Maintenance and Planned Outages Capacity Accreditation Under Seasonal Construct Workshop Agenda Item 03c, 3d, 3e.

Transcription

1 Maintenance and Planned Outages Capacity Accreditation Under Seasonal Construct Workshop Agenda Item 03c, 3d, 3e April 22 nd, 2016

2 Seasonal Objective: Accurately represent capacity available to serve summer and winter peak demand We see planned and maintenance outages on peak hours from historical data. We want to reflect planned outages over the peak periods. Outages will impact accreditation if they occur during peak or critical times. 2

3 Capacity Accreditation will consider planned and maintenance outages on peak Annual Outage Rate EFORd Summer Forced Outage Rate EFORd Winter Forced Outage Rate EFORd Summer Equivalent Outage Rate (EOR) Forced outages across 4 summer months Planned Outages and Maintenance Outages during peak and critical hours Winter Equivalent Outage Rate (EOR) Forced outages across 8 winter months Planned Outages and Maintenance Outages during peak and critical hours 3

4 Occurences Occurences MISO Definition of peak hours Summer peak hours: HE EST 15,16,17 during Jun/Jul/Aug Weekdays M-F Only Winter peak hours: HE EST 9,19,20 during Dec/Jan/Feb Weekdays M-F Only 200 MISO Summer Daily Peak, Hour Ending EST 250 MISO Winter Daily Peak, Hour Ending EST

5 MISO definition of critical hours In addition to predefined peak hours, critical hours will also include any time period where MISO operations declared a Max Gen Alert, Warning, or Event according to RTO-EOP-002. Only those generating units residing in the location of the declared max gen activity will be affected. 5

6 Historical MISO use of Max Generation Activities 1/7/2014 Max Generation Alert from 07:15 EST to 12:00 EST Market participants were asked to update and acknowledge their LMR Availability for the day Max Generation Warning from 07:30 EST to 11:15 EST No available external generation to schedule Curtailed non-firm exports Made emergency energy delivery to PJM, Power South and Southern Company Max Generation Alert from 11:15 EST to 22:00 EST 3/3/ :30 EST 3/3/ :00 EST: MISO Declared Maximum Generation Alert for the entire Market Footprint 3/4/ :00 EST 3/4/ :30 EST: MISO Maximum Generation Alert declared for MISO Balancing authority due to forced and unforced generation reductions combined with reduced NSI imports the reason. 3/4/ :30 EST 3/4/ :00 EST: MISO Maximum Generation Event Step 1a declared, AME units started and external resources (Module E) scheduled into MISO. 6

7 Maintenance Outage and Planned Outage impact to Accreditation

8 NERC definitions: MO, PO Maintenance Outage (MO): An unplanned outage that can be deferred beyond the end of the next weekend (defined as Sunday at 2400 hours or as Sunday turns into Monday), but requires that the unit be removed from service, another outage state, or Reserve Shutdown state before the next Planned Outage (PO). Characteristically, a MO can occur any time during the year, has a flexible start date, may or may not have a predetermined duration, and is usually much shorter than a PO. Planned Outage (PO): An outage that is scheduled well in advance and is of a predetermined duration, can last for several weeks, and occurs only once or twice a year. Turbine and boiler overhauls or inspections, testing, and nuclear refueling are typical planned outages. For a planned outage, all of the specific individual maintenance and operational tasks to be performed are determined in advance and are referred to as the "original scope of work." 8

9 IEEE Std , Definitions for Use in Reporting Electric Generating Unit Reliability, Availability and Productivity. 9

10 PowerGADS Event Types Active Available ( Zero to Full Load) Unavailable ( No Load) Reserve (Not Connected) In Service (Connected) Planned Deratings No Deratings (NC) Unplanned Deratings Planned Outage Unplanned Outage PD DP PO PE PO & PD D4 DM Planned well in advance and is of a predetermined duration, lasts for several weeks, and occurs only once or twice a year MO ME D1 D2 D3 U1 U2 U3 SF 10

11 PowerGADS Event Types Active Available ( Zero to Full Load) Unavailable ( No Load) Reserve (Not Connected) Planned Deratings PD No Deratings (NC) DP In Service (Connected) Unplanned Deratings MO & D4 An outage or a derate that can be deferred beyond the end of the next weekend Planned Outage PO PE Unplanned Outage D4 DM MO ME D1 D2 D3 U1 U2 U3 SF 11

12 PowerGADS Event Types Active Reserve (Not Connected) Planned Deratings Available ( Zero to Full Load) No Deratings (NC) In Service (Connected) PE, ME, DM & DP An extension of a Planned or a Maintenance Event beyond its estimated completion date. Use only in instances where the original scope of work requires more time. Unplanned Deratings Planned Outage Unavailable ( No Load) Unplanned Outage PD DP PO PE D4 DM MO ME D1 D2 D3 U1 U2 U3 SF 12

13 NERC definitions: EMOR, EPOR Equiv. Maintenance Outage Rate (EMOR): MOH + EMDH EMOR = MOH + SH MOH: Maintenance Outage Hours EMDH: Equivalent Maintenance Derated Hours Equiv. Planned Outage Rate (EPOR): EPOR = POH: Planned Outage Hours POH + EPDH POH + SH EPDH: Equivalent Planned Derated Hours 13

