Planning Committee Looks at Wind and Solar Resource Capabilities

  • PJM presents effective load carrying capability (ELCC) analysis and study results
  • Distributed Energy Resource Ride-Through Task Force effort endorsed
  • TEAC looks at generator deactivations

Effective Load Carrying Capability Analysis and Study Results

As part of its continuing look at the integration of renewable energy into the interconnection system, PJM has been examining effective load carrying capability (ELCC).

The methodology determines the contribution that an individual generator or a fleet of generators makes to overall system resource adequacy. Specifically, ELCC is a measure of the additional load the system can supply with the particular generator(s) of interest, without a change in reliability.

Patricio Rocha-Garrido, senior engineer – Resource Adequacy Planning, took stakeholder questions and feedback as he presented analysis and study results on wind and solar resources at the Planning Committee meeting on Nov. 8. The presentation was a follow-up to the introductory ELCC presentation at the September Planning Committee meeting.

PJM’s original objective was to calculate the effective load carrying capability of wind resources to support a change to the current wind-capacity credit calculation. The change uses the median instead of the mean performance of wind units over peak summer hours to calculate ELCC.

After PJM presented the ELCC results in September, stakeholders showed interest in the overall methodology, and PJM expanded the calculations to include solar resources. In addition, PJM moved the analysis from calendar year to delivery year.

Rocha-Garrido said that PJM looked at some of Mid-Continent ISO’s calculations for its wind analysis, as well as nine years of wind data and six years of solar data. He took stakeholders through the analytical steps, reviewing the pros and cons of three options to allocate the system-wide ELCC to both new and existing resources.

Rocha-Garrido pointed out that PJM is not advocating for any of the three options. PJM and stakeholders will determine how to proceed based on the information they gather.

PJM and stakeholders will examine the effect of changes to ELCC on the loss-of-load expectation and how these changes might impact a resource’s Reliability Pricing Model (capacity market) offer.

PJM is seeking further stakeholder feedback through December before it presents a first read of proposed changes to manual language at the January Planning Committee meeting. There will be a special Planning Committee meeting on Nov. 26 from 9–11 a.m. to discuss ELCC further.

Distributed Energy Resource Ride-Through Task Force Effort Endorsed

Stakeholders endorsed by acclamation the problem statement and issue charge for the Distributed Energy Resources (DER) Ride-Through Task Force. The new task force will implement part of the new IEEE standard 1547-2018 for DER interconnection. Emanuel Bernabeu, director – Applied Innovation & Analytics, who reviewed the presentation, had presented detailed education to stakeholders at the October Planning Committee meeting.

Cost Commitment Efforts Continue

Mark Sims, manager – Infrastructure Coordination, gave a monthly report on the cost commitment effort to develop and roll out an effective construction cost comparative framework. PJM continues to work on developing the overall framework, explaining the process by breaking it down into modules.

PJM has a joint meeting with Monitoring Analytics scheduled in November to begin the detailed technical cost and financial analysis mapping. Work will also include assuring that the cost containment steps can integrate into the overall decision process for PJM’s Regional Transmission Expansion Plan.

Progress on Order 841 – Electric Storage

Andrew Levitt, senior business solution architect, discussed PJM’s compliance with Federal Energy Regulatory Commission Order 841 with respect to behind-the-customer-meter electric storage resources and resilience electric storage resources.

Other Committee Business 

Transmission Expansion Advisory Committee

PJM and stakeholders looked at a number of generator deactivations Thursday, including the possible consequences of FirstEnergy’s Thursday announcement that it will accelerate the deactivation of two units at its Bruce Mansfield coal-fired power plant in Western Pennsylvania.

FirstEnergy announced on Thursday that Units 1 and 2 at the plant would close in February 2019. In August, it said it would deactivate all three of Bruce Mansfield’s generators in June 2021; the schedule for Unit 3 remains unchanged. The company previously announced the closing of several nuclear plants by 2022.

Planning will study the accelerated deactivation and coordinate with Operations to determine if PJM will be able to accommodate the earlier retirement through a combination of accelerating upgrades and potential operating procedures in the interim.

Jason Connell, manager – System Planning Modeling and Support, reviewed the recommended solutions for the generation deliverability concerns in the Allegheny Power, American Electric Power, Pennsylvania Electric and Duquesne transmission zones.

Other TEAC Business

PJM also reviewed the market efficiency re-evaluation analysis and acceleration analysis. The 2018–2019 Long-Term Market Efficiency Window opened on Nov. 2.

During the reliability analysis update, Aaron Berner, manager – Transmission Planning, looked at the 2018 Regional Transmission Expansion Plan baseline recommended solutions to a high-voltage issue in Dominion and a stability criteria violation in ComEd. Berner also said PJM is working through a number of topics, including a 15-year analysis, with more information available next month.

Stakeholders also heard presentations on the interregional planning update and the continued improvements to that have garnered praise from stakeholders.