Version 5.0
Reliability Coordinator Area
Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
APPLICABILITY: Reliability Coordinator
Transmission Operator
I. Purpose
Prepare Reliability Coordinator (RC) System Operators and Transmission Operators (TOP)
to enable effective coordination of the System restoration process to ensure reliability is
maintained during restoration and priority is placed on restoring the Interconnection.
II. Introduction
The RC System Operator (RCSO) has a coordinating role in system restoration to ensure
reliability of the Bulk Electric System (BES) is maintained during restoration and that priority
is placed on restoring the Western Interconnection. The RCSO accomplishes this task by
coordinating the actions of the Balancing Authorities (BA) and Transmission Operators
(TOPs) over a wide area. The wide area view of the RC Area gives the RCSO the distinct
advantage of being able to recognize how widespread the problem is, what needs to be
done to stabilize the remaining portion of the Interconnection, and how to efficiently restore
and resynchronize any islands that may have been formed during the disturbance. The Shift
Lead RCSO will be the single point of contact for the RCSOs regarding their restoration
coordination activities.
This restoration plan provides the RCSOs and TOPs with requirements and general
guidelines to use to address system restoration conditions and is categorized into the
following sections:
•
Communications
•
RCSO Roles and Responsibilities
•
TOP Roles and Responsibilities
•
System Restoration: Whole or Partial Transmission System Islanding
•
System Restoration: Blackout Restoration Using Connection to an Energized
System
•
System Restoration: Black Start Restoration – Energizing a De-energized
System
•
Post Restoration: Resuming Normal Operations
Appendices, presented as separate attachments from this plan, contain various
technical parameters and the individual TOP Restoration Plans. Additional information
such as designated Black Start units and Nuclear Plants are included within the
appendices.
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
Implementation of each TOP’s restoration plan, in coordination with the RCSO and the
requirements and guidelines contained in this document will ensure the necessary
coordination between RCSOs, BAs and TOPs and will enable the expeditious
restoration of the BES. The scope of this RC Area Restoration Plan begins when
either 1:
•
Blackstart Resources are utilized to re-energize a shut down area of the BES, or
•
Separation has occurred between neighboring RCs or with the Alberta Electric
System Operator (AESO) Area, or
•
An energized island has been formed on the BES within the RC Area.
Additionally, the RCSO will consider the system to be in an operational emergency
condition when any RC Area TOP has implemented their System Restoration Plan(s).
The RC Area Restoration Plan ends when all of the RC Area TOPs are interconnected.
Note 2: It is impossible to predict all the possible combinations of problems that may
occur after a major electric system failure or underfrequency load shedding event. If
the restoration plan cannot be implemented as expected because actual system
conditions do not match studied conditions, system operators shall utilize their
restoration plan philosophies to implement alternative measures for achieving system
restoration. This document is not intended to defer or replace professional operator
judgment during conditions requiring restoration of the system. The RCSOs shall
coordinate restoration activities, monitor restoration progress and coordinate any
needed assistance.
Communications3
The RCSO is the primary contact for disseminating information regarding restoration to
neighboring RCs, TOPs, and BAs in its RC Area. Active communications regarding the
status of the restoration effort will be established and maintained between the RCSO and
the BAs and TOPs utilizing RC conference calls and the Reliability Messaging Tool (RMT)
system. The RCSO will maintain close contact with the affected entities and TOPs should
provide periodic updates on restoration progress. The RCSO will distribute messages via
RMT to keep registered entities and AESO informed of the situation and via the Reliability
Coordinator Information System (RCIS) and the NERC Reliability Coordinator Hotline to
inform adjacent Reliability Coordinators. The Shift Lead RCSO will coordinate reporting to
regulatory agencies and government agencies as applicable.
1
NERC Standard EOP-006-2 Requirement R1
2
NERC Standard EOP-006-2 Requirements R7 and R8
3
NERC Standard EOP-006-2 Requirements R1.6, R1.7 and R1.8
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
RCSO communication, including directives, to the Generator Owners (GO) and Generator
Operators (GOP) will be conveyed through the host BA/TOP. The RCSO, TOPs, and BAs
will follow established protocols using three-part communications for all directives.
III. RCSO Roles and Responsibilities
The RCSO has the authority to coordinate restoration activities, monitor restoration progress
and coordinate any needed assistance. The Shift Lead RCSO will be the single point of
contact for the RCSOs regarding their restoration coordination activities.
Following a major disturbance, the RC Area may be totally or partially shut down and
contain isolated electrical islands consisting of load and generation. When such a
Disturbance occurs, the RCSO shall complete an initial assessment to determine whether
the RC Area Restoration Plan should be executed. The high level process to follow after an
event occurs can be broken down into the following actions: analyze, stabilize, restore, and
return to normal operations. 4
Analyze – The RCSO will conduct a detailed assessment of the RC Area status to determine
system conditions. Specifically, the RCSO must:
•
Determine if electrical islanding has occurred and, if so, identify the existing islands
and their respective boundaries;
•
Determine if a portion of the RC Area has been shut-down and if Blackstart
Resources are going to be used;
•
Identify TOPs impacted by the Disturbance and which TOPs must initiate their
restoration plans to restore shut-down areas to service or to resynchronize energized
islands;
•
Determine the status of transmission and generation facilities
o
At a minimum, the RCSO must identify major transmission and generation
facilities that are no longer in service and evaluate the resultant impact to
BES reliability;
•
Identify load required for the restoration effort;
•
Determine status of ties with neighboring RCs 5 and AESO;
•
Identify voltage levels and frequency; and
•
Identify any actual exceedances of both established limits and potential
Interconnected Reliability Operating Limits (IROL).
