Schedule “B”
HQCMÉ’s Registration Information and Applicable Standards for RTA
Standards
Included
Title
BAL-005-0b
Automatic
Generation
Control
Applicable to
RTA as:
GOP-2
Requirements
R1.1. Each Generator Operator with generation facilities
operating in an Interconnection1 shall ensure that those
generation facilities are included within the metered
boundaries of a Balancing Authority Area2.
Brief description
Making sure all generation (energy
injected or withdrawn from the BA
area is included within the metered
boundaries of a Balancing
Authority area. That is metered by
HQCMÉ as BA.
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
Bulk
While, RTA’s generation
resources are primarily for its
own load displacement needs,
it does enter into commercial
agreements from time to time,
for the purposes of providing
HQ net energy sales that are in
excess of its own needs.
Requirement ought to apply, as
per existing agreements and
current installations, in order to
have metering at the
interconnections with HQT for
monitoring and billing net
energy exchanges for use in
HQCMÉ’s resource adequacy
analysis for Québec load and
net energy injections required
to service RTA’s load and
those of HQ interconnected to
RTA’s Installations.
NA for each GO unit/plant.
CIP-001-1
Sabotage
Reporting
GOP2
R1. Each [...], Generator Operator [...], shall have procedures
for the recognition of and for making their operating personnel
aware of sabotage events on its facilities and multi-site
sabotage affecting larger portions of the Interconnection.
R2. Each [...], Generator Operator [...], shall have procedures
2
Each responsible entity must have
documented sabotage reporting
procedures and communication
protocols in place for
communicating such events to the
appropriate internal staff, other
Non Bulk
See NERC Glossary of terms; Interconnection means; when capitalized, any one of the three major electric system networks in North America: Eastern, Western, and ERCOT (Authors
note: now includes Québec).
See NERC Glossary of terms; Balancing Authority Area means; the collection of generation, transmission, and loads within the metered boundaries of the Balancing Authority. The
Balancing Authority maintains load-resource balance within this area.
#1732371
Page 1
Standards
Included
Title
Applicable to
RTA as:
Requirements
for the communication of information concerning sabotage
events to appropriate parties in the Interconnection.
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
entities and authorities, including
the RC.
R3. Each [...], Generator Operator [...], shall provide its
operating personnel with sabotage response guidelines,
including personnel to contact, for reporting disturbances due
to sabotage events.
R4. Each [...], Generator Operator [...], shall establish
communications contacts, as applicable, with local Federal
Bureau of Investigation (FBI) or Royal Canadian Mounted
Police (RCMP) officials and develop reporting procedures as
appropriate to their circumstances.
COM-002-2
EOP-004-1
Communication
and
Coordination
GOP-2
Disturbance
Reporting
GOP-2
R1. Each GOP 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.
Having the capability and staff to
communicate with HQCMÉ for
emergency situations.
R2.Each GOP shall promptly analyze Bulk Electric System
disturbances on its system or facilities.
Analysis and report of
disturbances affecting the
responsible entity’s facilities.
R3. Each GOP experiencing a reportable incident shall provide
a preliminary written report to its Regional Reliability
Organization and NERC. (Per Requirement R3.1, R3.2 and
R.3.3).
R3.4. 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.
#1732371
Non Bulk
RTA has existing processes,
procedures and communication
facilities in place with HQT
and HQCMÉ for its
interconnection with HQT.
Non Bulk
RTA has existing processes
and procedures with HQT
allowing appropriate
assessment of incidents in
order to enable HQT and
HQCMÉ to meet their
disturbance reporting
obligations to NERC and
NPCC, if such disturbance is
reportable.
RTA reporting (verbal and
written) should remain to
HQCMÉ, in its capacity as the
RC, per existing protocols, not
directly to NPCC and NERC.
Incident investigation / followups are best coordinated
exclusively by one entity, the
RC.
Page 2
Standards
Included
FAC-001-0
Title
Facility
Connection
Requirements
Applicable to
RTA as:
TO-3
Requirements
Brief description
R1. The Transmission Owner shall document, maintain, and
publish facility connection requirements to ensure compliance
with NERC Reliability Standards and applicable Regional
Reliability Organization, subregional, Power Pool, and
individual Transmission Owner planning criteria and facility
connection requirements. The Transmission Owner’s facility
connection requirements shall address connection requirements
for: i) generation, ii) transmission and iii) end-user facilities
Note: This standard is typically for
transmission owners like HQT,
Hydro One, etc. It is not normally
intended for generator owners that
have their own transmission
“distribution” assets used for
interconnecting their own facilities
and legacy local loads.
