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Application and Implementation of State Estimator at
Idaho Power Company
S. Kincic and M. Papic
Outline
1.1. BackgroundBackground
2.2. Overview of IPCO and its Overview of IPCO and its EMS SystemEMS System
3.3. IPC Experience with IPC Experience with State State EstimatorEstimator
4.4. Modeling IssuesModeling Issues
5.5. SE in PlanningSE in Planning
6.6. ConclusionsConclusions
1. Background
The Project addresses the NERC and WECC requirements for EMS functionality identified from the August 14th Blackout as well as improved coordination with additional Off-Line Planning Functions.
The EMS project has been initialized by Grid Operations and Planning following the recommendations of the US/Canada outage task force on the August 2003 blackout.
1. Background
Recommendation 22 – Evaluate and adopt better real-time tools for operators and reliability coordinatorsRecommendation 24 - Improve quality of system modeling data and data exchange practicesNERC should work with the regional reliability councils to establish regional power system models that enable the sharing of consistent and validated data among entities in the region. Power flow and transient stability simulations should be periodically benchmarked with actual system events to validate model data.
NE Blackout TF Recommendations
1. Background
Installation and complete modeling of the new EMS has been completed entirely by IPCO EMS teamProject completed in two phases:
Phase I: Implementation of SE and advanced applications (May 2005)Phase II: Cutover to the new SCADA (May 2007)
SE tuning has been accomplished throughout 2007
2. System Overview
Company:
Covers 24.000 sq. miles
Peak 3300MW
Net importer of energy
17 plantsShared ownership of three coal fire plants
4,600 miles of transmission lines
18,000 miles of distribution lines
British Columbia Alberta
Washington
OregonIdaho
Montana
W yoming
Colorado
Utah
Nevada
California
Arizona New Mexico
Mexico
12
MONTANA
UTAH
WASHINGTON
NEVADA
OREGON
WY
Geographic Location of I daho External Paths
2. IPC System Model
Planning Model (bus-branch representation)EMS/Dispatching Model (node-breaker representation)Models Accuracy and ValidationInter-Utility Data ExchangeThe system representation at any given time includes the static data (network topology) and the system conditions (loads, interchanges, flows) Wide System Model (WSM)
EMS System:Configuration:
Windows Based
One pair of servers for SCADA and Generation Application
One pair of servers for SE and Advanced Application
One pair of servers for ICCP data
One server for DTS
Two modeling Servers
EMS System: IPC Data Exchange:
PNSC
RDRCCMRC
IPC
PAC
BPA
SPPC
NWE
EHVDP
PGE
PG&E
3. State Estimator
Operates on PNSC model (North West WECC)
Model Includes: 8000 buses (1400 measured)5000 lines4000 substationsReceives about 15000 analogs and statuses
3. State Estimator
SE runs every 300 sec.RTNET includes SE and RTCASTNET includes PWRFLOW and CAAfter every State Estimate , the base case is monitored for violationsReal Time CA runs every 300 sec.Base Case used for STNET (outage schedule)
4. Modeling Issues
Planning model is used as a source of line and transformers parameters- occasionally conversion of p.u. in percentage omitted;
SE uses breaker oriented model-terminals of everydevice are attached to two or three nodes. Assignment of device to incorrect node – topologyerror;Series capacitors composed of modules that can beInserted and bypassed separately (often non-seen on company one line). If represented as a single device- Significant power flow error;
4. Modeling Issues
Breaker oriented model- over 30.000 breakers. Status of breakers required or topology error if breaker is in wrong position. Maintenance is required;Field changes have to be modeled- difficulty in obtaining new data;Mapping of the measurements into the model if the name change- composite key broken
METERINGMW, MVAR
MTie Line to JBRIG
ZBR
to MPSN
Capacitors
REACTORL342
303D302Z
305A 306ASCADA model
METERINGMW, MVAR
M
Tie Line to JBRIG
ZBR
to MPSN
Capacitors
306 A305 A
303 D302 Z
REACTORL342
NETWORK model
Bus configurations need attention;
breaker
100 MW
56 57
HV LV
transformer
100 MW 100 MW
100 MW100 MW
Wrong direction of measurements;
Load model;
Load model-time dependant schedule for operating area;
Individual loads follow the same pattern;
No load diversity;
Operating Area(time dependent
schedule)
Load1
Load2
LoadN
Bas
e 1 +
frac
tion 1
BaseN + fraction
N
Bas
e 2 +
fra
ctio
n2
Detailed load model
Operating Area(time dependent
schedule)
Spring
Winter
Summer
Industrialschedule
Residentialschedule
Irrigationschedule
Commercialschedule
North
NorthSouth
West
East
East
Load
Load
Load
Load
Load
LoadLoad
Load
Load
Load
Load
Load
Load
5. Application ofSE in Planning
Translation of dispatching (breaker to breaker) model into the planning model
6. Conclusion
Vendors provide operational structure
Utilities have to address modeling issues
The flow of measurement data among utilities has to be established
Idaho Power Company has successfully accomplished these tasks
What Next?
Continue working and improving IPCO model.Developing a process of updating IPCO model with external transmission facilities.Participating in the development of the WSMFurther Validating of SE, STNET and CA resultsImplementing of Metrics for SE Evaluation (*)Integrating of PMU data into IPCO SE.Start using POM to evaluate critical contingencies and develop a mitigation plan when the contingency occurs. (*)