4
NERC Standard EOP-006-2 Requirement R1.1
5
NERC Standard EOP-006-2 Requirement R1.4
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
Stabilize – The RCSO will request or direct actions necessary to stabilize and maintain
reliable operations of the RC Area as a whole and/or of existing electrical islands. The
RCSO must ensure on-line generation and load is balanced to operate within established
limits.
Restore – The RCSO will coordinate with impacted TOPs to identify and track restoration
objectives and goals. 6 The RCSO must coordinate restoration activities to ensure each TOP
completes the actions necessary to 7:
•
Provide off-site power requirements to nuclear power plants, as applicable;
•
Use Blackstart Resources as required to restore shut-down areas to service with
primary focus on providing start-up power to available generating units and restoring
substation station service;
•
Re-establish interconnections with other TOPs within the RC Area including
resynchronization of electrical islands; and
•
Transfer authority back to BAs
o
Identify when each TOP has restored its system to a state whereby the
choice of the next Load to be restored is not driven by the need to control
frequency or voltage.
Return to normal operation – The RCSO will declare a return to normal operations when all
TOPs are interconnected and each TOP has transferred authority back to its respective BA.
The RCSO will determine when it is appropriate to synchronize electrical islands and reestablish interconnections between TOPs within its RC Area and with Adjacent RCs and
AESO. 8 When determining if electrical islands should be synchronized, the RCSO must
coordinate with the TOP System Operators to 9:
•
Determine if each island is stable and operating within acceptable limits;
•
Determine if, once combined, the resultant island will be capable of sustaining all
credible contingencies (i.e., operating in an N-1 secure state);
•
Evaluate system conditions and determine:
6
NERC Standard EOP-006-2 Requirement R1.6
7
NERC Standard EOP-006-2 Requirement R1.3
8
NERC Standard EOP-006-2 Requirement R1.5
9
NERC Standard EOP-006-2 Requirement R8
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Restoration Plan
o
Point(s) of synchronization;
o
Status of auto-reclosing and synchronization relays;
o
Status of Remedial Action Schemes (RAS) or relays that may affect the
synchronization effort;
o
Automatic Generation Control (AGC) control mode(s) and unit(s) used for
frequency control; and
o
Acceptable transfer limits and expected interchange upon synchronization

•
NERC Standards
EOP-006-2 and
EOP-005-2
Zero schedules on tie lines is expected;
Ensure each island is operating within acceptable frequency and voltage ranges prior
to approving synchronization of islands.
Prior to granting permission to re-establish interconnections between TOPs within the RC
Area, the RCSO must coordinate with the TOP System Operators to:
•
Identify the point of interconnection and evaluate anticipated impacts to system
conditions;
•
Verify acceptable transfer limits and expected interchange;
TOPs must notify the RCSO prior to transferring operations and authority back to their
respective BA following a restoration event. Prior to returning to normal operation the
RCSO and TOP shall 10:
•
Verify restoration objectives met and all BAs and TOPs are prepared to return to
normal operations;
•
Verify the Interconnection is stable and frequency control and generation-load
balancing responsibilities may be returned to the BA (i.e., the next Load to be
restored is not driven by the need to control frequency and voltage);
•
Verify TOPs are operating synchronously (i.e., interconnected system operations);
and
•
Verify the status of the ties with neighboring RCs 11 and AESO.
The RCSO will work with the affected BAs and TOPs, including the GOPs via the host BA/
TOP, as well as neighboring RCs and AESO to monitor restoration progress, coordinate
restoration and take actions to restore the BES frequency within acceptable operating
10
NERC Standard EOP-006-2 Requirement R1.9
11
NERC Standard EOP-006-2 Requirement R1.4
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
limits. 12 Actions to take may include, but are not limited to, directing generation adjustments,
placing additional generators on-line or shedding load. If any part of the restoration plan(s)
cannot be implemented as expected because actual conditions do not match studied
conditions, the RCSO shall utilize restoration plan philosophies to implement alternative
measures for achieving system restoration. The RCSO shall approve, communicate and
coordinate the re-synchronization of major system islands and/or synchronizing points so as
not to cause a burden on adjacent TOPs, BAs, AESO or RC Areas. 13 The Shift Lead RCSO
shall ensure that appropriate regulatory reports are provided.
