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Office of Indian Energy Policy and Programs

Office of Indian Energy Policy and Programs. 2013 Tribal Webinar Series Regional Transmission Planning May 29, 2013 11:00 am – 12:30 PM. Bob Easton WAPA-RMR Planning Manager May 29, 2013. AGENDA May 29, 2013. Transmission Planning 101 WAPA Annual Planning Process Line Separation

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Office of Indian Energy Policy and Programs

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  1. Office of Indian Energy Policy and Programs 2013 Tribal Webinar Series Regional Transmission Planning May 29, 2013 11:00 am – 12:30 PM

  2. Bob Easton WAPA-RMR Planning Manager May 29, 2013

  3. AGENDA May 29, 2013 • Transmission Planning 101 • WAPA Annual Planning Process • Line Separation • TOT3 Example • Questions

  4. Transmission Planning 101

  5. Planning Criteria • North American Electric Reliability Corporation • NERC Standards • Western Electricity Coordinating Council • WECC Criteria/Business Practices/Standards • Western Area Power Administration Planning Criteria • Internal Planning Criteria Document

  6. Planning Criteria • Voltages – per unit (1.0 pu = 120 volts) for instance • Criteria = 0.90 pu to 1.1 pu • Thermal loading – MVA = thermal rating of wire/series element (switch, breaker) • 100% of Thermal Ampere Rating • N-0 (System Intact); N-1 (Single Contingency); N-n (Multiple Contingency)

  7. Planning Criteria • Mathematical Model of Entire Western Interconnection • Model Different Loads and Topology to Mimic a Certain Year and Season (2020 LSP) • Run Contingencies Mentioned • Put New Pieces in Place to “Fix” any Criteria Violations

  8. Flow Analysis NERC Category B NERC Category C NERC Category A Ten Year Seasonal Cases Results NERC Planning Standards - TPL • Analyze Against Criteria • Bus Voltages • Change in Bus Voltages • Power Flow

  9. WAPA 10-Yr Transmission • Study Timeline

  10. Study Timeline Load Forecast Data Example

  11. RMR North Case Modifications 2017 HS 2015 HA 2022 LS 2017-22 Study Process • Stress • TOT3 1739 MW • TOT5 874 MW • YTS 628 MW • No Stress • Loads modified without topology changes 2012 Study • Stress • TOT3 1692 MW • TOT5 1056 MW • YTS 618 MW • Stress • TOT3 1710 MW • TOT5 642 MW • YTS 626 MW

  12. Poncha 30 MVAR Reactor Big Horn Basin Sensitivity Study Sidney 230/115kV Xfmr Joint Study Basin-Nahne Jensen 115 kV Line Recond RMR North Recommendations • $2,500,000 • 106% load of norm/emerg. rating during YT-YTPACE N-1. • Case History: • 2015-2016-2017 • 2009-part of YTS Transfer Project • 2010-Removed • 2012-confirmed N-1 thermal issue sensitivity study may alter scope. $500,000 230 kV system history of high voltage during light loading; studies@ 1.067 pu. Project may be provided by PSCO. Case History: 2015-2017-2022 69 and 115 kV reactive support needed; thermal overload on 115 kV system. Sensitivity study to determine long term, low cost solution for the Big Horn Basin Area. Case History: 2015-2016-2017 Loss of TSGT‘s Sidney 230/115 kV transformer results in 6-10% voltage deviation on area 115 kV system; Joint study with TSGT recommended. Case History: 2015-2016-2017

  13. Capacity Adequacy Analysis • Performed by the Transmission Business Unit • Incorporated into the Ten Year Study as a means to identify transmission capacity issues that impede the commercial viability and efficient operation of the Western Transmission Network

  14. CAA Results • Several Significant Path Constraints Identified including: - Craig-Bonanza (CRCM) - Dave Johnston-Ault (LAPT) - Four Corners area from the South (Southern CRSP) - Paths into CA from AZ

  15. Line Separation

  16. Typical 500-kV Transmission Structure

  17. “Minimalist” Separation Distance

  18. “Span-Length” Separation

  19. No “One-Size Fits All” • Reliability Perspective – Further Apart to Minimize Possible Simultaneous Outages • Further Apart – Land Use/Environmental • One-Span Length Cuts down the Probability of a Wire being Swung from One Circuit to the Other

  20. No “One-Size Fits All” • Redundancy Leads to more Stable Network • Terrain – Mountainous vs. Farmland • NEW WECC Business Practice - Need 250’ Separation to be Considered Separate for Fault Simulations

