Solmar Insights
Utilities across the United States are being pushed to move beyond simple compliance checklists during grid asset inspections, as state regulators demand inspection findings that feed directly into risk and ignition models. This shift is driving adoption of centralized asset condition data systems that better inform both risk management and capital expenditure across transmission and distribution networks.
Key figures
16,000 utility assets managed by one system
Eight-year underground inspection cycles in Missouri
Non-entry underground inspections adopted by Evergy
Regulatory demands driving data centralization
State commissions in locations such as Hawaii and Texas are setting new expectations for utility inspection practices. Rather than accepting proof that inspections occurred, regulators now want to see results from inspections directly influencing wildfire mitigation strategies, risk models, and resulting grid investments. This has made asset condition data a foundational element for regulatory compliance and internal utility decision-making.
The evolution is exemplified by recent updates to wildfire mitigation plan (WMP) requirements, whereby inspection findings must be integrated into risk and ignition assessment tools. Separating inspection and modeling systems is seen as no longer adequate; actionable, current asset data is now essential for anticipating and mitigating emergent threats to grid infrastructure.
Asset data integration: from silos to digital hubs
Historically, inspection outputs such as images, GIS data, defect notes, and contractor reports were siloed across utility departments. These data sources frequently went dormant after initial compliance reporting, limiting their impact on ongoing risk management or operational planning. A fundamental shift is underway as utilities work to centralize asset data, transforming passive records into actively leveraged digital condition hubs.
The case of Coldwater Board of Public Utilities, a Michigan municipal utility, demonstrates scalable digital adoption. From a two-feeder pilot project, Coldwater has expanded to archive and actively use data covering about 16,000 assets, achieving utility-grade inspection capabilities previously seen only at larger investor-owned utilities. Importantly, this scale-up was accomplished without growing staff, indicating the operational advantages such platforms bring to small and medium-sized service areas.
Underground inspection: Evergy case study
Evergy, servicing the central United States, illustrates the operational transformation enabled by modern asset data practices. Starting in 2016, Evergy conducted underground manhole and vault inspections using three-person teams and manual entry, resulting in safety risks and frequent repeat visits due to poor-quality imagery. This changed in 2019 when Evergy adopted a non-entry method, capturing high-resolution images without crews entering confined spaces.
By 2026, Evergy centralized all inspection imagery within its Grid Vision repository. This digital system is now accessible to design, construction, and engineering teams, streamlining the pre-construction process. Where once crews would need field visits to confirm infrastructure status, teams can now verify conditions remotely, reducing safety exposure and operational overhead.
Operational and cost implications for utilities
The transition to centralized, searchable asset data produces concrete operational benefits. According to Evergy’s asset management engineering staff, broader access to updated, high-resolution inspection data has improved both maintenance planning and cross-departmental collaboration. Teams that previously had limited or outdated visibility into underground and overhead assets can now rely on shared, near-real-time information to drive investment and maintenance priorities.
Institutional investors and system owners are particularly attuned to the cost implications. As demonstrated by Coldwater’s experience, deployment of digital inspection systems can confer IOU-scale capabilities without proportional increases in staffing. For regional utilities, this offers an opportunity to stretch limited capital further, maintain regulatory compliance, and support higher levels of grid reliability as state standards rise.
Market significance and future expectations
For buyers, developers, and investors in U.S. energy infrastructure, these evolving inspection and risk management practices signal changes in due diligence expectations and asset valuation. With state commissions now considering data-driven risk scores when reviewing project plans and WMP filings, the bar for investment-grade documentation is higher. Digital condition hubs are becoming prerequisites for regulatory approval and risk-adjusted investment modeling.
The trend is expected to expand as more utility commissions review wildfire and climate resilience plans, and as digital data practices become entwined with physical grid improvements. Technology vendors and asset management platforms that integrate image capture, defect logging, and GIS mapping in a single system are likely to see expanding demand, particularly as compliance pressures mount and operational cost savings become visible across the sector.
What this means for buyers
Asset condition data and digital equipment management in the United States grid sector now strongly influence investor due diligence. The adoption of centralized hubs covering as many as 16,000 assets, alongside new regulatory demands, changes both the proof and substance required for risk assessment. Buyers will need to request integrated asset data as standard when evaluating utility assets and may see lowered operational risk profiles on digital-first systems.
Reporting via the original publisher