IV. TOP Roles and Responsibilities
Each RC Area TOP shall have a restoration plan to re-establish its electric system in a
stable and orderly manner in the event of a partial or total shutdown of its system. The plan
should include the following information:
•
Strategies for system restoration that is coordinated with the RC Area high level
strategy for restoring the Interconnection 14 of analyze, stabilize, restore and return to
normal operations.
o
The plan must include a requirement to coordinate with the RCSO to assess
initial conditions and to keep the RCSO informed of progress with key
milestones, load/generation restored and remaining islands not yet
synchronized to the Interconnection.
•
A description of how all Agreements or mutually agreed upon procedures or
protocols for off-site power requirements of nuclear power plants, including priority of
restoration, will be fulfilled during System restoration. 15
•
Procedures for restoring interconnections with other TOPs under the direction of the
RCSO. 16
o
TOP plans should include a list of synchronizing locations and a provision to
coordinate with neighboring entities when tie lines are affected, when there is
any potential for cross border impact and when preparing to resynchronize
islands.
o
Blackstart assistance that has been identified in the plan and is also included
in the neighboring TOP plan needs to be compared such that the point of
12
NERC Standard EOP-006-2 Requirement R7
13
NERC Standard EOP-006-2 Requirement R8
14
NERC Standard EOP-005-2 Requirement R1.1
15
NERC Standard EOP-005-2 Requirement R1.2
16
NERC Standard EOP-005-2 Requirement R1.3
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
interconnection for establishing the cranking path from the border is
consistent.
•
o
Identification of each Blackstart Resource and its characteristics including but
not limited to, the name of the Blackstart Resource, its location, its megawatt
and megavar capacity and the type of unit 17.
o
Fuel types and availability/duration of fuel supply need to be specified for
Blackstart generators.
o
If no Blackstart generator is identified, a path needs to be identified from the
external tie location to the unit(s) to be started and the external entity
identified.
Identification of Cranking Paths and initial switching requirements between each
Blackstart Resource and the unit(s) to be started 18.
o
•
•
TOPs must consider the availability of the Blackstart units and the initial
transmission switching requirements in assessing the viability of their
individual Blackstart Restoration Plan.
Identification of acceptable operating voltage and frequency limits during
restoration. 19
o
Acceptable operating voltages, voltage control considerations, and
techniques for controlling voltage are included in the plan.
o
Frequency limits, frequency control considerations and techniques for
controlling frequency are included in the plan.
o
For TOPs with no generation control, list the entity responsible for generation
control as specified in the plan.
Operating Processes to reestablish connections within the TOP’s system for areas
that have been restored and are prepared for reconnection. 20
o
The island resynchronization process described in the plan is consistent with
the RC Interconnection restoration process.
17
NERC Standard EOP-005-2 Requirement R1.4
18
NERC Standard EOP-005-2 Requirement R1.5
19
NERC Standard EOP-005-2 Requirement R1.6
20
NERC Standard EOP-005-2 Requirement R1.7
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Reliability Coordinator Area
Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
o
The resynchronization process described in the plan specifies that the RCSO
must be notified prior to synchronizing any internal/external islands.
o
The resynchronization process described in the plan specifies that
resynchronization to neighboring TOPs or connecting to the Eastern
Interconnection or to the Alberta System is under the direction of the RCSO.
•
Operating Processes to restore Loads required to restore the System, such as
station service for substations, units to be started or stabilized, the Load needed to
stabilize generation and frequency, and provide voltage control. 21
•
Operating Processes for transferring authority back to the BA in accordance with the
RC’s criteria. 22
o
TOPs must notify the RCSO prior to transferring operations and authority
back to their respective BA.
o
Verify restoration objectives met and all BAs and TOPs are prepared to return
to normal operations.
o
Verify the Interconnection is stable and frequency control and generation-load
balancing responsibilities may be returned to the BA (i.e., the next Load to be
restored is not driven by the need to control frequency and voltage).
o
Verify TOPs are operating synchronously (i.e., interconnected system
operations).
o
Verify status of interconnections with neighboring RCs and AESO.
Each TOP will submit the most recent version of its individual TOP restoration plan, in
accordance with EOP-005-2, to the RC either by uploading it through the secure portal on
peakrc.org or by emailing it to rctopplans@peakrc.com . All submissions must include a
completed RC Transmission Operator System Restoration Plan Worksheet. The latest
version of the RC Transmission Operator System Restoration Plan Worksheet is located on
both peakrc.org and peakrc.com.
•
Upon approval of a new or revised procedure/plan the entity shall notify neighboring
TOPs of the update.
Additional TOP responsibilities include:
•
Establish and maintain active communications with the RCSO, other TOPs, hosted
GOPs, and other load-serving entities within their operating areas.
21
NERC Standard EOP-005-2 Requirement R1.8
22
NERC Standard EOP-005-2 Requirement R1.9
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•
NERC Standards
EOP-006-2 and
EOP-005-2
All TOPs will notify the RCSO:
o
Prior to synchronizing electrical islands;
o
Before establishing interconnections with adjacent TOPs;
o
Prior to taking actions that deviate from established restoration strategies or
procedures (example: picking up load for reasons other than frequency or
voltage control);
o
Before altering acceptable operating voltage or frequency limits;
o
If Blackstart resources or identified cranking paths become unavailable or
inoperable;
o
If it is determined the TOP may be unable to or will have difficulty in meeting
restoration milestones; or
o
If established limits have been exceeded (i.e., IROLS, System Operating
Limits, acceptable voltage or frequency limits).
