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KEY
GENERATOR OPERATOR MAPPING MATRIX
NOTES
Requirements of standards could change depending on the NERC approval processes and
modified versions of the same standards
Requirements of standards could be added or deleted depending on version changes
Current viewpoints could change depending on factors like NERC and NPCC requirements
and inputs from other regulatory bodies
This is not a final list and is subject to change
The IESO may modify certification requirements as deemed appropriate, for reliability,
reporting, certification, or auditing concerns
The IESO will work with all market participants to guide them through the process.
CIP standards (CIP-002 through CIP-009) are not covered in these requirements. The IESO
will be working with each affected market participant in this regard.
The implementation dates for these standards are subject to change
Requirement applies and is appropriate to actively monitor market participants
Requirement applies but the IESO is reviewing the need to actively monitor market participants. Address
Requirement applies but managed through other processes and no need to actively monitor market partic
participants. Addressed by the IESO or IESO processes currently.
monitor market participants
Generator Operator
Requirement
IRCP Form
Number
Number
Standard
Text of Requirement Comments
Number
CIP-001-1 R1. 1610 Each Reliability Coordinator, Balancing Authority, Transmission Operator, Generator Dependent on the critical assets owned by
Operator, and Load Serving Entity shall have procedures for the recognition of and for the market participant and pursuant to the
making their operating personnel aware of sabotage events on its facilities and multi site market rules and Market Manual 7.1 . This
sabotage affecting larger portions of the Interconnection. will be determined by the IESO in
consultation with the MP.
CIP-001-1 R2. 1610 Each Reliability Coordinator, Balancing Authority, Transmission Operator, Generator Dependent on the critical assets owned by
Operator, and Load Serving Entity shall have procedures for the communication of the market participant and pursuant to the
information concerning sabotage events to appropriate parties in the Interconnection. market rules and Market Manual 7.1 . This
will be determined by the IESO in
consultation with the MP.
CIP-001-1 R3. 1610 Each Reliability Coordinator, Balancing Authority, Transmission Operator, Generator Dependent on the critical assets owned by
Operator, and Load Serving Entity shall provide its operating personnel with sabotage the market participant and pursuant to the
response guidelines, including personnel to contact, for reporting disturbances due to market rules and Market Manual 7.1 . This
sabotage events. will be determined by the IESO in
consultation with the MP.
CIP-001-1 R4. 1610 Each Reliability Coordinator, Balancing Authority, Transmission Operator, Generator Dependent on the critical assets owned by
Operator, and Load Serving Entity shall establish communications contacts, as the market participant and pursuant to the
applicable, with local Federal Bureau of Investigation (FBI) or Royal Canadian Mounted market rules and Market Manual 7.1 . This
Police (RCMP) officials and develop reporting procedures as appropriate to their will be determined by the IESO in
circumstances. consultation with the MP.
EOP-001-0 R1 1608 Each market participant shall ensure that its emergency preparedness plan is on file with Obligations are explicitly in accordance
the IESO (Ch. 5, S. 11.2.4 of the market rules ) and that it: with Ch., S.11. of the market rules as
establish in consultation with the EPTF and
fulfill the requirements of EOP-001
EOP-001-0 R1.1. 1608 Describes such planning, testing, information, communication and other elements "
designated by the IESO ;
EOP-001-0 R1.2. 1608 Complies with the OEEP emergency planning criteria "
Jan, 2007 4of-24
Generator Operator
Requirement
IRCP Form
Number
Number
Standard
Text of Requirement Comments
Number
EOP-001-0 R2 1608 Each market participant shall review its emergency preparedness plan at least annually, or "
as required, and shall, following such review, submit to the IESO :
EOP-001-0 R2.1. 1608 Certification confirming that the review has not required any change to be made to its "
emergency preparedness plan ; or
EOP-001-0 R2.2. 1608 A revised version of its emergency preparedness plan , amended as may be required by "
the results of the review, together with a statement identifying such amendments, as
the case may be.
