Transcript Slide 1

Application and Implementation
of State Estimator at
Idaho Power Company
S. Kincic and M. Papic
Outline
1.
2.
3.
4.
5.
6.
Background
Overview of IPCO and its
EMS System
IPC Experience with
State Estimator
Modeling Issues
SE in Planning
Conclusions
1. Background
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.
The Project addresses the NERC and WECC
requirements for EMS functionality identified
from the August 14th Blackout as well as
improved coordination with additional OffLine Planning Functions.
1. Background
NE Blackout TF Recommendations
Recommendation 22 – Evaluate and adopt better realtime tools for operators and reliability coordinators
Recommendation 24 - Improve quality of system
modeling data and data exchange practices
NERC 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.
1. Background
Installation and complete modeling of the
new EMS has been completed entirely by
IPCO EMS team
Project 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 plants
Shared ownership of three coal fire plants
4,600 miles of transmission lines
18,000 miles of distribution lines
British Columbia
Alberta
Geographic Location of Idaho
External Paths
WASHINGTON
Washington
Montana
MONTANA
Oregon
Idaho
Wyoming
OREGON
WY
Nevada
Utah
Colorado
California
Arizona
Mexico
New Mexico
NEVADA
UTAH
12
2. IPC System Model
Planning Model (bus-branch representation)
EMS/Dispatching Model (node-breaker
representation)
Models Accuracy and Validation
Inter-Utility Data Exchange
The 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:
IPC
PNSC
PAC
BPA
EHVDP
CMRC
RDRC
SPPC
NWE
PGE
PG&E
3. State Estimator
Operates on PNSC model (North West
WECC)
Model Includes:
8000 buses (1400 measured)
5000 lines
4000 substations
Receives about 15000 analogs and
statuses
3. State Estimator
SE runs every 300 sec.
RTNET includes SE and RTCA
STNET includes PWRFLOW and CA
After every State Estimate , the base
case is monitored for violations
Real 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 every
device are attached to two or three nodes.
Assignment of device to incorrect node – topology
error;
Series capacitors composed of modules that can be
Inserted 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
Bus configurations
need attention;
SCADA model
305A
306A
to
MPSN
METERING
MW, MVAR
ZBR
302Z
303D
M
Tie Line to
JBRIG
REACTOR
L342
Capacitors
NETWORK model
305 A
306 A
M
302 Z
to
MPSN
METERING
MW, MVAR
ZBR
303 D
Tie Line to
JBRIG
REACTOR
L342
Capacitors
Wrong direction of
measurements;
breaker
100 MW
100 MW
56
57
100 MW
transformer
100 MW
100 MW
HV
LV
Load model;
Load model-time dependant
schedule for operating area;
Individual loads follow
the same pattern;
Operating Area
(time dependent
schedule)
No load diversity;
LoadN
Load1
Load2
Spring
Winter
Summer
Operating Area
(time dependent
schedule)
Industrial
schedule
Commercial
schedule
Irrigation
schedule
Residential
schedule
Load
Load
East
North
Load
West
South
Load
East
Load
Load
Load
North
Load
Load
Load
Load
Load
Detailed load model
Load
5. Application of
SE 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 WSM
Further Validating of SE, STNET and CA results
Implementing 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. (*)