Automatic Reclosers and Feeder Automation: IEC 62271-111 Selection

A practical recloser guide for overhead, pad-mounted and dry-vault distribution feeders covering fault interruption, reclosing sequences, sensors, controls and

1. Scope and Installation Type

IEC 62271-111:2019 applies to AC automatic circuit reclosers installed overhead, pad-mounted, in dry vaults or in submersible arrangements above 1 kV and up to 38 kV. The standard covers the recloser device and its relevant test and rating boundary; the feeder automation scheme remains a system-engineering responsibility.

2. Electrical and Mechanical Selection

InputEngineering question
NetworkMaximum voltage, continuous current, fault current, X/R, grounding and phase arrangement
InterruptionCan the device interrupt the maximum available fault, including source and motor/inverter infeed?
WithstandAre thermal short-time, peak making, insulation and environmental duties declared for the exact model?
ControlAre CT/VT or line sensors, battery, auxiliary supply, local control and communications adequate?

The recloser’s duty must be checked against the actual feeder topology, not only the nominal line voltage. Pad-mounted and submersible installations add enclosure, water ingress, corrosion and cable-interface checks.

3. Reclosing and Coordination

Define the number and timing of shots, fast and delayed curves, single-phase or three-phase operation, lockout, fuse-saving or fuse-blowing philosophy, cold-load pickup and inrush behaviour. Coordinate with upstream breakers, downstream fuses, sectionalizers, distributed generation and customer protection.

Where a PV, BESS or generator source can backfeed the line, the control scheme must explicitly handle reverse power, loss of source, anti-islanding and fault contribution. A recloser setting is not transferable between a radial and an interconnected feeder.

4. Automation Acceptance

  • Test opening, closing, lockout, manual override, local/remote authority and battery autonomy.
  • Verify fault indicators, phase identification, time synchronization, event records and SCADA points.
  • Prove the communication-loss fallback and the safe state after auxiliary-power loss.
  • Record primary injection or equivalent functional evidence, protection curves and the final coordination study.

*Reference: IEC 62271-111:2019; IEEE Std C37.60; IEC 62271-1:2017+A1:2021.*