From:
Power System Automation
Considerations
Substation Automation (SA)—Considerations
For Installed Intelligent Electronic Devices (IEDs)
- Replacement of electromechanical relays with digital
- Use of data ports
- Protection engineer access
- Supervisory control and data acquisition/energy management system (SCADA/EMS) interface
- Use of data concentrators
For Installed Remote Terminal Units (RTUs)
- EMS/SCADA access
- Expansion options for new data pickup
- Ability to interface with data concentrators
Local Human Machine Interface Ability to view of raw data/basic alarming
- Mini SCADA with imbalanced phase modeling
- Full integration with master SCADA including security tags
Local Data Store
- Interface with electrical equipment monitoring/alarming/archiving
- Collects and pushes protection events
- Directly feeds time series historian (local use capable)
- Supports closed loop control (volt/var, reconfiguration, etc)
Distribution Automation (DA)—Considerations
- Remote capacitor controls and communication capabilities
- Ability to react to scheduled operations and associated confirmations
- Ability to reactive to system conditions
- Data historian interface
- Interface to central SCADA
- Interface to SA controlled volt/VAR management
- Ability to interface with smart meters
- Reclosers/fault detectors and associated communication options
- Engineering access / fault event retrieval
- Intelligent controller / work in teams
- SA controlled modes (i.e. storm mode)
- Ability to reconfigure operational schemes
- Ability to reconfigure and interface with SA controllers
Other Considerations
Is There a Data Historian (PI, EDNA, etc.)?
- Is it centrally implemented?
- Is it substation implemented (limited store)?
- Is it hybrid, substation has local application—all so central collector(s) for enterprise use?
Is There an Outage Management System (OMS)?
- Is it standalone?
- Does it have any live data telemetry?
- Does it integrate with SCADA?
Is There a Distribution Management System (DMS)?
- Is it standalone?
- Does it have any live data telemetry?
- Does it integrate with SCADA
Does a two-way radio communication option exist for DA?
- Is it Internet protocol- (IP-) based?
- Is it mesh or point to point?
- Where is it homed (central location or substation)?
- Does automatic meter reading/Advanced Metering Infrastructure (AMR/AMI) exist?
- Is DA communications infrastructure shared with AMI?
Does a GIS system exist?
- Is it implemented across the entire distribution system?
- Is it integrated with customer information system (CIS), at least customer to transformer?
- If above exists, does it have phase modeling?
- Does it have full connectivity modeling for the primaries?
- Does it have full connectivity modeling for secondaries?
- Does it integrate with engineering analysis tools (study models)?
- Does it integrate with OMS?
- Does it integrate with DMS?
- Does it integrate with SCADA?
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