1. Old Dominion Electric Cooperative Meter Estimation Project
Daryl Jaschen
Director of MIS
Old Dominion Electric Cooperative

2. Background
ODEC has 218 delivery points through which power is delivered to 12 member cooperatives.
The transmission service providers are Dominion Virginia Power, Connectiv, APCO, and Philadelphia Electric.

3. Background (cont.)
There are six weather stations (Richmond, Washington D.C., Dulles, Norfolk, Dover, Wilmington) which ODEC’s receive hourly readings of temperature, dew point, wind direction, wind speed, and cloud coverage.
Currently, of the 218 delivery points, all but 30 have direct mappings (by common name from Member’s SCADA system) into the ODEC’s SCADA database.

4. Background (cont.)
Data is transferred to ODEC via a LiveData ICCP node that connects ODEC to all 12 members.
ODEC is a co-owner of ACES Power Marketing.
ACES performs bulk power marketing services for ODEC.

5. Deregulation – the Source of Change in the Industry
Deregulation led to a termination of all requirements contract in Virginia.
The penalties associated with the new network service agreement drew attention to the need for more reliable hourly load forecasts.

6. The Problem
In order to avoid bulk power related scheduling penalties, an accurate hourly load consumption value for all 218 delivery points had to be provided to ACES on an hourly basis.

7. ODEC’s Solution
ODEC and ACES initiated a rigorous requirements definition process.
A specification was written and sent to 4 vendors.
After a vendor evaluation, RER (now Itron) was selected to design, install, and bring on-line a Meter Estimation and Validation System.

8. The Schedule The spec went out in July 2002
The vendor was chosen in August 2002
The system was designed, installed, tested, and brought on-line January 1, 2003.

9. A Successful Project Found errors in the data coming from members
Types of errors included:
The MVES is stable and runs reliably
The forecast errors are approximately