  21. TOT3 Example

  22. WECC Constrained Paths PRINCE RUPERT PEACE CANYON SUNDANCE MICA LANGDON LANGDON VANCOUVER AREA 3 CANADA SEATTLE CHIEF JOSEPH AREA UNITED STATES 8 HOT SPRINGS FT. PECK 14 PORTLAND AREA HELLS COLSTRIP CANYON BUCKLEY BURNS 18 BOISE MIDPOINT 19 MALIN 66 17 SHASTA 65 20 ROUND MTN TABLE MTN 30 36 SALT LAKE CITY AREA DENVER AREA SAN FRANCISCO AREA 34 PINTO 35 31 FOUR NAVAJO 23 CORNERS 46 HOOVER 22 PHOENIX AREA 48 MOJAVE ALBUQUERQUE 51 48 AREA LOS ANGELES LUGO 50 AREA DEVERS 47 45 EL PASO AREA 49 MEXICO Transmission Paths

  23. TOT-3 TTC/ATC Calculations TOT3 Ownership Capacity MBPP – 70.5% 1132 Western – 24.93% 475 T. State – 0.83% 13 PSCo – 3.74% 60 1680

  24. G G TOT3 MAJOR LINES 345KV 230KV 115KV LRS STEGALL 400 MW 700 MW SIDNEY ARCHER NEBRASKA WYOMING TOT3 COLORADO AULT STORY N.YUMA PAWNEE

  25. G G TOT3 MAJOR LINES 345KV 230KV 115KV LRS STEGALL 0 MW LOADs to 100% OUTAGE! SIDNEY 1000 MW ARCHER WYOMING NEBRASKA TOT3 LOW VOLTAGE COLORADO AULT STORY N.YUMA PAWNEE

  26. G G OVERLOAD TOT3 MAJOR LINES 345KV 230KV 115KV LRS STEGALL 450 MW W 200 MW injection 850 MW SIDNEY NEBRASKA WYOMING ARCHER TOT3 COLORADO AULT STORY N.YUMA PAWNEE

  27. G G TOT3 MAJOR LINES 345KV 230KV 115KV LRS STEGALL 0 MW OVERLOAD/ INSTABILITY OUTAGE! SIDNEY 1200 MW ARCHER WYOMING NEBRASKA TOT3 LOW VOLTAGE COLORADO AULT STORY N.YUMA PAWNEE

  28. August 14, 2003

  29. Planning Study Process within the UGPR Western Area Power Upper Great Plains Region Integrated System Gayle R. Nansel Manager of Transmission System Planning Upper Great Plains Region

  30. Planning Process within the IS • Established Order 890 Planning Process (Attachment P) • Local Planning Process • Roll-up of Local Plans to a Regional Plan • Drafting Order 1000 Approach • MAPP Regional Proposal: Regional cost allocation would apply where a proposed regional project would replace a project in the MAPP Roll-up Plan by solving the need at a lower cost. • Interregional Approach (MISO/SPP/Western Interconnect)

  31. Western’s UGPR Local Transmission Planning Process • Covers transmission facilities under Western’s Tariff – The Integrated System (IS) • Identifies upgrades and other investments to the IS • To reliably satisfy, over the planning horizon, Network resource & load growth expectations • for Native Load Customers; • for grandfathered, non-OATT agreements; • for Point-to-Point service needs including obligations for rollover • Provides opportunity to coordinate new projects with Stakeholders • Rolls up into the regional planning efforts

  32. Integrated System (IS) IS (Integrated System) MISO JOINT (MISO / Other)

  33. Integrated System (IS) Transmission Planning Coordinated Planning approach between IS partners: • Basin Electric Power Cooperative • Heartland Consumers Power District • Western Area Power Administration

  34. Local Planning Process Scope • Conduct local long-term planning for transmission facilities • To serve Western’s network load and firm transmission commitments • Provides long-term planning of transmission facilities needed for to meet firm commitments and Network Customers • Does not circumvent the procedures under the tariff • for Point-to-Point transmission service • for Generation Interconnects, Network Resource and • for Network load additions/removals

  35. Responsibilities • Development of the transmission plans to address transmission issues • Allow timely and meaningful stakeholder input and participation • Follow regional planning procedures • Provide summaries for stakeholders review to allow for comment on proposed facilities

  36. Transmission Planning Documentation Integrated System OASIS: http://www.oasis.oati.com/WAPA/index.html “Transmission Planning Process” folder Contact: Gayle Nansel, Transmission Planning Manager (UGP) 406-255-2830 nansel@wapa.gov

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