Regulators push utilities to connect inspection data to risk models, not just file it

State utility commissions are raising the evidentiary bar on grid inspections, moving from a compliance-filing model toward one where asset condition data must actively drive risk and ignition decisions. A Utility Dive analysis published 12 October 2026 by eSmart Systems argues that regulators across the country are converging on the same expectation: inspections must produce more than a compliance checklist.^[1]

What regulators now want to see

From Hawaii's wildfire mitigation plan updates to Texas's new wildfire mitigation plan filing guidance, state commissions increasingly want inspection findings fed into risk and ignition models, with asset condition data used to drive investment decisions and prioritize follow-on actions.^[1] The Smart Electric Power Alliance reinforced this at an industry level in its wildfire technology framework, positioning asset condition intelligence as a foundational input across every stage of wildfire risk reduction, from pre-season mitigation planning through post-event recovery.^[1]

The practical implication is that a utility can no longer treat inspection imagery as a record to be filed and forgotten. Regulators and consumer advocates increasingly want to see the logic chain: how a defect finding translated into a capital decision, and how that decision reduced ignition probability.

The data-silo problem

The gap most utilities face is not a shortage of inspection activity - it is that the resulting data sits in disconnected systems that risk, planning, and construction teams cannot easily reach. At one Mountain West utility, roughly 7% of observed cotter pins in an inspection cycle were found to be installed upside down, a defect that can raise the odds of conductor movement or arcing under high-wind, high-fire conditions.^[1] The finding only becomes actionable if it can be queried, prioritized, and routed to the teams that schedule remediation.

Evergy's experience illustrates what connecting that data looks like. In 2019, the Kansas City-based utility shifted to a non-entry underground inspection method that captures high-resolution imagery without sending workers into confined spaces.^[1] In early 2026, that imagery moved into eSmart Systems' Grid Vision platform as a central, searchable repository.^[1] Design and construction teams that previously had minimal access to inspection records can now pull up manhole imagery before a project rather than dispatching a crew to verify conditions already on file.^[1]

What a connected asset record enables

The shift from siloed inspection files to a connected asset record changes several downstream workflows:

• Risk modeling: defect findings can be weighted by asset type, location, and fire-weather exposure rather than treated as a flat list.
• Capital prioritization: investment decisions can be ranked by risk reduction per dollar rather than by inspection date or asset age.
• Regulatory documentation: the logic chain from field finding to capital action is auditable without being rebuilt by hand for each filing.
• Cross-team access: engineering, planning, and construction teams draw from the same condition record instead of maintaining parallel data sets.

What to watch

The regulatory pressure is clearest in California, Hawaii, and Texas, but the SEPA framework suggests the expectation is spreading to regions that have not historically faced severe wildfire exposure. Utilities that have not yet connected inspection outputs to their risk models face a growing documentation gap - one that is harder to close retroactively once a commission asks for it.