EOP-001-0 R3. 1608 Each market participant shall ensure that any revised emergency preparedness plan "
prepared and submitted pursuant to Requirement R2 complies with requirement R1.
EOP-005-1 R1. 1609 Each restoration participant shall ensure that its restoration participant attachment is on Obligations are explicitly in accordance
file with the IESO (Ch. 5, S. 11.3.6 of the market rules and Market Manual 7.8 - OPSRP). with Ch., S.11. of the market rules as
establish in consultation with the OPSRP-
WG and fulfill the requirements of EOP-005
EOP-005-1 R1.1. 1609 Each restoration participant shall review its restoration participant attachment at least "
annually, or more often if required, and shall submit a revised version of its restoration
participant attachment , amended as may be required by the results of the review.
EOP-005-1 R2. 1609 Each restoration participant shall ensure that records are maintained and available, "
and its restoration participant attachment (Ch. 5, S. 11.3.7 of the market rules and Market
Manual 7.8 - OPSRP):
EOP-005-1 R2.1. 1609 Identifies any constraints preventing or limiting its capability to execute its obligations "
assigned in the Ontario power system restoration plan .
EOP-005-1 R2.2. 1609 Identifies permanently installed emergency power generators including the facilities at "
which they are installed, and what they are intended to supply.
EOP-005-1 R3. 1609 Each restoration participant shall ensure its restoration participant attachment includes "
(Ch. 5, S. 11.3.7 of the market rules and Market Manual 7.8 – OPSRP):
Jan, 2007 5of-24
Generator Operator
Requirement
IRCP Form
Number
Number
Standard
Text of Requirement Comments
Number
EOP-005-1 R3.1. 1609 A declaration that on-shift operators have been trained on system restoration activities "
has an operator training program in place and operator training records are maintained
and available.
EOP-005-1 R3.2. 1609 For those restoration participants identified as owners of key facilities, a program for For Key Facility Owners only
testing the restoration participant’s critical components as designated in the Ontario power
system restoration plan ( Market Manual 7.8, - Ontario Power System Restoration Plan
Section 4.12), shall be maintained and available along with a record of the test results.
EOP-009-0 R2. 1532 The Generator Owner or Generator Operator shall provide documentation of the test For Black-start generator only
results of the start-up and operation of each blackstart generating unit to the Regional
Reliability Organizations and upon request to NERC.
PRC-001-1 R1. 1637 Each Transmission Operator, Balancing Authority, and Generator Operator shall be Each facility owner is required to be
familiar with the purpose and limitations of protection system schemes applied in its familiar with its facility protection systems
area. and the implications when such protection
systems fails for notifying the IESO.
PRC-001-1 R2. 1637 Each Generator Operator and Transmission Operator shall notify reliability entities of M.R and market manual 7.1 Section 3 and
relay or equipment failures as follows: market manual 7.3 - Outage Management
re: reporting of equipment failures or
degradation.
PRC-001-1 R2.1. 1637 If a protective relay or equipment failure reduces system reliability, the Generator ditto
Operator shall notify its Transmission Operator and Host Balancing Authority. The
Generator Operator shall take corrective action as soon as possible.
TOP-006-1 R1.1. 1645 Each Generator Operator shall inform its Host Balancing Authority and the Market rules obligates generators to notify
Transmission Operator of all generation resources available for use. the IESO when units are de-rated. Need to
monitor to ensure generators notify the
IESO of resource availability.
Jan, 2007 6of-24
Generator Operator
Requirement
IRCP Form
Number
Number
Standard
Text of Requirement Comments
Number
VAR-002-1.1a R1. 1571 The Generator Operator shall operate each generator connected to the interconnected
transmission system in the automatic voltage control mode (automatic voltage regulator
in service and controlling voltage) unless the Generator Operator has notified the
Transmission Operator.
