Power System Restoration Plan
RTO-PSR-001 Volume I
MISO System Operations
Power System Restoration Plan
Version 8
Issue Date: DRAFT
Effective Date: DRAFT
Volume I – Manual
Public
Power System Restoration Plan
RTO-PSR-001 Volume I
Disclaimer
This document is prepared for informational purposes only to support the application of
the provisions of the MISO Tariff and the services provided thereunder. MISO may
revise or terminate this document at any time at its discretion without notice. However,
every effort will be made by MISO to update this document and inform its users of
changes as soon as practicable. Nevertheless, it is the user’s responsibility to ensure
you are using the most recent version of this document in conjunction with the MISO
Tariff and other applicable procedures, including, but not limited to, the applicable
NERC Reliability Standards as they may be revised from time to time.
In the event of a conflict between this document and the MISO Tariff, the MISO Tariff
will control, and nothing in this document shall be interpreted to contradict, amend or
supersede the MISO Tariff. MISO is not responsible for any reliance on this document
by others, or for any errors or omissions or misleading information contained herein.
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Document Control Information a b
Issue
Reason for Issue
Date
0.0
Draft Working Document
JUL 18, 2004
0.1
Draft Working Document
AUG 11,2004
0.2
Draft Working Document including draft Forms
AUG 31, 2004
0.3
Draft Working Document (OE + RC Review)
SEP 24, 2004
1.0
Revisions From Annual Review Joe Smith
JAN 09 2006
1.1
Revisions
SEP 22, 2006
2.0
Revision to include Local Balancing Authority and MBA
Relationship
NOV 07, 2007
2.1
Revision to include Local Balancing Authority and MBA
Relationship based on Balancing Authority Operating Protocol
version 6
MAY 05,
2008
2.2
Annual Review
AUG 04, 2008
2.3
Removal of NPPD, LES and OPPD from MISO Reliability Footprint
APR 01, 2009
2.4
Additional of MEC and MPW to MISO BA
SEP 01, 2009
2.5
Addition of DPC to MISO BA and changed meetings to activities
Attachment E. This version posted as informational only.
APR 23, 2010
2.6
Updated current listing of TOPs and LBAs.
JUN 01, 2010
2.7
Updated TOP list to include BREC and correct SIPC omissions, GRE
sub region additions. Updated Attachment D to reflect the revised
Interconnection Checklist Rev6
SEP 01, 2010
2.8
Updated LBA listing to include BREC.
DEC 01, 2010
2.9
Annual Review - Added Attachment F – Philosophy. Corrected sec
3.7 responsible entities, Corrected sec 1.2 table for MDU. Removed
FE, Added OVEC.
JUN 01, 2011
3.0
Corrected section 1.2 entities to include MECS and LBWL;
removed CPP. Revised section 1.2 to reflect operational reorganization of regions from East, West, and Central to Carmel
and St. Paul. Revised section 2.1 to remove references of
“Reliability Authority” and clarify role as Reliability Coordinator.
Revised Section 2.1 to reflect MISO’s neighboring RCs. Revised
Attachment C title to remove reference of “Reliability Authority”.
Updated Attachment D to reflect changes to MISO’s
Interconnection Checklist. Updated version of Attachment F from
1.3 to 1.4 to reflect operational re-organization of regions from
East, West, and Central to Carmel and St. Paul. Modified
Attachment D Interconnection Checklist steps to add more detail
on determining worst effective contingency.
DEC 20, 2011
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4.0
Corrected entities in Applicability. Updated responsibilities of
TOP, BAs throughout. Removed Section1.1, 1.3, 2.3.2 references
to BA plans. Removed section 2.1 references to role of
Operations Engineer and references to BA plans. Removed
Section 3.3 references to Vol II. Revised section 3.7.1, 3.7.2,
3.7.5, 3.7.6 to clarify the interconnection process. Update 5.4 to
refer to telecom testing procedures. Removed section 8.1 reference
to Vol II. Clarified use of DTS in section 8.2. Added EOP
workshop reference in section 9. Removed references to BA plans
in Att A. Update Interconnection Checklist rev 8 in Att D.
Clarified TOP role in Att F and reformatted.
JUN 01, 2012
4.1
Revised due to Entergy Integration. Updated Introduction,
Applicability, sections 1.2, 2.1, and 7.
DEC 01, 2012
Annual review with EPPSRWG. Updates in preparation for EOP006-2. Updates for South Region RC Integration.
JUN 01, 2013
5.1
Corrected minor typos.
JUN 01, 2013
5.2
Remove references to EOP-005-1 and EOP-006-1. Noted
Interconnection Checklist Rev 9 was same as Rev 8 with only
changes to completed example.
JUL 01, 2013
5.3
Updated document to incorporate proposed changes associated
with the Standards of Conduct. Miscellaneous formatting,
punctuation, and stylistic corrections.
AUG 02, 2013
5.4
Updated St. Paul Control Center to Eagan Control Center.
DEC 10, 2013
5.5
Revised for South BA integration. Added new LBAs and removed
the BAs that will be going away.
DEC 19, 2013
6.0
Annual Review with EPPSRWG. Completed Compliance
Review. Updated restoration philosophy, TOP SRP review
worksheet and region names. Operating Procedure Owner
approval on file.
FEB 28, 2014
6.1
Added TOP PSR Plan submission schedule and other minor
updates. Added Appendix labels to Table of Contents. Updated
TOP/LBA/BA list. Operating Procedure Owner approval on file.
APR 18, 2014
7.0
Annual Review. Updated Compliance References. Operating
Procedure Owner approval on file.
JUN 01, 2014
7.1
Added METC to TOP list in Section 1.2. Operating Procedure
Owner approval on file.
AUG 01, 2014
7.2
Updated to incorporate the MIUP LBA. Operating Procedure
Owner approval on file.
DEC 01, 2014
8
Annual Review. Updated Compliance References. Operating
Procedure Owner approval on file.
