Restore Faster. Comply Automatically.
Predict Before It Fails.
The average U.S. distribution system was built for one-directional power flow in the 1970s. Now it handles rooftop solar backfeed, EV charging demand spikes, and battery storage dispatch , all on infrastructure where 70% of transformers exceed 25 years of age (DOE). Argus converges grid operations, SCADA monitoring, and compliance automation into unified operational intelligence that cuts SAIDI by 15-30%, reduces CAIDI by 20-40%, and generates NERC CIP audit evidence automatically.
From feeder topology tracing to storm restoration coordination, Argus provides the intelligence that keeps 99.98%+ availability a target you can actually hit.
See Your Grid. Trace Every Path. Isolate in Seconds.
Network topology is the foundation of grid operations , and it is where most utilities struggle. Legacy GIS models lag behind field conditions by weeks. Paper switching orders take 15-20 minutes to create. Operators rely on mental models of circuit configurations that break down during mutual aid events when visiting crews have zero system knowledge. Argus maps every feeder, switch, recloser, sectionaliser, and connection point in real time, continuously updated from SCADA and field crew reports. Your operators can trace faults, simulate isolation sequences, validate load transfer capacity, and generate switching orders in seconds , not minutes.
All feeders energised, normally-open and normally-closed switches in their standard positions, load balanced across phases within 10% tolerance. Real-time monitoring of current flow, voltage levels, power factor, and transformer loading at every node. Phase imbalance alerts trigger before neutral overloading causes equipment damage.
Every Reading. Every Alarm. One Dashboard.
SCADA data drives grid operations, but most utilities suffer from alarm floods that desensitise operators , ISA-18.2 studies show that operators miss 15-20% of actionable alarms when alarm rates exceed 6 per hour. Argus integrates telemetry from RTUs, IEDs, and AMI head-end systems into a unified operational view with ISA-18.2-aligned alarm management that suppresses the noise and surfaces the signals your operators need to act on.
Active Alarms
Immediate operator action required. Equipment damage imminent, safety risk to personnel, or protection system failure. Audible alert and screen flash per ISA-18.2 priority 1 standards.
Significant deviation from normal operating parameters. Equipment operating beyond thermal limits or approaching protection relay settings. Prompt investigation within 15 minutes.
Abnormal condition noted , parameter outside optimal range but within equipment rating. Monitor for trend escalation. Address during current shift if resources allow.
Status change logged. Device state transition, scheduled event completion, or communication restoration. No operator action needed , archived for event reconstruction.
The Metrics Your Regulators Measure. Tracked Automatically.
Reliability indices are the scorecard your state PUC uses to evaluate distribution performance, set performance-based rate incentives, and justify (or deny) capital investment recovery. Manual calculation from spreadsheets introduces errors and delays. Argus calculates SAIDI, SAIFI, CAIDI, MAIFI, and ASAI continuously from live outage data , with jurisdiction-appropriate definitions, Major Event Day exclusion per the IEEE 1366 2.5-beta method, and automated report formatting for your specific state commission filing template.
When the Storm Hits, Your Intelligence Should Already Be Working.
NOAA data shows that billion-dollar weather events have tripled in frequency since the 1980s. The average major storm costs a mid-size utility $15-50 million in restoration expenses and generates 50,000-200,000 individual outage events. The difference between restoring in 3 days and 7 days is not just customer frustration , it is the difference between recovering storm costs in your next rate case and facing a prudency disallowance from your PUC. Argus reshapes storm response from a reactive scramble into a coordinated, intelligence-driven restoration operation that starts 72 hours before the first outage.
Weather Monitoring
NWS forecast integration and proprietary storm severity models estimate potential outage counts by circuit, substation, and district. Historical correlation: 0.5 inches of ice accumulation = 15-25% of overhead customers affected. Wind gusts above 65 mph with trees in leaf = 8-12% outage rate on exposed feeders.
Pre-Positioning
Line crews, tree crews, and damage assessors staged at predetermined locations in the projected impact zone. Parts inventory (transformers, poles, crossarms, conductor) verified against damage model predictions. EEI mutual aid agreements activated when forecast severity exceeds internal crew capacity by 30%+. Contractor and mutual aid ETAs tracked in real time.
Storm Impact
Real-time outage tracking from AMI last-gasp data, SCADA relay operations, and IVR customer calls. Automated outage grouping clusters individual meter events into device-level outages. Customer-facing outage map updated every 60 seconds with accurate affected areas and initial ETR estimates. Life-support customer notifications trigger immediately.
Damage Assessment
Field patrol routes optimised by outage density and road accessibility. Damage assessors capture structured data , broken poles, downed conductors, failed transformers , via mobile app with photo documentation. Drone imagery integration for inaccessible areas. Priority restoration queue auto-generates from damage assessment data combined with critical facility status.
Systematic Restoration
Restoration prioritised by the trunk-to-lateral principle: restore backbone feeders first to maximise customers restored per crew-hour. Critical facilities (hospitals, water treatment, emergency services) receive priority dispatch. AI-optimised crew routing considers real-time traffic, road closures, and damage accessibility. ETRs refined continuously as damage assessment data flows in , accuracy within 2 hours of actual restoration for 85% of outage events.
Event Closeout
After-action report generated automatically with IEEE 1366 Major Event Day analysis. Regulatory filings prepared for state PUC storm cost recovery proceedings with documented crew hours, materials consumed, mutual aid invoices, and restoration timeline. Lessons learned captured and fed into pre-positioning models for future events. Total storm cost tracked against pre-event estimates for financial reporting.
Mutual Aid Coordination
When damage exceeds internal capacity, Argus coordinates mutual aid through the EEI/APPA mutual aid network , tracking incoming crews from arrival through demobilisation. Visiting crews receive digital work packages with local system maps, switching procedures, and safety briefings through the Argus mobile app. No more paper packets and two-hour orientation sessions. Typical mutual aid events involve 50-500 foreign crews , Argus manages them all from one dispatch board.
Your Grid Deserves Intelligence That Never Sleeps.
The North American electric grid serves 330 million people across 7,300 power plants, 160,000 miles of high-voltage transmission, and 5.5 million miles of local distribution lines. Your piece of that grid faces aging infrastructure, increasingly severe weather, DER integration complexity, NERC CIP compliance obligations, and a workforce where 50% of experienced lineworkers will retire by 2030. Reliability expectations from customers and regulators only move in one direction , up. Operating without unified intelligence means slower restoration, avoidable SAIDI penalties, compliance risk, and preventable asset failures.
Argus provides the operational data fusion platform that overhauls electric utility operations from reactive to predictive , where failures are forecast before they happen, storm response starts before the first outage, and NERC CIP evidence generates itself.
The grid that powers communities deserves protection that sees every feeder, every alarm, every threat , and the intelligence to act before the lights go out.
Talk to an Electric Utility SpecialistDeployed on-premise or in sovereign cloud. Integrates with existing SCADA/EMS (OSI, GE, ABB, Schneider), OMS, DMS, GIS (Esri, Schneider ArcFM, GE Smallworld), and AMI head-end systems (Itron, Landis+Gyr, Sensus). We serve investor-owned utilities, rural electric cooperatives, municipal power authorities, and G&T cooperatives.