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North American Markets Status

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

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North American Markets Status

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

  2. 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

  3. 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

  4. 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

  5. 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

  6. 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

  7. 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

  8. 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

  9. 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

  10. 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

  11. 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

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

  13. North American Markets

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