Disclaimer
• This training presentation is provided as a reference for
preparing for the PJM Certification Exam.
• Note that the following information may not reflect
current PJM rules and operating procedures.
• For current training material, please visit:
http://pjm.com/training/training-material.aspx
PJM©2014
Reserves Scheduling,
Reporting and Loading
RE Module
Interconnection Training Program
PJM State & Member Training Dept.
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Agenda
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Basics
Reserve Categories/Terminology
IRC Reporting
Loading of Reserves
Shared Reserve Agreements
Appendix
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Basics
MW
MW
Operating Reserve
Requirement
Reserve Generation
committed by PJM
External Bilateral
Sales
Pool Scheduled
and Committed
Capacity
Requirement
Energy
Requirement
PJM OI
Load Forecast
Self-Scheduled
External
Bilateral
Purchases
Generation Supply
Requirement
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Scheduling Reserves
• On a daily basis, PJM must schedule enough capacity to cover the
forecast load plus expected sales of energy off the system and
operating reserves
RFC Day-ahead Scheduling Reserve
VACAR Day-ahead Scheduling Reserve
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Purpose of Reserve Generation
• Reserve requirements are values of reserve which enable the
system to operate reliably and economically while providing
protection against load variations, forecast error and
equipment failure.
• Enables control area to restore tie lines to pre-contingency
state within 10 minutes of a contingency that causes an
imbalance between load and generation
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Agenda
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PJM©2011
Basics
Reserve Categories/Terminology
IRC Reporting
Loading of Reserves
Shared Reserve Agreements
Appendix
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Reserve Terminology
• Synchronous Reserve (a.k.a. Spinning Reserve)
– Increase in output energy level of a synchronized generator
which can be attained in 10 min.
• Or decrease in a Load Response Resource
– Max energy output achieved in 10 min by a unit operating as a
synchronous condenser
• Quick-start Reserve
– Not synchronized to system
– Includes maximum energy output level of a unit that can be
attained in 10 min. from the PJM request
– Generally run-of-river hydro, pumped hydro, combustion
turbines, combined cycle and diesel type units
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Reserve Terminology
• Contingency Reserve (a.k.a. Primary Reserve)
– Synchronous Reserve
- Spinning (Generation)
- Customer Demand Response
- Quick-Start Reserve
– All MW available within 10 minutes
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Reserve Terminology
• Supplemental Reserve (a.k.a. Secondary Reserve)
– The reserve capability that can be fully converted into energy in
>10 to 30 minute interval following a request by PJM
– Equipment does not need to be synchronized to the system
– Secondary reserve is tracked and reported in real-time for the
entire PJM footprint via Instantaneous Reserve Checks, or IRC’s
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Reserve Terminology
• Operating Reserve
– Generation available from either offline or online units within 30
minutes
– Scheduled to meet Operating Reserve requirements in DayAhead Market
– Contingency Reserve + Supplemental Reserve
– Calculated on an annual basis involving variables that adversely
impact system reliability:
- Load Forecast Error
- Generator Forced Outage Rates
Day Ahead Scheduling Reserves =
Load Forecast Error + Generator Forced Outage Rates
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Reserve Terminology
• Load Forecast Error:
- Based on a 3-year average of underforecasted load forecast
error
- Underforecasted LFE can result in capacity deficiencies
- Underforecasted LFE is based on the 80th percentile of the
rolling 3-year average
- Effective January 1, 2011, the LFE component of the DayAhead Scheduling Reserve will be 1.87%
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Reserve Terminology
• Forced Outage Rate:
- Based on a rolling 3-year average of forced outages that
occur on the scheduling day (18:00) through the operating
day (20:00)
- PJM dispatch has the ability to schedule additional reserves
during Hot and Cold Weather Alerts
- Effective January 1, 2010, the Forced Outage Rate
component for the Day-Ahead Scheduling Reserve is 5.23%
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Reserve Terminology
• Day-Ahead Scheduling Reserve Requirement:
PJM performs the calculations annually during November
- Calculations cover a 3-year window from November 1
(year 3) through October 31 (current year)
- Reserve calculations are implemented annually on January 1
- Effective January 1, 2011, the Day-Ahead Scheduling Reserve
is 7.11%
-
