Below is a compilation of frequently asked questions. This FAQ will be added to as more questions come in and we move through the auction. Updated 9/5/23.
2024-2025 PRA TIMELINE
|Date||Process and Notes||Responsible Entity||Tariff Reference|
|Sep 01, 2023||Cost of New Entry (CONE) arranged to be calculated in coordination with IMM by Sept 1. Later file with FERC.||MISO||69A.8(a)(3)|
|Sep 01, 2023||MISO publish historical monthly and seasonal Coincident Peak Load hours and LRZ seasonal coincident factors.||MISO||69A.1.1.(c)|
|Oct 02, 2023||MISO opens the new Planning Year in the MECT for all 4 Seasons.|
(1st Business Day - October)
|Oct 02, 2023||Transmission losses by Local Balancing Authority are posted by MISO.|
(1st Business Day - October)
|Oct 31, 2023||Generation Verification Test Capacity (GVTC) due.|
Resource Owners submit operational data or real power test for Sep. 1 - Aug. 31 period.
|Resource Owner||69A.3.1.a, b, & c, 69A.3.6|
|Oct 31, 2023||Updated historical performance submittal due for hours ending 15, 16, and 17 EST in summer, fall and spring cases, hours ending 8, 9, 19, 20 EST for the winter Season for Intermittent Generation & Intermittent BTMG that are not powered by wind.||Resource Owner||69A.3.1.a(1)(d)|
|Oct 31, 2023||Generator Availability Data due in GADS for those resources that are required to report for Q3.|
Resource Owners must also ensure at least 36 months of data is provided, if applicable.
|Nov 01, 2023||Seasonal Coincident and Non-Coincident Peak Demand forecasts by LSE/EDC, monthly peak demand, seasonal peak demand and energy-for-load forecast values by LSE due.|
No action needed by Retail Choice LSEs.
|Nov 01, 2023||Loss of Load Expectation study results published by MISO|
(Publish seasonal: PRM, Determine seasonal CIL and CEL, Establish seasonal LRRs)
Published by Nov. 1
|Nov 07, 2023||MP must request an extension from within 5 Business Days after Oct 31 deadline.||Resource Owner||69A.3.1.a, b, & c, 69A.3.6|
|Nov 15, 2023||Review list of units with Conditional Interconnection Service for results of annual study. Units may have NRIS/ERIS balance re-allocated. Published by Nov. 15||MISO|
|Dec 15, 2023||Seasonal Capacity accreditation values are published by MISO.|
Resources that do not meet the Oct. 31 milestones will have their initial capacity accreditation calculated using best estimated capacity submitted together with extension request ; MP starts submit resolution request though help center on for questions/discrepancy related to posted results
|Dec 15, 2023||Peak Load Contribution (PLC) submissions by EDC due (EDC will send the details of the PLCs to both the respective LSEs and MISO for review).|
The EDC-provided PLC data will be the default value for the LSEs' Retail Choice Coincident Peak.
|Retail Choice EDCs||69A.1.1( e)|
|Dec 31, 2023||For individual States establishing their own seasonal PRM, written letter by authorized State regulatory authority representative notifying MISO.||State Regulatory Authority||68A.1|
|Jan 15, 2024||Generation Verification Test Capacity (GVTC) due for generators that requested extension||Resource Owner||69A.3.1.a, b, & c, 69A.3.6|
|Jan 15, 2024||LSEs confirm the seasonal Retail Choice PLC in the MECT.|
LSEs should have all PLC questions resolved at this milestone. If an LSE desires a change in their PLC value, the appropriate EDC should be contacted directly for discussion
|LSEs, Retail Choice EDC||69A.1.1.1|
|Jan 15, 2024||Evidence for seasonal HUC/Zonal Deliverability Charge hedges due||LSE||69A.7.7(b)|
|Jan 31, 2024||Default technology specific avoidable costs posted by the IMM.|
Resource owners may use the default costs in lieu of submitting facility specific operating costs for a facility specific Reference Level request.
(59 days prior to deadline for offers)
|Feb 1, 2024||Last day to submit resolution request on ISAC posted for schedule 53 resources, on MISO help center||Resource Owner|
|Feb 01, 2024||Existing Load Modifying Resource / Energy Efficiency / External Resource registrations due for prompt Planning Year||LMR/EE/ER Owner|
|Feb 01, 2024||Loss of Load Expectation study begins for next Planning Year||MISO|
|Feb 01, 2024||Resource Owners confirm Seasonal Accredited Capacity posted in the MECT.|
Excludes SAC values for LMR and External Resource registrations.
|Feb 01, 2024||Evidence of Demand Resource testing due.|
Last day to submit evidence.