VAR-002-1.1a R2. 1571 Unless exempted by the Transmission Operator, each Generator Operator shall maintain
the generator voltage or Reactive Power output (within applicable Facility Ratings 1.
VAR-002-1.1a R2.1. 1571 When a generator’s automatic voltage regulator is out of service, the Generator Operator
shall use an alternative method to control the generator voltage and reactive output to
meet the voltage or Reactive Power schedule directed by the Transmission Operator.
VAR-002-1.1a R2.2. 1571 When directed to modify voltage, the Generator Operator shall comply or provide an
explanation of why the schedule cannot be met.
VAR-002-1.1a R3. 1571 Each Generator Operator shall notify its associated Transmission Operator as soon as Appendix 5.1-3, Chp.5 of Market Rules,
practical, but within 30 minutes of any of the following: states that :"Each ancillary service provider
shall: 1.3.6.1 notify the IMO immediately upon
the forced outage of the AVR at its registered
facility that is a generation facility being forced
out of service; or 1.3.6.2 for planned outages,
prior to the AVR being removed from its
registered facility that is a generation facility
for maintenance, follow the procedures outlined
in section 6" .
VAR-002-1.1a R3.1. 1571 A status or capability change on any generator Reactive Power resource, including the
status of each automatic voltage regulator and power system stabilizer and the expected
duration of the change in status or capability.
Jan, 2007 7of-24
Generator Operator
Requirement
IRCP Form
Number
Number
Standard
Text of Requirement Comments
Number
VAR-002-1.1a R3.2. 1571 A status or capability change on any other Reactive Power resources under the
Generator Operator’s control and the expected duration of the change in status or
capability.
VAR-002-1.1a R5.1. 1571 If the Generator Operator can’t comply with the Transmission Operator’s specifications,
the Generator Operator shall notify the Transmission Operator and shall provide the
technical justification.
1
When a Generator is operating in manual control, reactive power capability may change
based on stability considerations and this will lead to a change in the associated Facility
Ratings.
Jan, 2007 8of-24
Implementation
Requirement
Number
Standard
Date
Number
BAL-005-0b R1.1. 4/1/2005
COM-002-2 R1. 1/1/2007
EOP-004-1 R2. 1/1/2007
EOP-004-1 R3. 1/1/2007
EOP-004-1 R3.1. 1/1/2007
EOP-004-1 R3.2. 1/1/2007
EOP-004-1 R3.3. 1/1/2007
EOP-005-1 R3.2.1 Form 1532
EOP-004-1 R3.4. 1/1/2007
IRO-001-1 R8. 1/1/2007
IRO-004-1 R4. 11/1/2006
PRC-001-1 R3. 1/1/2007
PRC-001-1 R3.1. 1/1/2007
PRC-001-1 R5. 1/1/2007
PRC-001-1 R5.1. 1/1/2007
TOP-001-1 R3. 1/1/2007
TOP-001-1 R6. 1/1/2007
TOP-001-1 R7. 1/1/2007
TOP-001-1 R7.1. 1/1/2007
TOP-001-1 R7.3. 1/1/2007
TOP-002-2 R3. 1/1/2007
TOP-002-2 R13. 1/1/2007
TOP-002-2 R14. 1/1/2007
TOP-002-2 R14.1. 1/1/2007
TOP-002-2 R15. 1/1/2007
TOP-002-2 R18. 1/1/2007
TOP-003-0 R1. 1/4/2005
TOP-003-0 R1.1. 1/4/2005
TOP-003-0 R2. 1/4/2005
TOP-003-0 R3. 1/4/2005
Text of Requirement
Each Generator Operator with generation facilities operating in an Interconnection shall
ensure that those generation facilities are included within the metered boundaries of a
Balancing Authority Area.
Each Transmission Operator, Balancing Authority, and Generator Operator shall have
communications (voice and data links) with appropriate Reliability Coordinators,
Balancing Authorities, and Transmission Operators. Such communications shall be
staffed and available for addressing a real-time emergency condition.
