BAL-001-TRE-1 Primary Frequency Response Texas RE Board

Report
BAL-001-TRE-1
Primary Frequency Response
Update for Texas RE RSC
January 9, 2013
SAR-003 Standard Drafting Team
Name
Company
Sydney Niemeyer (Chair)
NRG Energy
Ananth Palani (Vice-Chair)
Optim Energy
Pamela Zdenek
Infigen Energy
Vann Weldon
ERCOT
Brenda Hampton
Luminant
Sandip Sharma
ERCOT (Non-voting SME)
2
BAL-001-TRE-1 RSC
January 9, 2013
Submittal for RSC Approval
● Drafting Team has finished the standard and
related documents.
 Each active team member approved all documents.
● Request RSC to approve standard for Posting,
Review and Balloting.
3
BAL-001-TRE-1 RSC
January 9, 2013
Requirements Overview
● Applies to BA, GO and GOP function
● Provides requirements for:
 Identifying Frequency Measureable Events (FME)
 Calculating the Primary Frequency Response (PFR) of each resource
in the Region
 Calculating the Interconnection minimum Frequency Response
 Monitoring the actual Frequency Response of the Interconnection
 Setting Governor deadband and droop parameters
 Providing Primary Frequency Response performance requirements.
● Importantly, the standard narrows the governor deadband and
requires the droop curve to begin at the edge of the deadband with
no step function.
4
BAL-001-TRE-1 RSC
January 9, 2013
Generator PFR Performance Measures
● Under this standard, two Primary Frequency Response
performance measures are calculated: “initial” and “sustained.”
 The initial PFR performance (R9) measures the actual response
compared to the expected response in the period from 20 to 52 seconds
after an FME starts.
 The sustained PFR performance (R10) measures the best actual
response from t(46) to t(60), compared to the expected response at t(46).
5
BAL-001-TRE-1 RSC
January 9, 2013
Increased Maintenance & Operating Costs?
● Generator Owners had concerns with smaller
dead-bands increasing costs.
● Data from before dead-band and droop curve
implementation compared to latest data
indicates a significant cost savings.
● Significant increase in grid reliability.
6
BAL-001-TRE-1 RSC
January 9, 2013
ERCOT Frequency Profile from 2008
ERCOT Frequency Profile Comparison
439,200 One Minute Periods in the Ten Months of Data January through October
45000
35000
30000
Prior to Nov 2008 nearly all generators
implemented a +/- 0.036 Hz dead-band
governor, many with a step-response at the
dead-band. The frequency profile reflected this
dead-band setting.
25000
20000
15000
10000
5000
60
.0
1
60
.0
2
60
.0
3
60
.0
4
60
.0
5
60
.0
6
60
.0
7
60
.0
8
60
.0
9
60
.1
60
0
59
.9
59
.9
1
59
.9
2
59
.9
3
59
.9
4
59
.9
5
59
.9
6
59
.9
7
59
.9
8
59
.9
9
One Minute Occurances
40000
2008
7
BAL-001-TRE-1 RSC
January 9, 2013
ERCOT Frequency Profile from 2012
ERCOT Frequency Profile Comparison
439,200 One Minute Periods in the Ten Months of Data January through October
45000
35000
30000
By the end of October 2012
more than 20% of ERCOT
generators had implemented
the smaller +/- 0.017 Hz deadband.
25000
20000
15000
10000
5000
60
60
.0
1
60
.0
2
60
.0
3
60
.0
4
60
.0
5
60
.0
6
60
.0
7
60
.0
8
60
.0
9
60
.1
0
59
.9
59
.9
1
59
.9
2
59
.9
3
59
.9
4
59
.9
5
59
.9
6
59
.9
7
59
.9
8
59
.9
9
One Minute Occurances
40000
2012
8
BAL-001-TRE-1 RSC
January 9, 2013
How Does This Impact Generator Movement?
Jan thru Oct 2008 and 2012
MW Movement of a Typical 600 MW Generator Exposed to ERCOT Frequency during Time Period
Due to Primary Frequency Response Only
160000
38.34% Decrease in MW
364610.0 MW Response of 0.0166 db
movement with
140000
lower deadband.
591324.0 MW Response of 0.036 db
120000
80000
60000
40000
20000
60
60
.0
60 1
.0
2
60
.0
60 3
.0
4
60
.0
60 5
.0
6
60
.0
60 7
.0
8
60
.0
9
60
.1
0
59
.
59 9
.9
1
59
.9
59 2
.9
3
59
.9
59 4
.9
5
59
.9
59 6
.9
7
59
.9
59 8
.9
9
MW
100000
With the lower dead-band setting a similar
size generator saw a 38% decrease in
movement between 2008 and 2012.
