1. General Understanding of Operating Procedure-5 Resource Maintenance and Outage Scheduling Demand Response Resources Outage Coordination July 1, 2019| Holyoke MA

2. Purpose • Under PRD, active demand resources receive comparable treatment to generators, this includes requirements to report and coordinate outages • The goal of this presentation is to deliver key information for demand response providers on how and when to coordinate outages with their Local Control Centers and the ISO • This presentation reviews the types of outages, procedures to reference, scheduling requirements, timelines, and contact information

3. OP-5 Resource Maintenance and Outage SchedulingTypes of Outages: • Planned Outage (PO) • An outage that is scheduled in advance and has a predetermined duration, typically for the purpose of performing annual maintenance, scheduled at least 15 days in advance and up to 730 days in advance • Maintenance Outage (MO) [Classified as Short Term Outage in software] • An outage of a Generator or DARD to be removed from service within 14 calendar days which: • Can occur any time during the year • Has a flexible start date • May or may not have a predetermined duration • Typically shorter than a PO • Overrun Planned Outage (OPO) • An overrun of a PO and considered a type of MO throughout the procedure • Forced Outage (FO) • An outage or inability, in whole or in part, of a generator or DARD to provide its Claimed Capability or Nominated Consumption Limit (NCL) that has not been approved by the ISO in the form of a PO or MO

4. OP-5 Resource Maintenance and Outage Scheduling An MP shall submit a request for a PO, MO or OPO when: • the outage impacts the Capacity Supply Obligation (CSO) of the associated capacity resource; • the request is associated with a generator without a CSO that is a Qualified Generator Reactive Resource under Schedule 2 of the OATT; • the DRR is for 5 MW or more and results in the associated Active Demand Capacity Resource (ADCR) falling short of its CSO by 5 MW or more (the DRR is the unit that is dispatched in the energy market, but the ADCR has the CSO); or • the outage would reduce the ability of a DARD to interrupt without reducing its load by a corresponding amount

5. OP-5 Resource Maintenance and Outage Scheduling An MP shall: Submit an outage request for a DRR if the DRR’s offered Maximum Reduction will be reduced by 5 MW or more, the DRR is associated with an ADCR, and the impact of the DRR’s reduced availability will result in the associated ADCR falling short of its CSO by 5 MW or more, the MP shall be required to report the outage to ISO. (The Maximum Reduction to be used shall be for the expected peak hour of the Operating Day.)

6. OP-5 Resource Maintenance and Outage Scheduling An MP shall: Submit an outage request for a DRR when there is more than one DRR associated with an ADCR, the impact from the reduced availability of a DRR on the ADCR’s CSO is determined by summing the offered Maximum Reductions of all of the DRRs that are associated with that ADCR. If the sum of the offered Maximum Reductions of all the DRRs associated with the ADCR will fall short of the CSO by 5 MW or more, and if a single DRR’s Maximum Reduction will be reduced by 5 MW or more, the MP shall be required to report the outage to ISO. (The Maximum Reduction to be used shall be for the expected peak hour of the Operating Day.)

7. Submitting an PO, MO or OPO Request Submit OP-5 Appendix B – Outage Request Form to opamoreq@iso-ne.com and GenerationOutageCoor@iso-ne.com or Calling the generation outage coordinator at (413) 535-4378 from 0700 hours to 1600 hours or Calling the forecaster by telephone at (413) 535-4340 from 1600 hours to 0700 hours

8. Requesting Implementation of an Outage For a DRR, a request for implementation of a PO, MO or OPO shall be entered in eMarket as the DRR’s bid parameters reflecting the implemented PO, MO or OPO The DRR’s bid will be the notification to ISO of implementing an outage

9. Notifying ISO of a Forced Outage For a DRR, a Forced Outage shall be entered in eMarket as the DRR’s bid parameters reflecting the implemented outage If the Forced Outage will extend past the current operating day, inform the Generation Coordinator or Forecaster as described in slide 7 The DRR’s bid will be the notification to ISO of implementing an outage

10. Notifying ISO of Return to Service For a DRR, the notification of return of service after the outage shall be entered in eMarket as the DRR’s bid parameters reflecting the return of service If the outage will extend past the current operating day, inform the Generation Coordinator or Forecasteras described in slide 7 The DRR’s bid will be the notification to ISO of implementing an outage

11. Resource Outage Coordination Process • Resource outage plans are submitted to the Local Control Center (LCC) by the Lead Participant; the outage request is assigned an outage ID and a priority • The LCC conducts preliminary reliability assessment and must approve the request prior to ISO review • Approved resource outage requests are then submitted to the ISO • ISO Long-Term outage coordinators will: • Conduct a reliability study on each outage request within 10 days (Long-Term) of receipt and place the outage request in the state of “Interim Approved”, “Denied,” or “Negotiate” • Review includes assessment of: • Operational capacity (local and system-wide) • Impact on transmission operation • Opportunity to reposition the outage to minimize reliability or economic impacts • Results posted to Annual Maintenance Schedule (AMS)

12. Outage Coordination Timelines

13. Annual Maintenance Schedule Report conveysCapacity, Forecasted Load and Margin https://www.iso-ne.com/isoexpress/web/reports/operations/-/tree/ann-mnt-schd

14. Resource Restriction Notification • The results of the ISO studies are communicated to affected parties and overall stakeholders within the constraints of the ISO New England Information Policy. • Who • Notification is sent to the generator operator/market participant • When • Long Term: • At the time in which a transmission or generation outage request is placed into the Interim Approved Status • Short Term: • At the time in which a transmission or generation outage request is placed into the Approved Status • Where • The contact information is captured in the Customer Asset Management System (CAMS) and the Outage Scheduling Tool • How • Communicated via email or phone and annotated in the outage scheduling tool

15. ISO-NE Procedure References Outage Coordination procedures and where to find them

16. Outage Coordination Procedures • ISO New England Operating Procedures (OP) • OP2 – Maintenance of Communications, Computers, Metering, and Computer Support Equipment • OP3 – Transmission Outage Scheduling • OP5 – Resource Maintenance and Outage Scheduling • OP19 – Transmission Operations • OP24 – Protection Outages Settings and Coordination • Master Local Control Center Procedures (MLCC) • MLCC 7 – Processing Transmission Outage Applications • System Operating Procedures (SOP) • SOP-OUTSCH.0030.0020 - Perform Short-Term Outage Coordination • SOP-OUTSCH.0030.0025 - Perform Long-Term Outage Coordination – Transmission • SOP-OUTSCH.0030.0040 - Perform Generation Outage Coordination – Long Term • SOP-OUTSCH.0030.0065 - Perform Short-Term Economic Evaluation • SOP-OUTSCH.0030.0070 - Perform Long-Term Economic Evaluation

17. Outage Coordination Procedures • http://www.iso-ne.com/participate/rules-procedures/operating-procedures