Below is a summary of the issues scheduled to be brought to a vote at the Markets and Reliability Committee on Thursday. Each item is listed by agenda number, description and projected time of discussion, followed by a summary of the issue and links to prior coverage in RTO Insider.
RTO Insider will be in Wilmington covering the discussions and votes. See next Tuesday’s newsletter for a full report.
Markets and Reliability Committee
2. PJM Manuals (9:40-9:55)
Members will be asked to endorse the following manual changes:
A. Manual 01: Control Center and Data Exchange Requirements — Major update and reorganization to Section 5 introducing definitions of two major data types: System Control and Monitoring (Instantaneous) and Billing (Accumulated). Also updates references to OASIS and adds requirements regarding synchrophasor data exchange.
B. Manual 13: Emergency Operations — Includes administrative changes, clarifications and updates. Adds reference to Manual 12 for member actions when PJM loads 100% synchronized reserves and a reference to the instantaneous reserve check process.
3. CAPACITY PERFORMANCE (9:55-10:45)
A. Manual 18: PJM Capacity Market — Updates the manual to incorporate Capacity Performance. Includes clarifications on non-performance assessments, acceptable replacement resources for CP and Base Capacity commitments, the CP effective date for Fixed Revenue Resource entities and the physical option for non-performance for FRR entities. (See PJM Delays Vote on Capacity Performance Rules.) Members endorsed an update to Section 4.8 of the manual regarding credit requirements at a special MRC meeting July 15. Relevant forms have been posted for member use.
B. Manual 20: PJM Resource Adequacy Analysis — Changes related to the determination of limited-availability resource constraints under Capacity Performance. Because Capacity Performance rules allow participation of limited availability resources for the 2018/19 and 2019/20 delivery years, constraints must be established on Base Capacity DR and Base Capacity generation to ensure reliability. Details of the constraint computation methodology were added as Section 6.
4. FERC Order 1000 Proposal Fee Update (10:45-10:55)
Members will be asked to approve a two-tiered fee schedule for proposed transmission projects. For greenfield projects or upgrades between $20 million and $100 million, PJM will assess $5,000 to cover its study expenses. Projects costing at least $100 million will be charged $30,000. Previously, a $30,000 fee for all projects greater than $20 million had been approved, but planners later realized they likely wouldn’t need to collect that much. (See PJM Lowers Proposed Tx Project Study Fee.)
5. MERCHANT NETWORK UPGRADE (10:55-11:10)
New tariff language is being proposed to more accurately reflect how PJM processes requests for merchant network upgrades. The changes address definitions, queue entry, agreements and the capacity market.
6. TIMING OF REPLACEMENT CAPACITY TRANSACTIONS (11:10-11:25)
Manual changes would allow market participants to enter replacement capacity transactions earlier than Nov. 30 prior to the start of the delivery year if the need is linked to a physical reason that would prevent a participant from meeting its commitment. The changes prohibit generation that is replaced early from being recommitted for the delivery year. (See Earlier Replacement Capacity Transactions Approved.)
7. MARKET DATA CONFIDENTIALITY CLARIFICATIONS (11:25-11:40)
Members will be asked to approve a problem statement and issue charge designed to relax confidentiality rules regarding uplift payments and generator outages. Stakeholders have requested more granular data, especially following severe weather events. Current rules allow the release of aggregate market data only if it includes information about at least three market participants and it is no more specific than a PJM transmission zone. PJM also is prohibited from releasing data that already has been made public elsewhere. As a result, it’s unable to be more specific about such issues as conditions surrounding weather events, closed-loop interfaces and transmission planning. PJM also is offering a proposed solution. (See PJM Considering Release of Uplift, Outage Data.)
8. REGULATION MARKET ISSUES (11:40-12:00)
The Independent Market Monitor will seek approval of a problem statement and issue charge on concerns that PJM is buying too much fast-responding RegD resources in the regulation market. The initiative also will consider changes to the marginal benefit factor that defines that substitutability between RegA and RegD megawatts, which the Monitor says is faulty. (See PJM Market Monitor: Faulty Marginal Benefit Factor Harming Regulation.)
9. MARKETS RELATED GOVERNING DOCUMENTS UPDATE (12:45-1:00)
The PJM Law Department is proposing an initiative to clean up language in the RTO’s governing documents that is “ambiguous, incorrect or requires clarification.” PJM’s proposed problem statement and issue charge would assign the task to the Market Implementation Committee, separating it from an effort already underway involving the Tariff Harmonization Senior Task Force. (See PJM Law Proposes Cleaning up Language in Governing Documents.)
10. FTR/ARR TASK FORCE (1:00-1:15)
Old Dominion Electric Cooperative will seek approval for a proposal that combines recommendations from PJM and the Independent Market Monitor in redesigning the financial transmission rights and auction revenue rights process. (See ODEC Seeks Last-Ditch Vote on Deadlocked FTR/ARR Issue.)
11. TARIFF HARMONIZATION SENIOR TASK FORCE (1:15-1:30)
Members will be asked to approve seven revised definitions, the first batch of changes from the task force. (See Task Force Proposed to Resolve Inconsistencies in PJM Governing Documents.)
— Suzanne Herel