DR testing or performance should take place during the calendar year prior to the upcoming Planning Year.
|Feb 01, 2024||Written letter from officer of company stating intention to leverage DR testing deferral provisions due.||DR Owner||69A.3.5(l)|
|Feb 14, 2024||If utilizing FSRL, last day to request from IMM Going-Forward Cost determination.|
Submit data for facility ZRC reference levels to IMM.
(45 days prior to close of PRA offer deadline)
|Feb 15, 2024||Final UCAP/ISAC ratio and SAC values for schedule 53 resources will be posted on MECT. Schedule 53 resource owners can start confirm/convert SAC into ZRCs||MISO|
|Feb 15, 2024||New Load Modifying Resource / Energy Efficiency Resource / External Resource registrations must be submitted for approval to be considered for inclusion in seasonal FRAP.||LSE||69A.9(a)|
|Feb 15, 2024||LSEs submit request to revise seasonal Coincident Peak Demand forecast originally submitted on November 1st.|
MISO will review and approve/deny request
|Feb 15, 2024||Written letter from officer of company stating intention to leverage ICAP Deferral provisions||Resource Owner||69A.7.9(a)|
|Feb 29, 2024||Capacity accreditation updated for resources granted ICAP Deferral||MISO|
|Mar 01, 2024||Seasonal Generator Verification Test Capacity / Generator Availability Data for new resources or resources with increased capacity due for prompt Planning Year||Generation Owner||69A.3.1.a(d)|
|Mar 01, 2024||New Load Modifying Resource / Energy Efficiency Resource / External Resource registrations must be submitted for approval in the MECT for the prompt Planning Year||LMR/EE/ER Owner||69A.9(a)|
|Mar 01, 2024||Deadline to satisfy credit requirements for DRs opting out of or deferring testing. Credit posting only required if DR doesn't have regulatory restriction or contractual obligation that precludes testing.||DR Owner||69A.3.5 (j)(2)&(l)|
|Mar 01, 2024||Publish seasonal Sub Regional Import Constraint (SRIC) and the seasonal Sub Regional Export Constraint (SREC) for each Sub Regional Resource Zone (SRRZ) no later than first business day in March.||MISO||68A.3.1|
|Mar 01, 2024||MISO to complete its seasonal Coincident Peak Demand forecast review process||MISO||69A.1.1( c)|
|Mar 01, 2024||Satisfy credit requirement for seasonal capacity accreditation issued from resources granted ICAP Deferral||Resource Owner||69A.7.9(b)|
|Mar 01, 2024||Resource Owners Confirm SAC posted in the MECT - Catch Up resources only||Resource Owner|
|Mar 01, 2024||Resource Owners submit Att Y for units scheduled for retirement/suspension between 3/30 and 5/31 to receive exemption from physical withholding||Resource Owner||38.2.7.a.(i)|
|Mar 09, 2024||Seasonal Fixed Resource Adequacy Plan due by LSE|
(7th Business Day of March)
|Mar 09, 2024||Finalize and submit HUC registrations in the MECT||LSE|
|Mar 14, 2024||Last day to notify IMM of deliverable resources requesting to be excluded from offering into seasonal PRAs or included in a FRAP.||Generation Owner|
|Mar 15, 2024||Fixed Resource Adequacy Plan review completed by MISO (The LSE will have until the PY offer window opens to remedy any deficiencies in their FRAP)||MISO(LSE)||69A.9(a)|
|Mar 19, 2024||Final date to update seasonal CIL and CEL values for each LRZ prior to the Planning Resource Auction.|
Changes due to firm capacity commitments from MISO resources to neighboring regions prior to the PRA
|Mar 19, 2024||CEL determined for each ERZ.|
Equal to the ZRC quantity of the External Resources registered to participate in the PRA.
(8th Business Day before the last Bus. Day)
|Mar 19, 2024||Final Preliminary seasonal PRA data is released by MISO. Reflects updated information from LSEs, Resource Owners and PJM auction results. Coincides with seasonal CIL/CEL calculations.||MISO|
|Mar 21, 2024||Provide Facility Specific Resource Level(s) to MPs 5 days prior to the close of the PRA offer window||IMM||64.1.4.g|
|Mar 26, 2024||Planning Resource Auction offer window for all Seasons is opened|
Auction Offer window is opened at 8:00 am EPT 3 Business Days prior to the last Business Day in March
(26th-29th of March)
|Mar 29, 2024||Planning Resource Auction offer window for all Seasons is closed|
Auction Offer window is closed at 6:00 pm EPT
(Last Business Day of March)
|Apr 01, 2024||Iterations of seasonal auction runs with adjusted seasonal CILs and CELs may be required to ensure that a network loading is not violated. Additionally, MISO will work with the IMM to evaluate potential withholding. The reference levels are used to determine financial withholding. The mitigation of financial withholding can be expected to reduce the auction clearing price|
(1st 20 Business Days of April)
|Apr26, 2024||Seasonal Planning Resource Auctions results posted|
(20th Business Day of April)
|May 1, 2024||For MP's selecting this option, assess the seasonal Capacity Deficiency Charge||MISO||69A.10(a)|
|May 8, 2024||MISO sends out the Capacity Deficiency Charge 5 business days (or as soon as practical) after assessment.||MISO|
|May 17, 2024||Capacity Deficiency Charge payment due|
Payment made within 7 business days of receipt.