R2. The Transmission Owner’s facility connection
requirements shall address, but are not limited to, the following
items: (all listed sub items).
Coordination of
Plans For New
Generation,
Transmission,
and End-User
TO3,
GO-2
R1. The.[...] Generator Owner, Transmission Owner,
Distribution Provider, and Load-Serving Entity seeking to
integrate generation facilities, transmission facilities, and
electricity end-user facilities shall each coordinate and
cooperate on its assessments with its Transmission Planner and
Planning Authority. The assessment shall include: R1.1 to
R1.5
Transmission
Vegetation
TO-3
R1. The Transmission Owner shall prepare, and keep current,
a formal transmission vegetation management program
Although RTA’s Installations
do interconnect HQ load
transfer customers3 per existing
transmission service
agreements, its facilities are
designed for its own use, and
are not intended for use by HQ
customers.
Connection requirements for
connecting HQ local loads to
RTA'
s Installations are
documented in the
transmission service provider’s
agreement with HQT.
Coordinating new connections, or
facilities with TP4 and PC5
Non Bulk
For facilities that potentially
affect the local area, requires
RTA to follow HQT
connection and approval
processes.
To that end, RTA has set up a
committee with HQT to
address additions and/or
modifications to RTA’s
Installations or changes to
HQT’s network that may
impact the local area.
R2. The Transmission Owner shall retain its documentation (of
its evaluation of the reliability impact of the new facilities and
their connections on the interconnected transmission systems)
for three years and shall provide the documentation to the
Regional Reliability Organization(s) and NERC on request
(within 30 calendar days).
FAC-003-1
NA
Therefore, a connection
requirement document is not
warranted.
R3. The Transmission Owner shall maintain and update its
facility connection requirements as required. The Transmission
Owner shall make documentation of these requirements
available to the users of the transmission system, the Regional
Reliability Organization, and NERC on request (five business
days).
FAC-002 -0
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
Maintaining vegetation under and
along transmission right-of-way
Non Bulk
RTA currently has a vegetation
3
Load transfer customer refers to situations where one distributor’s/transmission system transfers energy or provides transmission service to another entities load over its system.
TP means “Transmission Planner”.
5
PC means “Planning Coordinator”.
#1732371
4
Page 3
Standards
Included
Title
Applicable to
RTA as:
Management
Program
Requirements
(TVMP). The TVMP shall include the Transmission Owner’s
objectives, practices, approved procedures, and work
specifications.
R1.1 to R1.5
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
(ROW) for transmission lines 200
kV and above and those the RRO6
(RC in Québec’s case) deems
critical.
management program in place
on all transmission lines, with
current reporting to HQCMÉ.
R2. The Transmission Owner shall create and implement an
annual plan for vegetation management work to ensure the
reliability of the system. The plan shall describe the methods
used, such as manual clearing, mechanical clearing, herbicide
treatment, or other actions. The plan should be flexible enough
to adjust to changing conditions, taking into consideration
anticipated growth of vegetation and all other environmental
factors that may have an impact on the reliability of the
transmission systems. Adjustments to the plan shall be
documented as they occur. The plan should take into
consideration the time required to obtain permissions or
permits from landowners or regulatory authorities. Each
Transmission Owner shall have systems and procedures for
documenting and tracking the planned vegetation management
work and ensuring that the vegetation management work was
completed according to work specifications.
Application of the requirement
for “Non Bulk” lines of 200
kV and above to be based on
what HQT proposes for its own
“Non Bulk” transmission lines
for consistency in application.
R3. The Transmission Owner shall report quarterly to its RRO,
or the RRO’s designee, sustained transmission line outages
determined by the Transmission Owner to have been caused by
vegetation.
R3.1 to R3.4
FAC-008-1
Facility Ratings
Methodology
TO-3, GO-2
R1. The Transmission Owner and Generator Owner shall each
document its current methodology used for developing Facility
Ratings (Facility Ratings Methodology) of its solely and
jointly owned Facilities. The methodology shall include all of
the following: R1.1 to R1.3.5.
R2. The Transmission Owner and Generator Owner shall each
make its Facility Ratings Methodology available for inspection
and technical review by those Reliability Coordinators,
Transmission Operators, Transmission Planners, and Planning
Authorities that have responsibility for the area in which the
associated Facilities are located, within 15 business days of
receipt of a request.
