The Operating Committee last week approved changes to manuals 1 and 12, while the Planning Committee received a presentation on proposed changes to Manual 21 and the Market Implementation Committee heard a first reading on changes to Manual 28.
Manual 1: Control Center and Data Exchange Requirements
Reason for change: New rules for access to PJM Energy Management System (EMS).
Impacts:
- Added new section 2.5.7 detailing rules for transmission owner read-only access to PJM’s EMS. No screen scraping is allowed.
- Modified section 3.2.3 to clarify procedures for data communication outages.
- Modified section 4.2.4 to clarify repeating of All Call messages.
- Adds details to Information Access Matrix in Attachment A.
Next Step: Vote by Markets and Reliability Committee.
Manual 12: Balancing Operations
Reason for change: PJM is changing the regulation requirement to align it with operational needs and address volatility in light load periods.
Impacts:
- Changes On-peak (05:00-23:59) requirement to 700 effective MW, a decrease in the requirement for 52% of days, an increase for 48% of days. Net daily decrease of about 60 MW (section 4.4.3).
- Changes Off-peak (00:00-04:59) requirement to 525 effective MW, an increase for 66% of days and a decrease for 34% of days. Net daily increase of about 20 MW (section 4.4.3).
- Changes regulation scoring methods:
- Performance scoring for small regulation allocation: Historical performance scores will be used if the control signal has an average absolute value less than 1% of the regulation assignment (section 4.5.6)
- Performance scores when data is not available: Historical performance scores will be used if data is not available and for intervals less than 15 contiguous minutes (adds section 4.5.9)
- Regulation Assignments: Scoring will be suspended for 10 minutes after assignment to allow time to ramp into position (adds section 4.5.10).
Next Step: Vote by Markets and Reliability Committee.
PJM contact: Rus Ogborn
Manual 21: Rules and Procedures for Determination of Generating Capability
Reason for change: Clarifying ambiguous language, updating terms.
Impacts:
- Clarifies that intermittent resources (wind, solar) are not required to perform seasonal verification tests because their capacity credit calculation is used in place of a ratings test.
- Clarifies that all generators, except hydro, pumped storage and diesel units, are required to adjust rating test results for expected cooling water and ambient air conditions.
- Hydro and pumped storage units must perform their annual ratings test during the summer verification window and are not required to perform a winter test.
Next Step: Vote at next Planning Committee meeting.
PJM contact: Tom Falin
Manual 28: Operating Agreement Accounting
Reason for change: Incorporating changes to lost opportunity cost compensation as approved by FERC.
Impacts:
- Changes sections 5.2.6 and 5.2.8 (Operating Reserve & Reactive Services Lost Opportunity Cost Credits) to limit lost opportunity cost compensation to the lesser of a unit’s economic maximum or maximum facility output as approved in FERC Docket ER13-1200.
- Section 7.2 (Shortage Pricing) amended to incorporate calculation details for non-synchronized reserve market lost opportunity costs.
- Modifies section 5.3 (Operating Reserve) to correct errors and provide clarifications on exempting deviations during shortage conditions and revisions for associating interfaces to the East or West BOR regions.
- Modifies sections: 5.2.3 to incorporate details of Lost Opportunity Cost Credit for Synchronous Condensing; 5.2.6 (Wind Lost Opportunity Cost) to align language with Tariff; 17.3 (Allocation of Annual and Monthly FTR Auction Revenues) to correct section reference.
Next Step: Vote at next MIC meeting.
PJM contact: Suzanne Coyne