DRAFT
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TABLE OF CONTENTS
Introduction ...............................................................................................................................5
Applicability ................................................................................................................................5
Policy Statement ..........................................................................................................................6
Governmental Notification & Public Appeals Procedures ...................................................6
1
MISO SYSTEM RESTORATION PLAN ........................................................................7
1.1
1.2
1.3
2
ROLES AND RESPONSIBILITIES ...............................................................................10
2.1
2.1.1
2.1.2
2.1.3
2.2
2.3
2.3.1
2.3.2
2.3.3
2.4
3
MISO RELIABILITY COORDINATOR (RC) ROLES AND RESPONSIBILITY ................................ 10
MISO’S RELIABILITY COORDINATOR ROLES ............................................................................ 11
MISO’S RESPONSIBILITIES AND AUTHORITY............................................................................. 12
RELIABILITY COORDINATOR DIRECTIVES ................................................................................. 12
TRANSMISSION OPERATOR ROLE AND RESPONSIBILITY ........................................................... 12
BALANCING AUTHORITY ROLE AND RESPONSIBILITY .............................................................. 13
MISO BALANCING AUTHORITY AND LOCAL BALANCING AUTHORITY JOINT
RESPONSIBILITY .......................................................................................................................... 13
ADDITIONAL MISO BALANCING AUTHORITY RESPONSIBILITY ............................................... 14
ADDITIONAL LOCAL BALANCING AUTHORITY WITHIN MISO MARKET FOOTPRINT .............. 14
GENERATOR OPERATOR.............................................................................................................. 14
STAGES OF THE SYSTEM RESTORATION PROCESS .......................................15
3.1
3.2
3.3
3.4
3.5
3.5.1
3.5.2
3.6
3.7
3.7.1
3.7.2
3.7.3
3.7.4
3.7.5
3.7.6
3.8
4
OVERVIEW .................................................................................................................................... 7
ORGANIZATION ............................................................................................................................ 8
TRANSMISSION CORRIDORS .......................................................................................................... 9
ASSESSMENT OF SYSTEM CONDITIONS ....................................................................................... 15
COMMUNICATIONS WITH TRANSMISSION OPERATOR, BALANCING AUTHORITY, AND
GENERATOR OPERATOR AND ADJACENT RELIABILITY COORDINATORS AND BALANCING
AUTHORITY ................................................................................................................................. 16
EVALUATION OF IMPACTS TO THE STANDARDS OF CONDUCT ................................................... 16
SYSTEM RESTORATION PLAN PREPARATION ............................................................................. 17
PLAN IMPLEMENTATION.............................................................................................................. 17
PRIORITIES:.................................................................................................................................. 17
SYSTEM RESTORATION PLAN IMPLEMENTATION ...................................................................... 18
SYSTEM RESTORATION STRATEGIES .......................................................................................... 18
INTERCONNECTION AND SYNCHRONIZATION ............................................................................. 19
RE-SYNCHRONIZING ISLANDS ..................................................................................................... 19
INTERCONNECTION CHECKLIST ................................................................................................. 20
INTERCHANGE SCHEDULE ........................................................................................................... 21
LOAD SHEDDING ....................................................................................................................... 21
TYING SUB-SYSTEMS WITHIN A TRANSMISSION OPERATOR AREA............................................ 21
TYING SUB-SYSTEMS BETWEEN TRANSMISSION OPERATOR AREAS ......................................... 21
RESUMPTION OF NORMAL OPERATIONS..................................................................................... 22
COMMUNICATIONS AND LOGISTICS ....................................................................24
4.1
4.2
4.3
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PERSONNEL ................................................................................................................................. 24
FACILITIES ................................................................................................................................... 24
COMMUNICATIONS ...................................................................................................................... 24
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TELECOMMUNICATIONS REQUIREMENTS ........................................................25
5.1
5.2
5.3
5.4
6
ENERGY MANAGEMENT SYSTEM TOOLS ............................................................27
6.1
6.2
7
RESTORATION PLAN .................................................................................................................... 29
BLACKSTART RESOURCES ........................................................................................................... 29
SYNCHRONIZING LOCATIONS ...................................................................................................... 29
COORDINATION OF PLANS .......................................................................................30
8.1
8.2
8.3
9
MONITORING................................................................................................................................ 27
TOOLS ........................................................................................................................................... 27
TESTING AND VALIDATION ......................................................................................29
7.1
7.2
7.3
8
FUNCTIONALITY........................................................................................................................... 25
CONNECTIVITY............................................................................................................................. 26
CARMEL AND EAGAN CONTROL CENTERS ................................................................................. 26
MISO TELECOMMUNICATIONS INFRASTRUCTURE .................................................................... 26
RC COORDINATION OF TOP SYSTEM RESTORATION PLANS .................................................. 30
COORDINATION OF NEIGHBORING RC PLANS ........................................................................... 30
MISO EOP COORDINATION WORKSHOPS ................................................................................. 30
TRAINING AND DRILLS .............................................................................................31
9.1
9.2
9.3
9.4
EMERGENCY RESPONSE AND SYSTEM RESTORATION DRILLS................................................... 31
SIMULATOR .................................................................................................................................. 32
COMMUNICATIONS AND TOOLS................................................................................................... 32
SYSTEM RESTORATION TRAINING AND SEMINARS..................................................................... 32
10
PLAN MAINTENANCE AND OWNERSHIP .............................................................34
11
COMPLIANCE .................................................................................................................36
Attachment A Transmission Operator System Restoration Plans .....................................37
Attachment B TOP System Restoration Plan Review Worksheet .....................................38
Attachment C TOP System Restoration Plan Annual Submission Schedule ....................52
Attachment D MISO Interconnection Checklist and Example ..........................................53
Attachment E Eastern Interconnection RC Interconnection Checklist ............................58
Attachment F MISO PSR Philosophy Document ................................................................61
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Introduction
This document has the purpose of identifying the plans, procedures, and resources necessary to
restore the Bulk Electric System (BES) after a partial or complete system blackout.
MISO System Restoration Plan (SRP) is composed of two volumes: Volume I: Manual, and
Volume II: Guidelines and Strategies. Volume I is a public manual defining the roles and
relationships, procedures, responsibilities, communications protocols, and compliance
requirements needed to successfully restore the system. Volume II sets forth the operating
principles and expected actions of the participants – Transmission Operators (TOPs), Balancing
Authorities (BAs), Generator Operators (GOPs) and Reliability Coordinators (RCs) – in the
MISO Reliability Coordinator Area and neighboring regions. The Guidelines and Strategies
were developed for non-public use by a consensus with MISO members and non-members
during area-wide and sub-regional planning meetings and drills. c
Due to MISO’s large footprint, the plan is designed to focus separately on MISO’s three
operational regions: the MISO Central operational region – whose control center is in Carmel,
Indiana, the MISO North operational region – with the control center in Eagan, Minnesota, and
the MISO South operational region – with the control center in Carmel, Indiana.
The SRP has been prepared according to North American Electric Reliability Corporation
(NERC) Emergency Preparedness and Operations Standards. The MISO plan complies with
NERC EOP-006-2, and will be updated as changes and new revisions are issued. Volume I Manual, defines MISO’s role as the RC and BA responsible for system restoration within its
footprint:


As RC: MISO is responsible for the collection and exchange of information,
communication and coordination with TOPs, BAs, and adjacent RCs, as well as
the interconnection, synchronization, and resumption of normal operations. d
As BA: MISO is responsible to work and coordinate with TOPs, Local
Balancing Authorities (LBAs) and GOPs within its footprint and adjacent
entities to coordinate system restoration.
Applicability
The MISO System Restoration Plan applies to members and non-members of MISO as well as
FERC non-jurisdictional companies within the boundaries of its reliability footprint,
coordinating with neighboring RCs at PJM, TVA, SPP, SPC, IESO, and SERC. MISO also
borders WECC in the Western Interconnection. In its Reliability Coordination Area, the MISO
System Restoration Plan provides coordination between TOP restoration plans to ensure
reliability is maintained during system restoration events. All members should also refer to the
MISO Real Time Emergency Operating Procedures. All users should also refer to MISO’s Real
Time Emergency Operating Procedures.
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Policy Statement
(As addressed in MISO Emergency Operating Procedures)
The policy of MISO is to maintain, at all times, the integrity of MISO transmission systems and
to give maximum reasonable assistance to adjacent systems when a disturbance that is external to
MISO occurs. Power system disturbances generally result from the loss of generating or
transmission facilities or as a result of unexpected load changes. These disturbances may be, or
develop into, a magnitude sufficient to affect the reliable operation of MISO and/or the Eastern
Interconnection. These events demand timely, decisive action to prevent further propagation of
the disturbance. Reasonable efforts are made to avoid the interruption of load. However, under
certain operating conditions, it is necessary to interrupt customer load. MISO will work to
interrupt the minimum amount of load necessary to adequately respond to the Emergency.
MISO RC directs the TOP and Balancing Authority Operator (BAO) (or agent) to order load
shedding within MISO in order to preserve system reliability. The BAO (s) coordinate(s) with
the TOP (or Load-Servicing Entity (LSE) or agent) to curtail or interrupt customer load as
necessary. e
Governmental Notification & Public Appeals Procedures f g h
(As addressed in MISO Emergency Operating Procedures)
When a MISO BES Emergency is identified, the MISO RC will advise MISO Market
Participants (MPs), BAs and TOPs as far in advance as possible. This permits MPs, BAs, TOPs,
and MISO the maximum lead-time in determining the appropriate steps to take, including
governmental and public notification. Depending on the situation, BAs, TOPs, and MISO may
have responsibilities in notifying local, state, or federal agencies. GOPs may have separate
reporting obligations related to plant restrictions / operating conditions. Due to the wide variety
of conditions and the potential for the conditions to change rapidly, it is difficult to provide
precise criteria that fit all situations to trigger the issuance of an early alert to the governmental
agencies and the public. Each situation is evaluated to determine if any early alert to
governmental agencies is required, and if an early alert to the public is appropriate. It is the
ultimate responsibility of each BA, TOP and GOP to adjust their guidelines to respond to any
escalated concerns. It is also essential that the BAs, TOPs and GOPs and MISO are informed of
any operators’ unilateral actions or anticipated restrictions. When a Maximum Generation
Emergency is declared or a transmission system limitation affecting area supply is anticipated,
MISO performs a situation analysis and prepares a capacity/load/reserve projection for the
appropriate area and future time periods, including the effect of possible imports due to the
supply situation of various neighbors. The analysis identifies expected Emergency conditions.