Facility owners are responsible for
documents relating to
methodologies used in developing
facility and equipment ratings.
The facility ratings methodology
used could include nameplate
ratings, engineering analysis, IEEE
standards, standards developed
following accredited procedures of
the Canadian Standards
Association (CSA), etc.
Non Bulk
The primary focus of these
reliability requirements should
be the transmission facilities
interconnecting with HQT.
The facility ratings and the
capabilities of the generation
units have commercial
implications only rather than
reliability (security)
implications for HQT or
HQCMÉ.
6
RRC means “Regional Reliability Organization”.
#1732371
Page 4
Standards
Included
Title
Applicable to
RTA as:
Requirements
Brief description
R3. If a Reliability Coordinator, Transmission Operator,
Transmission Planner, or Planning Authority provides written
comments on its technical review of a Transmission Owner’s
or Generator Owner’s Facility Ratings Methodology, the
Transmission Owner or Generator Owner shall provide a
written response to that commenting entity within 45 calendar
days of receipt of those comments. The response shall indicate
whether a change will be made to the Facility Ratings
Methodology and, if no change will be made to that Facility
Ratings Methodology, the reason why.
FAC-009-1
Establish and
Communicate
Facility Ratings
TO-3, GO-2
R1. The Transmission Owner and Generator Owner shall each
establish Facility Ratings for its solely and jointly owned
Facilities that are consistent with the associated Facility
Ratings Methodology.
R2. The Transmission Owner and Generator Owner shall each
provide Facility Ratings for its solely and jointly owned
Facilities that are existing Facilities, new Facilities,
modifications to existing Facilities and re-ratings of existing
Facilities to its associated Reliability Coordinator(s), Planning
Authority(ies), Transmission Planner(s), and Transmission
Operator(s) as scheduled by such requesting entities.
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
Commercial arrangements
entered into with RTA for
HQCMÉ’s resource adequacy
relates to the provision of “net”
energy available in excess of
RTA’s needs at the
interconnection with HQT and
is unrelated to the capability of
any specific generating unit or
their interconnected facilities.
As such, the methodology used
to establish each unit’s
capability or their
interconnecting facilities is
unwarranted.
Requires establishment and
communication of the facility
ratings or changes to ratings
established in accordance with
methodologies established under
FAC-008, to its TOP, TP, PC and
RC.
Non Bulk
While HQT, in its role as the
TOP, the PC and the TP,
requires RTA’s facility rating
information for its
interconnection with HQT for
purposes of its (HQCMÉ’s and
HQT’s) models to meet the
transmission planning standards
and for calculating SOLs, this
is a local area impact issue for
the HQT interconnection and
should remain a local area
reliability related issue and be
managed accordingly per
HQCMÉ’s and HQT’s model
needs.
Commercial arrangements
entered into with RTA for
HQCMÉ’s resource adequacy
relates to the provision of “net”
energy available in excess of
RTA’s needs at the
interconnection with HQT and
is unrelated to the capability of
specific generating units unit or
their interconnected facilities.
#1732371
Page 5
Standards
Included
Title
Applicable to
RTA as:
Requirements
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
As such, the provision of
individual unit capability or
their interconnecting facilities’
ratings to others is unwarranted.
IRO-001-1
Reliability
Coordination —
Responsibilities
and Authorities
TSP-3, GOP-2
R8. The Generator Operators and Transmission Service
Providers, 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.
The standard establishes the
accountabilities and authorities of
the RC.
R8.: Requires the listed
responsible entities to take action
as directed by the RC (HQCMÉ)
for “real-time” day to day
operations. These actions typically
concern the to maintaining of
system operating limits (SOL),
which is a local area issue, and
related to the interconnections with
HQT.
Non Bulk
For the interconnections with
HQT, pursuant to the directive
of the RC, this standard is
related to SOL7 limits, which is
a local area reliability related
issue only.
With respect to any “net”
energy injections at these
interconnects per commercial
agreements, the standard is
applicable when SOLs or
IROLs are impacted by these
energy injections.
The TSP function is only
applicable to RTA if HQP uses
point to point service and the
associated required e-tags (INT
standards) or arranged for
transmission service to service
their loads via RTA’s
Installations.
IRO-004-1
Reliability
Coordination Operations
Planning
TSP-3
R1. Each Transmission Operator, Balancing Authority, and
Transmission Service Provider shall comply with the
directives of its Reliability Coordinator based on the next day
assessments in the same manner in which it would comply
during real time operating events.
