The common vegetation management practices for electric and gas utilities split along two lines. For electric utilities, the dominant practices are cyclic right-of-way trimming under NERC FAC-003-5 (with FAC-003 expansion to 100 kV facilities under active discussion following NERC's April 2026 wildfire report), Integrated Vegetation Management (IVM) using mechanical, manual, and selective-herbicide methods, and the growing use of satellite, LiDAR, and AI-driven risk analytics from vendors like AiDash and Overstory. For gas utilities, the dominant practices are PHMSA-required right-of-way maintenance that supports inspection access at 4.5- to 15-month intervals, native-vegetation balance with operator visibility, and contractor-led vegetation programs coordinated through the utility's work order management layer. The compliance, contractor coordination, and asset-register updates that come out of vegetation work are increasingly software-driven, with specialized risk-analytics platforms on the analysis side and operational work order platforms on the execution side.
For electric and gas utilities, vegetation management is the set of programs that keep trees, brush, and grass from interfering with transmission lines, distribution lines, substations, gas pipeline rights-of-way, and access roads. The scope is operational and regulatory at the same time: trim cycles, contractor crews, herbicide applications, and aerial inspections produce the outcomes, but the work happens against a regulatory backdrop (NERC FAC-003 for electric transmission, PHMSA right-of-way requirements for gas pipelines) that punishes documented gaps.
The 2026 industry direction is unambiguous: a move away from fixed, calendar-based trim cycles toward risk-based, data-driven prioritization. The drivers are wildfire risk in the western US, satellite and AI cost curves dropping, and regulators tightening documentation expectations after high-profile vegetation-related outages and ignitions. Practices that were standard fifteen years ago (a contractor cycle every five years across the entire ROW) are being replaced or supplemented by year-over-year risk modeling that targets high-consequence spans before they become incidents.
Electric utility vegetation management for transmission lines operates under NERC FAC-003-5, which requires that trees and other vegetation growing in or adjacent to the transmission line right-of-way be managed to prevent power outages caused by tree contact. FAC-003-4 currently applies to facilities rated 200 kV and above; the 2026 NERC wildfire report proposes expanding scope down to 100 kV facilities, which would significantly broaden the compliance footprint.
The common practices at this layer include:
For utilities running NERC-tied compliance work alongside vegetation operations, electric utility regulatory compliance covers the broader FAC-003, PUC, and state-level regulatory framework that vegetation programs sit within.
For distribution lines (below transmission), vegetation management is regulated primarily at the state PUC level rather than NERC, but the operational practices (cycle trimming, IVM, hazard tree work) are similar. Distribution lines also carry the bulk of customer-facing outage risk from vegetation contact, which is why utilities increasingly run risk-based programs on distribution feeders as well.
Gas utility vegetation management is structured around a different regulatory driver: PHMSA's requirement that the pipeline right-of-way be maintained so that operators can inspect surface conditions at required intervals. Per PHMSA guidance, natural gas transmission pipeline operators must inspect the right-of-way one to four times per year at intervals not exceeding 4.5 to 15 months, depending on the population density near the pipeline.
The common practices for gas:
For gas utilities running compliance documentation across PHMSA pipeline safety, state PUC requirements, and right-of-way management, the regulatory compliance software guide for utility companies covers the cross-rule compliance framework that gas utilities operate inside.
The practical operational difference between electric and gas vegetation programs is that electric programs are driven by clearance from energized conductors (an operational and reliability issue) while gas programs are driven by inspection access (a safety and integrity management issue). The vegetation methods overlap heavily; the regulatory documentation and risk modeling do not.
Which methods is your utility running today, and which ones are the audit, the wildfire risk model, or the budget pushing you toward in 2026?
The major method categories used across electric and gas utility vegetation programs:
Most modern programs combine four or five of these. The pure-cyclic, contractor-only programs that were standard in the 2000s are increasingly the minority at large utilities, replaced by hybrid programs that use risk analytics to target where the cyclic crews go.
The software stack supporting utility vegetation management has split into three layers, and confusing one for another is one of the most common procurement mistakes.