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1 MISO System Restoration Plan
1.1 Overview
Since the exact extent or nature of a blackout cannot be predicted, procedures are prepared as
general guidelines designed to be flexible in applications and adaptable to anticipated scenarios.
The SRP combines certain agreed upon procedures and communication protocols between RCs,
TOPs, and BAs in the interest of the reliable interconnections to return the BES to normal as
soon as possible.
The MISO RC’s primary role is to serve as a facilitator during the restoration process:
coordinating, compiling and disseminating information, and maintaining stability. During
interconnection, MISO’s role becomes central in order to facilitate and advance the restoration of
the system while maintaining stability so as to prevent a re-collapse of the system. i
For the MISO Market footprint, under the provisions of the Balancing Authority Agreement
(BAA), LBAs operate within the MISO Balancing Authority (MBA) Area. Throughout this
document, the term BA includes MISO BA, LBA, and Non-Market BA inside MISO Reliability
Footprint. When there are specific roles and responsibility, the document explicitly identifies the
appropriate entities.
The MISO BA’s primary role is to monitor the LBA generation control during restoration,
coordinate between LBAs, TOPs, GOPs, and the RC to ensure workable plans which will allow
for the interconnection of islands within MISO and interconnection with external entities. The
MISO BA is also responsible for working with the RC to review the Interchange Schedules
between LBAs, or LBAs, to facilitate the restoration.
The objectives of the MISO Power System Restoration Plan includes use of a common strategy
for entities involved in the restoration effort, coordinated communications to facilitate the
restoration activities, monitoring and operating the system within operating limits to maintain the
system in a secure state and a coordinated interconnection process to result in an interconnected
BES.
The plan is developed with collaboration from the stakeholder to ensure the use of an established
and agreed upon approach to the plan. The plan defines the roles and areas of responsibility, the
training required to prepare for events, guidelines and strategies for assessing and responding to
the event of various magnitudes and specific criteria used to assess the stability of the system
during the interconnection process. To ensure the effectiveness of the plan, coordination of the
plan includes a review of the TOP system restoration plans to verify that the approach is
consistent. Communications protocols are defined to keep abreast of ongoing progress of the
effort and information is distributed to all entities affected by the disturbance. In the ongoing
restoration effort, wide-area monitoring is provided and actions coordinated as needed to avoid
risk of recurrence. During the interconnection process, a standard assessment is conducted
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between all the key entities to evaluate conditions and readiness to re-synchronize separated
areas.
1.2 Organization
MISO operates as a single Reliability Coordination Area. For purposes of restoration planning,
MISO divides the facilities under its control into smaller reliability-monitoring areas, called subregions or sub-systems. The sub-regions are currently divided as follows:
MISO Central
Wisconsin and Upper
Michigan sub-region
Lower Michigan,
Northern Indiana subregion
Central and Southern
Indiana and Southern
Ohio sub-region
Missouri and
Southern Illinois subregion
MISO North
Canada
Dakota
Minnesota and
Western WI
Iowa
MISO South
Arkansas, Louisiana,
Mississippi and Texas
sub-region
Transmission
Operator
Local Balancing
Authority
ATC
WPS, WEC, MIUP,
ALTE, MGE, UPPC
CONS, DECO,
MECS, NIPS
ITC, METC,
NIPSCO, WPSC,
LBWL
Duke(CIN), Vectren
(SIGE), IPL, HE,
BREC, OVEC,
DOE/PORTS
Ameren, CWLD,
CWLP, SIPC
MHEB
MDU, OTP, MPC,
GRE
NSP, MP, OTP, GRE,
RPU, DPC
ITC-Midwest, MEC,
MPW,
EES, CLECO, LAFA,
SMEPA
CIN, SIGE, IPL, HE,
BREC
Balancing Authority*
OVEC
AMMO, AMIL,
CWLD, CWLP, SIPC
MHEB
MDU, OTP, GRE
NSP, MP, OTP, GRE,
SMP, DPC
ALTW, MEC, MPW
EAI, EES, CLECO,
LAFA, LEPA,
LAGN, SMEPA
*Note: The non-MISO Market Entities function as full BAs within MISO Reliability footprint.
The sub-regions are divided along electrical boundaries and may change as new members join,
new transmission lines are built, electrical interconnections change, or additional restoration
opportunities are identified across the Balancing Areas. Reliability coordination services are
also provided under contract to additional non-members.
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The individual TOPs and BAs within MISO’s operational regions are organized into sub-regions.
Throughout this document, the term “Balancing Authorities” refers to the MISO BA, LBAs in
the MISO Market footprint and BAs in the MISO RC footprint. During the restoration process,
the sub-regions (or islands) eventually interconnect to fully restore the grid throughout the MISO
footprint. As such, each sub-region in this plan meets the criteria set forth by MISO for a subsystem. These criteria include sufficient capabilities for blackstart, cranking or startup power,
interconnections, synchronization, and communications.
1.3 Transmission Corridors
MISO views the system restoration plans of the TOPs from a transmission corridor perspective.
Transmission corridors extend from Blackstart Resources to target facilities in to the sub-regions.
As these transmission corridors are energized during restoration they are then interconnected to
other TOP Areas or sub-regional transmission corridors to restore the entire grid. The
interconnections are not meant to be made sequentially or by completing sub-regions but made
whenever conditions permit.
MISO is responsible for coordinating the interconnection of electrical islands within its entire
footprint. The TOPs and BAs are responsible for using transmission, generation, and distribution
assets in their respective areas to restore power along designated transmission corridors.
The transmission corridor perspective recognizes the role of a transmission provider in the
system restoration process. System restoration plans within individual TOP Areas typically
match Blackstart Resources with larger coal fired resources and places priority to provide station
service power to Nuclear power plants. With the objective of interconnecting the BES, MISO
provides coordination of SRPs along with island interconnection and monitors transmission
corridor energizing, load pick-up, voltage and frequency on a wide area basis.
A transmission corridor perspective allows for islands to be built with different combinations of
Blackstart Resources, power plants, and load areas within the individual TOPs. These may also
cross Balancing Area boundaries. This approach optimizes the deployment of existing
Blackstart Resources throughout the MISO footprint. By taking a wide area view, MISO can
identify hot busses and inter-ties to increase the probability of “restoration opportunities” to be
recognized for inter-ties as restoration progresses.
Consistency between the TOP System Restoration Plans is a prerequisite to the MISO System
Restoration Plan.
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2 Roles and Responsibilities
The MISO Restoration Plan defines four major roles during system restoration, RC, TOPs,
GOPs, and BA.
Terms
As defined by the NERC Board of Trustees
Reliability Coordinator
The entity that is the highest level of authority who is responsible for the reliable operation of the
Bulk Electric System, has the Wide Area view of the Bulk Electric System, and has the operating
tools, processes and procedures, including the authority to prevent or mitigate emergency
operating situations in both next day analysis and real-time operations. The Reliability
Coordinator has the purview that is broad enough to enable the calculation of Interconnection
Reliability Operating Limits, which may be based on the operating parameters of transmission
systems beyond any Transmission Operator’s vision.
Transmission Operator
The entity responsible for the reliability of its “local” transmission system, and that operates or
directs the operations of the transmission facilities.
Balancing Authority;
The responsible entity that integrates resource plans ahead of time, maintains load-interchangegeneration balance within a Balancing Authority Area, and supports Interconnection frequency
in real time.
Generator Operator
The entity that operates generating unit(s) and performs the functions of supplying energy and
Interconnected Operations Services.
