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Long Term Study Task Force Update
Transmission Study Practices and Methodologies
April 5th,2011
LTS
Objectives
• Create a stable, reliable representation of the ERCOT System for the 2020 and 2030 horizon.
• Integrate a generation portfolio representative of the real energy needs of the 2020 and 2030 loads while maintaining an appropriate reserve margin
• Identify Transmission Solutions that meet the long term needs of the ERCOT system
• Evaluate the AC steady-state reliability needs of the system, and develop solutions that minimize total economic cost (by scenario)
LTS April 5th,20112
Process
LTS April 5th,2011
Develop Transmission Model
Perform Simplification Criteria
2016 SSWG Case
Load Forecast 2020/30 Install Generation
needed to meet real energy needs
Determine Transmission Needs
Implement and document results
Map case to Security Constrained Economic Dispatch Model (Promod)
Remove and Replace generation added for Reliability
Scenario Specific Economic Build Out
Generation Siting Process
Reassess Transmission Needs – Reliability and Economy
Defined Contingencies
Prepare final solution set
3
Load Forecast Development
• Load forecasts developed by weather zone
Included input from 15 years of weather data (1996-2010)
• Calculated Average, max, and min temperatures
• Applied median (50 percentile) temperature per weather month
• Loads were disaggregated by county (using Moody’s population data) and applied at the appropriate bus / equivalent bus in those counties
LTS April 5th,20114
2016 vs 2020
LTS April 5th,2011
2016: 1,984 MW 2020: 2,078 MW
2016: 3,112 MW 2020: 3,345 MW
2016: 21,106 MW 2020: 22,358 MW
2016: 5,947 MW 2020: 6,423 MW
2016: 2,294 MW 2020: 2,420 MW
2016: 2,052 MW 2020: 2,194 MW
2016: 27,273 MW2020: 29,185 MW
2016: 12,783 MW 2020: 14,115 MW
Non-coincident peak load2016: 76,551MW 2020: 82,118 MW
5
2016 vs 2030
LTS April 5th,2011
2016: 1,984 MW 2030: 2,174 MW
2016: 3,112 MW 2030: 3,777 MW
2016: 21,106 MW 2030: 24,466 MW
2016: 5,947 MW 2030: 7,409 MW
2016: 2,294 MW 2030: 2,637 MW
2016: 2,052 MW 2030: 2,461 MW
2016: 27,273 MW2030: 33,856 MW
2016: 12,783 MW 2030: 16,524 MW
Non-coincident peak load2016: 76,551MW 2030: 93,304 MW
6
Transmission Simplification Criteria
• Equivalence the 69kV System: All 69kV Loads and Generators are replaced at the nearest upstream 138kV or 345kV Bus
• Equivalence rural / radial lines (138kV): – Rural lines less than 30 miles rated less than 150MVA are
upgraded to 300MVA. – Rural lines less than 20 miles rated less than 440 MVA are
upgraded to 440 MVA– Any rural line with a rating higher than 440 is not upgraded
• Upgrade short urban lines (138kV): Any urban line shorter than 2.5 miles rated less than 800MVA is upgraded to 800MVA
LTS April 5th,20117
Reliability Screen – Generation additions
Increased loads are served by incremental generation added as follows:
•Selected existing generation sites are rebuilt as larger machines where practical
•Where excess transmission capacity exists, new generators are added
•For large load centers of interest, multiple generation sites are tested independently to identify worst case scenarios
Where:
fuel, cooling, existing transmission, and proximity to a major metropolitan area allow
LTS April 5th,20118
2020 and 2030 AC Cases
• Voltage issues and thermal limitations are corrected where necessary– Reactive support is applied at the worst offending busses in an
iterative approach to correct voltage to .98 PU (N-0)– Address thermal overloads, as well as voltage collapse for (N-1)
• Cases are stable, reliability assessment is underway– Includes N-1, G-3 stress testing of the steady-state model– NERC C & D criteria will be tested with proposed solutions
• Cases will be mapped to ProMod, with the newly developed contingency file, to determine opportunities for economic projects
LTS April 5th,20119
Transmission Simplification Validation
• Verify no material changes in system dispatch: Pre and post simplification models are compared to verify no material changes in production cost or dispatch occurred as a result of the simplification
• Preliminary comparisons are in Uplan, subsequent comparisons will be performed pre and post simplification in ProMod
LTS April 5th,2011
Case Description Difference in Production cost from Base Case(M$)
Base Case Full System -
Partially Simplified Full system - 69kV system 107.87 Fully simplified Full system - 69kV system +
simplified 138kV system129.96
10
Development of Contingency Events
• To maintain a plausible system dispatch, constraints must be defined to reflect new contingencies or redefine contingencies eliminated in the simplification process
• Previous study practices defined many contingencies with emphasis on any element with post-contingency loading beyond a user defined threshold.
