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Generator Frequency ResponseGenerator Frequency Response
Jessica Bian
North American Electric ReliabilityCorporation
May 5, 2009
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TodayTodays Sessions Session
Topic
Frequency response basics, trends, standards underdevelopment and next steps
Purpose
Engaged industry experts to share existing data inorder to raise awareness of this important issue
Goals Seeking to collect and analyze data to better
understand this emerging issue
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SpeakersSpeakers
Terry Bilke, Director, Standards & Compliance
Midwest ISO Bill Herbsleb, Senior Engineer
PJM
Sydney Niemeyer, Control Systems SpecialistNRG Texas
Raymond Vice, Consulting EngineerSouthern Company
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About NERC: MissionAbout NERC: Mission
Develop & enforce reliability standards
Assess current and future reliability
Analyze system events & recommend improved
practices
Encourage active participation by all stakeholders
Pursue mandatory standards across North America
To ensure the reliability of the North American
bulk power system
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NERC WebinarFrequency Response
May 5, 2009
Terry Bilke Midwest ISO Bill Herbsleb PJM
Sydney Niemeyer - NRG Raymond Vice - SOCO
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Agenda
Frequency Response Overview
Frequency Response Standard
Generator Response Discussion
Recommendations
Questions and Answers
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Frequency Response Basics
Frequency Response, termed beta (), isa fundamental reliability service
a combination of governor and load responseInversely related to frequency excursions
Frequency Response is decliningShould be increasing with load & generation
growth
Part of the decrease may be better measurement Performance-based standards quite possibly
on the horizon (FERC Order No. 693)
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Primary
Control
(Frequency Response)
Secondary
Control(AGC)
TertiaryControl
(Reserve Deployment)
TimeControl
Spinning Reserves
Seconds
Minutes
Hours
Non-Spinning Reserves
Other Reserves
Control Continuum
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59.9
59.92
59.94
59.96
59.98
60
60.02
0 6 12 18 24 30 36 42 48 54 60
Typical Frequency Event WECC
Avera e of 5 events T-5 to T+60
Seconds
Typical WECC
Frequency Excursion
Point C
Point A
Point B
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59.8
59.85
59.9
59.95
60
0 6 12 18 24 30 36 42 48 54 60
Typical Frequency Event - ERCOT
(Average of 7 events, T-5 to T+60)
Seconds
Typical ERCOT
Frequency Excursion
Point A
Point B
Int= MW/(10* f)BA = NiA/(10* f)Gen = MW/(10* f)
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59.94
59.95
59.96
59.97
59.98
59.99
60
60.01
60.02
0 6 12 18 24 30 36 42 48 54 60
Typical Eastern Interconnection Excursion
(T-5 to T+60)Typical Eastern Interconnection
Frequency Excursion
Seconds
No Point C to Point B Recovery
Response Withdrawal
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Frequency Response Trends
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Eastern Interconnection
Frequency Response (Then)
* Ingleson and Nagle StudyDecline of 72MW/0.1Hz/year
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Easter Interconnection B eta
2500
2600
2700
2800
2900
3000
3100
3200
3300
3400
3500
2000 2001 2002 2003 2004 2005 2006
MW/0
.1Hz
Mean Median
Recent Frequency Response
* Ingleson and Ellis/NERC Resources Subcommittee/Virginia Tech
2007-2008 Response = -2550MW/0.1Hz
*
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Short-TermFrequency Excursions
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Jan2002
Apr2002
Jul2002
Oct2002
Jan2003
Apr2003
Jul2003
Oct2003
Jan2004
Apr2004
Jul2004
Oct2004
Jan2005
Apr2005
Jul2005
Oct2005
Jan2006
Apr2006
Jul2006
Oct2006
Jan2007
Apr2007
Jul2007
Oct2007
0 - 1
2 - 3
4 - 5
6 - 7
8 - 9
10 - 11
12 - 13
14 - 15
16 - 17
18 - 19
20 - 21
22 - 23
COUNT OF FREQUENCY DISTURBANCES > 28 mHz
BY MONTH, BY HOUR OF DAY
0-4 4-8 8-12 12-16 16-20 20-24 24-28 28-32 32-36
Eastern Interconnection
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Month vs Weekday
1 Min Frequency Difference > 28 mHz
0
20
40
60
80
100
120
140
160
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
COUNT
OFEVENTS
1 Sun 2 Mon 3 Tue 4 Wed 5 Thu 6 Fri 7 Sat
Eastern Interconnection
More generators,yet fewer excursions(more load and governor response)
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Small Excursions (>28mHz)
Follows a seasonal pattern, # are increasing
28mHz represented loss of about 1000MW in 1994 Change believed to be primarily due to decline in