A Reliability Coordinator, Balancing Authority, Transmission Operator, Generator
Operator or Load Serving Entity shall promptly analyze Bulk Electric System
disturbances on its system or facilities.
A Reliability Coordinator, Balancing Authority, Transmission Operator, Generator
Operator or Load Serving Entity experiencing a reportable incident shall provide a
preliminary written report to its Regional Reliability Organization and NERC.
The affected Reliability Coordinator, Balancing Authority, Transmission Operator,
Generator Operator or Load Serving Entity shall submit within 24 hours of the
disturbance or unusual occurrence either a copy of the report submitted to DOE, or, if no
DOE report is required, a copy of the NERC Interconnection Reliability Operating Limit
and Preliminary Disturbance Report form. Events that are not identified until some time
after they occur shall be reported within 24 hours of being recognized.
Applicable reporting forms are provided in Attachments 022-1 and 022-2.
Under certain adverse conditions, e.g., severe weather, it may not be possible to assess
the damage caused by a disturbance and issue a written Interconnection Reliability
Operating Limit and Preliminary Disturbance Report within 24 hours. In such cases, the
affected Reliability Coordinator, Balancing Authority, Transmission Operator, Generator
Operator, or Load Serving Entity shall promptly notify its Regional Reliability
Organization(s) and NERC, and verbally provide as much information as is available at
that time. The affected Reliability Coordinator, Balancing Authority, Transmission
Operator, Generator Operator, or Load Serving Entity shall then provide timely, periodic
verbal updates until adequate information is available to issue a written Preliminary
Disturbance Report.
Testing of critical components associated with key facilities shall be performed at a frequency and for a
duration that is sufficient to reasonably ensure that the critical components will function properly when
isolated from all power sources not available during a partial or complete IESO-controlled grid blackout.
Currently, this frequency and duration of testing must meet the requirements of NPCC Document A-3
Section 4.10 or its successor A-12.
If, in the judgment of the Regional Reliability Organization, after consultation with the
Reliability Coordinator, Balancing Authority, Transmission Operator, Generator
Operator, or Load Serving Entity in which a disturbance occurred, a final report is
required, the affected Reliability Coordinator, Balancing Authority, Transmission
Operator, Generator Operator, or Load Serving Entity shall prepare this report within 60
days. As a minimum, the final report shall have a discussion of the events and its cause,
the conclusions reached, and recommendations to prevent recurrence of this type of
event. The report shall be subject to Regional Reliability Organization approval.
Transmission Operators, Balancing Authorities, Generator Operators, Transmission
Service Providers, Load-Serving Entities, and Purchasing-Selling Entities shall comply
with Reliability Coordinator directives unless such actions would violate safety,
equipment, or regulatory or statutory requirements. Under these circumstances, the
Transmission Operator, Balancing Authority, Generator Operator, Transmission Service
Provider, Load-Serving Entity, or Purchasing-Selling Entity shall immediately inform the
Reliability Coordinator of the inability to perform the directive so that the Reliability
Coordinator may implement alternate remedial actions.
Each Transmission Operator, Balancing Authority, Transmission Owner, Generator
Owner, Generator Operator, and Load-Serving Entity in the Reliability Coordinator Area
shall provide information required for system studies, such as critical facility status, Load,
generation, operating reserve projections, and known Interchange Transactions. This
information shall be available by 1200 Central Standard Time for the Eastern
Interconnection and 1200 Pacific Standard Time for the Western Interconnection.
A Generator Operator or Transmission Operator shall coordinate new protective systems
and changes as follows.
Each Generator Operator shall coordinate all new protective systems and all protective
system changes with its Transmission Operator and Host Balancing Authority.
A Generator Operator or Transmission Operator shall coordinate changes in generation,
transmission, load or operating conditions that could require changes in the protection
systems of others:
Each Generator Operator shall notify its Transmission Operator in advance of changes in
generation or operating conditions that could require changes in the Transmission
Operator’s protection systems.