|May 19, 2024||Capacity Deficiency Charge payments made to MPs.|
Actual payment date may vary depending on above payment receipt date.
|May 27, 2024||Publish details of the seasonal ZRC offers submitted in the PRA - Market Participant IDs are not revealed.|
(One month after PRA)
|May 27, 2024||MISO publishes cleared LMRs to applicable operations tool.|
Must Offer performance requirements in the applicable operations tool.
|May 31, 2024||Information due to satisfy ICAP Deferral must be submitted to MISO to avoid ICAP Deferral Non-Compliance Charge for Summer Season.|
(Last Business Day)
|May 31, 2024||Information due to satisfy DR Deferral Notice must be submitted to MISO in order to release credit requirements and avoid potential 3 x LMP performance penalties.||DR Owner||69A.3.5|
|Jun 01, 2024||Summer Season in New Planning Year starts||All||69A.7|
|Jun 01, 2024||Daily settlements for the Summer Season starts||All|
|August 30, 2024||Information due to satisfy ICAP Deferral must be submitted to MISO to avoid ICAP Deferral Non-Compliance Charge for Fall Season.|
(Last Business Day)
|Sep 01, 2024||Fall Season in New Planning Year starts||All||69A.7|
|Sep 01, 2024||Daily settlements for the Fall Season starts||All|
|November 29, 2024||Information due to satisfy ICAP Deferral must be submitted to MISO to avoid ICAP Deferral Non-Compliance Charge for Winter Season.|
(Last Business Day)
|Dec 01, 2024||Winter Season in New Planning Year starts||All||69A.7|
|Dec 01, 2024||Daily settlements for the Winter starts||All|
|February 28, 2025||Information due to satisfy ICAP Deferral must be submitted to MISO to avoid ICAP Deferral Non-Compliance Charge for Spring Season.|
(Last Business Day)
|Mar 01, 2025||Spring Season in New Planning Year starts||All||69A.7|
|Mar 01, 2025||Daily settlements for the Spring Season starts||All|
For coincident peak, is MISO requiring seasonal coincidence factors?
MISO only publishes only one seasonal coincident peak.
Do you need to look back 5 years to come up with your coincident peak or just the previous year?
You need a minimum of one year, but you can use more than one.
What are the minimum datapoints needed for seasonal Coincident Factor?
You need a minimum of one year.
Is there an import function to submit Non-Coincident Peak and Energy for Load?
This is not a current capability, but something we can look into for the future.
If the GVTC value is the same for all historic years or should it reflect the prior year.
Your units current GVTC is valid through all 3 lookback years.
What happens when Schedule 53 Seasonal Accredited Capacity (SAC) is greater than ICAP?
The linked knowledge article covers this topic. KA-01389 (misoenergy.org)
Are you able to submit an ICAP deferral for a new resource to include only a portion of the 4 seasons if they will not be operational prior to 6/1/23? Submit just offers for Fall, Winter, and Spring for example.
You can choose which seasons you are doing an ICAP deferral for, please refer to BPM-011-r27 for more information.
Is MISO going to post seasonal Interconnection Service for each resource?
MISO's Generator Interconnection Agreements (GIA) do not grant seasonal interconnection services. Under the Confirm SAC display in the MECT, each resource will have the same Interconnection Service values (NRIS and ERIS) display for each season. Example, if a Generator has a 100MW GIA that grants its 50MW of NRIS, each season will show Total IS= 100MW, 50MW of NRIS, and 50MW of ERIS.
Is the Interconnection Service limitation prior to conversion of ISAC or do you need enough Interconnection Service to cover the SAC too?
You must have enough Interconnection Service to be fully deliverable to your ICAP.
How does one convert the excess Energy Resource Interconnection Service (ERIS) SAC when there is no Transmission Service Rights (TSR) beyond the Network Resource Interconnection Service (NRIS) Service.
You must have enough Interconnection Service to be fully deliverable to your ICAP. Examples below shows three different scenarios.