• New tools (PAT, ProMod) and study practices focus on an iterative approach to define specific, targeted contingencies
• Increased engineering input allows system modeling with sufficient detail and decreased run times, allowing for additional analysis on specific topics and scenarios
LTS April 5th,201111
Economic Analysis
• Perform a security constrained economic dispatch study of the simplified transmission model with the updated generation portfolio
• Identify transmission projects that create societal benefit (measured as decreased system production cost)
• Analyze opportunities to replace a previously modeled reliability project with a project that meets both economic and reliability needs
• Benchmark each project against alternatives in each scenario
LTS April 5th,201112
Large Load Centers Currently in Study
• DFW Metro Area
• Houston Metro Area
• Lower Rio Grande Valley
LTS April 5th,201113
Dallas Fort Worth Metro Area
• Voltage deficiencies are significant and not correctable from incremental reactive resources (~9000MVar of switched shunt compensation required for N-0)
• Potential retirement of legacy generation exacerbates voltage issues
• Studies with incremental generation or lines into the DFW are underway
LTS April 5th,201114
Dallas Fort Worth Metro Area
As modeled, the Dallas metro area relies on heavy imports into the Region from the South and East
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JASPERNEWTON
WALKER
TRINITY
POLKTYLER
ANGELINA
SAN
AU
GU
STIN
E
SABINE
SHELBBY
PANOLA
NACOGDOCHESCHEROKEE
HOUSTON
HARRISON
MARION
CASSMO
RRIS
TITUS
CAMP
FRAN
KLI
N
UPSHURWOOD
GREGG
RUSK
RED RIVER
BOWIE
FANNIN
DELTA
HUNT
RAINS
VAN ZANDT
SMITH
KAUFMAN
HOPKINS
HENDERSON
ANDERSON
NAVARRO
FREESTONELIMESTONE
LEON
ELLISJOHNSON
HILL
McLENNAN
SOMERVELL
HOOD
ERATH
COMANCHE
HAMLITON
MILLS
CORYELL
BOSQUE
BURNET
SAN SABA
McCULLLOCH
LLANO
WILLIAMSON
BELL
FALLS
MILAM
LAMPASSAS
ROBERTSON
MADISON
BRAZOS
BROWN
CALLAHAN
EASTLAND
COLLINS
ROCKWALLDALLAS
TARRANT
PARKER
PALO PINTO
JACKWISE
DENTON
GRAYSON
ARCHERBAYLOR
YOUNG
THROCKMORTON
SHACKLEFORD
STEPHENS
SNGLTN_345
W_KRUM_5
90%A
Amps
90%A
Amps
91%A
Amps
94%A
Amps
80%A
Amps
80%A
Amps
47%A
Amps
47%A
Amps
59%A
Amps
59%A
Amps
72%A
Amps 72%
A
Amps
114%A
Amps
118%A
Amps
119%A
Amps119%
A
Amps
Low Voltage Issues
Post contingency stability limit violations exist - highlighted lines represent a possible solution.
April 5th,201115LTS
Lower Rio Grande Valley
• Peaks are comparable or higher than 2011 Winter Event levels
• Current 345kV importation is not sufficient for maintenance and/or voltage stability
LTS April 5th,2011
YearUpdated Forecast extrapolated by county
2016 30872020 32942030 3941
16
Lower Rio Grande Valley
L N H I L L 6
R I O H N D 6
E D N B R G 6
L A P A L M 6
W H I T E P T 6
L H E D M
L H E D L
L H R H M
L H R H L
8 4 5 5
8 3 8 3
8 3 1 8
8 3 1 7
8 9 0 1
8 9 0 5
8 9 0 3
8 9 0 2
R I O H N S T R
8 9 5 6
C I D - 2 3 08 6 1 0 5
ARANSASSAN PATRICIO
NUECES
DUVALWEBB J IM WELLS
ZAPATA
J IM HOGGBROOKS
KLEBERG
KENEDY
STARR
HIDALGO
WILLACY
CAMERON
ADC-23086103
RI OBRAV
112%A
Amps
112%A
Amps
113%A
Amps
Proposed 345 by AEP in RPG
Loss of this line causes angular
divergence
Loss of this line causes overload of the other under 2020 loads and
angular divergence under 2030 MW loads
April 5th,201117LTS
Lower Rio Grande Valley
L N H I L L 6
R I O H N D 6
E D N B R G 6
L A P A L M 6
W H I T E P T 6
L H E D M
L H E D L
L H R H M
L H R H L
8 4 5 5
8 3 8 3
8 3 1 8
8 3 1 7
8 9 0 1
8 9 0 5
8 9 0 3
8 9 0 2
R I O H N S T R
8 9 5 6
C I D - 2 3 08 6 1 0 5
ARANSASSAN PATRICIO
NUECES
DUVALWEBB J IM WELLS
ZAPATA
J IM HOGGBROOKS
KLEBERG
KENEDY
STARR
HIDALGO
WILLACY
CAMERON
ADC-23086103
RI OBRAV
112%A
Amps
112%A
Amps
113%A
Amps
Double circuit increases stability limit and thermal
rating.
Double circuit increases stability limit and thermal
rating.
Tie reduces contingency impact.
Series Compensation adjusted back to 50% after adding second
circuit.
Proposed new line is does not address all issues on a 20 year horizon. Contingent
flows on this line are low due to long distance to
generation.
April 5th,201118LTS
Houston under 2030 Load + 5%
• Large amounts of shunt reactive compensation, some likely dynamic, appears necessary.
• Preliminary analysis indicates that a new import path will be needed before 2030 to solve angular stability issues on the north (Singleton) and west (Fayette) import paths
• Analysis is ongoing
April 5th,201119LTS
Future Economic Studies
• Map the simplified transmission model to Promod
• Remove and replace any generation added for stability with generation fuel / location derived from Promod results.
• Perform a Promod run, identifying LMP values at each bus
• Identify opportunities for economic projects
LTS April 5th,201120
Questions?
LTS April 5th,201121