PJM stakeholders unanimously endorsed two manual changes at the Oct. 8 Operating Committee meeting.

Darrell Frogg, senior engineer of generation for PJM, reviewed updates to Manual 14D: Generator Operational Requirements.

Frogg said section 7.5.1 was changed to reflect that cold weather operational exercises will no longer be administered by PJM and instead be handled by generation owners. The RTO is recommending that generation owners self-schedule testing of resources that have not operated in eight weeks leading up to Dec. 1.

One change was made from the first read in September, Frogg said. Section 7.3, critical information and reporting requirements, calls for providing notification to PJM dispatchers at least 20 minutes prior to a change in state of each generating unit and will include any changes of more than 50 MW to the output of a self-scheduled resource that is not following the security-constrained economic dispatch (SCED) basepoint. Frogg said the change resulted from stakeholder questions.

Vince Stefanowicz, senior lead engineer of generation, reviewed updates to Manual 10: Pre-Scheduling Operations in a periodic review. The changes include several clarifying changes but nothing substantive, he said.

Stefanowicz said minor changes were made from the first read, including replacing the term “eDART Installed Capacity (eDART ICAP)” with the term “eDART Reportable MW” in Section 2.1, generation outage reporting overview. Stefanowicz said several stakeholders expressed concern over possible confusion with the capacity market term of ICAP.

Both manual updates will go to the Oct. 29 Markets and Reliability Committee meeting for first reads and final endorsements in November.

Day-ahead Schedule Reserve Update

David Kimmel, senior engineer of performance compliance, reviewed the preliminary proposed changes to the 2021 day-ahead scheduling reserve (DASR) requirement. He said the numbers may slightly change when the measure is brought for final endorsement in November.

The DASR is the sum of the requirements for all zones within PJM and any additional reserves scheduled in response to a weather alert or other conservative operations. It is the sum of the three-year average of under-forecasted load forecast error (LFE) and the three-year average of eDART forced outages.

Kimmel said the preliminary 2021 DASR requirement is 4.78%, slightly lower than the 2020 requirement of 5.07%. He said the number comes from the LFE component of 2.18% and the forced outage component of 2.6%.

Stakeholders will be asked to endorse the changes at the next OC meeting. The final 2021 DASR value will be incorporated into Manual 13 changes and be implemented in January.

Manual First Reads

Stakeholders heard several first reads of minor manual changes.

Maria Baptiste of PJM reviewed updates to Manual 3A: Energy Management System Model Updates and Quality Assurance. Baptiste said the changes include correcting grammatical mistakes and updating references to the behind-the-meter generation (BTMG) rules that took effect in September 2019. (See “Non-retail BTM Generation Rules Endorsed,” PJM MRC/MC Briefs: Sept. 26, 2019.)

Lagy Mathew of PJM reviewed updates to Manual 3: Transmission Operations. Mathew said the changes featured minor clarifications, including defining the term “extra-high voltage (EHV)” lines as those equal to or greater than 345 kV.

Kevin Hatch of PJM reviewed updates to Manual 12: Balancing Operations to address changes from the five-minute pricing and dispatch Market Implementation Committee special sessions. Hatch said PJM has been working with the Independent Market Monitor to identify sections of Manual 12 to be updated and to improve transparency on the dispatch process.

Hatch said the changes include updated terminology for “day-ahead market” instead of the outdated “two-pass system.”

Stakeholders will be asked to endorse the changes at the November OC meeting.