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ERCOT Reliability Must Run

ERCOT Reliability Must Run. Protocol Definition. Reliability Must Run (RMR) Unit (ERCOT Protocols Section 2: Definitions and Acronyms July 31, 2002)

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ERCOT Reliability Must Run

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  1. ERCOT Reliability Must Run

  2. Protocol Definition Reliability Must Run (RMR) Unit (ERCOT Protocols Section 2: Definitions and Acronyms July 31, 2002) A Generation Resource unit operated under the terms of an annual Agreement with ERCOT that would not otherwise be operated except that they are necessary to provide voltage support, stability or management of localized transmission constraints under first contingency criteria where Market Solutions do not exist.

  3. ERCOT STUDY • Includes • Security Operations • Transmission Services • Existing (history) and possible future conditions included in review • Category A & B contingencies in the ERCOT Planning Criteria • 100% of RATEB thermal limits • Voltage limits • Voltage 0.90 PU to 1.05 PU • Nuclear units license requirements • Sensitivity (priority) of units • Load shedding option with sensitivity

  4. Reliability Must Run (RMR) Units Resource Entity Unit MW Frontera Generation L.P. Frontera Power Station Unit 1 150 West Texas Utilities Fort Phantom Unit 2 202 West Texas Utilities San Angelo Unit 1 21 West Texas Utilities San Angelo Unit 2 102 West Texas Utilities Rio Pecos Unit 6 98 Central Power and Light J. L. Bates Unit 1 74 Central Power and Light J. L. Bates Unit 2 109 Central Power and Light B. M. Davis Unit 1 335 Central Power and Light B. M. Davis Unit 2 356 Central Power and Light La Palma Unit 4 23 Central Power and Light La Palma Unit 5 23 Central Power and Light La Palma Unit 6 153 Central Power and Light La Palma Unit 7 50 Central Power and Light Laredo Unit 1 35 Central Power and Light Laredo Unit 2 32 Central Power and Light Laredo Unit 3 105

  5. Fort Phantom Unit 2 (1977) • PROBLEM • Autotransformer Loading • Line Loading • SHORT TERM SOLUTION • None • LONG TERM SOLUTION • Loop Sweetwater Cogen to Graham 345 kV line into Fort Phantom • Create New 345/138 kV Switch Station • Time frame 2 to 3 years, assuming no problems with line

  6. Fort Phantom Unit 22003 Modified Summer Peak Base Case FlowsPaint Creek and Oak Creek off line Contingency Outage Mulberry Creek Auto Fort Phantom Off line MVA Limit Contour

  7. San Angelo Units 1 & 2 (1965 & 1966) • PROBLEM • Voltage Control/Collapse • SHORT TERM SOLUTION • Completion of Morgan Creek-Twin Buttes-Red Creek-Comanche Sw 345 kV line • Installation of Twin Buttes 345/138 kV autotransformer • Projects started December 1998 • Complete by June, 2003 • LONG TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal, light load and contingency conditions

  8. San Angelo Units 1&2 Modified Summer 2002 Base Case Powerflow N-1 Voltage Contour Contingency Outage Red Creek 345 KV San Angelo Plant Off Line Voltage Contour

  9. Rio Pecos Unit 6 (1969) • PROBLEM • Voltage Control McCamy Area • SHORT TERM SOLUTION • Install shunt reactive at Rio Pecos • In-Service Date April 2003 • LONG TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal, light load and contingency conditions • Remove waiver of reactive requirements for wind generators (can now be done with small SVC’s)

  10. Rio PecosLow Load (30,000 MW) High Wind (75% Cap Factor) Rio Pecos Rio Pecos Off Line

  11. BM Davis Unit 1 & 2 (1974, 1976) • PROBLEM • Voltage Control/Support • Line Loading (several contingencies & limiting elements) • SHORT TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal and contingency conditions • Continue upgrade of 138 kV system • LONG TERM SOLUTION • Loop Lon Hill to Rio Hondo 345 kV line into South Side of Corpus Christi • Create New 345/138 kV Switch Station • Time frame 3 to 4 years, assuming no problems with line

