WECC Joint Synchronized Information Subcommittee - Dmitry Kosterev

WECC Joint Synchronized Information SubcommitteeReport to WECC PCC and OCOctober 2014

Presented by Dmitry Kosterev1Western Interconnection Synchrophasor Program (WISP)Phase 1 WISP - $108M investment completedWECC 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,IPCDOE $2.9M are awarded to PG&E with the recipient cost-share of additional $3.9M

2WECC JSIS StructureData Delivery and Management

Engineering Analysis Applications

Control Room Applications3Data Delivery and ManagementDates:8/25/2014 -8/31/2014EntityPercent AvailabilityPMU CountAESO94.09%17APS94.99%17BCHA81.76%11BPA99.86%55IPCO83.13%20LDWP99.58%15NVE69.14%6NWE62.91%3PAC73.19%4PGAE0.00%2PNM75.86%6SCE38.07%7SDGE99.86%4SRP99.89%1TEPC100.00%2TSGT98.45%2WAPA99.81%5Overall:90.13%1774Data Delivery and ManagementWISP 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 calibration5Engineering AnalysisOscillation Analysis

Power Plant Model Validation

Frequency Response Analysis

System Model Validation6Oscillation AnalysisA paper is completed on modes of inter-area oscillations in the WestPDCI probing tests and brake tests:2013 report is completed2014 tests are done, report is under developmentAnalysis applicationsProny Robot is developed to calculate and tabulate oscillation frequency, damping and shape for 1,000s of simulation runsApplications for ambient data analysis are available, training required

7Oscillation Detection8

Oscillation Detection Application scans power and voltage at interties, power plants, PDCI, SVCs for growing or sustained high energy oscillationsEvents 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)Oscillation Detection9

BEFOREAFTER

Power Plant Model ValidationPPMV 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

10Frequency Response Analysis ToolFrequency Response Analysis Tool (FRAT) works atInterconnection (done)Balancing Authority (done)Power Plant / Generator (under development)Methodology is consistent with NERC BAL-003-1Adding capabilities to generate compliance reportsAn interconnection frequency response baseline is developed from 2008 to today

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Database of EventsAdd / View / Edit EventsPerformance Baseline12NERC-BAL-003-1 Reliability StandardFERC Approved BAL-003-1 Frequency Response and Frequency Bias Setting, effective April 1, 2015BAL-003-1 requires no UFLS for design event:Design Event is 2 Palo VerdeWECC Coordinated UFLS starts at 59.5 HzWestern Interconnection iFRO is about 950 MW per 0.1 HzRecalculated annuallyFrequency Response Measure (FRM), measured at Point B

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NERC-BAL-003-1 Reliability StandardFBFAFCFA = pre-disturbance frequency (average from -16 to 0 sec)FB = settling frequency (average from 20 to 52 sec)FC = minimum (nadir) frequency 14Western Interconnection Performance

15NERC-BAL-003-1 Reliability StandardiFRO is prorated among Balancing Authorities based on annual generation and served load energyAnnual median BA FRM needs to exceed BA FRO16BA Frequency Response Calculation

FAFCFBPint_APint_BFRM = (Pint_B Pint_A + BA Gen Loss) / ( FA FB)17

Balancing Authority PerformanceInterchange response is measured for compliance with NERC BAL-003-1Generation response is calculated to determine how much frequency response to acquire18NERC-BAL-003-1 Reliability StandardBAL-003-1 applies to Balancing AuthoritiesBAs need to acquire frequency responseFERC held a conference on frequency response acquisition in April 2014Formation of Reserve Sharing Groups is allowedTrading of FRO is not supported by NERC Staff

Transmission reservations and impact on SOLs ?19May 16, 2014 RAS Event20May 16, 2014 AC RAS Event2159.759.7559.859.8559.959.956060.0523:18:0023:18:1523:18:3023:18:4523:19:0023:19:1523:19:3023:19:4523:20:0023:20:1523:20:3023:20:45Frequency NW RAS = 2,563 MW Kemano = 110 MWSpringerville = 445 MWJohn Day Grizzly #1back in service May 16, 2014 Sequence of EventsPrior to event:John Day-Grizzly #2 and Grizzly-Malin #2 500-kV lines were out of service23:18:15:John Day-Grillzy #1 500-kV lines tripped to lock-outAC RAS gen.drop is initiated of about 2,500 MW at Grand Coulee, Wells, John Day, Biglow Canyon Wind and Dooley WindChief Joseph braking resistor is operatedFew seconds later:Kemano RAS in BC operated on power swing and tripped unit # 1 with 110 MW40 seconds later:Springerville unit#4 in Arizona tripped with ~425 MW due to boiler instability23:20:30:John Day-Grizzly #1 500-kV line is restored back to service

22Model Validation StudiesValidation Base Case DevelopmentWECC Planning base case is modified to match system conditionsGeneration MWs and statuses are taken from Peak RC WSMArea loads are adjusted to match major paths flowsWind generationMay 16 event had significant amount of wind generation EMS wind generation models are inadequate for most of WECC systemMany wind generators in California have no dynamic modelsSequence of events is simulated in GE PSLFWISP data from BPA, SCE, LADWP and SRP is used

23Model Validation Studies

Remarkable agreement of frequency response24Chief Joseph BrakeChief Joseph brake operated as designedIn May 16 event, Chief Joseph brake had little impact on COI stabilityHowever, the brake operation aggravated the Kemano power swingThere were no dynamic models for Chief Joseph brake BPA developed one since, will be seeking approval at next MVWGBPA Planning to initiate review of security of Chief Joseph brake control algorithm25

25Kemano RAS

There is no dynamic model for Kemano RASKemano owners to provide dynamic RAS models

There is no visibility of Kemano dynamic performanceKemano owners to install and network PMUs at Kemano and Kittimat

Kemano owners to review the security of RAS algorithm26SpringervilleSpringerville 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

27May 26, 2014 RAS Event28May 26, 2014 RAS Event29

PDCI Converter 1 failure triggered PDCI RAS gen.drop of 2,806 MWFrequency drop to 59.66 Hz, well above UFLS levels of 59.5 Hz Baselining Frequency Deviations PDCI RAS Events30