2.1 MISO Reliability Coordinator (RC) Roles and Responsibility j k
MISO RC is responsible for:







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Problem Definition
Regional Assessment
Islanding Decisions
Coordination Between Neighbors
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MISO as an RC facilitates restoration within its entire reliability footprint. The RC also needs to
coordinate and communicate with RCs in adjacent areas.
Neighboring Reliability Coordinators in Eastern Interconnection:
TVA / IESO / PJM / SPP / SPC / SOCO
Boundary Reliability Coordinators in Western Interconnection:
Peak Reliability
In system restoration events the MISO RC






Coordinates and communicates directly with TOPs and BAs within its reliability
footprint.
Coordinates and communicates with the neighboring RCs of adjacent areas during
restoration.
Disseminates information regarding restoration to neighboring RCs, TOPs, and BAs
within its Reliability Coordinator Area.
Coordinates reporting to regulatory agencies or government agencies for significant
events.
Collect information on the status and progress of the restoration of TOPs, LBAs and BAs
within the MISO RC Footprint, and of neighboring RCs.
Reformulates restoration strategies on current progress and adjust direction when
required.
2.1.1 MISO’s Reliability Coordinator Roles
As the RC for both MISO members and non-members in its footprint, the RC has the
responsibility for reliable operation of the BES over a wide area and the authority to mitigate
emergency operating situations. The RC performs the functions necessary for the reliable
restoration of the BES in its Reliability Coordinator Area.





Performs Real-Time monitoring of the system and analyzes system conditions for
potential System Operating Limit (SOL) and Interconnection Reliability Operating Limit
(IROL) exceedances.
Makes operating decisions with consultation, as appropriate, with BAs and TOPs
Communicates operating decisions to BAs, TOPs, and other RCs.
Coordinates island interconnection
Notify local, state, federal or regulatory agencies and submit final reports to DOE,
NERC, Regional Entities and others as appropriate or required.
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2.1.2 MISO’s Responsibilities and Authority
MISO as the RC has responsibility and authority over the transmission facilities belonging to the
TOPs that are in its reliability footprint. MISO has clear decision-making authority to direct the
actions to be taken by other TOPs and BAs within its RC Area to preserve the integrity and
reliability of the BES. As such, actions on its instructions during system restoration should be
taken without delay. These Reliability Coordination responsibilities for MISO are not delegated
to other entities.
MISO’s TOPs belong to the SPP, MRO, RFC, and SERC Regions. As NERC designated RC
for TOPs in those regions, MISO has responsibilities for coordination of system restoration of
those entities. However, there are some TOPs in MRO, RFC, and SERC Regions that are not
members of the MISO Reliability footprint and have another entity as their RC. For purposes of
coordination, MISO communicates directly with those RCs. Agreements are in place between
MISO and these other RCs to clearly state the requirements of both parties including requirement
for system restoration coordination.
The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is
central to the development and successful implementation of the restoration plan. Although
TOPs, BAs and GOPs must comply with directives of the RC, the relationship should be
understood as one of open communication and cooperation.
2.1.3 Reliability Coordinator Directives
All TOPs, BAs and GOPs shall comply with RC directives unless such actions would violate
equipment, safety, or either regulatory or statutory requirements. Under these circumstances the
entity must immediately inform the RC of the inability to perform the directive so that the RC
may implement alternate remedial actions.
Since the TOPs are required by NERC EOP-005-2.R1, to include certain elements in their
restoration plans, MISO expects certain criteria be met regarding procedures and facility
readiness in those plans. These criteria are stated in Attachments A, and B.
With respect to interconnection, RCs place the interests of reliability in its sub-regions and
region before those of the individual TOPs and BAs by monitoring restoration progress. The RC
shall act in the interests of reliability for the overall RC Area and its interconnection before the
interests of any other entity such as other BAs, TOPs, Purchasing-Selling Entity (PSE), or GOPs.
2.2 Transmission Operator Role and Responsibility l
The entity responsible for the reliability of its “local” transmission system, and that operates or
directs the operations of the transmission facilities. In coordination with the RC, BA, and GOP,
the main role of the TOP is to:
 Control, direct and coordinate the operation of generating resources, transmission
facilities, and loads within its transmission footprint.
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Notify local, state, federal or regulatory agencies and submit final reports to DOE,
NERC, Regional Entities and others as appropriate or required.
2.3 Balancing Authority Role and Responsibility m
The BA within the MISO RC footprint is responsible to integrate resource plans ahead of time,
maintain load-interchange-generation balance within a BA Area, and support frequency in Real
Time.
For the MISO Market footprint, under the provisions of the BAA, LBAs operate within the
MISO BA Area. Though many LBAs share the same “footprint” as the associated TOP, there
are also examples of multiple LBAs operating within a single TOP footprint, and multiple TOPs
operating within a single LBA Area. The requirements placed upon the LBA in this operating
protocol apply under any configuration.
2.3.1 MISO Balancing Authority and Local Balancing Authority Joint Responsibility n
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The MISO BA and LBA shall share information regarding their roles and responsibilities
under all SRPs.
The MISO BA and LBA shall be responsible for coordinating regional generation plans with
the RC during restoration events involving restoration of islands and interconnection of
LBAs.
The MISO BA and LBAs shall train their operating personnel in the implementation of the
restoration plan(s), and ensure they understand their roles and responsibilities during a
restoration event. Such training shall include simulated exercises, if practical.
The MISO BA and LBAs shall periodically test the telecommunication facilities needed to
implement the restoration plans to ensure that proper capabilities are maintained.
The MISO BA and LBAs shall verify the restoration procedures by actual testing or by
simulation.
Following a disturbance in which one or more areas of the BES become isolated or blacked
out, the affected TOPs, MISO BA, and LBAs shall begin immediately to return the BES to
normal.
The MISO BA and LBAs shall work in conjunction with the RCs to determine the extent and
condition of the isolated areas. The LBAs shall keep the MISO BA apprised of local
conditions.
The MISO BA and LBAs shall take the necessary actions to restore BES frequency to
normal, including adjusting generation, placing additional generators on line, or load
shedding. o p
The MISO BA and LBAs shall make all attempts to maintain the adjusted Interchange
Schedules, whether generation control is manual or automatic.
The MISO BA and LBAs shall notify local, state, federal or regulatory agencies and submit
final reports to DOE, NERC, Regional Entities and others as appropriate or required.
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2.3.2 Additional MISO Balancing Authority Responsibility
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The MISO BA shall monitor the generation control of LBAs and coordinate between the
LBAs, TOPs, GOPs, and RC to ensure workable plans which will allow for the
interconnection of islands within the MISO BA Area and interconnection with external
entities.
The MISO BA shall be responsible for working with their RC to review the Interchange
Schedules between LBAs, or fragments of LBAs to facilitate the restoration.
2.3.3 Additional Local Balancing Authority within MISO Market Footprint
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The LBAs are responsible for coordinating local restoration plans with the TOPs in their
areas. These plans will ensure the viability of restoring the local areas to the point of
interconnecting with adjacent LBAs or external entities.
As a minimum, LBAs shall maintain the capability to control an adequate amount of
generation necessary for operating under Constant Frequency & Constant Net Interchange
modes in order to facilitate interconnection of islands during a restoration event.
2.4 Generator Operator q
 The GOP operates generating unit(s) and performs the functions of supplying energy and
Interconnected Operations Services. The GOP follows the direction and works in
coordination with RC, TOP, and BA during system restoration.
 Notify local, state, federal or regulatory agencies and submit final reports to DOE, NERC,
Regional Entities and others as appropriate or required.
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3 Stages of the System Restoration Process
rstuv
The system restoration process involves a progression of events from the recognition of
abnormal conditions, through the constraint and mitigation of those conditions, to their resolution
and the actions necessary to restore normal operations.
MISO will organize the system restoration process in the following stages:
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Assessment of System Conditions and Market Level Status
Communications with TOPs BAs/LBAs, GOPs and adjacent RCs.