•
Implement area restoration following partial or complete blackout according to
individual TOP restoration procedures.
•
When requested, communicate to the RCSO the extent of the blackout and status of
the system.
•
Guide restoration of critical communications and computer links within their operating
areas.
System Restoration: Whole or Partial Transmission System Islanding23
V.
The RCSO is responsible for the overall coordination of the system restoration. The Shift
Lead RCSO will be the single point of contact for the RCSOs regarding their restoration
coordination activities. Blackout boundaries should be identified by the RCSO and all entities
notified. The RCSO will maintain the energized portion of the transmission system within
established line loadings, voltages and first contingency protections.
Once the RCSO has determined that islanded conditions exist within the RC Area, the RCSO
will inform all BAs and TOPs of the islanded condition. To ensure a coordinated restoration
following a disturbance, all TOPs will:
23
•
Communicate if they had any underfrequency load shedding relay operations and
•
Follow instructions given by the RCSO.
NERC Standard EOP-006-2 Requirement R1.2
Classification: Public
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
Before all systems have been synchronized:
•
All systems wholly within the separation zone will contact the RCSO to receive
instructions on a coordinated restoration procedure.
•
All systems wholly within the separation zone will instruct remaining generation
within the separation zone to increase generation until a frequency of at least 59.5
Hz but no greater than 60.5 Hz is achieved. At this point, each system operator can
set their net interchange schedule to the value of their system’s actual net
interchange and resume tie line control.
•
Systems partially affected by the separated zone may be requested by the RCSO to
adjust generation in the zone as necessary to assist in reestablishing synchronized
ties with the Interconnection.
•
If the above actions have not restored frequency to synchronizing range, it is the
responsibility of the RCSO to instruct the deficient systems to increase generation,
drop load or take other available action to promptly restore the frequency to
synchronizing range.
•
At no time shall any affected system manually restore load, unless specifically
instructed to do so by the RCSO.
After all systems have been synchronized:
•
The RCSO shall notify all entities once synchronization has been accomplished.
•
The RCSO shall direct load restoration with the affected entities.
•
At no time shall a system manually restore load without verbal permission from the
RCSO.
•
All operating reserves shall be reestablished.
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
VI. System Restoration: Blackout Restoration Using Connection to an Energized
System 24
Assumptions:
•
One or more TOPs in the RC Area have experienced a blackout or islanded
condition.
•
Other TOPs may be affected by the disturbance.
•
The restoration can be accomplished through the connection to another energized
system.
•
Restoration will be through the implementation of individual TOP’s blackout
restoration procedures in coordination with the RCSO.
•
All generators, transmission lines, breakers, reactive devices, SCADA, and
telecommunications are available.
Priorities:
•
If nuclear stations within the RC Area have lost access to off-site power, the RCSO
shall coordinate with the affected TOPs to give top priority to restoration of off-site
power to the affected nuclear stations.
•
Restore startup power to all available generating units. Units still running, but
carrying only their own auxiliary load, can be synchronized as soon as the plant has
stabilized and is ready and the transmission system is ready.
•
Notify the plant operator before energizing a system up to a generator.
o
•
Synchronize with the Interconnection as soon as possible.
•
Energize major transmission circuits.
o
•
24
CAUTION: In restoring startup power to a unit in a blackout condition (unit
did not stay on its own auxiliary transformer), the restoration must be done in
such a way that the plant auxiliary busses are not energized without plant
operating personnel assuring that no equipment is unduly connected to the
auxiliary bus. Failure to do this may result in equipment damage.
CAUTION: The system operator must carefully watch generators and tie lines
to avoid system separation or high/low voltage runaway during restoration.
Restore service to all customers.
NERC Standard EOP-006-2 Requirement R1.2
Classification: Public
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Reliability Coordinator Area
Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
General Procedures:
•
The RCSO will determine the boundaries of the blacked out area and its effect on the
Interconnection.
•
TOPs will determine the extent of the blackout for their area and communicate this to
the RCSO.
•
TOPs will determine a plan for restoration utilizing established priorities.
•
TOPs can begin restoration activities that do not affect the Interconnection.
•
The RCSO shall approve, communicate and coordinate the re-synchronizing of
major system or synchronizing points so as not to cause a burden on adjacent TOPs,
BAs or RC Areas.
•
The TOPs will begin restoration plans in coordination with the RCSO. If possible
restore the de-energized system from the interconnected system.
•
TOP’s restoration activities should maintain proper frequency, voltage, line loading
and generator loading within the emergency limits at all times.
•
o
Any expected violation of these parameters should be coordinated with the
RCSO and any affected entity.
o
Considerations should be made for cold load pickup normalization time of up to
30 minutes.
In re-energizing the system, protect utility and customer equipment from damage due
to overvoltage, undervoltage, overcurrent, overfrequency or underfrequency.
o
Emergency voltage limits are +/- 10% nominal voltage.