2008 MW Response of 0.036 db
9
2012 MW Response of 0.0166 db
BAL-001-TRE-1 RSC
January 9, 2013
Not All Improvement Due to Dead-Band & Droop
● Approximately 20% of ERCOT Generators now
meet R6 of this Standard.
● Other Changes Impacted Frequency Control
 Change in Market from Zonal to Nodal Dispatch.
 Many generators previously not providing PFR
correctly are now working correctly but at the larger
dead-band.
 Wind Generators are now required to have PFR
and governors in service.
● However, only the decrease in the dead-band
can significantly improve the frequency profile
inside the +/-0.036 Hz deviation range.
10
BAL-001-TRE-1 RSC
January 9, 2013
140
140
130
130
120
120
110
110
100
100
CPS1 Average
Impact on ERCOT CPS1 Performance
2
v- 12
Nop- 1
Sel-12
Ju y-122
Mar- 1
Man-12
Ja v- 111
Nop- 1
Sel-11
Ju y-111
Mar- 1
Man-11
Ja v- 100
Nop- 1
Sel-100
Ju y-1
Mar- 10
Man-10
Ja v- 099
Nop- 0
Sel-09
Ju y-09
Mar- 09
Man-09
Ja v- 088
Nop- 0
Sel-08
Ju y-088
Mar- 0
Man-08
Ja v- 077
Nop- 0
Sel-077
Ju y-0
Mar- 07
Man-07
Ja v- 066
Nop- 0
Sel-066
Ju y-0
Mar- 06
Man-06
Ja v- 05
5
Nop- 0
Sel-05
Ju y-05
Mar- 05
Man-05
Ja v- 044
Nop- 0
Sel-04
Ju y-044
Mar- 0
Man-04
Ja v- 033
Nop- 0
Sel-033
Ju y-0
Ma
12 Month Rolling Average
Monthly Average
BAL-001-TRE-1 RSC
January 9, 2013
11
170
170
Oct 2008 12 month
avg. CPS1 = 122.03
Oct 2012 12 month
avg. CPS1 = 160.17
ERCOT CPS1
160
160
150
150
With All the Improvement Why BAL-001-TRE
● Fair and accurate measure of PFR.




12 month rolling average or minimum 8 event avg.
Allows for event exclusion due to equipment limits.
Accounts for generator ramping before the event.
Adjusts expected performance due to known
generator delivery limitations.
 Accounts for non-frequency responsive capacity
like duct burner operation and other augmentation.
● Equal expectations for all generators.
 Wider dead-band governors benefiting from
generators with smaller dead-band.
 With the standard all generators will move less and
operate closer to their economic target.
12
BAL-001-TRE-1 RSC
January 9, 2013
Field Trial Results
● 28 generating units were evaluated in the trial,
which included 7 coal, 4 gas, 2 simple cycle
combustion turbine, 5 wind, and 10 combined
cycle units.
● Based on 35 events from June 2011 to June
2012.
● No high-frequency events were evaluated.
● 8-event average was not possible with some
units.
● These results use NEW R10 calculation.
13
BAL-001-TRE-1 RSC
January 9, 2013
Field Trial Results – Coal Units
Coal Plant
R9
R10
Generator 1
Generator 2
0.5841
0.4643
0.6460
0.3706
Generator 3
Generator 4
Generator 5
1.1892
0.8872
0.2530
1.2609
0.9909
0.4113
Generator 6
Generator 7
0.6092
1.1987
0.8444
1.3827
14
Comments
Participation in less than 8
events
Participation in less than 8
events
BAL-001-TRE-1 RSC
January 9, 2013
Field Trial – Gas Units
Gas Plant
R9
R10
Generator 1
Generator 2
Generator 3
0.7712
0.4716
1.3608
1.1068
0.7218
1.3778
Generator 4
1.3415
1.7862
Simple cycle combustion turbine
R9
R10
Generator 1
0.1001
0.0178
Generator 2
0.7409
0.8621
15
Comments
huge data latency
Participation in less than 8
events
Participation in less than 8
events
Comments
Participation in less than 8
events
BAL-001-TRE-1 RSC
January 9, 2013
Field Trial – Wind Units
Wind Generation
R9
R10
Generator 1
1.3824
1.3737
Generator 2
Generator 3
Generator 4
No Evaluation
No Evaluation
0.6259
Generator 5
0.8189
Comments
Participation in less than 8
events
No Evaluation No Participation
No Evaluation No Participation
1.0435
Participation in less than 8
events
0.7211
Participation in less than 8
events
16
BAL-001-TRE-1 RSC
January 9, 2013
Field Trial – Combined Cycle Units
Combined Cycle
R9
R10
Generator 1
Generator 2
0.2712
1.5976
0.2360
1.7676
Generator 3
Generator 4
Generator 5
Generator 6
Generator 7
Generator 8
Generator 9
Generator 10
0.7664
0.5668
0.9181
1.1232
0.6946
0.5710
0.3705
0.7794
0.7863
0.6246
1.2397
1.4586
0.9575
0.8235
0.7409
1.1074
17
Comments
Participation in less than 8
events
BAL-001-TRE-1 RSC
January 9, 2013
Changes Made after Field Trial and Comments
● Changed Sustained Measure (R10) from average
over several minutes to instantaneous at t(46).
