Electric utilities are managing increasingly aging infrastructure while facing higher reliability expectations, extreme weather, rising electricity demand, and growing maintenance costs. In this environment, relying primarily on reactive maintenance can leave utilities responding to failures rather than preventing them.
Condition-based asset management offers a different approach. Instead of maintaining equipment only after a failure or according to a fixed schedule, utilities can use asset condition, inspection data, operating history, and risk information to determine when maintenance is actually needed.
Why Utilities Need to Move Beyond Reactive Maintenance
Reactive maintenance can be effective for low-risk equipment, but it becomes problematic when applied to critical grid infrastructure. A failed transformer, deteriorated pole, damaged conductor, or defective substation component can lead to outages, emergency repairs, safety concerns, and significant operational costs.
Aging infrastructure makes early identification even more important. Two assets of the same age may have very different conditions because of loading, environmental exposure, maintenance history, and operating conditions.
The U.S. Department of Energy has highlighted the importance of proactive, data-driven approaches to managing aging grid infrastructure and improving reliability and resilience. DOE grid modernization resources
What Is Condition-Based Asset Management?
Condition-based asset management uses information about the actual condition of an asset to guide maintenance and lifecycle decisions.
Instead of asking only whether an asset has reached a certain age, utilities can evaluate:
Current asset condition
Deterioration trends
Maintenance history
Operating conditions
Asset criticality
Probability of failure
Consequences of failure
This approach does not mean eliminating scheduled maintenance. Rather, it allows utilities to combine scheduled programs with condition information so maintenance resources can be directed toward assets that need attention most.
Start With Better Asset Data
Condition-based management depends on reliable asset information. Utilities often have relevant data spread across GIS platforms, maintenance systems, inspection reports, SCADA systems, field records, and other databases.
Connecting these sources can give utility teams a more complete view of individual assets.
For example, an asset record could combine its location, age, inspection history, previous defects, maintenance activity, operating conditions, and current condition rating.
Better asset data can help utilities move from isolated inspection findings toward more informed maintenance decisions.
Use Inspection Data to Track Asset Condition
A single inspection provides a snapshot, while repeated inspections can reveal deterioration over time.
Consider a transmission structure where an inspection identifies early corrosion. If the same structure is assessed again later, the utility can determine whether the condition has remained stable or worsened.
This creates a useful cycle:
Inspect → Assess → Track → Prioritize → Maintain → Reinspect
Technologies such as thermal imaging, LiDAR, high-resolution photography, and other inspection methods can provide additional condition information. For utilities managing large and geographically distributed networks, drone inspections can also support the collection of visual, thermal, and spatial data.
Connect Condition With Asset Criticality
Condition alone does not determine risk.
A deteriorating asset supporting a critical transmission corridor may deserve faster intervention than an asset with similar deterioration but limited consequences if it fails.
A practical risk framework can consider:
Risk = Probability of Failure × Consequence of Failure
Probability may be influenced by condition, age, deterioration rate, operating stress, and environmental exposure.
Consequence may include customer impact, safety implications, restoration time, replacement cost, and network importance.
Combining these factors helps utilities prioritize maintenance based on risk rather than age alone.
Use Drones as Part of the Inspection Strategy
Drones can provide another source of condition information for overhead utility infrastructure. Visual, thermal, LiDAR, and other aerial inspection technologies can help utilities examine powerlines, towers, poles, and substations while reducing the need for extensive ground access.
For utilities evaluating aerial inspection programs, utility drone services can support the collection of condition data that can then be incorporated into broader asset management workflows. Electricity utility drone services
The important point is that drone inspection should not operate as a separate technology project. Its value increases when inspection findings are connected with asset records, risk assessments, and maintenance planning.
Establish Clear Condition-Based Maintenance Rules
Utilities also need consistent criteria for translating inspection findings into actions.
A simple framework might include:
Condition
Possible Response
Normal
Continue routine monitoring
Watch
Increase monitoring
Moderate
Schedule maintenance
High Risk
Prioritize repair
Critical
Immediate assessment or intervention
The exact thresholds should depend on the asset class and failure mechanism.
EPRI research emphasizes the importance of condition information, standardized condition assessments, historical tracking, and using asset data to support maintenance and lifecycle decisions. EPRI Asset Management Guidelines
Connect Inspection Findings With Maintenance
Inspection data only creates value when it leads to action.
A condition-based workflow can connect:
Inspection finding → Condition rating → Risk assessment → Maintenance priority → Work order → Repair → Verification
For example, an inspection can identify a deteriorating component and associate the finding with a specific asset. The maintenance team can then prioritize the work based on condition and criticality.
After the repair, the result should be added back to the asset record. This creates a continuous feedback loop that improves future maintenance decisions.
Adjust Inspection Frequency Based on Risk
Condition-based management can also change how utilities schedule inspections.
Assets in good condition with low risk may remain on a standard inspection cycle. Assets showing accelerated deterioration can receive more frequent inspections, while critical assets may require immediate assessment or intervention.
This allows utilities to direct inspection resources toward areas where additional information can have the greatest operational value.
A Practical Roadmap
Utilities can begin the transition gradually:
Identify priority asset classes based on reliability, safety, and financial consequences.
Standardize condition assessments and defect classifications.
Connect asset information across GIS, maintenance, inspection, and operational systems.
Introduce risk-based prioritization using condition and asset criticality.
Adjust maintenance and inspection intervals according to asset condition.
Measure results through reliability, emergency work, maintenance backlog, and asset performance indicators.
The objective is not simply to perform less maintenance. It is to perform maintenance at the right time and on the assets where it can provide the greatest value.
Moving Toward Proactive Utility Maintenance
The transition from reactive maintenance to condition-based asset management is ultimately a change in how utilities make decisions.
Instead of asking, “Is this asset due for maintenance?”, utilities can ask, “What does the available condition data tell us about this asset's current risk?”
That shift requires reliable asset data, consistent inspections, risk-based prioritization, and stronger connections between field information and maintenance systems.
For utilities managing aging grid infrastructure, condition-based asset management provides a practical path toward more proactive maintenance, better resource allocation, and improved long-term reliability.