•
Avoid energizing high voltage cables at the end of a long, lightly loaded system.
•
Open, or check to be open, breakers for transmission and substation capacitor banks
during the initial re-energization process. Use shunt reactors as required to control
voltage.
o
CAUTION: Until station service is restored to a substation, the breakers at that
station can be operated only a relatively few times before they become
inoperative due to loss of stored energy.
•
In restoring startup power to generating units, bypass bulk stations to speed up
restoration, if possible, except where required to control voltage or provide relay
protection.
•
When loading the system, in order to control the voltage, consideration should be
given to Surge Impedance Loading.
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Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
•
Switch lines necessary to provide synchronization at a plant location to the
Interconnection or to another island. It is also possible to provide synchronization at
an auto-synch location.
•
Adjust frequency and voltage to allow synchronization of the systems and utilize the
RC Interconnection Restoration Check Sheet available in the referenced appendices.
VII. System Restoration: Blackstart Restoration Energizing a De-energized System 25
Assumptions:
•
One or more TOPs of the RC Area have experienced a blackout condition.
•
Other TOPs may be affected by the disturbance.
•
The restoration through the connection to another energized system cannot be
accomplished in a timely manner or at all depending on the state of the transmission
system.
•
Restoration will utilize individual TOP Blackstart Restoration Plans in coordination
with the RCSO.
•
All transmission lines, breakers, reactive devices, SCADA and telecommunications
are available. Some generators are assumed to have Blackstart capability.
•
There is a defined process/method for synchronization of an island with the
energized Interconnection or with another island.
Priorities:
25
•
Start an Island as close as possible to a nuclear plant.
•
If the nuclear plants have lost off-site power, restore it as quickly as possible.
•
Restore startup power to all available generating units. Units still running, but
carrying only their own auxiliary load, can be synchronized as soon as the plant has
stabilized and is ready and the transmission system is ready.
•
Notify the plant operator before energizing a system up to a generator.
NERC Standard EOP-006-2 Requirement R1.2
Classification: Public
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o
NERC Standards
EOP-006-2 and
EOP-005-2
CAUTION: In restoring startup power to a unit in a blackout condition (unit
did not stay on its own auxiliary transformer), the restoration must be done in
such a way that the plant auxiliary busses are not energized without plant
operating personnel assuring that no equipment is unduly connected to the
auxiliary bus. Failure to do this may result in equipment damage.
•
Synchronize with the Interconnection as soon as possible.
•
Energize major transmission circuits.
o
•
CAUTION: The system operator must carefully watch generators and tie
lines to avoid system separation or high/low voltage runaway during
restoration.
Restore service to all customers.
General Procedures
•
The RCSO will determine the boundaries of the blacked out area and its effect on the
Interconnection.
•
TOPs will determine the extent of the blackout for their area and communicate this to
the RCSO.
•
TOPs will determine a plan for restoration utilizing established priorities.
•
TOPs can begin restoration activities that do not affect the Interconnection.
•
Open the de-energized tie lines.
•
Start Blackstart capable generation.
•
Communicate Blackstart generator status to the RCSO as conditions change.
•
Energize transmission circuits with a few substations to minimize load pickup.
•
Pick up radial load areas while maintaining the ability to synchronize the Island to an
energized high voltage transmission system.
•
It may be difficult to maintain a close tolerance on 60 Hz operation. Operation
between 59.5 Hz and 60.5 Hz should be tolerable.
•
In re-energizing portions of the blacked out system from isolated generation, try to
limit the frequency dip to a maximum of 0.2 Hz on each step of load pick up. A step
load pick up of 5% of generation capacity of units on line in the Island is roughly
equivalent to 0.2 Hz.
o
Considerations should be made for cold load pickup normalization time of up
to 30 minutes.
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NERC Standards
EOP-006-2 and
EOP-005-2
•
When possible, tie generation areas together to increase the amount of generation
available to pick up load and minimize frequency variations.
•
In re-energizing the system, protect utility and customer equipment from damage due
to overvoltage, undervoltage, overcurrent, overfrequency and underfrequency.
o
Emergency voltage limits are =/- 10% nominal voltage
•
Avoid energizing high voltage cables at the end of a long, lightly loaded system.
•
Open, or check to be open, breakers for transmission and substation capacitor banks
during the initial re-energization process. Use shunt reactors as required to control
voltage.
o
CAUTION: Until station service is restored to a substation, the breakers at
that station can be operated only a relatively few times before they become
inoperative due to loss of stored energy.
•
In restoring startup power to generating units, ensure the Island capacity is large
enough to withstand the impact of picking up subsequent auxiliary load.
•
In energizing the transmission system and restoring customer service, energize it in
a step-by-step ladder sequence.
•
When loading the system, in order to control the voltage, consideration should be
given to Surge Impedance Loading.
•
Switch lines necessary to provide synchronization at a plant location to the
Interconnection or to another island. It is also possible to provide synchronization at
an auto-synch location.
•
Adjust frequency and voltage to allow synchronization of the systems and utilize the
RC Interconnection Restoration Check Sheet available in the referenced appendices.
