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Transmission for a 33% RPS

Transmission for a 33% RPS. Keith E. Casey Vice President Market and Infrastructure Development California ISO The Independent Energy Producers Association 29 th Annual Meeting South Lake Tahoe, California September 22-24, 2010. Planning for a 33% RPS. Where are we and what is left?

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Transmission for a 33% RPS

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  1. Transmission for a 33% RPS Keith E. Casey Vice President Market and Infrastructure Development California ISO The Independent Energy Producers Association 29th Annual Meeting South Lake Tahoe, California September 22-24, 2010

  2. Planning for a 33% RPS • Where are we and what is left? • How do we plan effectively?

  3. Calculating the “33% RPS Net-Short” Numbers based on CTPG Phase 2 Study

  4. Approved transmission projects could potentially achieve the 33% RPS if fully utilized. Net-Short = 53 TWh

  5. Base case plan will heavily utilize new transmission facilities. • Base case – Generation projects with approved PPAs or in CAISO interconnection queue.

  6. Approved transmission provides a base case for evaluating supplemental needs. • Alternative resource scenarios might be desirable if • Reduce generation procurement costs • Can be developed more expeditiously (siting/land-use issues) • Provide integration benefits through regional diversity • Additional resource scenarios include: • Higher Out-of-State scenario (e.g., RECs) • Higher distributive generation scenario • Potential benefits of different resource procurement scenarios needs to be weighed against any incremental transmission costs.

  7. Next Steps • December 2, 2010 - ISO stakeholder meeting to review draft results of its 33% RPS transmission studies. • January 2011 – Draft report issued • January 2011 (or sooner) – FERC Order on CAISO revised transmission planning process. • March 2011 – ISO releases its 2011 Annual Transmission Plan

  8. California ISO proposed comprehensive revisions to its transmission planning process. • New criterion for “policy-driven” transmission to achieve 33% renewable energy by 2020 • Statewide planning approach • Whole system planning instead of single-project approach for a comprehensive transmission plan • Comprehensive planning process for addressing: • Reliability, • Generation interconnections, • Policy-driven (i.e., RPS mandates), and • Economics

  9. FERC notice of proposed rulemaking regarding transmission planning and cost allocation • Five areas of “deficiency” • Lack of requirement for regional plan • Lack of consideration for needs driven by federal and state policy • Obstacles to non-incumbent transmission providers • Lack of coordination between regions • Deficient cost allocation methodologies

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