PDCWGReport to ROS

David Kee Chair

CPS Energy

Sydney Niemeyer Vice Chair

NRG Energy

May Meetings• Met May 29 & 30, 2013

– May 29 – Joint & open meeting with QMWG re NPRR 524 & 527

– May 30 – Regular closed meeting. 28 members representing 16 companies as well as ERCOT & TRE.

• System oscillations• SCR 773 - update• FRRS data review• NPRR 524 - update• NPRR 527 – update• Event reviews• Frequency Control Report May 2013

System Oscillations - update

• Member reported that PSS tuning is working to protect generator

• PSS tuning SME reported that oscillations are still occurring– PSS only fixes symptom, not problem

• PMU data is still desired• Action Requested:

– ERCOT will look back at 2002 study as starting point for dynamic study

– Request RPG be given action to review study and results

SCR 773 - Update

• Early look at the data (five days)

• Some indications that SCR 773 may be successful

• Dataset is too small to draw any conclusions

FRRS update

• ERCOT presented analysis

• PDCWG provided feedback

• Consensus was that the response seems to impact frequency as expected

• No consensus on how to “fit” in current market design

ERCOT methodology for determining FRRS capacity

Questions for PDCWG• Can it be regulation?

– Yes it can, depending on how the Resource allocates its obligation and the performance to the deployments.

– FRRS can qualify for regulation AS and be evaluated by PDCWG via GREDP metric – Example: FRRS Resource with 60MW capacity can serve a 1MW obligation over 60 minutes. – FRRS Resources may want to follow the LFC regulation signal that Generation Resources follow to allow

for pilot to be evaluated for regulation service. Current deployment signal is separate from regulation signal

• Should it be regulation? – Maybe not. The quality of response has a higher quality closer to primary frequency response.– Responsive reserve may be a better fit.

• How does this improve reliability?– Seems to improve frequency decay during frequency event– Frequency nadir is raised.

• How much?– TBD – more of an economic question, QMWG?

• How much regulation can ERCOT stand to be offset by FRRS?– Current participation (33MW up & 33MW down) levels are expected to be acceptable– Maximum amount provided should not exceed “ 65MW up & 35MW down”– Not a 1:1 equivalence of capacity between conventional generators and FRRS resources

• Proposed Changes to deployment?– Proportional control– Reserve for unit trips as opposed to frequency control

NPRR 524

PDCWG & QMWG

5/29/13

Summary

• NPRR524 considered in joint meeting of PDCWG & QMWG on 5/29/13

• Language and comments were considered

• All issues raised in the group were understood by NPRR author

• Author plans to submit comments to incorporate the changes proposed by this group

Generator Specific Fundamentals

• Allocation & Awards• Currently up to 24% of the HSL can be

awarded RRS• Proposal for the first 20% of the HSL of the

Generation Resource is required to be frequency responsive

• The remaining 4% of the HSL can be carried as non-frequency responsive and must meet any subsequent deployments within 10 minutes

ERCOT Specific Fundamentals

Identified Risks

• Risk of not passing BAL003. If this is the case, ERCOT would reduce maximum percentage of RRS capacity on a single resource from 24% to 20% (or what is deemed appropriate to pass standard)

• No mechanism to allocate RRS to differentiate what capacity is frequency responsive.– NPRR 527

Qualification & Deployment

• 10 minute is a definite requirement for non frequency responsive capacity serving Responsive Reserve

• How will the deployment work? (NPRR 429 problem)– Some technology can provide the power

augmentation via AGC & follow SCED• When changes are made to provide non

frequency responsive capacity to market, RARF is updated to reflect the changes. – Qualification of new capacity may or may not be

required by ERCOT (issue not addressed)

Testing Impact

• Referring to Governor testing and test submissions via NDCRC application– HSL changes may be an issue in the

application

Market Policy

• Separation of services by value– Fast PFR– PFR– REG– RRS – GEN– RRS – LR– RRS – PA

NPRR 527

PDCWG & QMWG 5/29/13

PDCWG 5/30/13

NPRR 527

• Collaborated with QMWG

• Solution was agreed upon

• Currently drafting comment language

• Request to table NPRR527 for 1 month to allow PDCWG time to complete and submit comments. (Vote)

Event Review

• PDCWG Reviewed 3 events– 4/29/13 @13:59 loss of 522MW

• Combined cycles with duct firing capacity did not provide PFR. Regulation was nearly exhausted

– 5/3/13 @04:55 high frequency• Generators in startup or transitions on combined cycles

were noted as main driver based on the given dataset (repeat from last month)

• Seems that the online units are not dispatched down to make room for the generation that is coming online

– 5/22/13 @16:11 loss of 820MW• Combined cycles with duct firing capacity did not

provide PFR.

