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Status Update on North American Electric Markets: Insights from APEx Meeting in Leipzig

This report synthesizes key findings from the APEx meeting held in Leipzig, Germany, from October 10-12, 2004, featuring insights from various U.S. regions' electricity markets. Key highlights include peak loads, the shift toward nodal pricing by 2007, and the establishment of new markets. Updates on comprehensive market redesigns, including real-time energy markets and capacity considerations across California, ERCOT, MISO, PJM, and others are discussed. The evolving landscape underscores potential challenges and opportunities for stakeholders in North America's electricity sector.

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Status Update on North American Electric Markets: Insights from APEx Meeting in Leipzig

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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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