Evaluation of Impacts to the Standards of Conduct
Preparation of a SRP according to existing conditions
Implementation of the Plan
Interconnection and Synchronization
Resumption of Normal Operations
3.1 Assessment of System Conditions
Early attention to potential IROL violations and the consequences for system collapse may avert
a contingency that the system might not be able to withstand. The intent at this stage is to take
action when the system is at the limits of reliability. This may reduce the potential loss or
damage of equipment and facilities that will be needed during restoration.
Following a major system disturbance, the MISO RC will implement the RTO-EOP-004
Procedure or take other actions as necessary to mitigate the contingencies and stabilize the
system. MISO RC will study system conditions and develop strategies for containment and
restoration in the event of a system collapse.
Emergency Operations – Transmission Operator and Balancing Authority
The integrity and reliability of the Bulk Electric System is of paramount importance, and will
take precedence above all other aspects including commercial operations; therefore, all
Transmission Operators and Balancing Authorities are expected to cooperate and take
appropriate action to mitigate the severity or extent of any system emergency.
During the initial system restoration, MISO must assess the system condition and determine:
 appropriate declaration of Market Level Status as stated in MISO procedure RTO-AOP001
 if and when balancing control should be transferred to the LBA
 if and when its Standards of Conduct will be impacted
 The extent of impact caused by the disturbance and the state of the system after the
event. Potential scenarios may include, but not limited to:
o Complete MISO Area Blackout
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o Partial MISO Area Blackout
o Islanding situation within the MISO Area
3.2 Communications with Transmission Operator, Balancing Authority, and Generator
Operator and adjacent Reliability Coordinators and Balancing Authority w
The RC must notify each affected TOP and BA/LBA of any condition that could threaten the
reliability of the MISO Reliability Area.
The preferred method to complete this notification is to initiate a Blast Call, followed
immediately by electronic messaging via the MISO Communications System (MCS) to internal
MISO entities and via Reliability Coordinator Information System (RCIS) to neighboring RCs.
A conference call as needed to facilitate communications to all the affected entities.
The objective will be to recognize and isolate the affected at-risk areas and separate in a
controlled manner to avoid a cascading outage. By effectively containing the blackout area by
establishing controllable boundaries in advance of a cascading outage, the eventual restoration
will be expedited and the time to restore normal operations considerably reduced.
In the initial discussions following an event, the TOP and RC should identify the amount of load
and generation affected and boundary of the island or area of the blackout. If the affected area
includes multiple TOP areas and/or BAs/LBAs the RC will contact those entities and confirm the
status of generation and load that is involved in the event. Depending on the scale of the event
the RC should communicate the conditions to the neighboring TOPs, BAs/LBAs and to the
adjacent RCs to establish general awareness of the disturbance and the potential need for
restoration assistance.
During the restoration process, the TOP should provide routine status updates to the MISO RC to
maintain continuous communications of progress. These status updates should include
information pertaining to the number of islands, load and generation totals in the islands, and
entities that comprise the islands. The TOP should keep the RC informed of plans to
synchronize to adjacent island and notify the RC when ready. Key milestones should also be
reported including significant transmission that has been energized, tie lines restored to resynchronize to other areas, any additional tie lines returned to service, and changes to generation
status including the unit used for island frequency control.
The MISO RC should provide periodic updates of milestones posted to the RCIS to keep other
RCs informed of the ongoing restoration activities.
3.3 Evaluation of Impacts to the Standards of Conduct
All entities are individually responsible for assessing and managing their compliance with
Standards of Conduct, or suspension of Standards of Conduct.
When system conditions are determined to require regional restoration actions, the MISO RC
will refer to its internal MISO RTO-I-OP-035 Procedure.
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During the restoration process, from assessment until the resumption of normal operations, the
MISO RC will treat all users of the interconnected transmission systems in a fair and nondiscriminatory manner. Nonetheless, the MISO RC must take whatever steps are necessary to
maintain system reliability.
Unless required for the reliable restoration of the grid, information concerning the transmission
system throughout the restoration process will not be disclosed to merchants through non-public
communications. Public communications is assigned to MISO Corporate Communications and
will be made in accordance with the policies outlined in MISO Corporate Communications
policies.
3.4 System Restoration Plan Preparation
Following a condition in which portions of one or several TOP or BA Areas become isolated or
de-energized, the MISO RC will take steps immediately to begin returning the BES to normal.

The TOPs and BAs, working in conjunction with the RC, shall determine the extent and
condition of the affected area(s).

The MISO RC will assist the TOPs BAs and GOPs in taking the necessary action to
restore BES frequency to normal, including adjusting generation, placing additional
generators on line, or load shedding. x
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The MISO RC will assist the affected BAs in reviewing the interchange schedules
between those BA Areas or fragments of those BA areas. Areas within the separated area
and make adjustments as needed to facilitate the restoration. The affected BAs shall
make all attempts to maintain the adjusted interchange schedules whether generation
control is manual or automatic.
The MISO BA will coordinate the generation control, regulation requirement and
interchange schedule between the affected LBAs both internal and external to MISO
market footprint.
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3.5 Plan Implementation
The MISO RC must monitor conditions, communicate and coordinate with TOPs, BAs, and
adjacent RCs and TOPs during the implementation of the MISO SRP. The MISO RC will pay
particular attention to restoration priorities and insure that the priorities are respected as the
restoration progresses. The plan shall be in accordance with the NERC EOP-006-2 requirements.
3.5.1 Priorities:

During the restoration process, the MISO RC and TOPs will develop restoration
strategies with the priority of restoring the integrity of the interconnection.
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The TOP shall give high priority to restoration of off-site power to nuclear stations.
Restoration priority shall be given to the station supply of power plants and the
transmission system (critical substations and inter-ties). These priorities are outlined in
the TOP plans.
Cranking power to neighboring power plants shall have a priority over restoring internal
customer load in a BA Area (once sufficient load is established in an island).
Customer load shall be restored as generation and transmission equipment becomes
available, recognizing that load and generation must remain in balance at normal
frequency as the BES is restored.
3.5.2 System Restoration Plan Implementation y
MISO maintains a hard copy of its restoration plan and hard copies of each approved TOP
restoration plan in its Reliability Coordinator Area within its primary and backup control rooms.
Additionally, MISO’s latest restoration plan and copies of each approved TOP restoration plan in
its Reliability Coordinator Area are available to MISO operating personnel via Quick Links. In
accordance to NERC EOP-006-2 R7, the MISO RC shall monitor restoration progress and
coordinate any needed assistance. MISO will work with the affected Balancing Authorities/Local
Balancing Authorities, Generator Operators, Transmission Operators and the neighboring
Reliability Coordinators to monitor restoration progress, coordinate restoration, and take actions
to restore the BES frequency within acceptable operating limits. If the restoration plan cannot be
completed as expected, MISO will implement steps per the restoration plan strategies to facilitate
System Restoration.z
3.6 System Restoration Strategies aa
Volume I contains the system restoration strategies for the MISO footprint to return the BES to
normal operation. The TOP plans shall be coordinated with MISO and incorporated by reference
in the MISO plan.
TOP restoration plans and the MISO SRP are coordinated with neighboring RCs, TOPs, and
BAs.
Restoration strategies defined in this plan are developed from the general philosophy described
in Attachment F of the MISO SRP.
During the actual system restoration, a number of potential scenarios may occur. These
include, but not limited to:
 Complete MISO Blackout
The BAs and TOPs are to begin restoration process independently and keep MISO
informed of restoration progress.
Prior to interconnecting to neighboring BAs/LBAs or TOPs, the coordination process in
section 3.7 needs to be followed as detailed in the Interconnection Checklist (see
Attachment D).
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Partial MISO Blackout or Islanding Situation within MISO
In the event of a partial MISO blackout, MISO will determine the boundary of the
blacked out area. MISO will coordinate with the TOP and BA to make assessment and
will need to decide if restoration strategy should utilize internal Blackstart Resources or
external assistance.
