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WECC Joint Synchronized Information Subcommittee

WECC Joint Synchronized Information Subcommittee. Report to WECC PCC and OC October 2014 Presented by Dmitry Kosterev. Western Interconnection Synchrophasor Program (WISP). Phase 1 WISP - $108M investment completed WECC JSIS supports reporting to DOE Phase 2 WISP:

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WECC Joint Synchronized Information Subcommittee

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  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

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

  13. NERC-BAL-003-1 Reliability Standard • FERC Approved BAL-003-1 Frequency Response and Frequency Bias Setting, effective April 1, 2015 • BAL-003-1 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 Standard FA 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 Calculation FA 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-003-1 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. Frequency 60.05 NW RAS = 2,563 MW John Day – Grizzly #1 • back in service 60 59.95 Kemano = 110 MW 59.9 Springerville = 445 MW 59.85 59.8 59.75 59.7 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 May 16, 2014 AC RAS Event

  22. May 16, 2014 Sequence of Events • Prior to event: • 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 • Kemanoowners 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 59.66 Hz, well above UFLS levels of 59.5 Hz

  30. Baselining Frequency Deviations PDCI RAS Events

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