Post Restoration: Resuming Normal Operations 26
VIII.
Assumptions:
26
•
All RC Area TOPs that have the capability to be interconnected are interconnected
and operating synchronously.
•
The interconnected RC Area TOPs are connected to the Alberta System or the
Eastern Interconnection as appropriate.
•
The RCSO has verified that the RC Area BES is in a stable state
NERC Standard EOP-006-2 Requirement R1.9
Classification: Public
Page 15 of 17
Effective Date: June 1, 2016
Version 5.0
Reliability Coordinator Area
Restoration Plan
NERC Standards
EOP-006-2 and
EOP-005-2
•
The RCSO has verified with all RC Area BAs and TOPs that they are ready to return
to normal operations mode.
•
The RCSO has verified the status of adjacent interconnections with the adjacent
Reliability Coordinators and AESO and has confirmed that adjacent interconnections
are ready to return to normal operations mode with RC Area operating entities.
Priorities:
•
The RCSO has verified that the cause of the disturbance that initiated the restoration
event is known and is no longer a threat to the BES.
•
The RCSO has verified that all major load centers have been restored prior to
returning to normal operations.
•
Actual BES line flows and contingency analysis results should indicate that the BES
is operating within applicable System Operating Limits (SOLs) and Interconnected
Reliability Operating Limits (IROLs).
General Procedures:
•
The RCSO shall communicate with all RC Area BAs and TOPs (or their designated
agent) and verified the status of their systems and that they are ready to return to
normal operations.
•
The RCSO shall contact AESO and the neighboring RCs to verify that the
neighboring RC Areas and adjacent operating entities are ready to resume normal
operations with the RC Area’s operating entities.
•
The RCSO shall issue a message on RMT and RCIS messaging systems
announcing a return to normal operations.
Classification: Public
Page 16 of 17
Effective Date: June 1, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
Appendix
Description
Classification
1
Technical Parameters:
Nominal Voltage Ranges
Surge Impedance Loading
Public
2
RC Interconnection Restoration
Check Sheet
Public
3
Designated Blackstart Units
Confidential
4
Nuclear Plants
Confidential
5
TOP Arizona Electrical Power Co.
Confidential
6
TOP Arizona Public Service Plan
Confidential
7
TOP Avista Corporation Plan
Confidential
8
TOP Black Hills Power Plan
TOP Black Hills Corporation Plan
Confidential
9
TOP Bonneville Power
Administration Plan
Confidential
10
TOP California Independent System
Operator Plan (SDGE, PGAE, SCE,
TBC, VEA)
Confidential
11
TOP Chelan County PUD Plan
Confidential
12
TOP Clark County PUD Plan
Confidential
13
TOP Colorado Springs Utilities Plan
Confidential
Classification: Public
Page 1 of 6
Effective Date: July 15, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
14
TOP CENACE Plan
Confidential
15
Reserved
Confidential
16
TOP Douglas County PUD Plan
Confidential
17
TOP El Paso Electric Company Plan
Confidential
18
TOP Eugene Water and Electric
Board Plan
Confidential
19
TOP Farmington Electric Utility
Service Plan
Confidential
20
TOP Grant County PUD Plan
Confidential
21
TOP Hetch Hetchy Water and Power
Plan
Confidential
22
TOP Idaho Power Company Plan
Confidential
23
TOP Imperial Irrigation District Plan
Confidential
24
TOP Intermountain Rural Electric
Association Plan
Confidential
25
TOP Los Angeles Department of
Water and Power Plan
Confidential
26
Reserved
Confidential
27
TOP Modesto Irrigation District Plan
Confidential
Classification: Public
Page 2 of 6
Effective Date: July 15, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
28
TOP Montana Alberta Tie LTD Plan
(MATL)
Confidential
29
TOP National Nuclear Security
Administration – Los Alamos Plan
Confidential
30
TOP Nevada Power Plan
(NV Energy South, NVS)
Confidential
31
TOP Northwestern Energy Plan
Confidential
32
TOP PacifiCorp Plan
Confidential
33
TOP Pend Oreille County PUD Plan
Confidential
34
TOP Platt River Power Authority Plan
Confidential
35
TOP Portland General Electric Plan
Confidential
36
TOP Public Service of Colorado
Plan
Confidential
37
TOP Public Service Company of New
Mexico Plan
Confidential
38
TOP Puget Sound Energy Plan
Confidential
39
TOP Sacramento Municipal Utility
District Plan
Confidential
40
TOP Salt River Project Plan
Confidential
41
TOP Seattle City Light Plan
Confidential
Classification: Public
Page 3 of 6
Effective Date: July 15, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
42
TOP Sierra Pacific Power Plan
(NV Energy North, NVN)
Confidential
43
TOP Silicon Valley Power Plan
Confidential
44
TOP Snohomish PUD Plan
Confidential
45
Reserved
46
TOP Tacoma Power Plan
Confidential
47
TOP Tri-State Generation and
Transmission Association Plan
Confidential
48
TOP Tucson Electric Power Plan
Confidential
49
TOP Turlock Irrigation District Plan
Confidential
50
51
52
53
54
Classification: Public
TOP Western Area Power
Administration Colorado Missouri
Region Plan (WACM) and Western
Area Power Administration Lower
Colorado Region Plan (WALC)
TOP Western Area Power
Administration Sierra Nevada
Region Plan (WASN)
TOP Western Area Power
Administration Upper Great Plains
Region Plan (WAUW)
TOP BC Hydro Plan (BCHA)
(Includes BMWL, DGP, and
TMGP)
TOP Catalyst Paper – Powell River
Division Plan (CPPR)
Page 4 of 6
Confidential
Confidential
Confidential
Confidential
Confidential
Effective Date: July 15, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
55
Reserved
Confidential
56
TOP Fortis BC Plan (FBC)
Confidential
57
Reserved
Confidential
58
Reserved
Confidential
59
TOP Teck Metals Plan (TECK)
Confidential
Classification: Public
Page 5 of 6
Effective Date: July 15, 2016
Peak Reliability
Version 7.1
RC Area Restoration Plan
Appendix List
Version History
Rev.
