Below is a summary of the issues scheduled to be brought to a vote at the Markets and Reliability and Members committees 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 (9:10-9:30)
Members will be asked to endorse the following manual changes:
A. Manual 11: Energy & Ancillary Services Market Operations — Adds a method for screening of demand bids by load-serving entities. Bids would be limited to the LSE’s calculated zonal peak demand reference point for the day plus whichever value is more, 30% of the reference point or 10 MW. PJM said the need for such limits was illustrated by the default of a retail provider in January 2014. Due to an input error, the company entered a demand bid about 100 times the retailer’s actual load. (See MIC Briefs.)
B. Manual 12: Balancing Operations — Revisions describe the required regulation range, specifying that resources are required to symmetrically provide the total amount of regulation assigned. The changes also detail how performance evaluations are conducted and further define the basepoint around which the resource will be regulating.
3. FTR REVISIONS (9:30-9:45)
Members will be asked to approve non-substantive revisions regarding financial transmission rights. The changes concern clearing deadlines, bilateral trades and Tariff references.
4. ENERGY MARKET UPLIFT SR. TASK FORCE (9:45-10:15)
Members will be asked to endorse revisions to rules regarding treatment of combustion turbine lost opportunity costs and a proposal that uplift be treated as an input to the Regional Transmission Expansion Plan. Under the new CT rules, PJM would use the generator’s energy schedule to calculate opportunity costs except for self-scheduled units, for which the lesser of the available cost- or price-based curves would apply.
5. DEMAND RESPONSE Forecast for Use in RTEP (10:15-10:30)
Members will be asked to OK a proposed change to demand response modeling assumptions used in load deliverability analyses. The new method would use the average of the last three years of committed DR for each zone. (See Change Proposed in PJM Demand Response Modeling.)
6. FERC Order 1000 (10:30-10:45)
Members will be asked to endorse a $30,000 non-refundable fee for studying proposed transmission improvements with estimated costs of $20 million or more. The fee would apply to both greenfield projects and upgrades by incumbent transmission operators. The Federal Energy Regulatory Commission last month rejected an earlier proposal to exempt transmission upgrades from the study fee. (See FERC Rejects Fee on Greenfield Transmission Projects.)
Members Committee
CONSENT AGENDA (1:20-1:25)
B. Members will be asked to approve Tariff and Operating Agreement revisions to implement Coordinated Transaction Scheduling (CTS) with MISO. The objective is to improve interchange scheduling efficiency by aligning energy scheduling with interface prices and adding the option for market participants to schedule energy transactions using an interface bid. (See PJM, MISO Reach Agreement on New Interchange Product.)
ENDORSEMENTS (1:25-1:40)
1. FERC Order 1000: See MRC agenda item #6, above.
— Suzanne Herel