach lands while equipment and controls are still being specified. Qualified accounts can be auto-enrolled into Outreach or Salesloft sequences matched to the phase: feasibility, load analysis, and resiliency modeling where a large load is stuck in a queue, interconnection, tariff, and regulatory advisory where standby charges and upgrade costs determine viability, protection, switchgear, and islanding engineering where continuous operation through an outage is the requirement, microgrid control and real-time dispatch where multiple sources have to be balanced, battery energy storage permitting, hazard mitigation analysis, and fire code support where approval is the critical path, air permitting and emissions compliance for engines, turbines, and fuel cells, energy-as-a-service and power purchase structuring where the host wants to avoid capital outlay, tax credit transfer and incentive compliance where credit deadlines drive the schedule, submetering, load monitoring, and energy management where dispatch has to be measured and verified, asset performance management and maintenance programs where a facility now owns generation it has never operated, operational technology segmentation, monitoring, and remote access control for the controller and its vendor connections, demand response and capacity program participation where the asset can earn revenue, and commissioning, load bank testing, and sequence of operations validation before the site relies on it.
Start Tracking On-Site Generation Programs With Avina
An interconnection application plus a permitted storage system means a facility is building its own power and has not yet bought the controls or the security to run it. Activate this signal in Avina's Signals Library. Every plan includes a 7-day free trial with no credit card required.