1. WECC Joint Synchronized Information Subcommittee
Report to WECC PCC and OC
October 2014
Presented by Dmitry Kosterev

2. Western Interconnection Synchrophasor Program (WISP)
Phase 1 WISP - $108M investment completed
WECC JSIS supports reporting to DOE
Phase 2 WISP:
DOE awarded a new $6.2M grant to Peak RC, total of $12.4M with cost-share from BPA, CISO, SCE, SDG&E,IPC
DOE $2.9M are awarded to PG&E with the recipient cost-share of additional $3.9M

3. WECC JSIS Structure Data Delivery and Management
Engineering Analysis Applications
Control Room Applications

4. Data Delivery and Management
Dates:
8/25/ /31/2014
Entity
Percent Availability
PMU Count
AESO
94.09% 17
APS
94.99%
BCHA
81.76% 11
BPA
99.86% 55
IPCO
83.13% 20
LDWP
99.58% 15
NVE
69.14% 6
NWE
62.91% 3
PAC
73.19% 4
PGAE
0.00% 2
PNM
75.86%
SCE
38.07% 7
SDGE
SRP
99.89% 1
TEPC
100.00%
TSGT
98.45%
WAPA
99.81% 5
Overall:
90.13%
177

5. Data Delivery and Management
WISP 2.0 will focus on improving data quality
Applications are developed for analysis of data availability and latency
Applications are being developed for analysis of data validity and data calibration

6. Engineering Analysis Oscillation Analysis Power Plant Model Validation
Frequency Response Analysis
System Model Validation

7. Oscillation Analysis
A paper is completed on modes of inter-area oscillations in the West
PDCI probing tests and brake tests:
2013 report is completed
2014 tests are done, report is under development
Analysis applications
“Prony Robot” is developed to calculate and tabulate oscillation frequency, damping and shape for 1,000’s of simulation runs
Applications for ambient data analysis are available, training required

8. Oscillation Detection
Oscillation Detection Application scans power and voltage at interties, power plants, PDCI, SVCs for growing or sustained high energy oscillations
Events captured in 2014:
Wind power plant control system oscillation at 14 Hz
Generator PT failure resulting in oscillation (about 1 Hz)
Hydro plant operating in rough zone for extended period of time (about 0.33 Hz)

9. Oscillation Detection
BEFORE
AFTER

10. Power Plant Model Validation
PPMV plays in disturbance data into GE PSLF
A state-of-the art data management systems are developed
Technology transfer is in progress (BPA, IPC, PG&E, SRP)
Cost effective approach for compliance with MOD-026 and MOD-027 Reliability Standards

11. Frequency Response Analysis Tool
Frequency Response Analysis Tool (FRAT) works at
Interconnection (done)
Balancing Authority (done)
Power Plant / Generator (under development)
Methodology is consistent with NERC BAL-003-1
Adding capabilities to generate compliance reports
An interconnection frequency response baseline is developed from 2008 to today

12. Database of Events
Add / View / Edit Events
Performance Baseline

13. NERC-BAL-003-1 Reliability Standard
FERC Approved BAL Frequency Response and Frequency Bias Setting, effective April 1, 2015
BAL requires no UFLS for “design” event:
“Design Event” is 2 Palo Verde
WECC Coordinated UFLS starts at 59.5 Hz
Western Interconnection iFRO is about 950 MW per 0.1 Hz
Recalculated annually
Frequency Response Measure (FRM), measured at Point B

14. NERC-BAL-003-1 Reliability StandardFA FB FC
FA = pre-disturbance frequency (average from -16 to 0 sec)
FB = settling frequency (average from 20 to 52 sec)
FC = minimum (nadir) frequency

15. Western Interconnection Performance

16. NERC-BAL-003-1 Reliability Standard
iFRO is prorated among Balancing Authorities based on annual generation and served load energy
Annual median BA FRM needs to exceed BA FRO

17. BA Frequency Response CalculationFA FB FC
Pint_B
Pint_A
FRM = (Pint_B – Pint_A + BA Gen Loss) / ( FA – FB)

18. Balancing Authority Performance
Interchange response is measured for compliance with NERC BAL-003-1
Generation response is calculated to determine how much frequency response to acquire

19. NERC-BAL-003-1 Reliability Standard
BAL applies to Balancing Authorities
BAs need to acquire frequency response
FERC held a conference on frequency response acquisition in April 2014
Formation of Reserve Sharing Groups is allowed
Trading of FRO is not supported by NERC Staff
Transmission reservations and impact on SOLs ?

20. May 16, 2014 RAS Event

21. May 16, 2014 AC RAS Event Frequency NW RAS = 2,563 MW
59.7
59.75
59.8
59.85
59.9
59.95 60
60.05
23:18:00
23:18:15
23:18:30
23:18:45
23:19:00
23:19:15
23:19:30
23:19:45
23:20:00
23:20:15
23:20:30
23:20:45
Frequency
NW RAS = 2,563 MW
Kemano = 110 MW
Springerville = 445 MW
John Day – Grizzly #1
back in service

22. May 16, 2014 Sequence of Events Prior to event: 23:18:15:
John Day-Grizzly #2 and Grizzly-Malin #2 500-kV lines were out of service
23:18:15:
John Day-Grillzy #1 500-kV lines tripped to lock-out
AC RAS gen.drop is initiated of about 2,500 MW at Grand Coulee, Wells, John Day, Biglow Canyon Wind and Dooley Wind
Chief Joseph braking resistor is operated
Few seconds later:
Kemano RAS in BC operated on power swing and tripped unit # 1 with 110 MW
40 seconds later:
Springerville unit#4 in Arizona tripped with ~425 MW due to boiler instability
23:20:30:
John Day-Grizzly #1 500-kV line is restored back to service

23. Model Validation Studies
Validation Base Case Development
WECC Planning base case is modified to match system conditions
Generation MWs and statuses are taken from Peak RC WSM
Area loads are adjusted to match major paths flows
Wind generation
May 16 event had significant amount of wind generation
EMS wind generation models are inadequate for most of WECC system
Many wind generators in California have no dynamic models
Sequence of events is simulated in GE PSLF
WISP data from BPA, SCE, LADWP and SRP is used

24. Model Validation Studies
Remarkable agreement of frequency response

25. Chief Joseph Brake Chief Joseph brake operated as designed
In May 16 event, Chief Joseph brake had little impact on COI stability
However, the brake operation aggravated the Kemano power swing
There were no dynamic models for Chief Joseph brake – BPA developed one since, will be seeking approval at next MVWG
BPA Planning to initiate review of security of Chief Joseph brake control algorithm

26. Kemano RAS There is no dynamic model for Kemano RAS
Kemano owners to provide dynamic RAS models
There is no visibility of Kemano dynamic performance
Kemano owners to install and network PMUs at Kemano and Kittimat
Kemano owners to review the security of RAS algorithm

27. Springerville
Springerville unit #4 tripped due to boiler instability, although the frequency was well within PRC-024 Reliability Standards
Springerville would have tripped for 2 Palo Verde outage
2PV+Springerille would aggravate the COI voltages and power pick-up
Springerville owners are looking into solutions

28. May 26, 2014 RAS Event

29. May 26, 2014 RAS Event
PDCI Converter 1 failure triggered PDCI RAS gen.drop of 2,806 MW
Frequency drop to Hz, well above UFLS levels of 59.5 Hz

30. Baselining Frequency Deviations PDCI RAS Events