All the information in 8.3 shall be compliant to the IEC 61 850 series.
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1 Modbus® Protocol is a messaging structure developed by Modicon. This information is given for the convenience of users of this document and does not constitute an endorsement by IEC of the product named.
Equivalent products may be used if they can be shown to lead to the same results.
NOTE Optional functionalities will be described by use cases provided by IEC 61 850 series.
8.3.2 Information from FPIs for local indication of fault detection Only local indication of a fault current passage through the FPI is shown.
Minimum requirements for these FPIs are limited to the fault detection capabilities listed below:
a) overcurrent detection (for each different threshold present on the FPI);
and/or
b) phase to earth fault detection (for each different threshold present on the FPI) either non- directional or directional.
Using this information, personnel in field may follow the fault path.
Fault detection may or may not be based on confirmation through voltage absence detection.
User-defined logic to detect an intermittent fault may be introduced, as well as a counter, with the same user-defined features, for the evaluation of intermittent faults.
Optional functionalities (related information is available only locally) may be:
• report on device health (FPI internal status and alarms):
– internal fault,
– lack of auxiliary source, – auxiliary controls, – others;
• monitoring substation environment (environmental measurements, alarms, etc.);
• power flow monitoring (voltage and current measurements for operation purposes).
8.3.3 Information from FPIs for remote indication of fault detection
Signals/measurements (possible commands, for instance direction inversion) can be displayed locally and remotely transmitted (also locally stored). Transmission, collection and elaboration of information from FPIs shall be agreed upon between users and manufacturers on a case-by-case basis.
Minimum requirements for these FPIs are limited to the fault detection capabilities listed below:
a) overcurrent detection (for each different threshold present on the FPI);
and/or
b) phase to earth fault detection (for each different threshold present on the FPI) either non- directional or directional.
Fault detection may or may not be based on confirmation through voltage absence detection.
User-defined logic to detect an intermittent fault may be introduced, as well as a counter, with the same user-defined features, for the evaluation of intermittent faults.
Optional functionalities (related information is available locally and/or remotely) may be:
• report on device health (FPI internal status and alarms):
– internal fault,
– lack of auxiliary source,
– auxiliary controls, – others;
• monitoring substation environment (environmental measurements, alarms, etc.);
• power flow monitoring (voltage and current measurements for operation purposes);
• monitoring of external communications.
The abstract communication service interface (ACSI), which describes the communication between a client and a remote server for:
• real-time data access and retrieval,
• device control,
• event reporting and logging,
• publisher/subscriber,
• self-description of devices,
• data typing and discovery of data types,
• file transfer,
• substation-to-substation information exchange,
• information exchange for distributed generation, shall comply with IEC 61 850-7-2.
8.3.4 Information from DSUs fully integrated in network operation system (SCADA) These DSUs shall provide at least the following information/signals, to be transmitted and locally stored: DSUs' digital outputs may be common for similar faults, for instance for cross- country (multiple) faults and short circuits. These DSUs may integrate also other IED functions (for instance some typical functions obtained through remote terminal units).
Fault detection
According to DSU features, at least the following:
a) overcurrent detection (for each different threshold present on the DSU);
and/or
b) phase to earth fault detection (for each different threshold present on the DSU);
c) cross-country (multiple) fault detection (for each different threshold present on the DSU) either non-directional and directional;
d) upstream (and/or downstream) voltage presence/absence not strictly related to fault detection algorithms (for instance, fault confirmation).
Fault detection may or may not be based on confirmation through voltage absence detection.
User-defined logic to detect an intermittent fault may be introduced, as well as a counter, with the same user-defined features, for the evaluation of intermittent faults.
Optional functionalities (related information is available both locally and remotely) may be:
• report on device health (DSU internal status and alarms):
– internal fault,
– lack of auxiliary source, – auxiliary controls, – others;
• monitoring substation environment (environmental measurements, alarms, etc.);
• power flow monitoring (voltage and current measurements for operation purposes);
• monitoring of external communications;
• automatic voltage var control (VVC);
• DER management;
• embedded algorithms for FDIR/FLISR, i.e. MV network automation (based on local measurements and/or signals from field apparatus, for instance disconnector/circuit breaker position control) including also:
– transfer trip signal transmission, with the purpose to send other IEDs information able to cause DER disconnection;
– logic selectivity signals (transmission/reception of locking signals, cumulative for all fault detection thresholds or separately for each fault detection threshold implemented in the DSU), with the purpose to inhibit the transmission of fault detection signals to other IEDs and/or the start of any internal algorithms related to actions consequent to fault detection (for instance MV network automation, transfer trip signal transmission to DER, etc.).
The abstract communication service interface (ACSI), which describes the communication between a client and a remote server for:
• real-time data access and retrieval,
• device control,
• event reporting and logging,
• publisher/subscriber,
• self-description of devices,
• data typing and discovery of data types,
• file transfer,
• substation-to-substation information exchange,
• information exchange for distributed generation, shall comply with IEC 61 850-7-2.