ERCOT Frequency Control Report

Sydney Niemeyer NRG Energy

June 4, 2013

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167.17ERCOT Monthly CPS1 =

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May-2013

97.38ERCOT Monthly CPS2 =

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ERCOT CPS1 15 Minute Average - Monthly Score

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CPS2

*ERCOT as a single control area is exempt from CPS2. These scores are For Information Only

0.0100

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Daily RMS1 of ERCOT Frequency

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Daily RMS1 of ERCOT Frequency

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Daily RMS1 of ERCOT Frequency

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Comparing May 2010 vs May 2013 profile of frequency in 5 mHz bins

May-10

May-13

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ERCOT Frequency Profile Comparison

2010 2013

January through December of each Year

May Daily Time Error

Change

Data Start 01-MAY-13 00:00:00 Days with01-JUL-13 00:00:00 no TEC Fast

Time Daily Time or SlowError Delta Delta TEC

01-May-13 00:00:00 -29.031 1.513 02-May-13 00:00:00 -27.519 1.513 0.332 03-May-13 00:00:00 -27.187 0.332 0.273 04-May-13 00:00:00 -26.913 0.273 -0.461 05-May-13 00:00:00 -27.374 -0.461 0.403 06-May-13 00:00:00 -26.971 0.403 -0.333 07-May-13 00:00:00 -27.304 -0.333 -0.689 08-May-13 00:00:00 -27.993 -0.689 1.393 09-May-13 00:00:00 -26.600 1.393 1.206 10-May-13 00:00:00 -25.394 1.206 -0.106 11-May-13 00:00:00 -25.500 -0.106 0.378 12-May-13 00:00:00 -25.122 0.378 0.695 13-May-13 00:00:00 -24.427 0.695 -0.307 14-May-13 00:00:00 -24.733 -0.307 -0.320 15-May-13 00:00:00 -25.053 -0.320 -1.594 16-May-13 00:00:00 -26.647 -1.594 -0.968 17-May-13 00:00:00 -27.615 -0.968 -0.784 18-May-13 00:00:00 -28.399 -0.784 -1.093 19-May-13 00:00:00 -29.493 -1.093 TEC Slow20-May-13 00:00:00 -30.041 -0.549 TEC Slow21-May-13 00:00:00 -28.842 1.199 -0.599 22-May-13 00:00:00 -29.441 -0.599 TEC Slow23-May-13 00:00:00 -27.081 2.360 0.841 24-May-13 00:00:00 -26.240 0.841 0.132 25-May-13 00:00:00 -26.109 0.132 -0.108 26-May-13 00:00:00 -26.216 -0.108 0.420 27-May-13 00:00:00 -25.796 0.420 0.388 28-May-13 00:00:00 -25.408 0.388 -0.564 29-May-13 00:00:00 -25.972 -0.564 0.270 30-May-13 00:00:00 -25.702 0.270 -1.403 31-May-13 00:00:00 -27.105 -1.403 -1.403 01-Jun-13 00:00:00 -28.130 -1.403

Seconds 0.901 -0.089Month DailyTotal Average

2012 Jan 31 0 12 12 36.33 3.03 0.39 4.9%Feb 29 0 12 12 34.00 2.83 0.41 4.9%Mar 31 0 15 15 42.50 2.83 0.48 5.7%Apr 30 0 11 11 30.75 2.80 0.37 4.3%May 31 0 11 11 30.50 2.77 0.35 4.1%Jun 30 0 8 8 24.00 3.00 0.27 3.3%Jul 31 0 7 7 20.00 2.86 0.23 2.7%Aug 31 0 7 7 18.00 2.57 0.23 2.4%Sep 30 0 9 9 24.00 2.67 0.30 3.3%Oct 31 0 10 10 28.50 2.85 0.32 3.8%Nov 30 0 1 1 2.50 2.50 0.03 0.3%Dec 31 0 10 10 30.00 3.00 0.32 4.0%

2013 Jan 31 0 3 3 9.50 3.17 0.10 1.3%Feb 28 0 6 6 18.00 3.00 0.21 2.7%Mar 31 0 5 5 17.50 3.50 0.16 2.4%Apr 30 0 1 1 5.50 5.50 0.03 0.8%May 31 0 2 2 8.50 4.25 0.06 1.1%

Time Correction History

Total Hours on Avg Hours Avg Corrections % Time onYear Month Days Fast Slow Count Control Per Correction Per Day Correction

