Mark Sims, manager – Infrastructure Coordination, said PJM continues to work with the independent market monitor on establishing a comparative framework for evaluating competitive transmission proposals.
Sims said that the overall base approach for the process is established. PJM and IMM staff are working closely to define the details and further develop the process.
He added one of the most challenging aspects is conceptualizing the data. It’s difficult to take different formats of data and narratives and work to blend them into a single normalized format and unit of measure.
Resilience in the RTEP Process
As part of PJM’s holistic look at role of resilience in the Regional Transmission Expansion Plan (RTEP) process, the, Aaron Berner, manager – Transmission Planning, reviewed the ongoing process of examining planning elements.
PJM is exploring three approaches to resilience in the RTEP: “Do no harm,” (in which projects are evaluated to ensure there is no loss of resilience), an opportunistic approach (in which projects are evaluated to see if resilience measures can be easily incorporated) and stand-alone resilience criteria (in which projects are initiated to solve resilience issues).
Each approach incorporates the development of a measurement that deviates from the baseline measurement of resilience metrics. Those measurements are then used to differentiate between the different types of reinforcements that are available to fix a single violation.
These resilience metrics would likely incorporate information on the amount of megawatt loss of load and generation under severe conditions of system casualties.
Berner said there are a number of elements to consider and, at present, PJM continues to refine the tools to be used in order to develop the amount of megawatt load and generation loss under various conditions. In conjunction with the refinement of the tools, PJM will work to explore aspects of how this analysis might be incorporated in future RTEP decisions.
PJM’s goal is to incorporate the procedures into its manuals by the end of 2019.
Other Committee Business
The committee delayed endorsing two items, both concerning interconnection of renewable resources.
The first was a problem statement and issue charge on inverter-based distributed energy resources ride through. Through the Institute of Electrical and Electronics Engineers’ 1547 standard, distributed energy resources (DER) are allowed to “ride through” abnormalities of grid voltage.
Ride-through requirements affect wholesale distributed energy resources that come through Federal Energy Regulatory Commission (FERC) interconnections (i.e., large interconnections such as industrial interconnections).
The vast majority of DER on the system are through state interconnections and the vast majority of that energy is retail, not wholesale.
There will be a workshop on the ride through on Oct. 1–2, as originally planned before the vote delay. Instead of being part of the stakeholder process, however, it will be an ad hoc meeting designed for transmission owners, distribution owners and state commission representatives.
The second was proposed changes to Manual 21: Rules and Procedures for Determination of Generating Capability and revolved around capacity interconnection rights. PJM took note of stakeholder concerns around different technologies for renewables, especially wind power.
Stakeholders debated the efficacy of methods used in determining effective load carrying capability, which is the methodology to determine how much of a contribution an individual generator or a fleet of generators makes to overall system resource adequacy.
- Review of results of the 2018 Installed Reserve Margin study
- Endorsed changes to Manual 14F: Competitive Planning Process related to cost containment
- Preliminary 2019 project budget
- Contact Management update
- Special assessment by the North American Electric Reliability Corporation on accelerated generation retirements
- Update on current model build activities
- Reliability compliance update