Planning Committee looks at RTEP process enhancements


Members heard the process behind PJM’s Do No Harm assessment performed for projects in the Regional Transmission Expansion Plan at the Planning Committee meeting March 8.

Aaron Berner, manager – Transmission Planning, explained the purpose is to: assess for reliability issues caused by new upgrades; determine if new upgrades need to be more robust or less; and, as needed, evaluate and assess the cost efficiencies associated with an entire package of upgrades needed to mitigate reliability criteria. He said that PJM doesn’t want to make an upgrade only to find it needs to make a second upgrade a short time later.

Additionally, Berner discussed how PJM plans the system more efficiently through consideration of multiple upgrades that alleviate an issue that might be able to be solved by incorporating a single, larger upgrade in the RTEP. He explained that if one large project can solve the problem of three smaller upgrades, the cost effectiveness of the larger solution may make it a better choice.

A stakeholder presentation followed, examining a variety of areas including standardizing timeframes.

Berner also discussed how PJM is moving forward with revisions for the Transmission Expansion Advisory Committee (TEAC), the RTEP and the sub-regional RTEPs. Berner presented stakeholder feedback to the review process of the regional and local RTEPs, including those conducted at the TEAC and sub-regional RTEP committees.

While some stakeholders have requested detailed information on projects, some concerns accompany providing those details, including avoiding breaches of vital critical electric infrastructure and confidential information.

PJM is striving to improve transparency in the planning process while not revealing proprietary information. One of the tools to do that is the Planning Community. Berner said that PJM is looking to expand its use and will conduct additional education to help stakeholders better use the tool.

Earlier, stakeholders peppered Jerry Bell, senior lead engineer – Resource Adequacy Planning, with questions about the scope of proposed revisions to Manual 21: Rules & Procedures for Determination of Generating Capability.

Their concerns center on whether the revision language is broader than just Planning, encompassing Operations and Markets, as well. Ken Seiler, executive director – System Planning and chair of the committee, told stakeholders that he would discuss their concerns with the Operations and MIC teams before the March 22 Markets & Reliability Committee, where the language is scheduled for a first read.

Dave Egan, manager – Interconnection Projects, presented updated manual language for separating Manual 14A: New Services Request Process into two manuals with the addition of a new Manual 14G: Interconnection Requests and PJM Queue Position. The language covers System Impact Study costs, transition queue language, expedited/combined study requirements, and the FERC Order 807 requirements for multiple entities connecting behind a single point of interconnection.

Members looked at the draft charter for the Market Efficiency Process Enhancement Task Force. The group will review, evaluate and recommend any necessary solution(s) for:

  • Benefit-to-cost calculation
  • Facility Service Agreement modeling
  • Market efficiency window
  • Interregional market efficiency project selection process
  • Market efficiency reevaluation process
  • Regional target market efficiency project
  • Market efficiency mid-cycle assumption update

Other Committee Business

  • First read of revisions to Manual 14A: New Services Request Process


  • Revisions to Manual 14B: Regional Transmission Planning Process(periodic review, including a revision to the generator deliverability procedure)
  • External capacity filing (addition of reviews required to permit external generation to participate in PJM market as a pseudo-tied generator)

Informational Updates