Substation Fault Analysis & Relay Coordination Assistant
Analyze substation relay logs and SCADA data to pinpoint faults and optimize protection coordination
What You Can Do
You can reconstruct fault sequences from relay logs and SCADA data, identify protection coordination conflicts, and recommend device setting adjustments to improve substation reliability. The skill synthesizes event timestamps, voltage/current data, relay target codes, and breaker status to accelerate fault investigation from 4-8 hours of manual analysis to actionable insights in minutes, without requiring re-energization or live testing.
Features
chronologically maps relay operations, breaker trips, and SCADA alarms to identify fault progression
correlates voltage sags, current spikes, and relay target codes to pinpoint fault type, location, and initiating event
detects misoperations, sympathetic trips, and timing conflicts between primary and backup protective devices
suggests coordination margins and device adjustments aligned with IEEE/NERC standards
validates new protective relay settings against fault response specifications pre-energization
flags coordination gaps and non-conformances with industry protection standards
compares actual protection performance against design expectations to identify drift or configuration drift
Example Output
Example 1: Misoperation Analysis
Input: Relay logs showing 138 kV feeder trip at 14:22:35, backup relay operation at 14:22:42, and SCADA showing 2.8 kV voltage depression on adjacent bus.
Output:
- Fault sequence: Primary relay failed to clear 3-phase fault at 4.2 km on feeder; backup overcurrent relay (51) operated after 7-second delay
- Root cause: Primary impedance relay (21) setting miscalibration; threshold set 15% above actual fault impedance
- Recommendation: Recalibrate relay 21 threshold to 8.5 Ω (from 9.8 Ω); verify reach doesn't exceed 90% of protected zone
Example 2: Coordination Conflict
Input: SOE log showing two consecutive 69 kV breaker operations within 200 ms; SCADA differential current data for main transformer.
Output:
- Issue: Sympathetic trip — main transformer differential relay (87T) operated 0.18 seconds after upstream line relay (21), both clearing same fault
- Gap: Insufficient coordination margin between devices; 87T operating time exceeds 21 primary + backup margin
- Recommendation: Adjust 87T pickup from 0.32 A to 0.48 A; increase delay to 0.5 sec to maintain 150 ms coordination margin per NERC PRC-023
What's Included
- SKILL.md instruction file with fault analysis methodology:
- SOE Data Template: structured log format for relay events and timestamps
- SCADA Snapshot Analyzer Checklist: voltage, current, frequency data points to capture
- Protection Coordination Verification Worksheet: device pairs, timing margins, and compliance scoring
- Relay Setting Recommendation Framework: IEEE/NERC margin requirements by protection type
Who It's For
- Substation engineers investigating protection misoperations or unexpected relay trips
- Protection engineers commissioning new relays and coordinating multi-device settings
- System operators troubleshooting nuisance trips before escalation to field crews
- Utility compliance engineers verifying coordination against NERC/IEEE standards
- Asset managers analyzing fault history to prioritize relay upgrades
Best For
- Post-fault event analysis and root cause investigation
- Relay coordination verification during commissioning or retrofits
- Protection setting optimization to reduce misoperations and sympathetic trips
- NERC compliance validation and coordination margin documentation
- Troubleshooting unexplained breaker operations using historical SOE and SCADA data
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