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

                                                                                                                                                                             

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

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

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

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

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

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

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

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

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

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

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

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