Following an event, any islanded areas will become responsible for local generation
control. MISO will notify entities of any generation outside of their control that should
be turned over to the LBA. In addition, MISO will provide direction in relation to
generator control mode to the affected LBA:
o Flat Frequency Control should be utilized only to those instances when the LBA
becomes isolated from the Eastern Interconnection.
o Constant Interchange should be utilized when one or multiple BA/LBA are
completely isolated from the rest of Interconnection and MISO desires the
BA/LBA to maintain a given net interchange flow between them. Constant
Interchange should also be utilized when LBA becomes radially interconnected
with the Eastern Interconnection.
 When an LBA is radially interconnected, the MISO BA will provide the
interchange value to the LBA to maintain.
Prior to interconnecting to neighboring BA/LBAs or TOPs, the coordination process in
section 3.7 and Interconnection Checklist in Attachment D, needs to be followed.
The actual strategies that will be followed during the restoration must be developed according to
conditions at the time.
3.7 Interconnection and Synchronization bb
RCs are expected to follow policies and procedures to ensure the operational reliability of
interconnected systems. These include reliability analyses and identifying special operating
procedures, analyzing current operating conditions, and implementing procedures to mitigate
SOL and IROL violations on the transmission system. These requirements apply to the
interconnection stage of restoration, especially while re-synchronizing islands. During
restoration, the MISO RC must make every effort to ensure that the TOPs maintain their
transmission system within IROLs.
3.7.1 Re-synchronizing Islands cc
The TOPs will work with the appropriate BAs/LBAs and MISO RC to evaluate the stability of
the isolated system(s). The TOP will then coordinate the re-synchronization of the isolated
system(s) to the surrounding area(s) when voltage, frequency, and phase angle permit. The
MISO RC shall approve, communicate, and coordinate the re-synchronizing of major system
islands or synchronizing points so as not to burden adjacent TOP, BA/LBA, or RC. The TOP’s
restoration plan considers the number of synchronizing points in its area. Information that may
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be used to identify major system islands includes, but is not limited to, the size of the area being
reconnected and the capacity of the transmission lines used to tie the isolated area(s) to the
surrounding area(s).
The TOP will inform the MISO RC of restoration progress. The MISO RC will communicate to
all applicable TOPs and BAs/LBAs and neighboring RCs any situations posing the risk of a
possible SOL or IROL violation in the interconnection, or that place the interconnection at risk.
The MISO RC will provide guidance on the interconnection process to the TOPs and BAs/LBAs
in order to maintain stability of the interconnected systems. If the resynchronization cannot be
completed as expected, MISO RC will utilize its restoration strategies to facilitate
resynchronization.
Once the MISO RC confirms the isolated area(s) have been successfully re-synchronized,
internal system restoration within the area(s) may continue. After re-synchronization, the MISO
RC, TOPs and BA/LBAs must monitor generator reserves, system frequency and voltages, and
tie-line flow. TOPs need to coordinate load pick-up with the BAs/LBAs. The MISO RC will
verify that acceptable voltage and frequency parameters are maintained during load restoration.
No more than five percent of the synchronized system generating capacity should be added in a
single load block without notifying the MISO RC. BAs/LBAs shall disperse generator reserves
across a wide range of generators in the area in order to maintain system stability. After two or
more ties have been established between the re-synchronized areas without failure, governor
reserves may be computed as a whole between the two areas.
The MISO RC will observe analog/instantaneous recordings of frequency response to actual load
pickups. They will communicate any observations to the applicable TOPs and BAs/LBAs in
order to prevent excessive frequency excursions, as necessary.
3.7.2 Interconnection Checklist dd
The Interconnection Checklist is an assessment form designed to facilitate communications
between the MISO RC, TOPs and BAs/LBAs. The Interconnection Checklist provides step-bystep guidelines for evaluating key system parameters to help ensure the survivability and stability
of the resulting island and interconnection. These guidelines should be used by all entities
involved in the interconnection activities. It also facilitates understanding between all parties
while minimizing verbal exchanges in order to ensure successful and stable operation of the
resulting interconnection. The form provides a record of the information used to evaluate the
system conditions prior to interconnection. Prior to approving the re-synchronization of major
islands between TOPs within the MISO RC footprint, the MISO RC will confirm with
interconnecting entities that the items on the Interconnection Checklist (Attachment D) are crosschecked and completed satisfactorily. This checklist was developed by MISO and the TOPs in
its RC footprint, neighboring RC footprints may have different checklists. In 2013, several
Eastern Interconnection RCs developed a new checklist intended to be used across the Eastern
Interconnection. This form has not yet gained acceptance of the MISO EPPSRWG, but it is
included in Attachment E for use when interconnecting with neighboring RC regions.
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The following items require special attention:
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Systems to be interconnected are stable (firm).
Operators for each of the TOP Areas to be inter-tied agree on synchronization points and
synchrocheck relays to be used to tie the systems together.
Frequency control assignment is agreed.
Contingency reserves are sufficient to cover the most severe single effective contingency
in each system.
Direct communications are established to the synchronization point from the system
control room.
3.7.3 Interchange Schedule
Prior to interconnecting the BAs, an interchange schedule between the BAs must be planned.
This interchange schedule must be agreed to and be utilized by the sending and receiving BAs.
If only one tie is in place, a zero schedule should be used until additional ties can be restored.
Prior to approving re-synchronization, the MISO RC must confirm that both system operators
agree on the interchange schedule as part of the interconnection checklist.
3.7.4 Load Shedding
ee
The TOP or MISO RC may direct that load shall be shed in neighboring BA areas, where
required, to permit successful interconnected system restoration. Load shedding shall be
implemented in steps to minimize the risk of further uncontrolled separation, loss of generation,
or system shutdown.
3.7.5 Tying Sub-systems within a Transmission Operator Area
When islands within a TOP area have been established, and system conditions allow, plans
should be made to interconnect them, even if most of the load in the islands has not been
restored. MISO RC approval is not required if both islands reside within a single TOP area. The
TOP shall notify the MISO RC of plans to re-synchronize the islands and inform the MISO RC
when the systems have been re-synchronized. The MISO RC should be notified if the generation
control mode of an island is switched to Automatic Generation Control (AGC) operation.
The TOP will coordinate the interconnection process with the applicable BAs/LBAs and GOPs.
The TOP will confirm the mode of generation control, and the BAs/LBAS will specify which
units will be manually adjusted to maintain governor and operating reserves as load is restored.
Synchronization of islands should be done as soon as possible on a controlled and coordinated
basis in order to accelerate the restoration process.
3.7.6 Tying Sub-systems between Transmission Operator Areas
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Once islands have been established, and system conditions allow, preparations should be made to
interconnect these operating islands, within the TOP area or with neighboring TOP islands.
MISO RC approval is required when any island is re-synchronized to an island in a different
TOP area and either isolated area includes 1000MW or more of load. However, if the smaller
island has less than 3% of the load of the larger island, this can be considered load pickup for the
larger island and RC approval is not required. If neither island is greater than 1000 MW of Load,
the TOPs shall inform the MISO RC of plans to re-synchronize the islands and inform the MISO
RC when the systems have been re-synchronized.
In addition, the MISO RC will coordinate with neighboring RCs any and all islands to be
interconnected across RC boundaries. The interconnection assessment must meet the criteria of
both RCs and be approved by both RCs before the islands are resynchronized.
The MISO will approve an interconnection between TOPs only when the resulting island is
considered stable. The criteria for island stability prior to interconnection are set forth in the
MISO Interconnection Checklist.
The MISO BA will monitor the generation control, regulation requirement, and interchange
schedule between the affected LBAs internal to MISO market footprint and will coordinate
interchange adjustments for re-synchronization of islands to the Eastern Interconnection. The
MISO BA will make an assessment to identify the feasibility of resuming MISO AGC and
coordinate the resumption of normal operations with the affected LBAs.
3.8 Resumption of Normal Operations
Prior to resuming normal operations, the MISO RC will ensure that all BAs within the reliability
footprint carry at least enough Contingency Reserve to cover the most severe single contingency
and maintain generating capacity (regulating reserves) sufficient to maintain a stable frequency.
