Below is a summary of the issues scheduled to be brought to a vote at the Markets and Reliability Committee this 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, Del., covering the discussions and votes. See next Tuesday’s newsletter for a full report.

2. PJM Manuals (9:10-9:25)

Members will be asked to endorse the following manual changes:

1. Manual 10: Pre-Scheduling Operations. The changes define a generator planned outage and restrict scheduling planned outages during peak maintenance season; define generator maintenance outage; define unplanned outage and clarify notification requirements; and correct the definition of non-synchronized reserve.
2. Manual 11: Energy & Ancillary Services Market and Manual 28: Operating Agreement Accounting. Changes reflect Tariff revisions approved by FERC regarding the energy market offer cap that went into effect Monday (ER16-76). Cost-based offers for incremental energy are capped at $2,000/MWh and allowed to set prices. Costs above that cap will be recovered through an after-the-fact review and make-whole payments. Market-based offers for individual units are allowed to rise with their cost-based offers. (See PJM Members OK $2,000/MWh Energy Market Offer Cap.)
3. Manual 14D: Generator Operational Requirements. Revisions reflect the annual review of the manual as well as revisions to the reactive testing process. Revises and renames the wind farm communication model, making it applicable to all jointly owned resources to avoid confusion among control room operators. Adds definitions of generator planned, maintenance and forced outages.
4. Manual 39: Nuclear Plant Interface Coordination. Updates are the result of a three-year review and include safe shutdown loading requirements developed by the nuclear generation owners user group.

3. LOAD FORECASTING ENHANCEMENTS (9:25-9:40)

The committee will be asked to approve changes to Manual 19: Load Forecasting and Analysis that will allow distributed solar generation to be included in the load forecast. (See “Distributed Solar to be Included in Load Forecast” in PJM Planning and TEAC Briefs.)

4. LOAD FORECAST UPDATE (9:40-10:00)

Members will be asked to endorse amendments to Manual 18: PJM Capacity Market and Manual 18B: Energy Efficiency Measurement and Verification to accommodate the inclusion of energy efficiency resources in the capacity market when those resources are reflected in the peak load forecast. (See “Members Ask for More Time to Consider EE Resource Manual Changes” in PJM Markets and Reliability Committee Briefs.)

5. UNDERPERFORMANCE RISK MANAGEMENT IN RPM/CP (10:00-10:15)

Bob O’Connell, representing PPGI Fund A/B Development, will present a problem statement and issue charge related to underperformance risk management in the capacity market. It would evaluate ways for generators to minimize such penalties by netting them against over-performing generators. (See PJM Generator Risk Proposal Faces Resistance.)

6. DEMAND RESPONSE NON-SUMMER CAPACITY COMPLIANCE CLARIFICATION (10:15-10:30)

The committee will be asked to approve Tariff and manual revisions that clarify the process for establishing customer baseline load for non-summer demand response under Capacity Performance rules. (See “Members Endorse Method for Measuring Non-Summer DR” in PJM Market Implementation Committee Briefs.)