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Reserve Terminology
Synchronized
Reserves
Contingency
Reserve
0 to 10
Minutes
Quick-Start
Reserves
Operating
Reserves
10 to 30
Minutes
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Supplemental
Reserve
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Reserve Requirements
RRO
Control
Zone
Day-Ahead
Schedule
(Operating)
Contingency
(Primary)
Synchronized
Reserve
Regulation
Annual %
150% Largest
Unit
Largest Unit
1% Peak
MidAtlantic
Annual %
1700 MW
Largest Unit
1% Peak
Dominion
VACAR
ARS %
VACAR
ARS %
VACAR
ARS %
1% Peak
RFC
SERC
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Dominion Reserve Requirement
VACAR
Requirements
VACAR Contingency
Reserve (15 min)
DVP Contingency
Reserve (15 min)
Largest Unit in VACAR
VACAR Operating
Reserve
1.5
Peak Load Share (VACAR)
422 MW
for 2011
DVP Synchronized Reserve
(10 Minute)
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DVP Contingency
Reserve (15 min)
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DVP 15 minute
Non-Synchronized Resources
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Agenda
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Basics
Reserve Categories/Terminology
IRC Reporting
Loading of Reserves
Shared Reserve Agreements
Appendix
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Instantaneous Reserve Check
• Instantaneous Reserve Check (IRC) is used to verify reserve
situation
– ALL generators must report their reserve information to PJM
when requested
– Request for IRC data submittal given via PJM All-Call
– Data submittal for IRC through eDART application
– IRC results used to initiate some emergency procedures
– IRCs performed at least 3 times per day
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Instantaneous Reserve Check
• Instantaneous Reserve Check (IRC) reporting will be by PJM
Region
– MidAtlantic
• Traditional PJM zones
– Western Region
• AP, AEP, DPL, ComEd, DLCO
– Southern Region
• DVP
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Instantaneous Reserve Check Data Entry Form
• All regulating and non-regulating reserve
values are replaced by the Synchronized
Reserve Value
• Synchronized Reserve is equal to the lesser
of:
(Synchronized Ramp Rate x 10)
Or
(Synchronized Maximum Limit – Current Output)
• The “Reserve > 30” row will now be hidden
• East Synchronous Reserve and Load values
will not be displayed under Pool Totals
• For Ancillary Service Markets with only one
Control Zone, the Control Zone will be
hidden
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Instantaneous Reserve Check Report
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eDATA Instantaneous Reserve Check Report
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Agenda
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PJM©2011
Basics
Reserve Categories/Terminology
IRC Reporting
Loading of Reserves
Shared Reserve Agreements
Appendix
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100% Synchronized Reserve
• Definition
Implement 100% Synchronized Reserves and/or Contingency
Reserves if the unit loss is equal to or greater than 80% of the largest
unit contingency and there is insufficient regulation and economic
generation to recover the Area Control Error within the Disturbance
Control Standard of NERC
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100% Synchronized Reserve
Purpose
PJM orders to recover the ACE so that tie line schedules are
maintained following disturbance conditions (i.e., loss of
generation and/or steam lag)
• NERC Standards:
• Control Performance Standard 1 & BAAL
• Disturbance Control Standard
OR
To return the reactive transfers or other thermal limitations to
within the appropriate limits
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100% Synchronized Reserve
• Implementation:
Request made via the PJM ALL-CALL,
• Procedures
allow for calling of a percentage (25, 50, 75,
100%) of Synchronized Reserve
• May limit loading of synchronous to certain geographic
areas (Eastern PJM, spinning reserve zones)
• If
PJM©2011
quick start is required, will also direct its loading
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100% Synchronized Reserve
• Member Actions:
• Without regard to price and as quickly as possible, load the
requested percentage of Synchronized Reserve (and Quick-Start if
specifically requested). PJM Members continue to load generation
until directed by the PJM OI dispatcher to discontinue.
• If regulating units are increased above regulation bands, they MUST
be returned to regulation when regulation signal starts to lower from
“full raise”
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Agenda
•
•
•
•
•
•
PJM©2011
Basics
Reserve Categories/Terminology
IRC Reporting
Loading of Reserves
Shared Reserve Agreements
Appendix
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Shared Reserves
• Purpose
– To assist a neighboring system in recovering from a
large sudden loss of generation or energy purchase.
