ERCOT Reliability Must Run
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Transcript of ERCOT Reliability Must Run
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ERCOT Reliability Must
Run
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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.
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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
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Reliability Must Run (RMR) UnitsResource Entity Unit MWFrontera Generation L.P. Frontera Power Station Unit 1 150West Texas Utilities Fort Phantom Unit 2 202West Texas Utilities San Angelo Unit 1 21West Texas Utilities San Angelo Unit 2 102West Texas Utilities Rio Pecos Unit 6 98Central Power and Light J. L. Bates Unit 1 74Central Power and Light J. L. Bates Unit 2 109Central Power and Light B. M. Davis Unit 1 335Central Power and Light B. M. Davis Unit 2 356Central Power and Light La Palma Unit 4 23Central Power and Light La Palma Unit 5 23Central Power and Light La Palma Unit 6 153Central Power and Light La Palma Unit 7 50Central Power and Light Laredo Unit 1 35Central Power and Light Laredo Unit 2 32Central Power and Light Laredo Unit 3 105
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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
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Fort Phantom Unit 22003 Modified Summer Peak Base Case Flows
Paint Creek and Oak Creek off line
Fort PhantomOff line
Contingency OutageMulberry Creek Auto
MVA Limit Contour
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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
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San Angelo Units 1&2 Modified Summer 2002 Base Case Powerflow
N-1 Voltage Contour
San Angelo PlantOff Line
Contingency OutageRed Creek 345 KV
Voltage Contour
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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)
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Rio PecosLow Load (30,000 MW)
High Wind (75% Cap Factor)
Rio Pecos Off Line
Rio Pecos
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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
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B. M. Davis Units 1&2 N-1 (cross channel cable) Summer 2003 Base Case Flow
Oxygen531 MW
Gregory470 MW
CCEC0 MW
L Hill0 MW
Contingency OutageWhite Point – Nueces Bay cable 138 Kv
B DavisOff line
MVA Limit Contour
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Oxygen531 MW
Gregory470 MW
CCEC0 MW
L Hill0 MW
B DavisOff line
Contingency OutageHwy 9 - CCEC 138 Kv
B. M. Davis Units 1&2 N-1 (Hwy 9 - CCEC) Summer 2003 Base Case Flow
MVA Limit Contour
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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
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On Peak - Bates Bates 0 MW
Frontera dispatched at Max. Cap.Load = 57,000 MWCurrent line ratings used
ContingencyMV Pharr – Pharr 138
MVA Limit Contour
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On Peak - Frontera Unit 1 Frontera 0 MW
Bates dispatched at Max. Cap.Load = 57,000 MWCurrent line ratings used
ContingencyMV Pharr – Pharr 138
MVA Limit Contour
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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
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On Peak - La Palma Units 4-7La Palma Gen = 0 MW
ContingencyRio Hondo – La Palma 345
2003 Summer Peak DispatchLoad = 57,000MWCurrent line ratings used
MVA Limit Contour
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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
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Laredo Units 1-3Modified N-1 2003 Summer Base Case Flow
Contingency OutageRed Creek 345 KV
System Load at 57,000 MWLaredo at 25 MW
MVA Limit Contour
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Laredo Units 1-3Modified 2003 Summer Base Case Flow
Voltage Contour
Load = 57,000MWNo Laredo STATCOMNo Laredo Capacitor Banks
Laredo UnitsOff line
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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