The risk analytics layer is where satellite imagery, LiDAR, and aerial data are fused with ML models to identify high-risk spans and prioritize work. Specialized vendors dominate this layer: AiDash operates a satellite-first Intelligent Vegetation Management System that fuses satellite, LiDAR, aerial imagery, weather, and utility outage and customer data to model grow-in risk, fall-in risk, and tree vitality. Overstory uses similar satellite-and-AI approaches focused on vegetation analytics for electric corridors. EPRI and engineering consultants such as Trimble and ESRI also operate in this space with varying focus.
The GIS and asset layer is where the physical assets, ROW boundaries, conductor data, and pipeline routing live. ESRI is the dominant platform, with utility-specific tools layered on top. The risk analytics layer pulls from and writes back to the GIS layer. For broader context on how GIS sits inside a utility's asset management stack, GIS asset management software for utilities covers how GIS connects with the asset and work order layers that vegetation programs depend on.
The work order and contractor coordination layer is where the vegetation work actually happens operationally: dispatching crews, tracking completion, capturing photos and evidence, paying contractors, and updating asset records after the work is done. This is the operational backbone whether or not the utility uses sophisticated risk analytics on the analysis side. Many small and mid-size utilities run risk-based prioritization through a vendor like AiDash and execute the dispatched work through their work order management platform, with each side feeding the other.
For a utility evaluating whether to keep a pure-cyclic program, add risk analytics, or start fresh on an IVM-and-satellite combined model, what is the order of operations?
Five practical steps for utility leaders building or refreshing a vegetation management program for 2026:
The concrete data points a utility should maintain across its vegetation program, whether running cyclic, IVM, or risk-based prioritization:
The work order management layer is where most of these data points originate operationally. Risk analytics platforms generate the prioritization; the work order platform captures what actually happened in the field. Utilities running fragmented stacks (a risk analytics platform, a separate work order system, a separate contractor management portal) often find the integration layer is where evidence drops out. Utilities running integrated work order and asset management capture the full chain from dispatch to completion to asset register update.
The most common practices are cyclic trimming and pruning on three-to-five-year cycles, Integrated Vegetation Management (IVM) combining mechanical, manual, biological, and selective herbicide methods, hazard tree assessment and removal outside the right-of-way, aerial patrols, and increasingly the use of satellite and AI-driven risk analytics for prioritization. NERC FAC-003-5 governs transmission vegetation management at 200 kV and above, with the 2026 NERC wildfire report proposing expansion to 100 kV facilities.
Gas utility vegetation management focuses on maintaining pipeline right-of-way clearance to support PHMSA-required inspection access. Common practices include mechanical mowing and clearing, selective herbicide application, removal of landscaping or obstructions placed by adjacent property owners, and contractor-led ROW maintenance coordinated through the utility's work order system. Native low-growing vegetation is generally permitted where compatible with inspection access.
Integrated Vegetation Management is a program approach that combines mechanical, manual, biological, and chemical (herbicide) methods to manage right-of-way vegetation in environmentally responsible ways. The core idea is to control incompatible tall-growing species and encourage low-growing native vegetation, which reduces long-term mechanical-trim cost, supports biodiversity, and reduces fall-in risk over time.
Utility vegetation management software splits across three layers. Risk analytics platforms (AiDash, Overstory, and similar) fuse satellite, LiDAR, and aerial imagery with ML models to identify high-risk spans. GIS platforms (ESRI dominant) hold the asset and right-of-way data. Work order management platforms dispatch crews, track completion, and update asset records after vegetation work is done. Most utilities use a combination, with the risk analytics layer feeding into the work order layer for execution.
The 2026 direction is away from pure cyclic trimming toward risk-based, data-driven prioritization. Drivers include the increased wildfire risk focus (especially in the western US), the falling cost of satellite and AI analytics, and tightening regulatory documentation expectations. The April 2026 NERC wildfire report proposes expanding FAC-003 from 200 kV down to 100 kV facilities, which would significantly broaden the compliance footprint for electric utilities. Gas utility programs continue to evolve under PHMSA inspection access requirements.
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