Transcript ERCOT Reliability Must Run 2003

ERCOT
Reliability Must
Run
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.
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
Reliability Must Run (RMR) Units
Resource Entity
Frontera Generation L.P.
West Texas Utilities
West Texas Utilities
West Texas Utilities
West Texas Utilities
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Central Power and Light
Unit
Frontera Power Station
Fort Phantom
San Angelo
San Angelo
Rio Pecos
J. L. Bates
J. L. Bates
B. M. Davis
B. M. Davis
La Palma
La Palma
La Palma
La Palma
Laredo
Laredo
Laredo
Unit 1
Unit 2
Unit 1
Unit 2
Unit 6
Unit 1
Unit 2
Unit 1
Unit 2
Unit 4
Unit 5
Unit 6
Unit 7
Unit 1
Unit 2
Unit 3
MW
150
202
21
102
98
74
109
335
356
23
23
153
50
35
32
105
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
Fort Phantom Unit 2
2003 Modified Summer Peak Base Case Flows
Paint Creek and Oak Creek off line
Contingency Outage
Mulberry Creek Auto
Fort Phantom
Off line
MVA Limit Contour
San Angelo Units 1 & 2 (1965 & 1966)
• PROBLEM
– Voltage Control/Collapse
• SHORT TERM SOLUTION
– Completion of Morgan Creek-Twin Buttes-Red CreekComanche 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
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
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)
Rio Pecos
Low Load (30,000 MW)
High Wind (75% Cap Factor)
Rio Pecos
Rio Pecos Off Line
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
B. M. Davis Units 1&2
N-1 (cross channel cable) Summer 2003 Base Case Flow
L Hill
0 MW
CCEC
0 MW
Gregory
470 MW
Contingency Outage
White Point – Nueces
Bay cable 138 Kv
Oxygen
531 MW
MVA Limit Contour
B Davis
Off line
B. M. Davis Units 1&2
N-1 (Hwy 9 - CCEC) Summer 2003 Base Case Flow
L Hill
0 MW
CCEC
0 MW
Gregory
470 MW
Contingency Outage
Hwy 9 - CCEC 138 Kv
Oxygen
531 MW
MVA Limit Contour
B Davis
Off line
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
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
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
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
On Peak - La Palma Units 4-7
La Palma Gen = 0 MW
Contingency
Rio Hondo – La Palma 345
MVA Limit Contour
2003 Summer Peak Dispatch
Load = 57,000MW
Current line ratings used
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
Laredo Units 1-3
Modified 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
Laredo Units 1-3
Modified 2003 Summer Base Case Flow
Voltage Contour
Load = 57,000MW
No Laredo STATCOM
No Laredo Capacitor Banks
Laredo Units
Off line
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