An outage tracing tool can combine network, meter, customer, and operational signals to estimate where an interruption is, which customers or assets may be affected, and what response actions need attention. An outage management system (OMS) can help coordinate operators and crews; with a suitable network model and automated distribution equipment, FLISR can isolate a fault and restore unaffected sections in the right conditions. These tools do not guarantee an exact fault location or repair a damaged line: accuracy and automation depend on data, integrations, equipment, operating rules, and human oversight.
What an outage tracing tool can do
Detect and group outage signals
An OMS can combine customer trouble reports, meter alerts, network information, and other operational signals to detect and group possible outage events. Oracle describes automated outage detection and event identification in its OMS product material; actual results depend on the signals a utility has available and how its system is configured.
Estimate affected customers and equipment
GIS and network tracing can connect an incident to modeled lines, devices, customers, and facilities. A trace is an estimate based on the network data and tracing method, not independent confirmation of what is happening in the field. UOMS describes affected-area methods, hosted-data Trace Lite, and more precise Utility Network tracing for Enterprise deployments; it also states that Trace Lite does not reproduce every Utility Network capability. The distinction matters when evaluating what a result can establish: see the UOMS product information.
Support prioritization and crew coordination
An OMS can give operators and dispatchers a shared view of events, help prioritize response, coordinate crews, and track restoration status. Meter signals can add useful clues: a U.S. Department of Energy report on the 2016 Smart Grid Investment Grant program describes how AMI “last-gasp” alerts can help operators identify outage locations and dispatch repair crews. Such alerts inform response; they do not fix infrastructure. Read the DOE report.
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Support automated switching in defined conditions
Fault location, isolation, and service restoration (FLISR) uses fault indications and network information to identify a faulted section, isolate it, and assess whether an alternate supply can serve unaffected parts of the system. NEMA’s technical chapter describes the capability conditionally: “If most of the distribution system is still functional, a fault location, isolation, and service restoration (FLISR) system, integrated into the OMS, can restore power to unfaulted portions of a faulted line in seconds.” That is a scenario-specific technical capability, not a universal restoration-time promise. See the NEMA technical chapter.
What it cannot safely promise
A trace is not ground truth
A tool may estimate an affected area or suggest candidate isolation points, but an inaccurate or outdated network model can misrepresent which customers and equipment are connected. Unrecorded field changes, missing meter communications, ambiguous signals, and unusual switching configurations can also weaken the inferred picture. DOE’s implementation report notes the practical need to adapt systems to utility configurations and integrate with existing SCADA, OMS, and DMS systems.
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Some deployments can operate switches automatically; others present options for operator review. The capability depends on the software, license, utility configuration, procedures, and the physical network. Oracle’s release 25.02 NMS licensing information describes outage adapters and DMS fault-location, isolation, and restoration functionality based on SCADA triggers and network data; that description is version- and licensing-specific, not a statement about every OMS. Consult the Oracle NMS licensing information for release 25.02.
Even a capable FLISR system can act only when the detected fault, current network state, available alternate feed, switch equipment, and operating rules permit it. It cannot inspect a damaged pole or cable, clear debris, replace failed equipment, or verify on-site safety. Field crews still investigate damage and perform physical repairs, while operators remain responsible for decisions that require assessment.
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How to compare tools or deployments
Ask vendors and utility teams about the complete operational path—from incoming signals to a field-verified restoration—not just whether the product offers “outage tracing” or “automation.”
- Network-model quality: How current is the connectivity and equipment model, and how is it kept consistent with the as-operated system?
- Signal coverage and freshness: Which SCADA, AMI, customer-report, and field signals are available? How quickly do they arrive, and what happens when a signal is missing or delayed?
- Trace method and precision: Is the system doing service-area analysis, network-aware tracing on hosted data, or Utility Network tracing? What capabilities are omitted by the chosen method?
- System integration: How does it exchange data with GIS, SCADA, AMI, customer information systems, mobile tools, and crew systems? How are mismatches and model updates handled?
- Automation and safety controls: Which actions are recommendations, which require operator approval, and which can execute automatically? What interlocks, switching studies, and approval workflows apply?
- Field feedback: Can crews report damage, confirm switching, and update restoration status so that the operational picture reflects what they find?
What deployment figures do—and do not—show
Oracle’s undated product page, accessed in 2026, reports more than 60 million meters in production worldwide. That is Oracle’s own deployment figure; by itself it does not establish accuracy, restoration speed, or comparative performance against other systems.
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