Time Corrections

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Slow Fast

ERCOT Primary Frequency Response – BAL-003-1

2014 Bias and Frequency Response Measure

12/10/2012 12:32:54 CST -0.076 12:32:54 -0.076 -0.076 0.0 0.0 790.9 0.0 -1042.1 -1042.1

12/12/2012 7:31:10 CST -0.093 7:31:10 -0.093 -0.093 0.0 0.0 641.6 0.0 -690.4 -690.4

12/25/2012 4:30:20 CST -0.134 4:30:20 -0.134 -0.134 0.0 0.0 912.6 100.0 -604.5 -604.5

1/2/2013 14:41:26 CST -0.134 14:41:26 -0.134 -0.134 0.0 0.0 827.4 0.0 -618.9 -618.9

1/13/2013 20:35:06 CST -0.111 20:35:06 -0.111 -0.111 0.0 0.0 810.1 0.0 -730.6 -730.6

1/15/2013 10:04:14 CST -0.158 10:04:14 -0.158 -0.158 0.0 0.0 740.0 0.0 -468.5 -468.5

1/19/2013 23:10:16 CST -0.088 23:10:16 -0.088 -0.088 0.0 0.0 714.6 0.0 -816.1 -816.1

1/22/2013 16:06:24 CST -0.076 16:06:24 -0.076 -0.076 0.0 0.0 857.0 80.0 -1028.7 -1028.7

3/4/2013 21:47:48 CST -0.146 21:47:48 -0.146 -0.146 0.0 0.0 595.0 0.0 -406.8 -406.8

3/7/2013 17:05:56 CST -0.085 17:05:56 -0.085 -0.085 0.0 0.0 781.1 0.0 -914.0 -914.0

3/15/2013 18:39:50 CDT -0.086 18:39:50 -0.086 -0.086 0.0 0.0 528.9 0.0 -615.2 -615.2

3/18/2013 17:21:22 CDT -0.082 17:21:22 -0.082 -0.082 0.0 0.0 494.6 0.0 -603.8 -603.8

4/2/2013 21:25:34 CDT -0.098 21:25:34 -0.098 -0.098 0.0 0.0 758.2 0.0 -770.3 -770.3

4/9/2013 18:21:40 CDT -0.073 18:21:40 -0.073 -0.073 0.0 0.0 758.5 0.0 -1037.2 -1037.2

4/23/2013 11:19:30 CDT -0.063 11:19:30 -0.063 -0.063 0.0 0.0 469.1 0.0 -739.1 -739.1

4/29/2013 13:59:14 CDT -0.126 13:59:14 -0.126 -0.126 0.0 0.0 522.1 0.0 -413.1 -413.1

5/7/2013 3:07:26 CDT -0.120 3:07:26 -0.120 -0.120 0.0 0.0 504.8 0.0 -422.1 -422.1

5/11/2013 20:13:48 CDT -0.089 20:13:48 -0.089 -0.089 0.0 0.0 392.0 0.0 -438.8 -438.8

5/17/2013 13:38:22 CDT -0.052 13:38:22 -0.052 -0.052 0.0 0.0 473.1 0.0 -902.7 -902.7

5/22/2013 16:11:30 CDT -0.151 16:11:30 -0.151 -0.151 0.0 0.0 846.0 0.0 -559.6 -559.6

5/29/2013 23:47:34 CDT -0.109 23:47:34 -0.109 -0.109 0.0 0.0 699.0 0.0 -639.7 -639.7

5/30/2013 14:46:22 CDT -0.119 14:46:22 -0.119 -0.119 0.0 0.0 785.0 0.0 -660.5 -660.5

Date/Time (t-0) BA BA BA Relay Lmt Value "A" Information Value "B" Information SEFRD (FRM)Time Bias R1 for Bias for R1

BA Time Zone DelFreq Time DelFreq DelFreq MW/Load Lost Adjustment MW/Load Lost Adjustment (MW/0.1Hz) (MW/0.1Hz)

-687.38 2013 FRM - Average Estimated Frequency Response MW/0.1 Hz using SEFRD for R1

-613.59 2013 FRM - Regression Estimated Frequency Response MW/0.1Hz using SEFRD for R1

-650.10 2013 FRM - Median Estimated Frequency Response MW/0.1Hz for BA Compliance to R1, minimum Frequency Response

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Focus for 2013 Formal & documented review/report of frequency responsiveness

for Power Augmentation on Combined Cycle Resources (train not individual unit)

• Review regulation/GTBD deployment effectiveness (SCR 773)• Study the impact of HSL/basepoint/generation deviation on

compliance and reliability• Responsive Reserve requirements, qualification vs. compliance.

(10min vs. 16 second)• Standardized/consistent metrics for PFR analysis (BAL001-TRE). • Standardized/reasonable expectations for extreme events (2750MW

or larger lost) – driven by NERC.• No performance required for nonpayment (freq. resp AS)• ERS impact review with appropriate ERCOT group. Target Q1-

2014• PMU data understanding of implications• Pilot of fast frequency response – characterize & create evaluation

process.• Work on realistic measurement of combined cycles

Questions?