R1. TSP must follow the direction
of the RC for security (SOL and
IROL) assessment that the RC has
made for next day operations,
similar to those required to follow
for real time (IRO-005).
Typically, this regards
interconnections between
jurisdictions, e.g. Québec - New
York, and the transfer capabilities
of those ties lines, for next day
operations, unless point to point
Non Bulk
For RTA’s Installations, based
on HQCMÉ studies, this is
limited to the interconnection
with HQT for local area SOL
limits and “net” energy
injections, per existing
commercial agreements, which
is the limit of HQCMÉ’s
purview as the RC for RTA’s
Installations with respect to
managing facilities within their
7
SOL means “System Operating Limit”.
#1732371
Page 6
Standards
Included
Title
Applicable to
RTA as:
Requirements
Brief description
transmission service is also used.
ratings.
The standard places the obligation
on RTA as a TSP to follow the
direction of the RC for day ahead
SOL limits (local area limits)
related to physical transmission
service it has provided to PSEs
(e.g. HQP) for arranged
commercial energy transactions.
RTA’s explicit TSP reliability
obligations under this standard
for actions related to provision
of point to point transmission
service to HQ loads or
otherwise need to be clarified
by HQCMÉ.
For a TSP, this is the same as
Requirement R8 in IRO-001, but
for next day’s operations.
IRO-005-2
Reliability
Coordination Current Day
Operations
TSP-3, GOP-2
R13. Each Reliability Coordinator shall ensure that all
Transmission Operators, Balancing Authorities, Generator
Operators, Transmission Service Providers, Load-Serving
Entities, and Purchasing-Selling Entities operate to prevent the
likelihood that a disturbance, action, or non-action in its
Reliability Coordinator Area will result in a SOL or IROL
violation in another area of the Interconnection. In instances
where there is a difference in derived limits, the Reliability
Coordinator and its Transmission Operators, Balancing
Authorities, Generator Operators, Transmission Service
Providers, Load-Serving Entities, and Purchasing-Selling
Entities shall always operate the Bulk Electric System to the
most limiting parameter.
R14. Each Reliability Coordinator shall make known to
Transmission Service Providers within its Reliability
Coordinator Area, SOLs or IROLs within its wide-area view.
The Transmission Service Providers shall respect these SOLs
or IROLs in accordance with filed tariffs and regional Total
Transfer Calculation and Available Transfer Calculation
processes.
8
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
With the exception of R14, which
requires the TSP to take action,
these are obligations for the RC.
It must coordinate actions to
ensure that GOPs and the TSP
(and others), as required, are aware
of, and that the RC takes actions to
mitigate, potential and actual SOL
or IROL in another area of the
Interconnection8 (jurisdiction).
Typically this is with respect to
interconnections, between
jurisdictions e.g. Québec - New
York and the transfer capabilities
of those ties lines for real time
operations unless point to point
transmission service is also.
R13. require all entities to use the
most limiting parameter if there is
Note: version 2 of the standard
is in effect now rather than the
version 1 HQCMÉ submitted
and is now only applicable to
BAs, TOPs and TSPs to follow
the direction of RC. This latest
version eliminates duplications
of requirements that exist in
other standards.
Non Bulk
For RTA’s Installations, based
on HQCMÉ studies, this is
limited to the interconnection
with HQT for local area SOL
limits and “net” energy
injections, per existing
commercial agreements, which
is the limit of HQCMÉ’s
purview as the RC for RTA’s
Installations with respect to
managing facilities within their
ratings.
Responsibility to manage
RTA’s other facilities, within
their respective facility ratings
lies within RTA’s purview.
RTA’s explicit TSP reliability
obligations under this standard
for actions related to provision
See NERC Glossary of terms; Interconnection means: When capitalized, any one of the three major electric system networks in North America: Eastern, Western, and ERCOT (also
includes Québec now).
#1732371
Page 7
Standards
Included
Title
Applicable to
RTA as:
Requirements
R17. When an IROL or SOL is exceeded, the Reliability
Coordinator shall evaluate the local and wide-area impacts,
both real-time and post-contingency, and determine if the
actions being taken are appropriate and sufficient to return the
system to within IROL in thirty minutes. If the actions being
taken are not appropriate or sufficient, the Reliability
Coordinator shall direct the Transmission Operator,
Balancing Authority, Generator Operator, or Load-Serving
Entity to return the system to within IROL or SOL.