The ERIS conversion is requiring a TSR# on the conversion page. How do you convert the ERIS SAC?
Converting ERIS SAC requires firm transmission in the form of PTP to NITS. These TSR numbers are entered in the MECT. New features in the MECT automate the TSR approval process, there are currently some technical issues going on that is being researched. In the case of non-automation, MISO staff will manually approve TSRs.
Can an LSE assign NITS from a different zone for ERIS capacity?
Yes, you can participate, if, you have firm transmission service in the form of PTP or NITS. Please refer to BPM-011 for more information.
How will MISO address the ISAC calculation on jointly owned units where different owners submit separate offers?
Market Participants may request a review with MISO staff to go over calculations with joint owners on how to confirm the computations are handling the proper shares.
If there are adjustments to ISAC, does MISO plan to update the System UCAP/SAC ratios for any changes?
MISO will be giving the final ratio on December 15th.
Can your ISAC calculation be greater than NRIS?
ISAC generally will not be, but SAC can be higher.
LOAD MODIFYING RESOURCES (LMR)
For the SAC determination of an LMR, will the value be the same across all four seasons for this upcoming year (23/24)?
LMRs are not Schedule 53 resources, but they will be seasonal on what they can curtail.
Are there any similar types of adjustments for LMRs, either BTMG or DR for the upcoming auction?
The number of calls is defined five for Summer and Winter. Three for Spring and Fall.
The Multi-Day Operating Margin (MOM) report shows peak hour operating margin for 6 days, for planning purposes don't market participants need hourly granularity?
The MOM forecast provides estimates of operating margins for the expected peak hour next 6 days. Maintenance Margin is also based on expected peak loads. For planning purposes which should be many weeks or days in advance, that is the appropriate level of hourly granularity.
What maintenance margin and/or operating margins reports contain hourly data.
The Multi-Day Operating Margin (MOM) forecast estimates the timing of the peak hours for the next 6 days. Typically, the other hours from the dame days would have lower and higher operating margins.
What affect does Market Clearing above CONE in a single season have and what affect does that have on other seasons?
Technically, Cost of New Entry (CONE) itself is an annual figure, an industry-wide term, used to indicate that current, annualized, capital cost of constructing a power plant. There is never a price that if going over [annual] CONE. MISO does apply different denominators to CONE based upon the way it is used. The highest auction price you can have CONE [annual] divided by the number of days in that season, For Auction Clearing Prices, that is the maximum. If we have 2 or more seasons that are in Zonal Resource Credit (ZRC) shortage or near shortage it would be CONE divided by the number of days in those seasons.
NEW RESOURCES OR RESOURCES WITH INSUFFICIENT PERFORMANCE DATA
What if my new resource or existing resources does not have at least 60 days of Real-Time offered availability when designated for Resource Adequacy Requirement (RAR) over the last 3 years for each season, what will the SAC be based on?
The resource will have a SAC based on the Class Average SAC to ICAP Ratio for its resource type.
When and where are Operating Margins posted?
We have shared this data in the spreadsheets that can be used to calculate unit level SAC values. MISO will explore posting such information shortly after each season or possibly on an ongoing weekly basis via an automated report for future Planning Years.
What is the report name that shows the daily operating margin for the next 7 days?
The Multi-Day Operating Margin (MOM) forecast estimates the operating margins for the next 6 days.
Where can we see reporting on our historical outages that received exemption flags in CROW?
Market Participants can obtain their own outage data because MISO's CROW system does have report functionality which Market Participants can utilize. MISO will be updating the CROW User's Guide available on the MISO Market and Operations webpage
If there was an outage in the past that was >30 days and we are calculating SAC, should we exclude that season in the SAC Calculation? If yes, do we just divide by 2 years instead of 3?
If you don't offer into a season because your outage is more than 31 days, and the unit was coded as exempt you don't need to do anything. It will be removed from the calculations. You will use the seasons it was in use for the calculations.
Which maintenance margin should we be utilizing to get an exemption? Central or MISO whole maintenance margin?
The margin is where the asset is physically located, not MISO wide.
The IMM has provided guidance to deduct "otherwise reasonably expected unavailability" from the 31 days of threshold under the 31-Day rule to determine how many actual planned outage days could occur in a season before having to withhold/replace. Does MISO agree with this guidance? If so, what is MISO's recommendation on how to determine such "reasonably expected unavailability" to deduct from the 31-day threshold for each unit?
This was added as a fail-safe at the recommendation of the IMM, so people can't offer in PRA when it is out for the season. Language will be added by the IMM to BPM-009 that clarifies the standard.
How do we know what Annual Average Offer Capacity (AAOC) hours to use if the unit is in outage and has an exemption during the AAOC hour?
