Stakeholders look at NERC, FERC standards

1271

Another periodic roundup of action and updates from PJM subcommittees and senior task forces.

Primary Frequency Response Senior Task Force

The Federal Energy Regulatory Commission’s recent final rule on primary frequency response will have minimal impact on the current work of the Primary Frequency Response Senior Task Force, PJM said at the Feb. 28 task force meeting.

Jim Burlew, PJM senior counsel, indicated that the regulations in Order 842 apply to newly interconnecting large and small generating facilities, both synchronous and non-synchronous, and to facilities that execute a new Interconnection Services Agreement after the enforcement date. The facilities must install, maintain and operate equipment capable of providing primary frequency response as a condition of interconnection.

The changes are designed to address the potential reliability impact of the evolving generation resource mix. Reliable operation of the grid requires maintaining system frequency as close to 60 hertz as possible.

Primary frequency response involves the rapid, automatic and autonomous actions of generating facilities to arrest and stabilize frequency deviations and allows the interconnected grid to maintain frequency within acceptable boundaries following the sudden loss of generation or load.

Danielle Croop, PJM senior engineer – Operation Analysis & Compliance, reviewed updates on the performance assessment process for primary frequency response.

PJM will reserve the right to perform performance assessments between 20 and 30 times a year and will aim to find two to three frequency events per month for performance assessments. System conditions may provide fewer opportunities, however, and there will be no prearranged set number of events. It will be a pass/fail assessment based on a 12-month rolling average.

Tom Hauske, senior lead engineer – Operation Analysis & Compliance, presented a revised PJM position on cost recovery. Updates include no cost recovery for new or upgrading units (for new ISAs). A one-time cost recovery would be allowed for existing units to perform capital improvements in order to provide primary frequency response.

Monitoring Analytics, PJM’s independent market monitor, provided additional details on its position for cost recovery.

PJM and stakeholders provided updates to the solutions matrix. PJM also offered examples of exemptions from primary frequency response requirements. The task force is moving toward a vote on these issues following its March 21 meeting.

Dispatcher Training Subcommittee

All member transmission companies are in compliance with PJM training and certification requirements, the Dispatcher Training Subcommittee reported at its monthly meeting Feb. 20. In addition:

  • Three generation companies are noncompliant with training requirements, compared with four the previous month.
  • Three generation companies are noncompliant with certification requirements, compared with four the previous month.
  • One small-generation company is noncompliant with training requirements, compared with none the previous month.
  • One solar power company is noncompliant with training requirements, compared with none the previous month.

The spring restoration drill will take place May 15–16, with May 22–23 being held as a back-up date.

Members were invited to submit items for future meetings regarding the new human performance component for dispatcher training. The Operating Committee on Feb. 6 officially added that topic to the subcommittee’s charter for regular discussion.

System Operations Subcommittee

Distributed energy resources are proliferating at such a pace that “ride through” requirements for these small generators are becoming essential, Andrew Levitt, senior market strategist – Emerging Markets, told the System Operations Subcommittee at its March 1 meeting.

The term “ride through” refers to the capability of a generator to remain connected to the grid for up to a few seconds during abnormal conditions such as significantly high or low voltage or frequency. Requiring generators to stay connected during a disturbance is essential to the reliability of the bulk electric system, Levitt said in his presentation.

Most DER currently lacks a ride-through requirement.

The IEEE has been studying the issue and has prepared a draft revision of its technical standard to incorporate DER. It is, however, available only through purchase only for $145 from the IEEE Standards Store.

PJM supports establishing these new requirements. It has been discussing with transmission owners the interaction of the new standard with transmission fault clearing times and other bulk electric system considerations and met with four utilities on February 28 for a day-long workshop

Chidi Ofoegbu, senior engineer – Outage Analysis Technologies, delivered the eDART status update, noting that the new instantaneous reserve check stats report slated as a future enhancement has been pushed back to the second quarter of 2018. She encouraged anyone with questions or suggestions for the refresh team to contact her.

Preston Walker, senior analyst – Reliability Compliance, reviewed North American Electric Reliability Corporation standards that are under development and issued a reminder that the System Operator Certification Program Survey is due by March 15.

Stakeholders also heard the operations summary and second reads for updates to Manual 37, Manual 03A and Manual 01 .