14 Intermediate terms: EMORp, EPORp Equiv. Maintenance Outage Rate on peak (EMORp): EMOR p = MOH p + EMDH p MOH p + SH p MOH p : Maintenace Outage Hours (MOH) overlapping peak hours or critical hours defined in slides 4-5 EMDH p : Equivalent Maintenance Derated Hours (EMDH) overlapping peak hours or critical hours defined in slides 4-5 SH p : Service Hours (SH) overlapping peak hours or critical hours Equiv. Planned Outage Rate on peak (EPORp): EPOR p = POH p + EPDH p POH p + SH p POH p : Planned Outage Hours (POH) overlapping peak hours or critical hours defined in slides 4-5 EPDH p : Equivalent Planned Derated Hours (EPDH) overlapping peak hours or critical hours defined in slides

15 How to blend EMORp, EPORp, EFORd Equivalent Outage Rate (EOR): EOR = FOH d + EFDH d + MOH p + EMDH p + POH p + EPDH p FOH d + SH + MOH p + (POH p ) EFOR d still dominates the EOR value, determined from forced outage behavior overlapping demand. Maintenance and planned outage behavior during peak or critical times are counted equally to forced outages in demand. Units with zero (0) maintenance or planned outages during peak or critical times will have EOR = EFOR d for the season. 15

16 Outage States that will affect MISO Available Capacity (ACAP) by inclusion in Equivalent Outage Rate (EOR) calculation: Forced Outage Hours (Full or Derate) overlapping period of demand. Maintenace Outage Hours (Full or Derate) overlapping period of peak or critical hours. Planned Outage Hours (Full or Derate) overlapping period of peak or critical hours. 16

17 EORd Example #5: Baseload Using same FO behavior as Example #3b, but with 20 MO and PO Hours & 5 Equiv. Derated Hours during summer peak 40 MO and PO Hours & 10 Equiv. Derated Hours during winter peak Season Winter Summer 3 year Total Totals Totals Time Period 10/01-5/31 6/01-9/30 10/01/2014-9/30/2017 SH Caclulated Values f FOH = FOHd fp EFDH = EFDHd EFORd MO, PO Impact MOH+EMDH POH+EPDH MOHp+POHp EMDHp+EPDHp EOR % Change from EFORd 6.1% 4.1% 5.2% EOR - EFORd

18 EORd Example #6: Peaker Using same FO + RSH behavior as Example #4d, but with 20 MO and PO Hours & 5 Equiv. Derated Hours during summer peak 40 MO and PO Hours & 10 Equiv. Derated Hours during winter peak Season Winter Summer 3 year Total Totals Totals Time Period 10/01-5/31 6/01-9/30 10/01/2014-9/30/2017 SH Caclulated Values f FOH = FOHd fp EFDH = EFDHd EFORd MO, PO Impact MOH+EMDH POH+EPDH MOHp+POHp EMDHp+EPDHp EOR % Change from EFORd 103.8% 90.3% 62.6% EOR - EFORd

19 Summary Result of MO and PO inclusion Maintenance Outages and Plannd Outages during peak or critical hours (MOHp and POHp) will have the same impact to EOR as Forced Outage Hours in Demand (FOHd). The incremental impact of MOHp and POHp will be felt greater by low SH peaking units rather than high SH baseload units. This is an intuitive outcome, since peaking units are needed most specifically for peak load times when their availability can be crucial. This is a similar relationship to how low SH units are impacted more by incremental FO hours in typical EFORd calculations, while high SH units are less impacted by the same FO hours. 19

20 EORd Class Average with Planned Outages during Critical Hours [%] Summer Annual Winter CC Steam - Gas CT 0-20 MW CT MW CT 50+ MW Diesel Coal Coal Coal Coal MISO Weighted Average

21 Impacts of planned outages will be phased in over time after June 1 st, 2016 Planned Outages 1 in 2016/17 Planned Outages 1 in 2017/18 Planned Outages 1 in 2018/19 Rolling 3 years going forward 2018/19 PRA will include 1 Year of planned and maintenance outages 2019/20 PRA will include 2 Years of planned and maintenance outages 2020/21 PRA will include 3 Years of planned and maintenance outages 21

22 Other Seasonal Topics

23 Winter GVTC Requirements The same verification test can be used to create a summer GVTC value and a winter GVTC value. Winter: Temperature corrections will use the Date/Time of the MISO Winter Peak from the last 5 years. The MISO will provide this information. The average site temperature will be the value to correct to using unit manufacturer curves.

24 Other BPM Guidelines Minimum consecutive months of operation are needed to calculate EOR, otherwise the unit will receive a class average value Previous Annual Minimum: 12 months Summer Minimum: 4 months Winters Minimum: 8 months Units with low service hours less than 80 hours per year have an adjustment made to the SH value when calculating XEFORd. A similar adjustment will be made considering 4-month summer and 8-month winter seasons. 24

25 Other topics for future LOLEWG meetings Seasonal Wind ELCC Seasonal Solar Capacity Credit Seasonal Intermittent Generation and Dispatchable Intermittent Resources Seasonal LMR 25

26 Questions? John Reinhart Resource Adequacy Coordination (651) Ryan Westphal Resource Adequacy Coordination (651)