  12. B. M. Davis Units 1&2N-1 (cross channel cable) Summer 2003 Base Case Flow L Hill 0 MW CCEC 0 MW Gregory 470 MW Oxygen 531 MW Contingency Outage White Point – Nueces Bay cable 138 Kv MVA Limit Contour B Davis Off line

  13. B. M. Davis Units 1&2N-1 (Hwy 9 - CCEC) Summer 2003 Base Case Flow L Hill 0 MW CCEC 0 MW Gregory 470 MW Oxygen 531 MW Contingency Outage Hwy 9 - CCEC 138 Kv MVA Limit Contour B Davis Off line

  14. J L Bates Unit 1 & 2 (1958, 1960)Frontera Unit 1 (1999) • PROBLEM • Extreme line loading (many contingencies and limiting elements) • SHORT TERM SOLUTION • Continue upgrade of 138 kV system • Immediate reconductor of Edinburg-McColl Rd 138 kV line with high temperature conductor • Complete by April 2003 • LONG TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal and contingency conditions • Construct Edinburgh-Bates-South McAllen 345 kV line • Install two 345/138 kV switch stations at Bates and South McAllen • Construct 345 kV line from South McAllen to Lomo Alto to LaPalma • Install 345/138 kV autotransformer at Lomo Alto • Time frame 3 to 6 years, assuming no problems with lines

  15. On Peak - Bates Bates 0 MW Contingency MV Pharr – Pharr 138 MVA Limit Contour Frontera dispatched at Max. Cap. Load = 57,000 MW Current line ratings used

  16. On Peak - Frontera Unit 1 Frontera 0 MW Contingency MV Pharr – Pharr 138 MVA Limit Contour Bates dispatched at Max. Cap. Load = 57,000 MW Current line ratings used

  17. La Palma Unit 4,5,6,&7 (1947,1949,1970,1975) • PROBLEM • Line loading (many contingencies and limiting elements) • SHORT TERM SOLUTION • Continue upgrade of 138 kV system • LONG TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal and contingency conditions • Construct Edinburgh-Bates-South McAllen 345 kV line • Install two 345/138 kV switch stations at Bates and South McAllen • Construct 345 kV line from South McAllen to Lomo Alto to LaPalma • Install 345/138 kV autotransformer at Lomo Alto • Time frame 3 to 6 years, assuming no problems with lines

  18. On Peak - La Palma Units 4-7La Palma Gen = 0 MW Contingency Rio Hondo – La Palma 345 MVA Limit Contour 2003 Summer Peak Dispatch Load = 57,000MW Current line ratings used

  19. Laredo Unit 1,2&3 (1951, 1955, 1975) • PROBLEM • Line loading • Voltage control/support • SHORT TERM SOLUTION • Install static and dynamic reactive resources to control/support voltage under normal and contingency conditions • Already in-service, does not solve line loading • LONG TERM SOLUTION • Construct San Miguel-Laredo-Bates 345 kV line • May need series compensation • Install two 345/138 kV switch stations around Laredo • Time frame 4 to 8 years, assuming no problems with lines

  20. Laredo Units 1-3Modified N-1 2003 Summer Base Case Flow Contingency Outage Red Creek 345 KV MVA Limit Contour System Load at 57,000 MW Laredo at 25 MW

  21. Laredo Units 1-3Modified 2003 Summer Base Case Flow Laredo Units Off line Voltage Contour Load = 57,000MW No Laredo STATCOM No Laredo Capacitor Banks

  22. TRANSMISSION RESOURCES • ARE NOT INFINITE • Capital Limitations • Planning Limitations • Construction Limitations • FOCUSING RESOURCES ON RMR WILL DIVERT IT AWAY FROM OTHER PROJECTS • PRIORITIZATION CRITERIA NEEDED • Reliability Needs (serving load) • Congestion Needs • RMR Needs • Generation Interconnection Needs

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