ERSC
ABB Inc. , Electric System Consulting Dept.
MBPC Study – 1st Load Pocket
Preliminary Results for Discussion only
Entergy Regional State Committee (ERSC)
Southwest Power Pool (SPP)
February 16, 2011
© ABB Group
August 23,2010 | Slide 1
ERSC
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Agenda
Study Overview
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Study Status
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Task List and Study Approach
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Case List
Reference Case
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Production Costing
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Power Flow
Very Preliminary Results for Western Load Pocket
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Production Costing
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Power Flow Analysis
Next Steps
© ABB Group
August 23,2010 | Slide 2
ERSC
Study Status
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Study assumption document submitted for review
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Completed development of production costing and power flow
models for 2013 Reference Case (RMR nomograms enforced)
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Analysis started for Western Load Pocket
© ABB Group
August 23,2010 | Slide 3
Task List
ERSC
Task 1 – Develop Data base and System Models
Task 2 – Transmission Analyses with RMR Unit
Task 3 – Transmission Analyses w/o RMR Unit & no Transmission Change
Task 4 – Transmission Analyses w/o RMR Unit & Transmission Change
Task 5 – Production Cost Simulation with RMR Unit
Task 6 – Production Cost Simulation w/o RMR Unit & no related Transfer Limit Constraint
Task 7 – Production Cost Simulation w/o RMR Unit & with Transmission Changes
Task 8 – Economic Comparison of Benefits and Costs
Task 9 – Collate results by Units, Plants and Groups.
Task 10 – Congestion Analysis
Task 11 – Fuel Price Elasticity
Task 12 – Sensitivity Analysis
Task 13 – Perform ATC Calculations
Task 14 – Study Report Preparation, Discussion and Presentation
Task 15 – Additional Transmission Upgrades required for Flexible Capacity
(Optional)
© ABB Group
August 23,2010 | Slide 4
ERSC
© ABB Group
August 23,2010 | Slide 5
Study Approach - Overview
ERSC
© ABB Group
August 23,2010 | Slide 6
Case List
ERSC
Reference Case
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Reference case provides a base for determining the impact of
removing the RMR designations for the study units
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RMR nomograms are enforced in the reference case
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Modeling assumptions described in Study Assumptions Document
© ABB Group
August 23,2010 | Slide 7
ERSC
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Reference Case (Production Costing)
Benchmarked with Entergy units, using following statistics for 2007,
2008, 2009:
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Annual energy production
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Annual service hours
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RMR guidelines modeling was verified
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Operating reserve modeling was verified
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Entergy generation units data were checked
© ABB Group
August 23,2010 | Slide 8
ERSC
Reference Case (Power Flow)
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Reference case represents system conditions at the Entergy system
peak hour (Aug. 26, 2013 @ 3 pm)
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Started from 2013 power flow case prepared by SPP-ICT
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Synchronized Loads in the Power Flow and Production Costing at the
peak hour
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Synchronized dispatch of generating units within Entergy footprint
based on Production Costing dispatch (SCED) at the peak hour
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Also ensured interchange between Entergy footprint and Tier 1
matches Production Costing interchange
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Entergy footprint totals at the peak hour:
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Load + losses: 33,810 MW
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Generation: 32,068 MW
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Import from Tier 1: 1,742 MW
© ABB Group
August 23,2010 | Slide 9
ERSC
© ABB Group
August 23,2010 | Slide 10
Reference Case (Power Flow)
ERSC
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Reference Case Results (Power Flow)
Ran power flow analysis on Reference Case to check steady-state
performance in Entergy footprint for following conditions:
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System intact
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N-1 contingencies
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G-1,N-1 contingencies (WOTAB and Amite South)
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Results submitted to SPP
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SPP reviewed results and provided Construction Plan projects and
comments on results
© ABB Group
August 23,2010 | Slide 11
ERSC
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Western Load Pocket Analysis
Following cases were simulated
Case
Name
West_0
West_1
West_2
West_3
West_4
© ABB Group
August 23,2010 | Slide 12
Definition
Same as reference case
Same as West_0 with no nomogram
Same as West_1 with no Western area
transmission limits and no limits on 8 tie-lines
between Western & WOTAB in production
costing analysis
Same as West_0 with plant turned off
Same as West_3 with no Western area
transmission limits and no limits on 8 tie-lines
between Western & WOTAB in production
costing analysis
ERSC
Western Analysis (Contd.)
Preliminary results
For case West_1, it is found that:
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Lewis Creek units are still being dispatched on the security
constrained economic dispatch basis and also due to transmission
constraints that limit the import of power into the WOTAB/Western
load pocket.
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Power flow analysis: When RMR designation was not used for
Western units (Case West_1), generation dispatch is identical to that
in the Reference Case (West_0 with RMR rule enforced) at the peak
load hour. Hence, there was no need to repeat power flow for the
West_1 Case.
© ABB Group
August 23,2010 | Slide 13
ERSC
Western Analysis (Contd.)
Preliminary results
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In Case West_2, reduction (appr. 40%) in the Lewis Creek plant annual
energy (MWh) production was observed.
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Power flow analysis showed degradation in steady-state performance (more
overloads) compared to West_1 case, because the plant was dispatched at
about 20% lower MW level (than in West_1 Case) during Entergy’s peak load
hour.
© ABB Group
August 23,2010 | Slide 14
ERSC
Western Analysis (Contd.)
Preliminary results
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For West_3 Case, with Lewis Creek plant turned off, the
annual production cost, in the Entergy footprint, increased.
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Power flow analysis showed further degradation in steady-state
performance (overloads) compared to West_2 case, including
Voltage Collapse for certain double contingencies and several G1N1
contingencies. This is mainly due to erosion of reactive capability in
Western Load pocket.
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The results for West_4 Case were similar to West_3 Case.
© ABB Group
August 23,2010 | Slide 15
ERSC
Next Steps
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Relieve all constraining flowgates
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Increase WOTAB import limit
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Power flow analysis will be run to check for transmission constraints
associated with import of cheaper power into Western
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Addition of transmission projects to increase load pocket import
capability
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Analysis (production costing and power flow):
a) Is more economical generation available than assumed in the
Production Costing model?
b) If so, does that case require associated transmission fixes?
- PV curves, OPF etc.
© ABB Group
August 23,2010 | Slide 16
ERSC
Q&A
Thank you!
© ABB Group
August 23,2010 | Slide 17