AAOC hours are used to help ensure sufficient sample size as a proxy. MISO doesn't backfill annual Resource Adequacy (RA) hours, less of an issue since 260 of them per Planning Year instead of 65 per season. It is measured by what you had. So, if you were exempt for 10 then you would not be reflected in the calculations.
The 31-Day rule applies to outages in CROW at the time of the auction, correct? What happens if outages have been submitted in CROW, but have not yet been approved/exempted by MISO by the time of the auction? What is MISO subsequently denies or does not provide an exemption for an outage in CROW after the auction but, for example such unit was withheld assuming the outage would be approved?
Planned outages are counted after the fact based on what actually happened. When submitted or approved doesn't matter for counting days towards the 31-day threshold. Regarding unplanned outages that were known or could be reasonably anticipated the determination whether to count them is determined by the IMM. Combination of planned and unplanned, but IMM counted outage days is compared to 31 days to determine replacement requirement and related non-compliance charges.
If we shorten an outage in CROW, will we lose our exemption if the maintenance margin is <0 on any day of outage on the date we shorten the outage even if it was >0 when we initially submitted the longer outage?
If an outage is reduced by more than 20% of their duration, the outage will be re-evaluated for exemptions. The Change Request (CR) date will be used to determine exemption eligibilities. BPM-008 Section 4.8.2 Changes by Generator Owner or Generator Operator does address this and gives an example. If reduced by less than 20%, outage is not re-evaluated and all exemptions that were previously granted will remain.
If a planned outage begins, and the work is completed quicker than anticipated, can the planned outage duration be shortened? If so, are there any associated exemption status or other types of impacts?
"Implemented" tickets in CROW can be "Completed" earlier than the end date/time with no impact to the exemptions on ticket. Completing a ticket in CROW is not considered a Change Request.
Where can I find more details regarding outages and exemptions.
For additional details, please see in the Outage Exemption Chart. See Schedule 53.II Tier 1 and Tier 2 Planned Outage Exemption Requirements.
For a unit with a planned outage greater than 31 days, my understanding is that you could either seek an exemption from the IMM to not participate in that season's PRA or you could participate and be subject to a penalty for days greater than 31. If you use the second option, and you replace the capacity for the days above 31 you would avoid the penalty. Is this correct? Also, in addition to all this, the outage would not hurt future accreditation as long as it was submitted with sufficient notice, etc.?
Penalties would not apply if the capacity on an outage greater than 31 days was replaced. There are other variables that factor into capacity accreditation in addition to the outage notice timeline.
Do some forced outages get exemptions?
No, only planned outages receive exemptions.
Do gas outages Code 124 get exemptions?
Inability to get gas does not get an exemption.
If there is a change to the outage start or end dates occurring for an outage that was previously exempt, do the unchanged days (in the original outage window) still have an exemption while the newly added days do not?
Please refer to the Maintenance Margin before extending an outage. If the maintenance margin is good and it is still timely you can do a change request. If you are extending and the maintenance margin is not great, submit a ticket so you can retain your exemptions on your original ticket.
Change requests that shorten an outage by no more than 20% or reduce capacity of the outage will not lose exemption(s). All other change requests will reset the queue position and be cause for re-evaluation of exemptions using the date of change as the evaluation date. BPM-008 Section 4.8.2 discusses this further. If extending an outage would cause you to lose exemptions MISO suggests submitting a new ticket so you do not lose the exemption on your 1st ticket. New requests are required to extend an outage already in progress.
Where in CROW Reporting is the Exemption Submittal box?
MISO is working with the vendor to fix this bug and putting instructions on how to do this will be added to the Appendix in CROW. It will be coming soon.
Does MISO have an outage cause code reference that corresponds to NERC/GADS or PSC outage codes?
The CROW user guide has an attachment of all cause coded for MISO.
What is the impact if you have Time Requirement Exemption (TRE) but not a Maintenance Margin Exemption (MME)?
If only ONE of these boxes is checked, you will have a Tier 1 exemption. If BOTH are checked it is a Tier 2 exemption. If no boxes are checked then you do not have an exemption.
What outage codes count and do not count toward accreditation impacts?
The TRE and MME exemption boxes are checked or not based on the rules laid out in Section II of Schedule 53. MISO has discretion to provide an exemption in some circumstance, for example there is a code 126 Transmission System Limitations which can result in the granting of an exemption upon consultation with the Planning Operations Team.
Do you loose accreditation if you make scheduled outage changes?
Change requests that shorten an outage by no more than 20% or reduce capacity of the outage will not lose exemption(s). All other change requests will reset the queue position and be cause for re-evaluation of exemptions using the date of changes as the evaluation date. BPM-008 Section 4.8.2 discusses this further. If extending an outage would cause you to lose exemptions MISO suggests submitting a new ticket so you do not lose the exemption on your first ticket. New requests are required to extend an outage already in progress.