– To achieve recovery from such a loss faster than
otherwise achieved, thereby improving the reliability of
the interconnected system
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Shared Reserves – PJM Mid-Atlantic Region
Manual Reference
for Shared Reserve:
M-12, Dispatching
Operations Manual
Section 4
MARITIMES
IESO
Participants
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PJM Mid-Atlantic Region
NY-ISO
ISO New England
New York ISO
Independent Electricity System Operator (IESO,
formerly Ontario Hydro)
• Maritimes
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ISO-NE
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Shared Reserves – PJM Mid-Atlantic Region
• Highlights of the agreement
• NYISO is plan coordinator
• Shared reserves involves the use of unloaded on-line
capacity (spinning reserves)
• Can be requested when lost generation is equal to or greater
than 500 MW in any amount up to 50% of the loss (300 MW
for the Maritimes)
• Is expected to be delivered within 10 minutes of request;
termination is within 10 minutes but no longer than 30 minutes
• Payback of reserve energy is currently not required
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Synchronized Reserve Markets
• The current Synchronized Reserve Market has two
Synchronized Reserve Zones and one sub-zone
– RTO Synchronized Reserve Zone
• Mid-Atlantic Sub-Zone
– Southern Synchronized Reserve Zone (existing)
• The limiting factor between the RTO market and Mid-Atlantic
Sub-Zone is the AP-South Reactive Transfer Interface
– This functions the same way the Eastern Sub-Zone did
previously but includes the entire Mid-Atlantic region
• The limits and flows on these will be summed to provide
west-to-east transfer capability
• No changes to the Regulation Market
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Synchronized Reserve Market Areas
RTO Synchronized
Reserve Zone
DLCO
Mid Atlantic
Synchronized Reserve
Sub-zone
ComEd
AP
AEP
DAY
Control Zone
Ancillary Service
Region
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DOM
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Southern
Synchronized Reserve
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Synchronized Reserve Requirements
• The RTO (except DOM) will have a single requirement
– DVP will remain separate and will keep the same requirement as
today
• When AP-South transfers are near the limit:
– Mid-Atlantic Sub-Zone will have a locational requirement
– Will result in a higher clearing price in the Mid-Atlantic, similar
to the old Eastern sub-zone
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Requirements
• RTO Synchronized Reserve Zone (excluding Dominion)
Requirement is the greater of:
– Calculated RFC minimum requirement OR
– Largest contingency in RTO Synchronized Reserve Zone
• Expected to be about 1350 MW (RFC)
• Mid-Atlantic sub-zone requirement is equal to:
– Largest contingency in Mid-Atlantic region
• Normally 1300 MW
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Shared Reserves – PJM Southern Region
• VACAR Reserve Sharing
– Dominion, Duke, South Carolina Electric and Gas, Progress –
Carolinas, South Carolina Public Service Authority
– Telephone request for reserve energy
• Up to 12 hours
– PJM schedules delivery between PJM and CPL
• Dominion Virginia Power
– Performs billing and provide compensation for energy deliveries
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Operational Considerations
• Request for Synchronized Reserve in Eastern Reserve subzone is no longer an option
– If limited on the AP-South Interface, call for Synchronized
Reserve in Mid-Atlantic subzone only
• Be aware of possible over-response as more units will be
providing spinning reserve when the RTO Synchronized
Reserve zone is called
– PJM discussing with Operating Committee the use of less than
100% synchronized reserve if this continues to be an issue
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Operational Considerations
• For loss of unit in Dominion, call for Synchronized Reserve in
Southern Synchronized Reserve Zone only
– If needed, request VACAR reserve sharing
– Same as existing procedure
• For loss of a unit in any area other than Dominion, call for
Synchronized Reserve in RTO Synchronized Reserve Zone
– Call only Mid-Atlantic sub-zone if limited on transfer interfaces
– Initiate the NPCC reserve sharing, if needed
• For low ACE, call for Synchronized Reserve in Spinning Reserve
zone with largest negative ACE
– Southern Synchronized Reserve Zone OR
– RTO Synchronized Reserve Region
– Entire RTO may be requested if needed
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Shared Reserves – Summary
• RTO
- Triggers Dominion, RFC, and Mid-Atlantic Sub-Zone
• RFC
- Triggers RFC and Mid-Atlantic Sub-Zone
• PJM Mid-Atlantic Region
– Reserve sharing with NYISO, NEISO, IMO, Maritimes
• PJM Southern Region
– Reserve sharing with other VACAR members
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Questions?
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Disclaimer:
PJM has made all efforts possible to accurately document all
information in this presentation. The information seen here
does not supersede the PJM Operating Agreement or the
PJM Tariff both of which can be found by accessing:
http://www.pjm.com/documents/agreements/pjmagreements.aspx
For additional detailed information on any of the topics
discussed, please refer to the appropriate PJM manual
which can be found by accessing:
http://www.pjm.com/documents/manuals.aspx
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