 Too much happens during former averaging window.
● Added 5 MW limit to the 2% exception criteria.
● Moved examples of “legitimate operating
conditions that may support exclusion” from
Measures to Requirements (R9 and R10).
● M7 re-written to focus on notice from GO to GOP
of change in Governor status.
 Avoids concern about 24/7 proof issue.
● Changed deadband setting from 0.01666 to 0.017
Hz.
● Reformatted R2 to break into sub-requirements.
● Added non-frequency responsive augmented
capacity exclusion.
18
BAL-001-TRE-1 RSC
January 9, 2013
Benefits of the Field Trial
● Presentations prepared and delivered to each
participant.
 One presentation for each generator with one
graph for each event evaluated (generator on line
during the event). Potentially 980 graphs total.
Included Performance summary and critique.
● Reviewed performance with each participant
through web conferences.
● Participants became familiar with the
standard, proper PFR expectations and could
easily see shortcomings in performance.
19
BAL-001-TRE-1 RSC
January 9, 2013
Example of New R10 Measure
Thursday, December 15, 2011
Unit:Sample Generator
60.06
Initial P.U. Performance
Sustained P.U. Performance
1.434
610.0
3) Generator performance
is based on “best”
performance between
t(+46) through t(+60).
60.04
60.005
60.02
1.178
60
59.98
600.0
592.65
59.96
590.0
59.94
59.92
Frequency - Hz
59.88
580.0
MW
2) Based on Frequency @
t(+46) expected
performance is calculated.
59.9
59.86
59.84
570.0
59.844
59.82
59.8
59.78
1) Frequency @ t(+46)
sets the expected
performance.
564.70
59.76
59.74
59.72
560.0
550.0
59.7
59.68
59.66
13:15:43
13:15:53
Hz
13:16:03
13:16:13
13:16:23
Average Frequency
13:16:33
MW
13:16:43
13:16:53
Average MW
20
13:17:03
13:17:13
Initial EPFR(Final)
13:17:23
13:17:33
540.0
13:17:43
EPFR([email protected](+46))
BAL-001-TRE-1 RSC
January 9, 2013
Primary Frequency Response Reference
Document
● This Primary Frequency Response Reference
Document is not considered to be a part of the
regional standard.
● This document will be maintained by Texas RE
and will be subject to modification as approved by
the Texas RE Board of Directors, without being
required to go through the formal Standard
Development Process.
 This arrangement provides Regional flexibility in
adjusting the technical details of the performance
metric calculations.
 The PFR Reference Document includes flowcharts
that detail the calculations
21
BAL-001-TRE-1 RSC
January 9, 2013
PFR Reference Document Revision Process
● A Revision Request may be submitted to the
Texas RE Reliability Standards Manager
● The Reliability Standards Committee (RSC) will
consider the request
 The revision request will be posted in accordance with
RSC procedures
 The RSC shall discuss the revision request in a public
meeting, and will accept and consider verbal and written
comments pertaining to the request
 The RSC will make a recommendation to the Texas RE
Board of Directors
● The Board may adopt the revision request, reject
it, or adopt it with modifications
 Any approved revision to the Primary Frequency
Response Reference Document shall be filed with
NERC and FERC for informational purposes
22
BAL-001-TRE-1 RSC
January 9, 2013
Implementation Plan
● 12 months after Effective Date
 The BA must be compliant with Requirement R1
 At least 50% of the GO’s generating units/generating facilities must
be compliant with Requirement R6 (if >1 unit/facility)
 At least 50% of the GO’s generating units/generating facilities must
be compliant with Requirement R7 (if >1 unit/facility)
 The GOP must be compliant with Requirement R8
● 18 months after Effective Date
 The BA must be compliant with Requirements R2, R3, R4, and R5
 100% of the GO’s generating units/generating facilities must be
compliant with Requirement R6
 100% of the GO’s generating units/generating facilities must be
compliant with Requirement R7
23
BAL-001-TRE-1 RSC January 9,
2013
Implementation Plan
● 24 months after Effective Date
 At least 50% of the GO’s generating units/generating facilities must
be compliant with Requirement R9 (if >1 unit/facility)
 At least 50% of the GO’s generating units/generating facilities must
be compliant with Requirement R10 (if >1 unit/facility)
● 30 months after Effective Date
 100% of the GO’s generating units/generating facilities must be
compliant with Requirement R9
 100% of the GO’s generating units/generating facilities must be
compliant with Requirement R10
24
BAL-001-TRE-1 RSC January 9,
2013

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