A planned derate is not eligible for exemption currently, but will it be looked at in the future?
Yes, exemptions for derates will be looked at in the future.
Does MISO let market participants know in CROW that outage has received a Time Exemption Requirement (TRE) or Maintenance Margin Exemption (MME)?
This is in the works. They are hoping to get it into CCE by the end of November.
If you have multiple units on single CROW ticket, if you remove a unit from the ticket, does this trigger a re-evaluation of the exemption status?
This would be considered reduction of capacity of outage. Change requests that shorten an outage by no more than 20% or reduce capacity of the outage will not lose exemption(s). All other change requests will reset the queue position and be cause for re-evaluation of exemptions using the date of change as the evaluation date. BPM-008 Section 4.8.2 discusses this further. If extending an outage would cause you to lose exemptions MISO suggests submitting a new ticket so you do not lose the exemption on your first ticket. New requests are required to extend an outage already in progress.
Is MISO open to retroactive exemptions prior to 9/1/2022?
You either have an exemption or not prior to 9/1/2022.
If the planned outage is occurring PY 23/24 does the 31-day limit apply or not?
Yes, the capacity replacement provisions are effective for the 2023/2024 Planning Year.
Will exemptions be granted for outages for the upcoming planning year that are in excess of 31 days in a season, if planned prior to FERC filing?
Exemptions remove the applicable hours from the Schedule 53 calculations. Any day with planned outages in a season whether exempt or not counts towards the 31-day threshold after which replacement is required by the Tariff regardless of when planned.
What data point triggers the end of an outage to determine the duration between outages?
The planned end date of previous outage for the unit in CROW.
If an outage starts 10 hours earlier than planned for a planned outage that was given an exemption, does it affect the exemption outage?
Implementing early by a few hours on the same day does not affect your exemption status. If it is a day early, then it would be looked at.
If an outage lasts 10 hours after the exemption, will it affect the exemption outage?
If you are going to be into the next day you will need to put in another ticket, so you don't lose your exemption on the current ticket.
Should we expect prior CROW tickets that had no exemptions marked, but submitted >120 days in advance to show a Time Requirement Exemption (TRE)?
These Time Requirement Exemptions should show as flagged in CROW.
What is the status of BPM-008 for Outage Coordination for RAN?
Subsection 4.1.1 should be able to see in revision 21.
If an outage starts in the middle of the hour, is that hour coded as being in outage for SAC Calculation, if it is not in exemption?
MISO compares the Real-Time Offer market time stamp with the CROW outage start time. Real-Time Offer market time stamps are reflected on an hour interval basis, whereas CROW outages are reflected on a minute internal basis. Let's use an example to help explain the process:
- An outage starts in the middle of the hour and is reflected in CROW as starting at 9:15 a.m.
- MISO would flag the outage in the SAC process as hour beginning 10:00 a.m., unless the Real-Time Offer Status already indicates this unit is in outage starting from 9:00 a.m. If this is true, MISO will flag outage as hour beginning at 9:00 a.m.
How should I submit and outage exemption dispute?
Submit a case in the MISO Help Center.
What has been done to resolve combined cycle and exemptions for each individual steam/gas turbine?
Not all combined cycle units offer into the market the same. SAC templates have been posted to the market portal accounting for different circumstances. The general rules are if outages are submitted based on individual turbines, the combine cycle unit will be exempt if all individual units are outaged and exempt. Otherwise, it is based on outage submitted on parent unit.
PLANNING RESERVE MARGIN (PRM)
Is the Planning Reserve Margin (PRM) final and official?
The Planning Reserve Margin (PRM) and the Local Reliability Requirement % (LRR) are official and should not change from the 23/24 LOLE Report.
Is the Planning Reserve Margin % (PRM) and the Local Reliability Requirement % (LRR) are official and should not change from the 23/24 LOLE Report?
The Planning Reserve Margin Requirement MW(PRMR) will be updated with the new load forecasts, transmission losses, and the Local Clearing Requirement (MW (LCR) will be posted in Q1 2023, as MISO starts to publish preliminary PRA data.
In comparing RA hours for 9/19-8/21 to what was used during development, it appears there may be numerous changes in the identification of the Tier 2 hours. Could you please discuss what drove the changes in the Tier 2 hours from what was previously provided.
The underlying data changes when MISO put it into production. MISO's data team went through all the data to get the margin MW accordingly. That is why MISO made the data in late September preliminary. MISO wanted to make sure that we had your MW correct. There should be no changes in the data for that time period when the new one comes out.