The MISO RC must prescribe operating criteria that will ensure reliable operations as normal
operations are resumed. As the restoration effort reaches a conclusion, the MISO RC must
constantly be alert for any conditions that may cause the system to re-collapse. Once areas have
been synchronized, further actions should continue to strengthen the system prior to resuming
normal generation control. When the TOP has agreed that conditions are acceptable, the BA
will assume control of generation under normal operations.
Once the system has been restored and interconnected with the BES, the TOP should return
normal operation of generation to the authority of the BA. In order to maintain the stability of
the system and maintain system within acceptable limits, criteria have been established for
assessing the readiness to transfer control. ff
 Two or more interconnected transmission lines should be established to the BES to
protect against contingent loss of one of the facilities. Additional ties should be
considered to increase the resilience of the system to contingency events.
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System can withstand the next contingency without exceeding voltage or thermal limits.
Contingency analysis should be performed to determine any impacts from the loss of the
next facility.
Operating reserves are distributed adequately such that deployment of reserves does not
exceed limits
Frequency is stable within 59.97 – 60.03 Hz. System frequency should not be adversely
impacted by shifting of reserves between generation resources.
Interchange schedules are equal to actual interchange. Tie line flows should not change
appreciably following the transfer of operations.
Tie line flows are verified by adjacent BA. Tie line data should be compared to
determine if the information is accurate
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4 Communications and Logistics gg
4.1 Personnel hh
The MISO RC, TOPs, BAs/LBAs, GOPs, will augment the staffing levels needed to implement
the restoration plan as appropriate. Personnel engaged in the effort may include additional
operations staff as well as support staff necessary to ensure the availability communication and
information systems.
4.2 Facilities
During significant events the affected entities may utilize their backup control center or
information systems or communications facilities.
4.3 Communications ii
Voice communications are an essential tool for sharing of information regarding the status of the
restoration effort. The MISO RC will maintain close contact with the affected entities and TOPs
should provide periodic updates on restoration progress. The MISO RC will distribute messages
via MISO Communications System (MCS) to internal MISO entities and via Reliability
Coordinator Information System (RCIS) to neighboring RCs. MISO as a Reliability Coordinator
will coordinate reporting to regulatory agencies or government agencies for significant events as
required.
The MISO RC, TOPs, BAs/LBAs and GOPs will follow established communications protocols
to use three-way communications for all directives.
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5 Telecommunications Requirements jj
Telecommunication is an essential service for system restoration. It is important to establish
communications between the MISO RC and TOPs and BAs/LBAs as well as the RCs in adjacent
areas. MISO has both primary telephone systems and backup telecommunications facilities that
can be implemented to maintain contact during restoration events. MISO utilizes a Wide Area
Network (WAN) to transfer system data used to monitor the system conditions. The MCS is an
electronic messaging system that enables notifications between the entities in the reliability
footprint.
Voice communications are critically important. The Public Switched Telephone Network
provides point to point communications as well as conferencing capability. In addition MISO
has established pre-defined Blast Calls that enable multi-party communications via a single
phone call. Backup voice communications is also available using satellite phones and VoiceOver-Internet Protocol (VOIP) over the MISO WAN which offers redundancy to the public
phone network.
The SRP relies on the connectivity and functionality of the communications system, and it will
be maintained and tested periodically per established testing protocols.
Reliability of telecommunication infrastructure and support services is a prerequisite for a
successful SRP. Telecommunication services are available to MISO from multiple sources.
Among these are:
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VoIP over the MISO WAN
MCN over the MISO WAN
Public Switched Telephone Network
Commercial Internet
Cell Phones
Satellite Phones
In the event that the MISO RC, TOP, BA/LBA or GOP cannot be contacted, the entity initiating
the call should inform other parties in order to assess the communications capabilities that
remain. If the primary communications mechanism is inoperable, backup systems should be
utilized to establish contact. MISO Communications System (MCS) is used for communications
to internal MISO entities and Reliability Coordinator Information System (RCIS) is used for
communications to neighboring RCs.
5.1 Functionality
The primary IPC phone system is configured with speed dial and multiline capability and speed
dial to facilitate user contact. Phone lines included recording and call logging for review of
communications between parties. Phone transfers to secondary CISCO systems are conducted
as part of business continuity testing.
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5.2 Connectivity
The MISO WAN, designed to carry ICCP data, is redundant and reliable and well designed.
Data communications for ICCP data are in place over the WAN, and meet the requirements for
both normal and emergency operations.
5.3 Carmel, Eagan, and Little Rock Control Centers
The turret system at the MISO Carmel Control Center (CCC), Eagan Control Center (ECC), and
the Little Rock Control Center (LRCC) is installed and maintained at the same level of
functionality, equivalent and compatible in every respect (e.g., blast and conference calling
capabilities, operator training). CISCO phone systems provide added system redundancy with
similar capabilities using the public phone network.
5.4 MISO Telecommunications Infrastructure
Telecommunication facilities needed to implement the MISO SRP will be tested periodically in
accordance with MISO telecom testing procedures.
Facilities will be tested at:
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Carmel Control Center (CCC)
Sheridan Control Center (SCC)
Eagan Control Center (ECC)
Little Rock Control Center (LRCC)
Connectivity to TOP and BA Control Centers
Connectivity to Neighboring RC Control Centers
Connectivity to NERC
TOPs and BAs will test the connectivity and functionality of their own telecommunications
facilities at least annually.
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6 Energy Management System Tools
6.1 Monitoring
The MISO EMS applications make substantial contributions to MISO RC actions during system
restoration. By virtue of its wide area visibility, MISO disseminates information to the TOP and
BA, contributing to reliability during restoration and interconnection, and thereby advancing the
resumption of normal operations. kk The Balancing Area Displays developed in the Control
Room are an important tool for communication between MISO and the BAs. The information
will be made available in Real Time during restoration events.
MISO has substantial tools to monitor the system and obtain wide area visibility. MISO has
developed and implemented visualization tools allowing operators to monitor overviews of the
system. Real Time overview displays show the transmission system in the entire MISO footprint
and surrounding areas for all 230 kV and above transmission lines as well as significant
underlying facilities of 100 kV and above (69 kV and above in some areas).
Monitoring tools that are particularly beneficial during restoration are:
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EMS System Overview Displays
EMS Area One-line Displays
State Estimation and Real Time Contingency Analysis
Market Monitoring Display
Non-Market Monitoring Display
Generation Monitoring Tool
Transmission Delta-Flow Monitoring Tool
Tie-line Error Monitoring Display
6.2 Tools
The RC will share data with the TOP and BA to provide visibility over system conditions. The
MISO RC shall also serve as the primary contact for disseminating information regarding
restoration to neighboring RCs and TOPs and BAs not immediately involved in restoration. ll
Pre-event tools include:
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State Estimator (RTNET)
Real Time Contingency Analysis (RTCA)
Post-event tools include


Real Time Contingency Analysis (RTCA)
State estimator that works in multiple islands
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

Frequency records to determine island boundaries
Identification of low and no voltage points
The MISO RC should identify system separation points following a major disturbance by
observations of system parameters:




Frequency variation
Abnormal MVA, MW and MVAR flows
Abnormal voltages
Facility outages
Initial discussions with the TOP and the BAs/LBAs in the footprint will also help provide insight
into the magnitude of the event.
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7 Testing and Validation
7.1 Restoration Plan
The MISO RC receives the SRPs of the TOPs that are incorporated by reference into the MISO
SRP. The TOP SRPs will provide adequate detail of the steps needed to restore the system from
blackstart conditions. TOPs will test the plan as per the requirements in NERC EOP-005-2 R6.
7.2 Blackstart Resources
The TOP SRP will identify the Blackstart Resources and any requirements for availability.
Blackstart Resources that are identified in the SRPs of the TOP are incorporated by reference
into the MISO SRP. Blackstart Resources will be tested in accordance with NERC EOP-0052.R16. Tests will include startup and operation of Blackstart Resources in the TOP Area.
7.3 Synchronizing Locations
The TOP SRP will identify the locations in the TOP Area that are intended to be utilized for
interconnecting with neighboring TOPs.