frequency response (70 MW/0.1Hz /year since 94)
Pumped storage and interchange schedule changesnow causing excursions of this size
Small excursions are a symptom, not necessarily aproblem themselves
Patterns give a clue to sampling techniques neededto objectively calculate Balancing Authority andGenerator Frequency Response
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Frequency Response Standard
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Frequency Response Standard
Development Purpose/Need
Frequency Response is a fundamental component
to the reliable operation of the bulk power system,particularly during disturbances and restoration
Put in place an objective methodology to measure
response at the BA and Interconnection Evidence of a continued decline in when it shouldbe increasing Enable proper modeling and analysis and facilitate aperformance based standard as the need
approaches
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Frequency Response StandardDevelopment Goals
Benchmark and track performance(both Balancing Authority and Interconnection)
Maintain historic levels of reliability
Enable technically sound decisions
Measure performance rather than
mandate reserve set-asides
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Frequency Response StandardDevelopment Goals (Continued)
Consistent measurement allows flexibility and
consistency in measure for planning and definingspecific interconnection needs
As limits are approached, enable performance-
based rather than commodity-based standards Allow the Industry and markets to solve and findinnovative solutions which embrace newtechnology solutions rather than specific
methods to mandate how to meet the standard
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Frequency Response Standard
Development Timeline SAR completed in July 2007
Drafting team initiated work on first draft of thestandard in October 2007
First draft data collection letter will be posted for
comment in 30-60 days FERC/NERC staff interested in using NERCs data
collection authority to jump start the measurementprocess
Data collected will be used to drive future standarddevelopment efforts
O th di l ith ti t d t d th
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60.03659.964
Open up the dialog with generation to understand thepotential for better frequency control and reliability
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Generator Response Discussion
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Comparing November 2008 vs March 2008 profile
of frequency in 5 mHz bins
0
0.010.02
0.03
0.04
0.050.06
0.07
0.08
0.09
59.900
59.910
59.920
59.930
59.940
59.950
59.960
59.970
59.980
59.990
60.000
60.010
60.020
60.030
60.040
60.050
60.060
60.070
60.080
60.090
60.100
Nov-08
Mar-08
Recent ERCOT Governor Work
Four Governors Tuned in Oct-Early Nov 2008
Total 2500MW, 4% of Interconnection Peak
Deadband changed to 1RPM, Droop 5%
Improved Frequency and CPS
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Frequency Response
Based On
Droop Setting and Deadband
0.0%
2.0%
4.0%
6.0%
8.0%
10.0%
12.0%
14.0%
16.0%
18.0%
20.0%
59.50 59.55 59.60 59.65 59.70 59.75 59.80 59.85 59.90 59.95 60.00 60.05 60.10 60.15 60.20 60.25 60.30 60.35 60.40 60.45 60.50
Hz
Droop
Droop Setting 5.00% Ideal Performance Droop % Minimum Standard Performance Droop %
Prime Mover Deadband Setting
0.03600 Hz+/-
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0.036 Hz
0.050 Hz0.0166 Hz 0.066 Hz 0.083 Hz 0.100 Hz
2.160 RPM
0.033 Hz
RPM and Hz for 2 pole, 3600 rpm prime mover.
3600 rpm
60.000 Hz59.983 Hz
59.966 Hz 59.950Hz 59.933 Hz 59.917 Hz 59.900Hz
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Frequency Response
Based On
Droop Setting and Deadband
0.0%
2.0%
4.0%
6.0%
8.0%
10.0%
12.0%
14.0%
16.0%
18.0%
20.0%
59.50 59.55 59.60 59.65 59.70 59.75 59.80 59.85 59.90 59.95 60.00 60.05 60.10 60.15 60.20 60.25 60.30 60.35 60.40 60.45 60.50
Hz
Droop
Droop Setting 5.00% Ideal Performance Droop % Minimum Standard Performance Droop %
Prime Mover Deadband Setting
0.01667 Hz+/-
Single Resource BA with 50 MW load
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50 MW
59.9Hz
53.5 MW
3.5 MW/0.1 Hz3.5 MW/0.1 Hz
Single Resource BA with 50 MW load105 MW Capacity, 5% droop, Zero Deadband
Ia-Is
50 MW
ACE
ACE = (Ia-Is) [(Fa-Fs)*10*-3.5] note -3.5 = -3.5 MW/0.1 Hz BA Bias (beta)0 = (3.5-0) [(59.9-60.00)*10*-3.5]0 = (0-0)
[(60.00-60.00)*10*-3.5]
0 = (3.5-0) [(-0.1)*10*-3.5]0 = (3.5) [3.5]
-3.5 = (0) [3.5]
+3.5 MW
BA EMS LFC& EconomicDispatch
BA EMS UnitAGC Control
GO/GOPBA
If frequency response of Resource is not sustainedAGC will attempt to redeploy the expected frequency
response calculated in the Bias obligation.The frequency response should be withdrawnproportional to the frequency recovery.
