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March-April 2009 Issue I
SCADA
SCADA systems are globally accepted as a means of real-time
monitoring and control of electric power systems, particularly
generation and transmission systems. RTUs (Remote Terminal
Units) are used to collect analog and status telemetry data from
field devices, as well as communicate control commands to the field
devices. Installed at a centralized location, such as the utility control
center, are front-end data acquisition equipment, SCADA software,
operator GUI (graphical user interface), engineering applications that
act on the data, historian software, and other components.
Recent trends in SCADA include providing increased situational
awareness through improved GUIs and presentation of data and
information; intelligent alarm processing; the utilization of thin clients
and web-based clients; improved integration with other engineering
and business systems; and enhanced security features.
Outage Management Systems
Modern computer-based OMS, utilizing connectivity models and
graphical user interfaces, has been in operation for some time now.
OMS typically includes functions such as trouble-call handling, outage
analysis and prediction, crew management, and reliability reporting.
Connectivity maps of the distribution system assist operators with
outage management, including partial restorations and detection of
nested outages.
In recent years, OMS has become more automated. Outage prediction
– the process of analyzing outage events such as trouble calls, AMI
outage notifications, and SCADA-reported status changes – has
improved. Interfaces to Interactive Voice Response systems (IVR)
permit trouble call entry into an OMS without call-taker interaction
and also permits the OMS to provide outage status information to
customers and provide restoration verification call-backs to customers
who request them.
OMS systems have also become more integrated with other
operational systems such as Geographic Information Systems (GIS),
Customer Information Systems (CIS), Work Management Systems
(WMS), Mobile Workforce Management (MWM), SCADA, and AMI.
Integration of OMS with these systems results in improved workflow
efficiency and enhanced customer service.
Today’s OMS is a mission-critical system. At some utilities, it
can be utilized simultaneously by hundreds of users. It integrates
information about customers, system status, and resources such as
crews, providing a platform for operational decision support.
Integrated SCADA/DMS/OMS:
Increasing Distribution
Operations Efficiency
By Tim Taylor, Business Development Manager
and Hormoz Kazemzadeh, Director of Marketing
ABB Inc.
Tim Taylor Hormoz Kazemzadeh
Many electric distribution organizations are presently evaluating their approach to integrating three key operational systems – SCADA
(Supervisory Control and Data Acquisition), OMS (Outage Management System) and DMS (Distribution Management System). SCADA,
which has long been prevalent throughout transmission systems, is finding increased applications on distribution systems.
Modern OMS, utilizing GIS-based connectivity models, is now well established and a key component of many organizations’ outage
management business processes. The implementation of DMS functionality is a relatively recent trend. While a DMS can include and
improve the traditional outage management functions, a DMS also typically includes applications that assist in the improved operation
of the electric distribution system, as well as functionality for improving planned work on the system.
This article first reviews SCADA, OMS, and DMS systems. Considering that both OMS and DMS require a connectivity model of the
distribution system, the benefits of integrating OMS and DMS are presented. Next, the integration of SCADA with DMS/OMS is discussed,
including the functionality of the integration and the resulting benefits. Finally, a proposed architecture for an integrated distribution
operations center is presented.
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