MOD-010-0
Steady-State
Data for
Transmission
System
Modeling and
Simulation
TO-3, GO-2
R1. The Transmission Owners and Generator Owners,
(specified in the data requirements and reporting procedures of
MOD-011-0_R1) shall provide appropriate equipment
characteristics, system data, and existing and future
Interchange Schedules in compliance with its respective
Interconnection Regional steady-state modeling and simulation
data requirements and reporting procedures as defined in
Reliability Standard MOD-011-0_R 1.
Brief description
disagreement on limit values.
The Measures of the standard with
the exception of M14 and to some
degree M12, all relate to the RC’s
obligations to show it did what
was required.
The requirement of entities to
follow the RC directives is covered
elsewhere (see IRO-001, IRO-004
and TOP-001).
This standard requires submissions
of steady data for its facilities to
the NERC and the RE (NPCC)
typically via the RC.
R2. The Transmission Owners and Generator Owners
(specified in the data requirements and reporting procedures of
MOD-011-0_R1) shall provide this steady-state modeling and
simulation data to the Regional Reliability Organizations,
NERC, and those entities specified within Reliability Standard
MOD-011-0_R 1. If no schedule exists, then these entities
shall provide the data on request (30 calendar days).
MOD-012-0
Dynamics Data
for Modeling
and Simulation
of the
Interconnected
Transmission
System
TO-3, GO-2
R1. The Transmission Owners, Transmission Planners,
Generator Owners, and Resource Planners (specified in the
data requirements and reporting procedures of
MOD-013-0_R1) shall provide appropriate equipment
characteristics and system data in compliance with the
respective Interconnection-wide Regional dynamics system
modeling and simulation data requirements and reporting
procedures as defined in Reliability Standard MOD-013-0_R1.
R2. The Transmission Owners, Transmission Planners,
Generator Owners, and Resource Planners (specified in the
data requirements and reporting procedures of
MOD-013-0_R4) shall provide dynamics system modeling and
simulation data to its Regional Reliability Organization(s),
NERC, and those entities specified within the applicable
#1732371
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
of point to point transmission
service to HQ loads or
otherwise need to be clarified
by HQCMÉ.
Note: version 2 of the standard
is in effect and should be
applicable now not version 1
HQCMÉ has listed.
Non Bulk
The extent to which modeling
data is required by HQCMÉ as
the RC and HQT as the PC and
TP to maintain its models
current need to be established
jointly and the standard
applicability applied
accordingly.
Processes currently in place
have met HQCMÉ’s and
HQT’s requirements to-date.
Those deemed for “Bulk”
needs, will be managed
accordingly under the proposed
QCMEP.
This standard requires submissions
of Dynamic data for its facilities to
the NERC and the RE (NPCC)
typically via the RC.
Non Bulk
The extent to which modeling
data is required by HQCMÉ as
RC and HQT as the PC and TP
to maintain its models current
need to be established jointly
and the standard applicability
applied accordingly.
Processes currently in place
have met HQCMÉ’s and
HQT’s requirements to-date.
Those deemed for “Bulk”
needs, will be managed
Page 8
Standards
Included
Title
Applicable to
RTA as:
Requirements
Brief description
reporting procedures identified in Reliability Standard MOD013-0_R 1. If no schedule exists, then these entities shall
provide data on request (30 calendar days).
PRC-001-1
System
Protection
Coordination
GOP-2
R1. Each Transmission Operator, Balancing Authority, and
Generator Operator shall be familiar with the purpose and
limitations of protection system schemes applied in its area.
R2. Each Generator Operator and Transmission Operator shall
notify reliability entities of relay or equipment failures as
follows:
R2.1. If a protective relay or equipment failure reduces system
reliability, the Generator Operator shall notify its Transmission
Operator and Host Balancing Authority. The Generator
Operator shall take corrective action as soon as possible.
R3. A Generator Operator or Transmission Operator shall
coordinate new protective systems and changes as follows.
R3.1. Each Generator Operator shall coordinate all new
protective systems and all protective system changes with its
Transmission Operator and Host Balancing.
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
accordingly under the proposed
QCMEP.
Each facility owner is required to
be familiar with its facility
protection systems and the
implications when such protection
systems fail for notifying the RC.
Non Bulk
See detailed Response 6.5.