50 MW
3.5 MW/0.1 Hz
Wednesday March 18 2009P U Performance 0 908 572 MW Steam Turbine Coal Fired
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5% Droop Setting with +/-0.0166 Hz deadband
59.75
59.80
59.85
59.90
59.95
60.00
60.05
7:12:58 7:13:08 7:13:18 7:13:28 7:13:38 7:13:48 7:13:58 7:14:08 7:14:18 7:14:28 7:14:38 7:14:48 7:14:58
Hz
395.0
401.0
407.0
413.0
419.0
425.0
431.0
MW
HZ Average Frequency MW Average MW Standard Minimum Performance MW change
Wednesday, March 18, 2009P.U. Performance 0.908
30.98
25.69
19.27
23.32
Ideal MW change based on droop setting and deadband
Ideal MW change Adjusted for db and limiting factor
Standard Minimum Performance MW
MW Change
-0.1766 HZ Change
7.32% Actual Droop
8.86% Standard Minimum Performance Droop
6.64% Ideal Droop Adjusted for db and limiting factor
5.51% Ideal Droop based on droop setting and deadband
Spinning 170.93
572 MW Steam Turbine Coal Fired
13.20 MW/0.1 Hz Actual Frequency Response Contribution
Attainable FrequencyResponse is calculated fromdroop setting, deadband andavailable stored energy intime frame of the measure.Minimum performance levelis 75% of this value.
Equivalent droop values.
Event Performance Level.90.8% or 0.908 per unit.
Same event as previous slide.60 minutes of evaluation 5
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350
358
366
374
382
390
398
406
414
422
430
438
446
454
462
470
7:00 7:05 7:10 7:15 7:20 7:25 7:30 7:35 7:40 7:45 7:50 7:55 8:00
59.80
59.82
59.84
59.86
59.88
59.90
59.92
59.94
59.96
59.98
60.00
60.02
60.04
60.06
60.08
60.10
Target Net MW HSL HZ
March 18, 2009
Black Trend is 5% droopplus AGC control to the
unit = TARGET.
60 minutes of evaluation. 5minutes per vertical grid line.
Frequency Response to smallchanges in frequency are also
important for grid stability.
Green Trend is actualMW output of unit.
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Recommendations
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Recommendations/Actions
BAs and Generators use data historians to
automate generator and Balancing Authorityresponse calculationsIdentify generators with low (especially +)
frequency responseDo controls withdraw response (setpoint control)?
BA Operators should know governor andprime mover modes on key units and ifalternatives are available (put units in moreresponsive mode when grid is stressed)
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Recommendations (Continued)
Frequency excursions often occur at the top
of the hourBAs should have guidelines for ramps and
acceptable schedule changes
BAs and generators should dispatch pumpedstorage and other quick start/stop units with aneye toward frequency patterns, not just the clock
Comment on standardsFrequency Response
Generator Verification
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More Information
NERC Resources Subcommittee http://www.nerc.com/filez/rs.html Decline of Eastern Interconnection Frequency Response
Frequency Response Standard White Paper
Frequency Response Characteristic Survey Training Document
NERC Frequency Response Standardhttp://www.nerc.com/filez/standards/Frequency_Response.html
NERC Generator Verification Standardhttp://www.nerc.com/filez/standards/Generator-Verification-Project-2007-09.html
[email protected] (email address for balancing-related questions)
Texas Regional Entity Supporting Documents(Resource frequency response evaluation spreadsheets)http://trackstandard.texasre.org/texasre_rsvp/action/PubMainAction?type=Detail&id=17
http://www.nerc.com/filez/rs.htmlhttp://www.nerc.com/docs/standards/sar/opman_12-13Mar08_FrequencyResponseCharacteristicSurveyTrainingDocument.pdfhttp://www.nerc.com/filez/standards/Frequency_Response.htmlhttp://www.nerc.com/filez/standards/Generator-Verification-Project-2007-09.htmlhttp://www.nerc.com/filez/standards/Generator-Verification-Project-2007-09.htmlmailto:[email protected]://trackstandard.texasre.org/texasre_rsvp/action/PubMainAction?type=Detail&id=17http://trackstandard.texasre.org/texasre_rsvp/action/PubMainAction?type=Detail&id=17mailto:[email protected]://www.nerc.com/filez/standards/Generator-Verification-Project-2007-09.htmlhttp://www.nerc.com/filez/standards/Frequency_Response.htmlhttp://www.nerc.com/docs/standards/sar/opman_12-13Mar08_FrequencyResponseCharacteristicSurveyTrainingDocument.pdfhttp://www.nerc.com/filez/rs.html