When will we know the Tier 2 hours for the previous season? Are these going to be provided quarterly?
MISO has not announced the date the Tier 2 hours will be available and has not yet identified the process for providing updated values to stakeholders.
What is the best way to predict Resource Adequacy Hours?
Consult the daily Multi Day Operating Margin Forecast which gives information for the next 6 days. This is located on the MISO website within Market Reports.
When is the registrations page unlocked in MECT to submit entries?
December 15th is when registrations can be submitted.
Is the intent to submit the same "supporting documentation" for each season?
We assume this question pertains to the "Registrations" for Load Modifying Resources (LMR) which can be Demand Response (DR) or Behind-the-Meter Generation (BTMG). The Module-E Capacity Tracking (MECT) tool is currently designed to allow for one (1) 'registration' for the Planning Year. Within the one registration, the 'seasonality' is broken out. All supporting documentation can be uploaded for the specific LMR in one 'registration.' So, the Market Participant can upload one file with the supporting documentation on the seasonality of the LMR of the MP can upload specific files for each season. It is up to the Market Participant at this time.
When will MECT be open to register LMRs?
New LMR Registrations is open now.
What is the Deadline to register New CPNode Resources?
You will need to have GVTC, be in the Commercial Model, and be operatable. March 1st should show this as available in MECT.
If a replacement capacity goes into a forced outage does the unit still count as replacement capacity?
If it goes into forced outage after the replacement goes into effect, then yes but it can't be replaced with capacity already on a forced outage.
Is there a way for generation owners to state they have excess capacity which is available to be contracted for replacement capacity?
Yes, MISO provides via the Market Portal, a bulletin board for the purpose of communicating both a need to buy or sell capacity.
The following article discusses it in further detail. The bulletin board is called the Non-MISO Transaction Bulletin Board.
Does replacement capacity have to be available during the same days that the original resource is offline (do the days have to overlap)?
Capacity replacement works by shifting the "designated as Resource Adequacy Requirements (RAR)" and related performance requirements from one resource to another resource that have uncleared Zonal Resource Credits (ZRC) in sufficient quantity. They can't both be designated as RAR at the same time since the tariff requires replacement from "uncleared ZRCs". Whenever a resource is designated for RAR and is on a full or partial outage the count toward the 31-day threshold in a season will continue. Note, if unit A accrues 31 days of planned outages and then replaces with uncleared ZRCs from unit B then has any planned outages in that season then the MP that converted the ZRCs for unit A will be subject to the capacity replacement obligation and related non-compliance obligations since the tariff states that "ZRC replacement shall have no impact on settlements". All of this is covered in Module E-1 Section 69A.3.a.h.a.
Is it possible for SAC to be larger than ICAP?
Under the RAN Seasonal construct, Schedule 53 resources can have a SAC that is higher than the units effective ICAP (lesser of Interconnection Service or GVTC). All of this SAC can be converted and offered into the PRA. The Must Offer obligation would still be capped at your units effective ICAP. For example, if you convert and offer 100% of your SAC, your Must Offer obligation would be 100%*ICAP. If you only convert and offer 90% of your SAC, your Must Offer obligation would be 90%*ICAP.
Where does the data come from for SAC Calculations?
From MECT: GVTC Data
From DART: Resource Real-Time hourly offered EmerMax and CommitStatus, Resource Lead-Time (calculated by DART engine based on resource offer and status), 5-minute UDS state estimate and control status; for creating online indicator
From CROW: Completed of Implemented Out-of-Service outage for creating outage indicator, RAN Phase I exemption flag for creating exemption indicator
Will MISO use the last complete planning year for calculation of SAC or the most recent 3 seasons ending with the most recent Summer?
The lookback period is Sept 1- Aug 31. This is so the latest summer will be used in calculation.
How do we measure the impact on SAC of moving an outage?
Moving an outage can lead to the loss of one or both exemptions in which case the Real-Time offers of 0 during the OOS outage could be used in the Schedule 53 calculations. Limited impact for non-RA Hours but more impactful for RA Hours that have a higher weighting.
How are Tier 1 and Tier 2 hours applied to SAC?
The Conceptual Design Document explains this, along with SAC template.
What values are the weighted percentages applied to in SAC?
In the first year 40% is applied to the Tier 1 ISAC and 60% to the Tier 2 ISAC to get the combine ISAC value. In Planning Year 2024/25 it will be 30% and 70% respectively and the in the Planning Year 2025/26 it will be 20% and 80% where it will stay.
Will MISO be providing an unlocked SAC template?
MISO has posted both the original locked version and an unlocked version of the Schedule 53 SAC Calculation tool. Both can be found on the Resource Adequacy webpage.