Further is required to coordinate
applicable protection systems with
its TOP. For RTA’s Installations
this should at the interconnections
with HQT.
In a broader sense, RTA needs to
ensure coordination internally with
respect to its generation, loads and
transmission elements for its own
system reliability.
R5. 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: (Include sub-Requirement R5.1).
PRC-004-1
Analysis and
Mitigation of
Transmission
and Generation
Protection
System
Mis-operations
TO-3, GO-2
R1. The Transmission Owner and any Distribution Provider
that owns a transmission Protection System shall each analyze
its transmission Protection System Misoperations and shall
develop and implement a Corrective Action Plan to avoid
future Misoperations of a similar nature according to the
Regional Reliability Organization’s procedures developed for
Reliability Standard PRC-003 Requirement 1.
R2. The Generator Owner and Transmission Owner shall
analyze its generator Protection System Misoperations, and
shall develop and implement a Corrective Action Plan to avoid
future Misoperations of a similar nature according to the
Regional Reliability Organization’s procedures developed for
PRC-003 R1.
Investigation and reporting
protection misoperations.
Non Bulk
RTA has its own process and a
committee to discuss these
analysis with HQT and
implement mitigating actions,
as required, based on the
findings to prevent reoccurrences.
R3. The Transmission Owner, any Distribution Provider that
owns a transmission Protection System, and the Generator
Owner shall each provide to its Regional Reliability
Organization, documentation of its Misoperations analyses and
#1732371
Page 9
Standards
Included
Title
Applicable to
RTA as:
Requirements
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
Corrective Action Plans according to the Regional Reliability
Organization’s procedures developed for PRC-003 R1.
PRC-018-1
Disturbance
Monitoring
Equipment
Installation and
Data Reporting
TO-3, GO-2
R1. Each Transmission Owner and Generator Owner required
to install DMEs by its Regional Reliability Organization
(reliability standard PRC-002 Requirements 1-3) shall have
DMEs installed that meet the following requirements:
R1.1. Internal Clocks in DME devices shall be synchronized to
within 2 milliseconds or less of Universal Coordinated Time
scale (UTC).
R1.2. Recorded data from each Disturbance shall be
retrievable for ten calendar days.
R2. The Transmission Owner and Generator Owner shall each
install DMEs in accordance with its Regional Reliability
Organization’s installation requirements (reliability standard
PRC-002 Requirements 1 through 3).
R3. The Transmission Owner and Generator Owner shall each
maintain, and report to its Regional Reliability Organization on
request, the following data on the DMEs installed to meet that
region’s installation requirements (reliability standard
PRC-002 Requirements1.1, 2.1 and 3.1):
Owners required to install DMEs
by their Regional Reliability
Organization (reliability standard
PRC-002 Requirements 1-3) shall
have DMEs installed that meet
specific requirements: these need
to be or should be at the
interconnection with HQT and
could be an obligation on either
party.
Entities may wish to have their
own DME installations for their
own purposes, which can be used
during incident investigation, even
where they are not required to
meet the specific requirements of
this standard.
NA
DME installations, if required
by HQCMÉ, for local area
incident reviews, need to be at
the interconnections with HQT
and owned by HQT.
While RTA does have, for its
own purposes, its own DME
installations that can also be
used to facilitate incident
investigations, if required, they
should not be required to meet
the specific requirements of the
standard.
R4. The Transmission Owner and Generator Owner shall each
provide Disturbance data (recorded by DMEs) in accordance
with its Regional Reliability Organization’s requirements
(reliability standard PRC-002 Requirement 4).
R5. The Transmission Owner and Generator Owner shall each
archive all data recorded by DMEs for Regional Reliability
Organization-identified events for at least three years.
R6. Each Transmission Owner and Generator Owner that is
required by its Regional Reliability Organization to have
DMEs shall have a maintenance and testing program for those
DMEs that includes: R6.1 and R6.2.
TOP-001-1
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Reliability
Responsibilities
and Authorities
GOP-2
R3. Each TOP, BA, 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
R3. Follow the “directives” of the
RC and the TOP.
R6. Help out to extent possible in
case of an emergency.
Non Bulk
R7. Removal of RTA’s
Installations from service
should be limited to those that
impact “net energy” exchanges
with HQ above a set threshold
or impact the commercial
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Standards
Included
Title
Applicable to
RTA as:
Requirements
Coordinator or Transmission Operator of the inability to
perform the directive so that the Reliability Coordinator or
Transmission Operator can implement alternate remedial
actions.
