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Northwest Wind Integration Action Plan

Northwest Wind Integration Action Plan. Jeff King Northwest Power & Conservation Council June 27, 2007. Northwest wind power development. Northwest generating capacity 54,600 MW. Operating Under construction Expected to be constructed in near-term

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Northwest Wind Integration Action Plan

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  1. Northwest Wind Integration Action Plan Jeff King Northwest Power & Conservation Council June 27, 2007

  2. Northwest wind power development June 2007

  3. Northwest generating capacity 54,600 MW June 2007

  4. Operating Under construction Expected to be constructed in near-term 100 MW (area proportional to installed capacity) Wind projects

  5. Drivers of wind power development • Federal Production Tax Credit • Natural gas price uncertainty and volatility • Concerns regarding climate change • WA, OR & CA restrictions on acquiring CO2-intensive resources. • State Renewable Portfolio Standards • Washington (15% by 2020) • Oregon (25% by 2025) • California (33% by 2020) • (Until recently) Favorable competitive position of new wind (w/PTC) vs. new fossil plants. June 2007

  6. Wind Integration Forum • Chartered as a Council advisory committee for a two-year period • Monitor, facilitate and review implementation of WIAP actions. • Actions are funded and otherwise supported by participating organizations • Semiannual meetings of the Steering Committee; bimonthly meetings of the Technical Work Group June 2007

  7. Issues addressed by WIAP Phase I • What is the role of wind energy in a power supply portfolio? • Does the Northwest have the operational capability (“system flexibility”) to integrate 6000 MW of wind? • What are the transmission requirements for 6000 MW of wind power? • How will the costs of wind integration be recovered? • Over the longer-term, how can the Northwest secure its wind potential in the most cost-effective manner? June 2007

  8. Key findings: Role of wind energy The principal benefits of wind energy are energy-related: • Displacement of fossil fuel emissions • Displacement of carbon dioxide production • Primarily through displacement of baseload natural gas plants • Reduced exposure to natural gas price uncertainty and volatility Extreme heating and cooling events frequently are accompanied by region-wide high-pressure weather systems (i.e., stagnant air). Wind’s capacity value probably lower than provisional 15%. Northwest utilities will need to rely on capacity resources (hydro, thermal or demand-side) to meet peak loads. June 2007

  9. Wind generation declines during extreme temperature conditions June 2007

  10. Action A1: Reassess 15% pilot sustained wind capacity value (Adequacy Forum, underway) June 2007

  11. Key findings: System Integration Wind energy behaves like negative load. Not fundamentally different from managing load variability. However, wind output is more variable and less predictable than load. Integration cost is the cost of committing generating capacity for operating reserves and for managing hour-to-hour changes in wind output. • Range from $2 - 16/MWh • Low end: Diversified low (e.g., 5 – 10%) penetration within control area • High end: Undiversified high (e.g., 20 – 30%) penetration within control area No fundamental technical barriers to integrating 6000 MW. Load growth and additional constraints on operation of hydro system will erode this capability. June 2007

  12. Raw wind plant output > Output following within-hour regulation & load-following > Output with storage and shaping > System Integration Process

  13. Impact of wind on system variability June 2007

  14. Integration costs are small fraction of delivered wind energy cost NO CO2 cost or risk No fuel cost or fuel price risk Operating reserves for integration Large transmission component Large capital investment. Value of $, commodity cost & wind demand risks Fifth Power Plan assumptions IOU ownership 30% capacity factor 2010 service E. WA/OR location Current costs are substantially higher PTC acts as negative variable cost

  15. Integration actions A2: Refine estimates of the cost and supply of wind integration services (BPA and other control areas) A3: Develop high resolution, chronological Northwest wind data set (BPA, NREL - funded for 2007) A11: Evaluate costs & benefits of wind forecasting network (Forum - 2008 action) A12: Implement ACE diversity interchange pilot (PAC, IPC, NWE, BCTC - underway) A13: Improve markets for flexibility services (Forum - kickoff workshop 7/12/07) June 2007

  16. Key findings: Transmission • Existing transmission capacity can support anticipated wind development only through 2009. • The current practice of relying entirely on firm transmission capacity for an energy resource with little firm capacity contribution needs to be revisited. • Additional development will require combination of transmission expansion and innovative “less-than-firm” transmission products • Access to wind sites with higher capacity factors and more diverse generation patterns will lower busbar and wind integration costs. June 2007

  17. Transmission path constraints June 2007

  18. Path constraints are affecting location of wind project proposals June 2007

  19. Transmission actions I A7: Develop “less-than-firm” transmission products and other means to improve efficiency of transmission use (BPA - underway). A8: Develop plans of service for reinforcing constrained paths (BPA - underway) A9: Develop approach to financing market-driven reinforcements and expansions (BPA - underway) A6: Review and amend as necessary regulatory policies to support more efficient use of transmission (Commissions, OPUC lead - underway) June 2007

  20. Transmission actions II A4: Develop transmission planning principles and methodology for optimal firmness of service (NTAC - kickoff workshop 6/21/07) A5: Apply technical planning methodology to identify least-cost transmission expansions (Columbia Grid & NTTG, 2008 action) A10: Evaluate approaches to delivering wind energy from Montana and other promising but isolated resource areas (NTAC - 2008 action) June 2007

  21. Securing wind potential in the most cost-effective manner in the long-term A14a: Characterize demand-side, power generation, storage and other options for augmenting system flexibility (Forum - 2008) A14b: Improve understanding of tradeoff between competing uses of system flexibility (NPCC - 2008) A15: Develop planning framework to optimize tradeoffs between: • costs transmission expansion and resulting benefits of geographic diversification of wind projects, and • costs of augmenting system flexibility • (NPCC - Sixth Power Plan) June 2007

  22. http://www.nwcouncil.org/energy/Wind/library/2007-1.pdf June 2007

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