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