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Western Area Power Administration Rocky Mountain Region Generation and Marketing

Western Area Power Administration Rocky Mountain Region Generation and Marketing. Ancillary Services Technical Workshop March 18, 2004 --Ron Steinbach. Western Area Power Administration. Five Regions 10,000 MW installed capacity 15 separate Congressionally authorized multipurpose projects

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Western Area Power Administration Rocky Mountain Region Generation and Marketing

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  1. Western Area Power AdministrationRocky Mountain RegionGeneration and Marketing Ancillary Services Technical Workshop March 18, 2004 --Ron Steinbach

  2. Western Area Power Administration • Five Regions • 10,000 MW installed capacity • 15 separate Congressionally authorized multipurpose projects • Water requirements are project specific and dictate project operations • Power operations are secondary (or lower)

  3. Rocky Mountain Region Generating Capability • Four River Systems • 20 Powerplants; 39 units • Installed Capacity: 830 MW • Operating Capability (FY 02): 744 MW • Average Annual Generation: 2,160 GWH

  4. Four Major River Basins • Pick-Sloan Missouri Basin Proram • Bighorn River Basin • North Platte River • Colorado-Big Thompson (CBT) • Fryingpan-Arkansas (Fry-Ark) • Fry-Ark’s main feature—Mount Elbert—is a pump-generator • CBT and Fry-Ark are “Trans-mountain Diversion Systems”

  5. Big Horn River Basin • Boysen 15 MW • Buffalo Bill 18 MW • Heart Mountain 5 MW • Pilot Butte 2 MW • Shoshone 3 MW • Spirit Mountain 5 MW • Yellowtail 125 MW • (Yellowtail total is 250—1/2 plant is marketed by Pick Sloan-Eastern Division)

  6. North Platte River • Alcova 41 MW • Fremont Canyon 67 MW • Glendo 38 MW • Guernsey 6 MW • Kortes 36 MW • Seminoe 52 MW • Glendo and Guernsey generate only during summer season

  7. Colorado Big Thompson • Big Thompson 5 MW • Estes 45 MW • Flatiron 95 MW • Green Mountain 26 MW • Mary’s Lake 8 MW • Pole Hill 38 MW • Flatiron includes one 9 MW pump-generator • Big Thompson generates only during runoff

  8. Fryingpan—Arkansas • Mount Elbert Pump-Generator • 206 MW: one 100 MW unit • and one 106 MW unit • Pumping requirement 132 MW per unit

  9. Limited System Capability • RMR manages the power system on a efficient, tightly controlled water system • Numerous Water and Operational limitations • Most water schedules change daily • End-of-day elevation targets are critical • In several cases, one reservoir serves as the afterbay for one plant and the forebay for the next

  10. Plant Characteristics • Average annual inflow for entire system is less than 5,000,000 acre-feet • Eight plants capable of regulating • Alcova, Fremont Canyon, Kortes (limited), Seminoe, Yellowtail, Estes, Flatiron, Mt Elbert • Ability to regulate is governed by water schedules • Only plant with day-to-day flexibility is Mount Elbert

  11. Plant Limitations • Examples of specific plant limitations: • Alcova: fluctuations limited to +/- 1 foot • Yellowtail: 2 units have rough zones between 14 and 42 MW • Fremont Canyon: during runoff units are often block-loaded at full output and additional river flow is bypassed • Flatiron afterbay active storage is less than 400 acre-feet

  12. Other Restrictions • Flow related: • Estes: runoff conditions make generation and regulation unpredictable • Kortes: Miracle Mile fishing releases • Environmental: • Yellowtail: Nitrogen super-saturation • Fremont Canyon: ESA minimum releases

  13. Loveland Area Projects Marketing Plan • Developed 1981 to 1985 • Implemented October 1, 1989 • Combined Pick-Sloan—Western Division and Fryingpan-Arkansas Projects • LAP power is delivered to 180 preference customers, including 60 Coops, 85 municipals and 6 Tribes • Contracts terminate 9/30/2024

  14. Determination of Marketable Resource • Capacity—90% Probability of Exceedance for Pick-Sloan Generation • Log-Pearson statistical analysis • Plus installed capacity of Mt Elbert • Represents higher level of risk • Customers agreed to assume risk of difference between 90 and 99% probability • Either purchase or reduced CROD

  15. Determination of Marketable Resource • No capacity was set aside for losses or regulation • Assumed that diversity would be adequate • Energy—Long Term Average • 40-50 Year averages for most plants • Minimum generation levels: • Vary by month • 17 to 32 percent

  16. Pumped Storage Feature • Used to supplement LAP firm schedules • Combined hourly Schedule of Firm and Pumped-Storage can not exceed monthly entitlement • Off-peak Pump-back requirement is 1.4:1 • Mt Elbert is trapped on XCEL system • Losses increase payback to about 1.6:1

  17. Pumped Storage Energy Account • Pumped-Storage Energy Account • Summer 3.9 kwh/kw of CROD • Winter 4.4 kwh/kw of CROD • Example: Customer with 100 MW CROD can call on 390 or 440 MWh of energy before having to “repay” it • Account can not go below 0 or above 100% and must be full at season-end

  18. Summer (MW) April 611 May 561 June 664 July 713 August 628 September 607 Winter (MW) October 610 November 600 December 654 January 636 February 594 March 538 Resource Available

  19. Firm Customer Use • Firm Customers options • Firm Power • Pumped Storage Option • During 2003 Summer Season • On-peak: 7 out of 10 hours customer usage consumes all marketed capacity • Assumes customers schedule minimum during off-peak hours

  20. Total System Use • In addition to Customer Use RMR must carry reserves: Reserve Pool requirement is 40 MW • Western has calculated a need for 75 MW for regulation and ramping • 55 MW is LAP responsibility • Adding these requirements increases number of hours at full capacity to 80% in Summer 2003

  21. Off-Peak Requirements • Customers typically schedule minimums or slightly above (except daytime Sundays) • Minimum stream flows must be accommodated • Mount Elbert is in pump mode—not available for regulation • Meeting negative regulation needs is often harder than meeting the positive side

  22. Current Resource Integration Obligations • Hydro-thermal Integration: • Laramie River Station (1,100 MW) • since 1981; contract term: 2029. • Regulation Exchange: • RMR provides regulation in exchange for fixed price firm energy purchase thru 2008

  23. Conclusion • RMR operates a system approaching or exceeding maximum capability • Capacity obligations already assume moderate to high level of risk • Obligations: • Firm and Project use power • Control Area requirements • Existing contractual requirements

  24. Conclusion • From a resource management perspective: • How much more can RMR’s resource handle? • How does LAP acquire additional resources to meet control area needs? • How should additional costs be allocated?

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