Each Transmission Operator, Balancing Authority, and Generator Operator shall comply
with reliability directives issued by the Reliability Coordinator, and each Balancing
Authority and Generator Operator shall comply with reliability directives issued by the
Transmission Operator, unless such actions would violate safety, equipment, regulatory
or statutory requirements. Under these circumstances the Transmission Operator,
Balancing Authority or Generator Operator shall immediately inform the Reliability
Coordinator or Transmission Operator of the inability to perform the directive so that the
Reliability Coordinator or Transmission Operator can implement alternate remedial
actions.
Each Transmission Operator, Balancing Authority, and Generator Operator shall render
all available emergency assistance to others as requested, provided that the requesting
entity has implemented its comparable emergency procedures, unless such actions would
violate safety, equipment, or regulatory or statutory requirements.
Each Transmission Operator and Generator Operator shall not remove Bulk Electric
System facilities from service if removing those facilities would burden neighboring
systems unless:
For a generator outage, the Generator Operator shall notify and coordinate with the
Transmission Operator. The Transmission Operator shall notify the Reliability
Coordinator and other affected Transmission Operators, and coordinate the impact of
removing the Bulk Electric System facility.
When time does not permit such notifications and coordination, or when immediate
action is required to prevent a hazard to the public, lengthy customer service
interruption, or damage to facilities, the Generator Operator shall notify the Transmission
Operator, and the Transmission Operator shall notify its Reliability Coordinator and
adjacent Transmission Operators, at the earliest possible time.
Each Load Serving Entity and Generator Operator shall coordinate (where confidentiality
agreements allow) its current-day, next-day, and seasonal operations with its Host
Balancing Authority and Transmission Service Provider. Each Balancing Authority and
Transmission Service Provider shall coordinate its current-day, next-day, and seasonal
operations with its Transmission Operator.
At the request of the Balancing Authority or Transmission Operator, a Generator
Operator shall perform generating real and reactive capability verification that shall
include, among other variables, weather, ambient air and water conditions, and fuel
quality and quantity, and provide the results to the Balancing Authority or Transmission
Operator operating personnel as requested.
Generator Operators shall, without any intentional time delay, notify their Balancing
Authority and Transmission Operator of changes in capabilities and characteristics
including but not limited to:
Changes in real output capabilities. (Effective August 1, 2007)
Generation Operators shall, at the request of the Balancing Authority or Transmission
Operator, provide a forecast of expected real power output to assist in operations
planning (e.g., a seven-day forecast of real output).
Neighboring Balancing Authorities, Transmission Operators, Generator Operators,
Transmission Service Providers and Load Serving Entities shall use uniform line
identifiers when referring to transmission facilities of an interconnected network.
Generator Operators and Transmission Operators shall provide planned outage
information.
Each Generator Operator shall provide outage information daily to its Transmission
Operator for scheduled generator outages planned for the next day (any foreseen outage
of a generator greater than 50 MW). The Transmission Operator shall establish the
outage reporting requirements.
Each Transmission Operator, Balancing Authority, and Generator Operator shall plan
and coordinate scheduled outages of system voltage regulating equipment, such as
automatic voltage regulators on generators, supplementary excitation control,
synchronous condensers, shunt and series capacitors, reactors, etc., among affected
Balancing Authorities and Transmission Operators as required.
Each Transmission Operator, Balancing Authority, and Generator Operator shall plan
and coordinate scheduled outages of telemetering and control equipment and associated
communication channels between the affected areas.
Comments
Although the responsibility to have and
maintain metering equipment
operationally lies with the facility owner
under the market rules, the IESO assures
adherence to the requirement through ME
registration and enforcement through
MACD for the Ontario Area.
Communication (voice and data) and
staffing requirements are explicitly defined
by the market rules and must are required
to be in place as a prerequisite to being
registering and permitted to participate in
the IAM.
