Transmission planning remains hot topic for Planning Committee


The review process of regional and local transmission plans once again was a top item of discussion at Thursday’s Planning Committee meeting.

Mark Sims, manager – Interconnection Coordination, said progress is being made in striking an efficient balance between the large number, breadth and depth of data requests about projects that PJM receives and process. PJM is looking to maximize efficiency among staff and engineering time, computing time and the time spent face-to-face and virtually during the stakeholder meeting process.

“We’re working with transmission owners to improve data,” he said. Meanwhile, stakeholders are requesting information beyond that which typically is considered. “You’re asking us to do additional simulations, market efficiency simulation, what-if scenarios,” he said.

“Some of the discussion will be why is the information being requested, what is it being used for? When a request is more general, we can’t provide every PJM database, but a subset of that data may be useful,” he said. “We’re just looking for cooperation and participation in the overall effort.”

During the discussion, American Municipal Power presented a slide of topics for stakeholder review.

Members deferred one of the items presented for endorsement involving changes to Manual 14B, Regional Transmission Planning Process. Proposed language would update which voltage of a transformer is considered for ranking of units allowed to contribute to the cumulative ramping impact. Previously, a transformer was included if its highest terminal voltage level was greater than or equal to 500 kV. The proposed language would change to it being included if its lowest terminal voltage level is greater than or equal to 500 kV. The issue affects about 187 transformers.

Another change involves the pending integration of OVEC into PJM. It adds OVEC to the Western Region Locational Deliverability Area.

The committee endorsed changes to Manual 14A, New Services Request Process, and Manual 14E, Additional Information for Upgrade and Transmission Interconnection Projects, as well as to Manual 2, Transmission Service Request.

Also endorsed was a motion to close out the Designated Entity Design Standards Task Force and convert it to a subcommittee that will meet every two years.

The committee heard one first read, of changes to Manual 14A, New Services Request Process, to clarify language to match existing procedures.

Suzanne Glatz, director – Infrastructure Planning, announced a series of five meetings to be held over the next two months to engage stakeholders in considering changes to the Operating Agreement regarding cost containment. A proposal is expected to be made at the May 24 meeting of the Markets and Reliability Committee. The meetings are scheduled for Feb. 9, March 6, March 16, April 3 and April 27.

In other informational updates:

  • David Egan, manager – Interconnection Projects, explained how FERC Order 807 is applied to multiple entities connecting behind a single point of interconnection.
  • Jerry Bell of the Resource Adequacy Department presented changes to Manual 21, Rules and Procedures for Determination of Generating Capability.
  • The addition of reviews required to permit external generation to participate in PJM’s market as a pseudo-tied generator were discussed.
  • PJM presented changes to the Generation Deactivation page on

The next Planning Committee meeting is scheduled for March 8.