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* = Peak Load in Megawatts

The Effects of Integrating Wind Power on the Reliability, Planning and Operations of the New York State Power System John M. Adams Director, System and Resource Planning. Hydro Quebec 35,137 MW*. ISO - New England 25,348 MW*. IMO 25,414 MW*. 1050 MW. 1000 MW. 1500 MW. 1325 MW.

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* = Peak Load in Megawatts

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  1. The Effects of Integrating Wind Power on the Reliability, Planningand Operations of theNew York State Power SystemJohn M. AdamsDirector, System and Resource Planning

  2. Hydro Quebec 35,137 MW* ISO - New England 25,348 MW* IMO 25,414 MW* 1050 MW 1000 MW 1500 MW 1325 MW 975 MW NYISO 31,741 MW* 1500 MW 2625 MW 2375 MW PJM / PJM West 131,330 MW* * = Peak Load in Megawatts

  3. NY’s Renewable Portfolio Standard (RPS) • 25% of energy retailed in NY should come from eligible renewable resources by 2013 • Current level is about 19.5% • RPS estimates that this need will be met by: • 2,779 MW of NY-based Wind Farms • 1,350 MW of Imports (including 250 MW of Wind in PJM) • 294 MW of Biomass Co-Firing w/Coal • 121 MW of Landfill Gas • Initial RECs awards made to 7 renewable facilities – 820,000 MWh contracted for 2006 – first-year payments estimated at roughly $18 million

  4. NY Energy by Fuel Type

  5. NY’s Wind Generation Interconnection Queue Zone D B = 7, 726 T = 7, 726 Total NY A = 3, 48 MW B = 46, 5210 MW T = 49, 5258 MW Zone F B = 1, 100 T = 1, 100 Key: A = # Projects In-Service, #MW B = # Projects Proposed, #MW T = Total # Projects, #MW Zone B A = 1, 6 T = 1, 6 Zone A B = 14, 1856 T = 14, 1856 Zone E A = 1, 11.5 B = 12, 1429 T = 13, 1441 Zone C A = 1, 30 B = 11, 959 T = 12, 989 Zone K B = 1, 140 T = 1, 140

  6. How Will RPS Impact System Reliability? • GE Energy Consulting engaged by NYSERDA and NYISO to evaluate reliability needs of RPS • Looked at 3300 MW of wind resources connected to NY system by 2008 • Phase II study results released on Feb. 10, 2005 – available at www.nyserda.com/rps

  7. Study Objective • To produce empirical information that will assist the NYISO in evaluating the reliability implications of the large scale integration of wind generation • Phase 1: Preliminary Overall Reliability Analysis • Phase 2: System Performance Evaluation

  8. Unit Dispatch 700 600 500 400 MW 300 200 100 0 0 2000 4000 6000 8000 Hour 2001 Average Load vs Average Wind 30,000 1,600 1,400 25,000 1,200 20,000 1,000 Wind Output (MW) NYISO Load (MW) 15,000 800 600 10,000 400 5,000 200 July load August load September load July wind August wind September wind 0 0 1 6 11 16 21 Hour 3000 2500 2000 MW 1500 1000 500 0 1 61 121 Minutes September Morning August Morning May Evening October Evening April Afternoon Planning and Technology Operation Process Time Scales for System Planningand Operation Processes Issues 1 Year Capacity Valuation Resource and (UCAP, ICAP) Capacity Planning and Long - Term Load (Reliability) Growth Forecasting Time Frame Slower (Years) 1 Day Unit Commitment Day - ahead and and Multi - Day Day - Ahead Forecasting Scheduling Operation and Planning Data Spanning All These Time Frames Was Compiled for This Study 3 Hours Hour - Ahead Forecasting Load Following and (5 Minute Dispatch) Plant Active Power Maneuvering and Management Faster (seconds) 10 Minutes Real - Time and Frequency and Autonomous Protection Tie - Line Regulation and Control Functions (AGC) (AGC, LVRT, PSS, Governor, V - Reg , etc.)

  9. Study Findings – Interconnection Req. • If state of the art wind technology is utilized, the NYSBPS can reliably interconnect wind generation on a large scale with only minor adjustments to its existing planning, operation, and reliability practices. • State of the art wind generators would have the following features/capabilities: • Low-Voltage Ride Through • Leading/Lagging Power Factor Range • SCADA • Ratings of wind farms would need to be within the capacity of local transmission facilities and subject to congestion management: • Power Curtailment Capability

  10. Study Findings – Planning and Operations

  11. Study Findings – Capacity Value • Based on rigorous LOLP calculations using 2001 - 2003 load and wind profiles: • Inland Wind Sites: • Capacity factors ~ 30% • Effective capacity, UCAP ~ 10% • Offshore Wind Site: • Capacity factors ~ 40% • Effective capacity, UCAP ~ 39 • Developed approximate calculation method: • UCAP ~ On-Peak Capacity Factor for 1:00-5:00pm, June-August

  12. 2001 Average Load Vs Average Wind August July September

  13. One week in July 2002

  14. Market-Related Wind Issues – Schedule for Market Participant Discussions • The NYISO is developing straw proposals addressing a number of market-related issues: • Centralized wind forecasting system • Interim market rules clarification of 500 MW limit • End-state market rules • NYISO expects to discuss these proposals within the Market Structures Working Group in the July/August timeframe

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