Per the M.R. all incidents are to be analysed
& reported to the IESO in real time. Follow-
up reporting needs will be determined by
the IESO on a case by case bases in
consultation with the MP.
Reported to the IESO CRO in real-time.
Follow-up is performed by Market
Analysis Incident review and F/U
processes, as required for all reportable
incidents.
Reported to the IESO CRO in real-time.
Follow-up is performed by Market
Analysis Incident review and F/U
processes, as required for all reportable
incidents.
Reported to the IESO CRO in real-time.
Follow-up is performed by Market
Analysis Incident review and F/U
processes, as required for all reportable
incidents.
Reported to the IESO CRO in real-time.
Follow-up is performed by Market
Analysis Incident review and F/U
processes, as required for all reportable
incidents.
Obligations for critical component testing
explicit for key facility owners and is in
accordance with NPCC A3, S4.10 and is
monitored via A3-1 template IESO form
1532
Incident Report prepared by the IESO with
input from all affected market participants
as required.
Obligations under Ch. 5 of the MRs & MM
7.4 S. 4.0 requires MPs to take action as
directed by the IESO.
Real-time day to day operations and
logging of compliance issues by the CRO
with MACD F/U.
Existing obligations under the MRs for the
provision of information as required for
Day-ahead MFI analysis. Reviewing need
to monitor through IRCP?
CAA Process and requirements of the OEB
codes for connecting to transmitter or
distribution system.
CAA Process and requirements of the OEB
codes for connecting to transmitter or
distribution system
CAA Process and requirements of the OEB
codes for connecting to transmitter or
distribution system
CAA Process and requirements of the OEB
codes for connecting to transmitter or
distribution system
See IRO-001 R8; Obligations covered by
Ch. 5 of the M.R and compliance issues
logged by the CRO in Real-time operations
(also see IRO-001-R8)
IESO real-time operations provides
emergency assistance to other Areas
pursuant to agreements and will direct
MPs as appropriate.
Managed by the IESO Outage Management
and Approval process. IESO MFI Outage
analysis determines implications and
approves accordingly
Part of the IESO outage approval process
and in accordance with obligations under
the market rules. Reviewing need for active
monitoring
Notification and F/U in real-time
GOP must notify the IESO when
generating unit is unavailable and is
factored into SAA
IESO initiates these tests pursuant to Ch 5
of the MRs and is considering to monitor
through IRCP?
Also addressed by the MOD-024 MOD-025
standards (NPCC A13 and A14)
May monitor to ensure obligations are
understood and followed by all.
May monitor to ensure obligations are
understood and followed by all.
GOP must notify when generating unit is
unavailable and is factored into SAA
May monitor to ensure obligations are
understood and followed by all.
N/A since managed by the IESO through
Use of SDX standards for uploading to
NERC. IESO for R/T and day-ahead
IESO outage Process under the market rules
Obligations to notify the IESO for planned
outages under the M.R and part of the
outage process. Will consider need for
active monitoring via IRCP.
Obligations to coordinate planned outages
with the IESO as part of the outage process
and reviewed by MFI and market limits to
assess impact.
Not necessary since the market rules and
Market Manual obligates all generators to
notify the IESO when units are unavailable
or de-rated. Notification failures are logged
and F/U by MACD.
Corresponding NERC
Criteria Sections GOP Forms Standard
Directory #2 - Emergency Section 5.4 - Generator Underfrequency
Operations Tripping Requirement √ IESO Form 1519 PRC-007
Directory #3 - Maintenance Section 5.0 - NPCC Full Member, More
Criteria for Bulk Power Stringent Criteria (Transmission facilities
System Protection protection system maintenance & test
program) √ IESO Form 1521 PRC-005
Directory #9 - Verification of
Generator Gross and Net
Real Power Capability √ IESO Form 1635 MOD-024
Directory #10 - Verification
of Generator Gross and Net
Reactive Power Capability
√ IESO Form 1636 MOD-025