R6. Each TOP, BA, 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.
Brief description
R7. Not remove BES equipment
from service if such removal will
impact the BES. A GOP is
required to notify the TOP if it
does so.
R7. Each TOP and Generator Operator shall not remove Bulk
Electric System facilities from service if removing those
facilities would burden neighbouring systems unless:
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
transaction in place and not on
a unit basis, as well as those
that impact SOLs and those for
contingency limit planning.
The specific RTA’s
Installations are identified
through the existing
agreements. These again
impact local area operations
only (see worst case
contingency in Response 6.7).
R7.1. 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.
R7.3. 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.
TOP-002-2
Normal
Operations
Planning
TSP-3, GOP-2
R3. Each 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.
R12. The Transmission Service Provider shall include known
SOLs or IROLs within its area and neighbouring areas in the
determination of transfer capabilities, in accordance with filed
tariffs and/or regional Total Transfer Capability and Available
Transfer Capability calculation processes
R13. At the request of the Balancing Authority or
Transmission Operator, a Generator Operator shall perform
generating real and reactive capability verification that shall
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Coordinating generation operation
with the BA and TSP through day
ahead planning.
Non Bulk with respect to the
GOP function
R3, R13, R14 and R15. The
need for generator
coordination, capability
verifications and forecasting
should be limited to the
generators which are under the
direct control of the RC and
explicitly available to the BA
for management of its
load / generation balance, for
the “area” within its purview.
For a load customer with load
displacement generation, such
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Standards
Included
Title
Applicable to
RTA as:
Requirements
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.
R14. 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:
R14.1. Changes in real output capabilities. (Effective August
1, 2007)
R15. 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).
R.18. Neighbouring 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.
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
as RTA, these requirements
should be limited to the
provision of forecasts for load
requirements and the forecasts
of excess “net” generation
availability.
While there is a need for load
customers, including those
with load displacement, to
provide the BAs and TOPs
with reasonable forecast of
load requirements and changes
to load needs, there is no need
to validate each load
displacement generation unit.
R13. NA
Should not apply to load
displacement generators, as
they serve their own loads
only.
R18. NA for the GOP
The TSP requirements are also
Non Bulk for interconnections
with HQT or the transmission
service RTA provides to
service HQ’s Load.
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Standards
Included
TOP-003-0
(1a)
Title
Planned Outage
Coordination
Applicable to
RTA as:
GOP-2
Requirements
Brief description
R1. Generator Operators and Transmission Operators shall
provide planned outage information.
R1. Plan outages that impact the
BES.
R1.1. 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.
R.1.1. Notify TOP if
“net”generation output deviates
more than 50 MV from planned
production.
R1.3. Such information shall be available by 1200 Central
Standard Time for the Eastern Interconnection and 1200
Pacific Standard Time for the Western Interconnection.
R2. Each TOP, BA, 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.
R3. Each TOP, BA, and Generator Operator shall plan and
coordinate scheduled outages of telemetering and control
equipment and associated communication channels between
the affected areas.
R2. Plan with and notify TOP if
AVR9 or stabiliser equipments are
to be removed from service.
R3. Plan with and notify TOP if
telemetering or control equipment
that affects the BES is to be
removed from service.
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
Non Bulk
R1. Should be applicable from
a “net energy” availability
perspective only (see
comments for TOP-002
above). RTA transmission line
outages between the stations
only need to be identified for
HQT/HQCMÉ local area
security analysis.
R2. Applicable as Non Bulk
and from the “net” reactive
power (VAR) capability
perspective to meet RTA’s
own VAR requirements and to
maintain voltage limits at unity
power factor at the
interconnections with HQT. It
should not be viewed from the
individual generation unit
AVR outage coordination
perspective. Provision of
reactive support over and
above these requirements
should be through commercial
arrangements.
Bulk. With respect to stabilizer
outage reporting, only if
stabilizer “in-service” statuses
affect HQT’s / HQCMÉ’s
established IROLs. Otherwise,
“Non Bulk” if only affects
SOLs; would be determined
through discussions with
HQCMÉ.
R3. Would continue to apply
for local area requirements per
current outage reporting
practices.
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Standards
Included
TOP-006
Title
Monitoring
System
Conditions
Applicable to
RTA as:
GOP-2
Requirements
R1.1. Each Generator Operator shall inform its Host Balancing
Authority and the Transmission Operator of all generation
resources available for use.
