WECC Joint Synchronized
Information Subcommittee
Report to WECC PCC and OC
October 2014
Presented by Dmitry Kosterev
1
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
2
WECC JSIS Structure
• Data Delivery and Management
• Engineering Analysis Applications
• Control Room Applications
3
Data Delivery and Management
Dates:
Entity
AESO
APS
BCHA
BPA
IPCO
LDWP
NVE
NWE
PAC
PGAE
PNM
SCE
SDGE
SRP
TEPC
TSGT
WAPA
Overall:
8/25/2014 -8/31/2014
Percent Availability
PMU Count
94.09%
94.99%
81.76%
99.86%
83.13%
99.58%
69.14%
62.91%
73.19%
0.00%
75.86%
38.07%
99.86%
99.89%
100.00%
98.45%
99.81%
17
17
11
55
20
15
6
3
4
2
6
7
4
1
2
2
5
90.13%
177
4
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
5
Engineering Analysis
• Oscillation Analysis
• Power Plant Model Validation
• Frequency Response Analysis
• System Model Validation
6
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
7
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)
8
Oscillation Detection
FREQUENCY
60.05
1/30/2014 9:21:56 AM
FREQUENCY
JOHN DAY VOLTAGE
1/30/2014 9:21:56 AM
VOLTAGE
239,500
60.03
239,000
60.02
60.01
238,500
60
59.99
238,000
59.98
59.97
237,500
59.95
237,000
5:30
6:00
6:30
8:00
JOHN DAY - BIGLOW MW
9:00
5:30
1/30/2014 9:21:56 AM
ACTIVE POWER
-240
8:30
6:00
6:30
8:00
JOHN DAY - BIGLOW MVAR
8:30
9:00
1/30/2014 9:21:56 AM
REACTIVE POWER
80
70
-280
BEFORE
60
-300
50
-320
40
-340
30
-360
20
-400
10
5:30
6:00
6:30
FREQUENCY
FREQUENCY
60.05
8:00
8:30
9:00
5:30
4/15/2014 4:14:59 PM
6:00
6:30
JOHN DAY VOLTAGE
VOLTAGE
8:00
8:30
9:00
4/15/2014 4:14:59 PM
242,000
241,000
60.03
60.02
240,000
60.01
60
239,000
59.99
238,000
59.98
59.97
237,000
59.95
236,000
17:00
JOHN DAY - BIGLOW MW
ACTIVE POWER
16:00
4/15/2014 4:14:59 PM
17:00
JOHN DAY - BIGLOW MVAR
REACTIVE POWER
-50
60
-150
40
-200
30
-250
20
-300
10
-350
0
-450
16:00
4/15/2014 4:14:59 PM
9
-20
17:00
16:00
17:00
AFTER
16:00
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
10
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
11
Database of Events
Add / View / Edit Events
Performance Baseline
12
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
13
NERC-BAL-003-1 Reliability Standard
WECC Frequency
60.04
FA
60
59.96
FB
59.92
59.88
59.84
59.8
-20
-10
0
10
FC
20
30
40
50
60
FA = pre-disturbance frequency (average from -16 to 0 sec)
FB = settling frequency (average from 20 to 52 sec)
FC = minimum (nadir) frequency
70
80
14
Western Interconnection Performance
15
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
16
BA Frequency Response Calculation
FA
FB
FC
Pint_B
Pint_A
FRM = (Pint_B – Pint_A + BA Gen Loss) / ( FA – FB)
17
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
18
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 ?
19
May 16, 2014 RAS Event
20
May 16, 2014 AC RAS Event
Frequency
60.05
60
NW RAS = 2,563 MW
John Day – Grizzly #1
back in service
59.95
Kemano = 110 MW
59.9
59.85
Springerville = 445 MW
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
21
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
22
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
23
Model Validation Studies
Malin Frequency
Grand Coulee Frequency
60.1
60.1
Actual
Simulated
60.05
60
Frequency (Hz)
Frequency (Hz)
60
59.95
59.9
59.85
59.95
59.9
59.85
59.8
59.8
59.75
59.75
59.7
Actual
Simulated
60.05
0
10
20
30
40
Time (sec)
50
60
70
59.7
80
0
10
20
Custer Frequency
50
60
70
80
60.1
Actual
Simulated
60.05
Actual
Simulated
60.05
60
Frequency (Hz)
60
Frequency (Hz)
40
Time (sec)
Sylmar Frequency
60.1
59.95
59.9
59.85
59.95
59.9
59.85
59.8
59.8
59.75
59.75
59.7
30
0
10
20
30
40
Time (sec)
50
60
70
80
59.7
0
10
20
30
40
Time (sec)
50
Remarkable agreement of frequency response
60
70
80
24
Chief Joseph Brake
MIN-287-kV Voltage
Voltage (kV)
1.05
1
0.95
0.9
Original
No brake
0.85
5
10
15
Time (sec)
20
25
KIT-MIN Power Flow
600
550
500
Power (MW)
• 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
1.1
450
400
350
300
Original
No brake
250
200
5
10
15
Time (sec)
20
25
25
Kemano RAS
• There is no dynamic model
for Kemano RAS
500
Power (MW)
– Kemano owners to provide
dynamic RAS models
KIT-MIN Power Flow
600
400
300
200
• There is no visibility of
Kemano dynamic
performance
100
0
10
20
30
40
Time (sec)
50
60
70
80
MIN287 Voltage
1.1
1.05
Voltage (kV)
– Kemano owners to install and
network PMUs at Kemano
and Kittimat
KMO RAS Operates
KMO RAS Does Not Operate
1
0.95
0.9
• Kemano owners to review
the security of RAS algorithm
KMO RAS Operates
KMO RAS Does Not Operate
0.85
0
10
20
30
40
Time (sec)
50
60
70
80
26
Springerville
Frequency (Hz)
• Springerville unit #4 tripped
due to boiler instability,
although the frequency was
well within PRC-024
Reliability Standards
System Frequency
60
59.9
59.8
59.7
59.6
2PV
2PV+Springerville
0
10
20
30
40
50
Time (sec)
Malin 500-kV Bus Voltage
60
70
80
• Springerville would have
tripped for 2 Palo Verde
outage
Voltage (kV)
560
540
520
500
480
• Springerville owners are
looking into solutions
0
10
20
30
40
Time (sec)
COI Power
50
60
70
80
5000
Power (MW)
• 2PV+Springerille would
aggravate the COI voltages
and power pick-up
2PV
2PV+Springerville
4500
4000
3500
3000
2PV
2PV+Springerville
0
10
20
30
40
Time (sec)
50
60
70
80
27
May 26, 2014 RAS Event
28
May 26, 2014 RAS Event
PDCI Converter 1 failure triggered PDCI RAS gen.drop of 2,806 MW
Frequency - 05-26-2014
60.05
60
59.95
59.9
59.85
59.8
59.75
59.7
59.65
59.6
17:31:00
17:31:30
17:32:00
17:32:30
17:33:00
17:33:30
17:34:00
17:34:30
17:35:00
17:35:30
Frequency drop to 59.66 Hz, well above UFLS levels of 59.5 Hz
29
Baselining Frequency Deviations PDCI RAS Events
0.1
0
-0.1
-0.2
-0.3
-0.4
-0.5
-10
0
10
20
30
40
50
May 26 2014, 2806 MW
May 30 2013, 2895 MW
May 29 2008, 2888 MW
May 20 2008, 2805 MW
60
30