Date
Action
By
Change Tracking
1.0
06/21/2013
Issued for Implementation
P Savage
J Hoyt
Original WECC RC Area Restoration
Plan Appendix List
1.1
10/09/2013
Revised and Reissued
P Savage
Added TOP MATL
2.0
12/19/2013
Revised and Reissued
M Granath
Updated to Peak Reliability template
and associated language,
alphabetized TOP’s
3.0
3.26.2014
Revised and Reissued
M Granath
Milford (First Wind) removed, no
longer a registered TOP
4.0
5/05/2014
Revised and Reissued
M Granath
Cedar Creek Wind Energy removed,
no longer a registered TOP. New
Harquahala is no longer a
registered TOP.
5.0
5/28/2014
Revised and Reissued
M Granath
Arlington Valley is no longer a
registered TOP, removed.
5.1
10/15/2014
Revised and Reissued
M Granath
Mesquite Power deregistered as a
TOP, removed from list.
6.0
7/30/2015
Revised and Reissued
M Granath
CFE named changed to CENACE,
Added Appendices 53 - 59
7.0
5/10/2016
Revised and Reissued
M Granath
SWTC renamed to AEPC
7.1
7/14/2016
Revised and Reissued
B Taylor
Innergex is no longer a registered
TOP. Catalyst Paper- Crofton
Division and Port Alberni Division
(CPCD, CPPAD) are no longer
registered TOP’s.
Classification: Public
Page 6 of 6
Effective Date: July 15, 2016
Peak Reliability
Version 1.1
RC Area Restoration Plan
Appendix 1
Technical Parameters
Nominal Transmission Voltage Ranges*
Maximum
Voltage (kV)
Maximum
Voltage (kV)
Continuous
Emergency
450
550
550
345
311
362
379
230
207
245
253
138
124
145
152
115
104
121
125
69
62
73
75
Nominal Voltage
(kV)
Minimum Voltage
(kV)
500
* The values shown are general guidelines only. Individual TOPs should utilize their voltage range
standards.
Surge impedance Loading (SIL)**
Nominal Voltage
(kV)
Surge Impedance
Loading (SIL)
500
940 MW
345
420 MW
230
132 MW
138
48 MW
115
33 MW
69
12 MW
**SIL values shown are to be used as general guidelines. The true SIL value will vary with the
actual characteristic impedance of the line.
A transmission line loaded to its surge impedance loading has no net reactive power flow
into or out of the line and will have approximately a flat voltage profile along its length.
The SIL of a line should be recognized during restoration because a line loaded below its SIL
generates VARS, a line loaded above its SIL, absorbs VARS. Voltage control is a critical
element of successful restoration efforts.
Classification: Public
Page 1 of 2
Effective Date: May 24, 2014
Peak Reliability
Version 1.1
RC Area Restoration Plan
Appendix 1
Technical Parameters
Version History
Rev.
Date
Action
By
Change Tracking
1.0
12/19/2013
Issued for Implementation
M. Granath
Updated to Peak Reliability template
and associated language.
1.1
4/15/2014
Revised and Reissued
M. Granath
Added 345 kV to tables
Classification: Public
Page 2 of 2
Effective Date: May 24, 2014
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
A. Island Definition and Contact Information
Island “A” Balancing Authority
List all BAs in this island:
Island “A” contact name:
Island “A” contact phone:
Island “B” Balancing Authority
List all BAs in this island:
Island “B” contact name:
Island “B” contact phone:
B. Evaluate Stability of Existing Islands
1. Frequency range (preferred within 60.0 +/- 0.2 Hz)
Island A:
Island B:
2. Voltage range at boundary bus (preferred nominal within +/- 2%)
Island A:
Island B:
3. Total online capacity (maximum capability of all online units)
Island A:
Island B:
4. Spinning Reserve
Island A:
Island B:
5. UFLS restored
Island A:
Island B:
6. Largest generation contingency
Island A:
Classification: Public
Island B:
Page 1 of 6
Effective Date: July 1, 2015
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
7. Verify total dynamic reserve (lines 4 & 5) equals or exceeds the largest
contingency (line 6).
