Most automation by electric utilities has been applied in the substation and at the enterprise level. Relatively few utilities have deployed distribution automation-the automation of devices outside the substation fence (i.e., out on the feeders themselves). This is due primarily to the potentially large expense of implementing DA, the lack of economic justification for such expenditures, and the unique and difficult technical challenges of implementing DA on a widespread basis.
Drivers include:
- increased customer expectations in terms of power quality and reliability;
- growing number of regulatory incentives, both positive and negative;
- increased performance and affordability of DA communications choices; and,
- increased variety and capability of automation devices and software.
An efficient, reliable and secure communication infrastructure is vital for a successful DA implementation. Unfortunately, there is no single “cookbook” communication solution or model for success that can be applied to all utilities. Each utility’s unique characteristics-geography, distribution feeder electrical capabilities and constraints, customer density, human and financial resources, customer demographics and preferences, and a host of other characteristics-will determine the requirements for the communication system.