Brief description
Required for BA to conduct
appropriate resource adequacy
analysis and be aware when
resources designated to meet the
BA’s area load requirements
become unavailable and enables
the TOP to conduct security
analysis for SOL.
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
NA from a generating unit
specific perspective.
Bulk from a “net” energy
availability forecast
perspective per existing
agreements for HQCMÉ
resource adequacy and security
(reliability) analysis.
The need to inform the host
BA (HQCMÉ) and the TOP
(HQT) of generator availability
should be limited to those
generators that are under the
direct control of the RC and
TOP and explicitly available to
the BA for purposes of
management of
load/generation balance, for
the “area” within its purview
(Québec Load), if used for that
purpose and for local area
security analysis.
For a load customer with load
displacement generation, such
as RTA, this requirement
should be limited to the
provision of forecasts of excess
“net” generation availability
per its commercial agreements
with HQP and used for the
purposes of HQCMÉ’s
reliability analysis.
VAR-002-1a
Generator
Operation for
Maintaining
Network
Voltage
Schedules
GOP-2, GO-2
R1. 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. (Sub- Requirements
R2.1 and R2.2)
R2. Unless exempted by the Transmission Operator, each
Generator Operator shall maintain the generator voltage or
Reactive Power output (within applicable Facility Ratings10) as
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GOP must 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 GOP has
notified the TOP otherwise.
Non Bulk
In the absence of commercial
arrangements to do otherwise ,
applicability of this standard
should be limited to assuring
the availability of sufficient
reactive power (VAR) to meet
RTA’s own requirements and
assure HQT interconnection
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Standards
Included
Title
Applicable to
RTA as:
Requirements
directed by the Transmission Operator.
R3. Each Generator Operator shall notify its associated
Transmission Operator as soon as practical, but within 30
minutes of any of the following: (Sub- Requirements R3.1 and
R3.2)
R4. The Generator Owner shall provide the following to its
associated Transmission Operator and Transmission Planner
within 30 calendar days of a request. (Sub- Requirements
R4.1)
Brief description
“Bulk”, “Non Bulk” or
NA (not applicable) in the
context of the proposed
two-tier approach process
voltage limits, which have
local area reliability
implications, within the
objective of maintaining unity
power factor, in accordance
with existing agreements with
HQT though not within the
standards prescribed AVR
control mode11 on a unit by
unit basis.
R5. After consultation with the Transmission Operator
regarding necessary step-up transformer tap changes, the
Generator Owner shall ensure that transformer tap positions
are changed according to the specifications provided by the
Transmission Operator, unless such action would violate
safety, an equipment rating, a regulatory requirement, or a
statutory requirement. ( Sub- Requirements R5.1)
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Page 15
A number of standards were excluded in HQCMÉ’s application. Of the standards excluded, PRC-005 is required for local area reliability. PRC-015,
PRC-016 and PRC-017 do not apply since there is no special protection scheme (SPS) in place. Otherwise, they would be required for local area reliability,
unless designated as a class 1 SPS, in which case it becomes a “Bulk” system requirement. Another standard that was not included by HQCMÉ is the Cyber
Standard, which requires internal assessment by HQCMÉ.
Standard
not
Included
PRC-005
Title
Transmission and
Generation
Protection System
Maintenance and
Testing
Applicable
to RTA as:
GO-2
TO-3
Requirements
R1. System and each Generator Owner that owns a
generation Protection System shall have a Protection
System maintenance and testing program for
Protection Systems that affect the reliability of the
BES. The program shall include:
R1.1. Maintenance and testing intervals and their
basis.
R1.2. Summary of maintenance and testing
procedures.
Brief description
Protection system maintenance
programs in place.
“Bulk”, “Non Bulk” or NA (not
applicable) in the context of the
proposed two-tier approach
process
Non Bulk
There is no U/F relays in place on the
generators and transmission classed as
“Non Bulk”.
Required for local area reliability only
and ensures incidents only remove
facilities required to clear the fault.
R2. Each Transmission Owner and any Distribution
Provider that owns a transmission Protection System
and each Generator Owner that owns a generation
Protection System shall provide documentation of its
Protection System maintenance and testing program
and the implementation of that program to its
Regional Reliability Organization on request (within
30 calendar days). The documentation of the
program implementation shall include:
R2.1. Evidence Protection System devices were
maintained and tested within the defined intervals.
R2.2. Date each Protection System device was last
tested/maintained.
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