Where are historical class averages posted by MISO?
Historical class averages (ISAC/ICAP) will be available when SAC accreditation is made available.
In the SAC Template, step 2-2 limits availability based on the GVTC or the Real-Time Offer EmerMax?
Real-Time offered Hourly Emergency Maximum Limit is the "availability" used in Schedule 53, it is capped by the most recently submitted seasonal corrected GVTC to account for changes in the maximum output of a resource.
There are 800 Tier 2 seasonal RA hours shown in step 5 tab of the SAC North Template, while the initial RA hours has 640 hours. Though only 65 hours per season for seasonal RA and I have 100 hours in winter of 2020-2021.
There was a glitch on the day of posting and the workbooks had been swapped, but the corrected versions are now available.
What fields in CROW does MISO look at exemptions for the SAC Calculations?
They look at actual outage tickets in CROW, then the actual start and end time in CROW.
How will Combined Cycle be calculated with SAC?
MISO is working to develop the process to match Real-Time Offers to MECT registrations. This process is still under development and may result in the need to raise issues to be addressed during the SAC confirmation process.
Is it possible that the SAC result could be greater than the GVTC quantity?
Yes, that is likely to happen for well performing resources given use of the conversion ratio.
Is the time between December 15, 2022 and February 1, 2023 a period to work with MISO if we do not agree with the published values?
What is the recommended timing for selecting the "Reject SAC" for current cases that are being reviewed?
February 1st. If a resource that has a late GVTC, ICAP Deferral, New Resources or any other that needs time. March 1st.
Can the SAC only exceed ICAP due to the ICAP/SAC ratio or is there more that goes into that calculation for example ancillary services or generators that are more available during tight hours?
SAC would only be higher than ICAP for Schedule 53 Resources due to the UCAP/ISAC Ratio.
Can The UCAP/ISAC ratio that has been posted in truncated to two decimal points. However, the SAC workbooks have a ration truncated to three decimal points. It appears in the MECT the two different SAC values are using different ratios in the top SAC value versus the SAC value at the bottom of the page. Can you explain why this is? Which SAC value should we be using?
The SAC value at the top of the page in the MECT is the correct value. The value at the bottom is a shadow calculation in the MECT meant to show more details on how the calculation is being made. The difference between the two are due to rounding.
SCHEDULE 53 RESOURCES
Is a non-run of river, non-pumped storage hydro unit considered Schedule 53 resource?
A non-pumped storage hydro unit that is NOT enrolled as an Electric Storage Resource (ESR) may be considered a Schedule 53 resource, However, hydro resources defined as a Run of River or Use Limited Resources are not considered as Schedule 53 resources.
START UP TIMES
Schedule 53.V.C states that the sum of the Resource's Start-Up Time and Start-Up Notification Time Offers exceeds 24 hours . . . . the [availability] will be set to zero. However, the BPM references the cold start time. Please discuss this discrepancy.
MISO will be updating the BPM to match the Tariff language.
SUPPLY CHAIN ISSUES
How does MISO verify gas transmission system limitations, restrictions, supply chain?
MISO does not look at the ability to get coal or gas as a planned outage that should be exempt if sufficiently coordinated. Rather this is a risk that should contribute to the accreditation of a resource.
ZONAL RESOURCE CREDITS (ZRC)
If a Market Participant is in a FRAP and converts capacity to ZRCs and transfers those ZRCs to another Market Participant will all four seasons ZRCs have to be transferred at the same time?
No. Each season will essentially be a different auction. You will have to transfer the ZRCs in each season individually and just needs to occur before the auction.
Is there more than one opportunity to transfer ZRCs in MECT if circumstances change?
After the auction clears if a Market Participant needs to get replacement ZRC's they go through the non-Miso bilateral market.
If an MP offers a capacity resource into the PRA and it clears, then the MP status is changed from one entity to another entity who holds the ZRC replacement responsibility if that resource has a catastrophic event? Will it be the new MP entity or the entity that submitted the resources to the PRA prior to changing MP status?
The ZRC replacement obligation is with the MP that Converts the SAC to ZRCs. In this specific situation of catastrophic outages, the Tariff uses the term "may replace" not "must replace". If they do replace, they will be designated non-Resource Adequacy Requirement (RAR) and would not affect accreditation in the future. The "must offer" obligation for the cleared ZRCs remains with the original owner of the resource (operating company), the responsibility for the resource replacement should go to the operating company.
How does MISO verify gas transmission system limitations, restrictions, supply chain?
MISO does not look at the ability to get coal or gas as a planned outage that should be exempt if sufficiently coordinated. Rather this is a risk that should contribute to the accreditation of a resource.