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© ABB Group August 23,2010 | Slide 1
MBPC Study – 1st Load PocketPreliminary Results for Discussion only
Entergy Regional State Committee (ERSC) Southwest Power Pool (SPP)
February 16, 2011
ABB Inc. , Electric System Consulting Dept.
ERSC
ERSC
© ABB Group August 23,2010 | Slide 2
Agenda
Study Overview
Study Status
Task List and Study Approach
Case List
Reference Case
Production Costing
Power Flow
Very Preliminary Results for Western Load Pocket
Production Costing
Power Flow Analysis
Next Steps
ERSC
© ABB Group August 23,2010 | Slide 3
Study Status
Study assumption document submitted for review
Completed development of production costing and power flow models for 2013 Reference Case (RMR nomograms enforced)
Analysis started for Western Load Pocket
ERSC
© ABB Group August 23,2010 | Slide 4
Task List
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)
ERSC
© ABB Group August 23,2010 | Slide 7
Reference Case
Reference case provides a base for determining the impact of removing the RMR designations for the study units
RMR nomograms are enforced in the reference case
Modeling assumptions described in Study Assumptions Document
ERSC
© ABB Group August 23,2010 | Slide 8
Reference Case (Production Costing)
Benchmarked with Entergy units, using following statistics for 2007, 2008, 2009:
Annual energy production
Annual service hours
RMR guidelines modeling was verified
Operating reserve modeling was verified
Entergy generation units data were checked
ERSC
© ABB Group August 23,2010 | Slide 9
Reference Case (Power Flow)
Reference case represents system conditions at the Entergy system peak hour (Aug. 26, 2013 @ 3 pm)
Started from 2013 power flow case prepared by SPP-ICT
Synchronized Loads in the Power Flow and Production Costing at the peak hour
Synchronized dispatch of generating units within Entergy footprint based on Production Costing dispatch (SCED) at the peak hour
Also ensured interchange between Entergy footprint and Tier 1 matches Production Costing interchange
Entergy footprint totals at the peak hour:
Load + losses: 33,810 MW
Generation: 32,068 MW
Import from Tier 1: 1,742 MW
ERSC
© ABB Group August 23,2010 | Slide 11
Reference Case Results (Power Flow)
Ran power flow analysis on Reference Case to check steady-state performance in Entergy footprint for following conditions:
System intact
N-1 contingencies
G-1,N-1 contingencies (WOTAB and Amite South)
Results submitted to SPP
SPP reviewed results and provided Construction Plan projects and comments on results
ERSC
© ABB Group August 23,2010 | Slide 12
Western Load Pocket Analysis
Following cases were simulated
Case Name
Definition
West_0 Same as reference case West_1 Same as West_0 with no nomogram
West_2 Same as West_1 with no Western area transmission limits and no limits on 8 tie-lines between Western & WOTAB in production costing analysis
West_3 Same as West_0 with plant turned off
West_4 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
© ABB Group August 23,2010 | Slide 13
Western Analysis (Contd.)
Preliminary results
For case West_1, it is found that:
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.
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.
ERSC
© ABB Group August 23,2010 | Slide 14
Western Analysis (Contd.)
Preliminary results
In Case West_2, reduction (appr. 40%) in the Lewis Creek plant annual energy (MWh) production was observed.
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.
ERSC
© ABB Group August 23,2010 | Slide 15
Western Analysis (Contd.)
Preliminary results
For West_3 Case, with Lewis Creek plant turned off, theannual production cost, in the Entergy footprint, increased.
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.
The results for West_4 Case were similar to West_3 Case.
ERSC
© ABB Group August 23,2010 | Slide 16
Next Steps
Relieve all constraining flowgates
Increase WOTAB import limit
Power flow analysis will be run to check for transmission constraints associated with import of cheaper power into Western
Addition of transmission projects to increase load pocket import capability
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.