CHARACTERISTICS

Distribution automation refers to a system that enables an electric utility to remotely monitor, coordinate and operate distribution components in a real-time mode. Automation components include remote switch control, integrated volt-var control, service restoration, feeder configuration, trouble call, fault location and isolation, load checks and safety checks. Customer automation options include remote metering, load control, load shedding and shaping, economic operation, cold load pickup, remote connect/disconnect, trouble call and tamper detection.

Together, these services help optimize line power flow and increase system efficiency (and reduce cost), which reduces generation demand and the emission of greenhouse gases, while providing the same level of service.

Work on superconducting technology (and other products) is underway that is expected to further increase efficiency of distribution controls.

SIZE:
The most widely-used distribution voltages are 12.47, 13.2 and 13.8 kV although complete range is from 4.16-34.5 kV. A primary distribution system uses transformers that step the primary distribution voltage down to voltages in the range of 120-600V.

FEATURES:
Automation components include remote switch control, integrated volt-var control, service restoration, feeder configuration, trouble call, fault location and isolation, load checks and safety checks. Design lifetime of transformers is 30 years.

COST:
Varies with the voltage (higher voltage systems are more expensive). Cost of developing communications systems is relatively expensive.

CURRENT USAGE:
In the U.S. and other countries, a number of companies have automated their distribution systems.¹

POTENTIAL USAGE:
Automated distribution systems can be used in every country.

ISSUES ASSOCIATED WITH IMPLEMENTING ACTION

• Conventional utility accounting may not justify implementing a distribution automation system.
• There is a high cost associated with developing the required communication system, together with the equipment and electronic database maintenance. However, as communication systems and distribution automation hardware costs decrease, expansion of distribution automation systems will become increasingly viable.

CLIMATE CHANGE IMPACT

EMISSION EFFECT:
    

CONDITIONS FOR EMISSIONS MITIGATION:

• Distribution (and transmission) do not directly produce carbon emissions, but indirectly impact GHG emissions.

EMISSION ESTIMATE:
Varies according to the fuel mix used in generation.

COST-EFFECTIVENESS:
N/A

SECONDARY EFFECTS:
Varies according to the generation fuel mix.

RESOURCES

• Several U.S. utilities have undertaken projects to improve distribution systems. More information on their projects is available in the U.S. Department of Energy Climate Challenge Options Workbook. http://www.eren.doe.gov/climatechallenge/
• The Electric Power Research Institute is sponsoring a research project to address distribution system impacts of dispersed energy systems and technologies.
• EPRI has prepared Guidelines for Evaluating Distribution Automation to assist firms in determining the costs and benefits of various automation options for distribution systems. More information is available at http://www.epri.com/pdg/products/.
• Tepel, R.C. et al., 1987, Customer System Efficiency Improvement Assessment: Supply Curves for Transmission and Distribution Conservation Options, Battelle Pacific Northwest Laboratory, PNL-6076.

CONTACTS

Harza Engineering
Peter Donalek
Electric Power Systems Department
Chicago, IL
Tel: (312) 831-3170
Fax: (312) 831-3999
pdonalek@harza.com
http://www.harza.com

National Rural Electric Cooperative Association (NRECA)
James Willis
Electrical Engineer
International Programs Division
Arlington, VA
Tel: (703) 907-5669
Fax: (703) 907-5532
jim.willis@nreca.org
http://www.nreca.org

Oak Ridge National Laboratory
Jim Van Coevening
Power Systems Technology Program
Energy Division
Oak Ridge, TN
Tel: (615) 574-4829
http://www.ornl.gov