1. North American Markets Status
APEx meeting
Leipzig, Germany
October 10-12, 2004
Kenneth W. Laughlin
©2003 PJM

3. California ISO Peak Load 46,000 MWs
Zonal energy market with redispatch to manage congestion within zones
Comprehensive market redesign – expect to move to nodal pricing in 2007
No capacity market

4. Grid West (NWPP Area) Peak Load 58,000 MWs
Markets are under discussion and will probably not begin for at least three years, but are expected to include:
Nodal Pricing
Transmission Rights for full footprint
Real Time Energy for about 38,000 MW

5. Alberta Electric System Operator
Peak load 9,000 MWs
Wholesale generation market opened in 1996; Retail competition opened in 2001
Wholesale real time energy market with a single market clearing price
Future consideration of day-ahead market, unit commitment, and capacity Market

6. SPP
Peak Load 48,000 MWs
Full nodal energy imbalance energy market expected to become operational in 2005
Transmission Services market
No retail open access in footprint

7. ERCOT
Peak Load 60,000 MWs
85% of Texas; Not subject to FERC; 3 DC Ties
37,000 miles of Transmission
Firm Transmission (PTP only)
77,000+ MW of Generation
Centralized registry for 5.9 million retail choice customers

8. MISO RTO
Peak load 110,000 MWs
Market opening planned for March 1, 2005
Full nodal real time and day-ahead energy markets
Territory encompasses fifteen states and one Canadian province

9. Ontario Market Operator
Peak Load 25,000 MWs
5 minute wholesale spot market, single market clearing price
Day-ahead and capacity markets under development
Significant capacity shortfalls possible in 2008 with mandated shutdown of coal plants

10. PJM Peak load 110,000 MWs Full nodal markets (real time and day-ahead)
Integrating an additional 25,000 MWs of peak load area into marketplace by January 1, 2005.
Developing a new capacity market

11. New York ISO Peak Load 31,000 MWs
Full nodal pricing with real time and day-ahead energy markets
Installed capacity market with a demand curve
Will soon implement a synchronized day-ahead and real-time system of reserve and ancillary services markets

12. New England RTO Peak Load 25,000 MWs Implemented nodal pricing in 2003
Implemented wholesale markets in 1999
Capacity market in development with Demand Curve

13. Entergy Peak load 22,000 MWs Single utility Bilateral markets
38,000 MWs of utility and merchant generation in footprint

14. North American Markets Yes. New under development
Peak Load
Nodal pricing
Retail Markets
Capacity market
California ISO
46,000
2007 No
None
Grid West (NWPP Area)
58,000
3 yrs +
Alberta Electric System Operator
9,000
Yes
Future
SPP
48,000
2005
ERCOT
60,000
MISO
110,000
Partial
Ontario Market Operator
25,000
Under development
PJM
1998
Yes. New under development
NYISO
31,000
2001
ISO-NE
2003
Entergy
22,000