Modified autonomous fault management strategy for enhancing distribution network reliability


Successful fault management strategies are essential for implementing practical self-healing procedures in the automated distribution systems. Such tools effectively decrease repairing times by precise detecting and locating the deteriorated components in distribution networks. In this paper, the reliability analysis is computed using dynamic distribution network measurements for a modified autonomous control according to the most common IEEE reliability indices. The reliability of the proposed management control method is enhanced by reducing the number of communication hops. Also, the reliability of the proposed control is compared with both that of the actual control method using recorded data along six months and that of applying other advanced methods in same actual system using Markov model analysis. The results confirm the efficacy of the proposed fault management for enhancing distribution network reliability and service continuity.

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Corresponding author

Correspondence to Ehab M. Esmail.



Parameters of the simulated system

The system consists of two overhead parallel incoming feeders, cascaded with one outgoing cable feeder. The buses are renumbered for simplicity, 64 normally closed switches located at each section terminals while one circuit breaker is added at the beginning of the feeder. Also, normally open switches (Tie switches) are added to the system to verify system reconfiguration. Each of the overhead parallel incoming feeder parameters is illustrated in Table

Table 5 Parameters of incoming feeders


This outgoing feeder is characterized by the positive sequence data of the feeder and loads listed in Table

Table 6 Parameters for the outgoing feeder

6. The positive and zero sequence resistance are equal to 1.62, 0.5 (Ω/ km), respectively, while the positive and zero sequences inductance are equal to 3.82, 7.14 (mH/km), respectively, the positive and zero sequence capacitances are equal to 0.0067 and 0.0041 µf/km, respectively. Also, wind turbine data are introduced in Table

Table 7 Selected wind turbine generator data


Utilized master control system

The Master Control Center (SCADA) consists of seven parts as outlined in Fig. 

Fig. 17

Utilized master control

17. Through which collect all real-time data incoming from the remote terminal unit as well as the operations of existing control in any substations (primary substation distribution panel), and secondary substation (transformers). This part collects all data in the Master Control Center using the local remote terminal unit. This part performs all operation control and sends real-time data to all units of computers located in the master center through the local area network. The second part is called the information management server (IMs). This part is composed of a server in addition to the external storage unit containing a central data database for medium voltage network components and real-time data received from data collection (RTC/TCS). These data stored on external drives can be retrieved when needed. Through this part is being built power system analysis such as (fault detection—load flow—short circuit calculation). A third part called dispatcher workstation (electrical engineer). Using SCADA system, the electrical engineer can be monitoring for primary substation 66/11 kV, and control the distribution panel 11 kV, and the operation of secondary substations. In addition to, the section manger can be monitoring the continuity of electricity service in all network, and safety equipment performance for the master center. The fourth part is called supervisory workstation, which controls all works as well as routine maintenance, removal of software failure, and monitors the status of communication between the master center and external sites. The fifth part is called the rear protection system, through which the display monitors are enlarged to follow up the operation, control of the electric grid. The sixth part is called time system and its purpose is to adjust the synchronization between the master center, remote terminal unit, and digital protection relays in the outstation.

The seventh part is called local area network (LAN), which connects various computer units in the master center of each other. This part is used to transfer the information between the connecting unit. Further components were added to the system such as system recorders where the current and voltage measurements are recorded by digital relays during normal operation and fault conditions. The communications between the protection relays, distributions panels, and control center were based on the standard protocol communication IEC60870. This protocol facilitated transmissions and communications of fault indications, measured values, and commands.

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Esmail, E.M., Elkalashy, N.I., Kawady, T.A. et al. Modified autonomous fault management strategy for enhancing distribution network reliability. Electr Eng (2021).

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  • Automated distribution network
  • Modified autonomous fault management strategy
  • Reliability enhancement