Both numbers positive? If yes, OK.
C. Evaluate Interconnection of Islands
1.
Establish conference call
st
2. Tie line voltage of 1 interconnect
3. Tie line voltage of 2
nd
interconnect
4. Sync
location to
be used:
Breaker ID:
5. Auto reclosing relays off?
6. Relaying or RAS concerns at sync?
7. Frequency control unit to be used (no more than 1 unit on 0% droop after
sync):
Preferably largest island:
8. AGC control modes (flat freq, flat tie, TLB):
9. Does sync point have synchronizing relays?
10. Apply island changes to accommodate synchronizing.
11. Confirm islands involved will avoid system changes during synchronizing.
12. Confirm schedules zero on tie lines.
13. The RC approves this interconnection:
Time approved:
RCSO initials:
14. Synchronize across the tie point and then close the tie.
Time closed:
15. Establish additional ties as soon as possible.
Classification: Public
Page 2 of 6
Effective Date: July 1, 2015
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
16. Each BA should not pick up more than 5% of its online capacity without
notifying the RC.
17. BAs must agree on scheduled interchange. Flow should be maintained near
zero if only one tie line.
18. As islands grow, AGC modes, reserves, tie line flows, etc. need to be reviewed
with all BAs.
D. Restoration Milestones
Number of Islands identified and their boundaries.
Islands stabilized – both frequency and voltage within limits.
TOP Restoration Procedures started and monitored.
Hourly RC conference calls to poll restoration progress (load/generation
restored).
Synchronizing Islands – BA to BA
Re-establish interconnection with agreed upon flow limits.
Resume normal operations.
Complete reporting and notifications.
Rules of thumb:
Load pickup and load shed – a conservative estimate of load pickup is between three and
five percent (3-5%) of synchronized generation on line. This avoids the hazard of picking up
too much load and activating the UFLS relays.
When stabilizing an island to bring the under frequency closer to 60 Hz, use 6-10% of load
shed to increase frequency by 1 Hz.
Classification: Public
Page 3 of 6
Effective Date: July 1, 2015
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
Notes
Classification: Public
Page 4 of 6
Effective Date: July 1, 2015
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
Simplified Interconnection Restoration Checklist:
Island 1
Island 2
BAs in Island
Contact Person / Phone No.
/
SYNC’D
Capacity / Load / Spin
/
/
Armed UFLS MWs / MSSC
Dynamic Reserve > MSSC
/
/
/
/
/
Spinning Reserve + Enabled
UFLS > MSSC?
(Yes)
Spinning Reserve + Enabled
UFLS > MSSC?
(Yes)
On Conference Call establish the following:
SYNC PT:
Location / CB / Method
/
/
Tie Line / kV / Limit
/
/
/
/
kV / Nominal ± 2%
/
(Yes / No)
/
(Yes / No)
Frequency / 60 ± 0.2 Hz
/
(Yes / No)
/
(Yes / No)
Auto Reclose disabled?
(Yes)
Concerns: Relaying / RAS?
(Yes)
/
/
Additional Tie(s) / kV
Unit on 0% Droop
AGC Mode
Confirm: Tie Line Schedules zeroed / System changes to be avoided in Islands during
synchronizing
Time:
Initials:
SYNC Time:
Parallel Time:
RC Approval
Notes:
Establish additional ties as soon as possible.
For load pickup greater than 5% of on-line capacity, notify the RCSO.
BAs must agree on scheduled interchange. Flow should be maintained near zero if only one tie-line is available.
As islands grow, AGC modes, reserves, tie-line flows, etc., need to be reviewed with all BAs.
Rules of thumb:
6-10% change in load will change frequency by 1 Hz (shedding load will raise voltage, picking up load will lower
voltage)
Typical MVAR production: 500 kV 2MVAR/mile; 345 kV 0.75 MVAR/mile; 230 kV 0.33 MVAR/mile
Classification: Public
Page 5 of 6
Effective Date: July 1, 2015
Peak Reliability
Version 5.0
RC Area Restoration Plan
Appendix 2
RC Interconnection Restoration
Check Sheet
Version History
Rev.
Date
Action
By
Change Tracking
0
04/06/2009
Issued for Implementation
Reword and add communication
data, rule of thumb.
1
7/08/2009
Issued for Implementation
Added appendices, TOC
2
11/16/2009
Issued for Implementation
Replaced
CMRC/RDRC/PNSC ref.
Removed ref. to RC-001 &
applicable NERC Standards
3
3/24/2010
Issued for Implementation
4
6/19/2013
Revised and Reissued
J. Hoyt
Modified format, minor grammar
changes
4.1
12/19/2013
Revised and Reissued
M. Granath
Updated to Peak Reliability template
and associated language
5.0
04/16/2015
Revised and Reissued
J Hoyt
Added simplified Interconnection
Restoration checklist
Classification: Public
Edited Interconnection
Check sheet
Page 6 of 6
Effective Date: July 1, 2015