Frequency Response
Operating Committee Meeting
February 9, 2016
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Agenda
• Frequency Response Communications
• NERC Industry Advisory Review
• Frequency Response in System Restoration
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Frequency Response Communications
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PJM initial GO Governor Survey: 12/2013
NERC Advisory on Generator Governor Frequency Response issued: 2/5/2015
FERC issued a Notice of Proposed Rulemaking to allow Third Party Provision
on Primary Frequency Response Service: 2/19/15
NERC Webinar on Frequency Response: 4/7/2015
Manual M14D, Section 7.1.1 - Added generator governor and distributed control
system dead band and droop setting requirements consistent with the NERC
Advisory: 5/1/2015
Summary of Frequency Response Performance (BAL-003-1) and 2015
Generator Governor Survey: 1/2016.
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Frequency Response Communications
New Governor Survey issued February 2016
• PJM conducting to improve response rate and clarify responses
PJM Governor Survey Question Types:
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Does the unit have a governor and is it enabling frequency response
Governor Dead Band Setting / Droop Setting
Provide reasons if NERC Advisory / PJM Manual M14D criteria not able to be met
Governors operated in a mode which allows generator to respond to frequency
deviations (Manual M36 Section 6.1.7)
Survey Timing & Response Method:
• PJM sent surveys to GOs via eDART on 2/5/2016
• Survey responses from GOs due 3/4/2016
• Pre-populated where possible, Bulk XML upload, copy-forward options available
Governor Response Survey Summary & Next Steps: May 2016
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NERC Industry Advisory Review
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NERC Resources Subcommittee has determined that a significant portion of the
Eastern Interconnection generator dead bands or governor control settings inhibit
or prevent frequency response.
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Generator Owners and Operators should communicate governor settings and
other important governor control system data to their Balancing Authority and
Transmission Planning Authority to ensure accuracy of PJM & NERC models.
– Advisory issued February 5, 2015
– Generating resources with gross plant / facility aggregate nameplate rating
greater than 75 MVA excluding nuclear generators.
– Governor dead bands do not exceed +/- 36 mHz, droop setting does not
exceed 5%.
– Link to NERC Advisory:
http://www.nerc.com/pa/rrm/bpsa/Alerts%20DL/2015%20Alerts/NERC%20Alert%20A-2015-02-0501%20Generator%20Governor%20Frequency%20Response.pdf
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NERC Industry Advisory Review
PJM Manual M14D revised effective May 1, 2015 to include advisory
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Excerpt from, M14D, Section 7.1.1 – Generator Real Power Control
“With exception of nuclear generators, all generating resources with gross plant / facility
aggregate nameplate rating greater than 75 MVA are requested to ensure that, in the
absence of technical or operational considerations, the generator governor and Distributed
Control System (DCS) settings provide dead bands that do not exceed +/- 36 mHz, and
droop settings that do not exceed 5%. Should a generating resource be unable to meet
these criteria, the generating resource’s actual settings and reasons for being unable to
meet these criteria shall be forwarded to PJM.”
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Frequency Response in System Restoration
• M-12 Balancing Operations, Section 4.6.10 Black Start
Performance Standards
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The capability to maintain frequency under varying load. This may be demonstrated by (a)
picking up an isolated block of load, or (b) by appropriate dynamic off-line testing of the
governor controls.
• M-36 System Restoration, Section 6.1.7 Blocking Governors
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During system restoration, governors must not be blocked and plant operators must operate the
generator in a mode which allows the governors to respond to frequency deviations if this mode
of control is available. Generating units which cannot meet this criteria do not contribute to
Dynamic Reserves.
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Frequency Response in System Restoration
• Dynamic Reserve is the amount of reserve that is available to
preserve the system during a frequency disturbance
– Reserve amount must be enough to survive the largest
energy contingency
– Can be a combination of load armed to trip by automatic underfrequency load shedding relays and generator governor action
– Automatic function
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Frequency Response in System Restoration
• Dynamic Reserve from generation is determined by “load pick-up
factors” for units paralleled to the system
• “Load Pick-Up Factor” is the maximum load a generator can pick
up as a percentage of the generator rating without incurring a
decline in frequency below safe operating levels
• PJM uses the following load pick-up factors:
– 5% for steam units
– 15% for hydroelectric units
– 25% for combustion turbine units
– Or the unloaded capacity of the unit, whichever is less
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Frequency Response in System Restoration
Frequency response of unit for a sudden load increase of 10%
steam
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hydroelectric
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combustion turbine
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Frequency Response in System Restoration
• During the restoration process:
– Goal in the early stages is to create the island(s) restoring load
connected with under-frequency load shed
– In the very early stages, under-frequency load should not be
restored
– No more than 50% of the total Dynamic Reserve should be made
up of under-frequency relay load
– Ultimate goal is to rely on generation unit governor response to
arrest frequency declines
– Dynamic Reserve is an automatic function, and must be
calculated for each island
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Frequency Response in System Restoration
Questions?
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