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8 Coordination of Plans
8.1 RC Coordination of TOP System Restoration Plans mm nn
MISO provides guidance in the development of the TOP SRPs to ensure consistent restoration
strategies in the MISO footprint. Attachment A discusses the general responsibilities for
Blackstart Resources. NERC EOP-005-2 R1 provides elements required for inclusion in TOP
restoration plans.
The MISO RC reviews the TOP SRPs to verify that the plan clearly demonstrates the restoration
capability of the TOP. The MISO RC shall determine if the plan is coordinated and compatible
the MISO RC restoration plan and other TOP restoration plans in the MISO RC Area. MISO
evaluates the plan content using the MISO TOP System Restoration Plan Review Worksheet in
Attachment B which identifies the key criteria for MISO RC approval. The MISO RC will
document the review and approve or reject the TOP restoration plan within 30 calendar days.
Any issues identified must be resolved before the plan is approved. oo
8.2 Coordination of Neighboring RC Plans pp qq
To ensure coordination with neighboring RCs, the MISO restoration plan is provided to entities
for their review and comment. Plans received from neighbors are reviewed to determine if the
plan contains consistent approach for areas that require interaction including:
 Communications methods
 Monitoring of operating limits
 Common Interconnection criteria
If MISO finds and conflicts between its restoration plan and any of its neighboring RC’s
restoration plans, the conflicts shall be resolved in 30 calendar days. rr
8.3 MISO EOP Coordination Workshops
MISO hosts annual Emergency Operating Plan (EOP) Coordination Workshops to facilitate the
exchange of emergency plan information between the TOPs and BAs in the reliability footprint
and neighboring entities. These workshops provide a coordinated forum to review a summary of
the entity plans including SRPs and an open discussion to foster a better understanding of the
plans of other entities.
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9 Training and Drills ss tt
MISO as an RC includes in its training plan annual System restoration training for its operators.
MISO also coordinates two System restoration drills, exercises, or simulations per calendar year.
Restoration drills, complemented by seminars and other operator training, provide a means for
operators to gain experience in emergency operations and system restoration
9.1 Emergency Response and System Restoration Drills
The objectives of drills are to:











Identify emergency conditions using emergency criteria
Demonstrate the process of restoration techniques
Use MISO emergency criteria
Maintain system control
Identify and start Blackstart Resources
Practice RC procedures
Practice communications with TOPs and BAs
Practice communications with neighboring RCs
Gain knowledge of TOP’s SRPs
Develop restoration strategies in a sub-regional context
Refine MISO and its member SRPs
Drill development must include high degree of involvement by the MISO RC staff and system
operators at the TOPs and BAs. A high level of operator interaction is strongly encouraged.
Drills will be designed to verify the restoration plans, procedures, and communications
protocols.
In order to continue building the plan and ensuring its continuance, drills must be organized and
led by MISO as the RC. Drills include TOPs, BAs in the MISO reliability footprint and
neighboring entities and may be structured as Emergency Response and System Restoration
Drills. Large scale MISO-wide Emergency Response and System Restoration Drills are
conducted in the fall. These drills are designed around two possible objectives: (1) emergency
response necessitating re-dispatch and load shedding to mitigate or prevent widespread blackouts
and (2) partial or complete blackouts with requirements for both blackstart and island
interconnections.
Drills are the primary means of exploring restoration opportunities and identifying transmission
corridors across TOP and BA boundaries. Whether they are simple desk top exercises, table top
drills, sub-regional or regional MISO wide drills, these opportunities to examine the details of
the SRPs provide a mechanism to improve overall system restoration strategies. They are a
means of training operators in the TOP and MISO SRPs and identifying plan improvements.
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Drills are the primary vehicle for establishing and reinforcing working relationships between
RCs and TOP and BA/LBAs. System Operators are included in the drill planning process to the
greatest extent possible. Per EOP-006-2:R10.1, MISO as an RC will request each TOP identified
in its restoration plan and each GOP identified in the TOP’s restoration plans to participate in
MISO PSR drills at least every two calendar years.
Drills prepare operators on how to respond to events potentially leading to a blackout and
demonstrate their actions in response to such events. Drills are developed to reflect real
operating scenarios using knowledge gained from prior blackouts and emergencies.
Drills are designed to demonstrate the effectiveness of monitoring tools and. will demonstrate the
effectiveness of the communications skills of RCs, TOPs and BAs/LBAs.
9.2 Simulator
The simulator is a beneficial training tool for emergency response as well as system restoration
drills. Simulators at MISO and the TOP and BA/LBA will be assigned for use in drills and
scheduled for support of drills wherever possible. The MISO Dispatcher Training Simulator
(DTS) may be used to simulate a Real Time event for emergency preparedness exercises.
Simulations are also conducted in normal operator training to present operators with possible or
historical situations, and promote the development of skills and understanding of procedures.
9.3 Communications and Tools
Due to the importance of communications to the RCs during system restoration, special training
should be organized by MISO staff in the following areas:
 Practice in communications & information sharing techniques
 Communications protocols between RCs and system operators
 Practice in the interaction between voice communications and visualization tools
 Training in conference call procedures
 Procedures for interregional communication
Practice in using multiple levels of communications (e.g. conference calling, message system,
and internet)
9.4 System Restoration Training and Seminars
MISO RC training is conducted at MISO facilities with the voice and messaging
communications methods used during normal operations. Wherever possible this training should
be scheduled in conjunction with training sessions for the TOP and BA/LBA.
System Restoration Seminars and industry courses are helpful in developing skills, increasing
operator understanding and communicating new procedures. They should be designed and
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scheduled as a major component of overall system operator training. They should also support
the system restoration planning process and drills.
Updates and changes to this Volume I will be included in the curriculum of system restoration
seminars, and the MISO Technical Training Department will be advised to updates and changes
in order to prepare and schedule appropriate training.
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10 Plan Maintenance and Ownership
The MISO SRP must be updated with changes in facilities and transmission assets, as well as
with the operating procedures and communication protocols of MISO and the TOP and
BA/LBA.
Changes in facilities, communications, procedures, regulations, and standards affect the MISO
SRP and the plans of the TOP and BA/LBA. Updates with respect to tie lines, restoration paths
and interconnections across TOP Areas are particularly relevant to the plan. MISO and the TOP
and BA/LBA jointly share responsibility maintaining the regional plan.
Among the administrative support activities required to maintain the plan are:






Facility updates
Map updates
Lessons from drills
Document management
Records management
Coordination with TOP and BA/LBA with respect to regional restoration strategy
The MISO RC will coordinate maintenance of the plan and the participating utilities in its
footprint (TOP and BA and neighboring RC’s). This will be done in conjunction with the MISO
Emergency Planning and Power System Restoration Working Group (EPPSRWG) and the
Reliability Subcommittee (RSC).
In addition to keeping the plan current and in compliance with NERC requirements, the MISO
RC will provide guidance to the TOP for the elements of their plans that require coordination.
MISO needs to provide current and consistent input to the TOP and regarding developments in
the wide area of its footprint, changes in facilities and operational protocols.
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Responsibility for maintenance of both Volumes of the MISO SRP is assigned according to plan
ownership.
Staff Assignments – Plan Ownership
Element
Position
MISO PSR Plan
MISO Restoration DrillTools
Restoration Training Registration
Drill Logistics
Simulator
MISO Liaison to MISO EP/PSRWG
Regional Operations Engineering
MISO Customer Training Dept.
MISO Drill Coordinators and Training Dept.
MISO Technical Training Dept.
Per NERC EOP-001 the SRP shall be up to date. Volume I will be reviewed and updated
annually. Updates to the plan will be coordinated with TOPs, BAs and neighboring entities.
Volume II is reviewed annually to reflect MISO internal protocols and changes in entity roles
and responsibilities.
As stated in NERC EOP-005, TOPs shall review their SRPs annually and submit to the RC.
MISO Contribution to TOP’s Restoration Plans
As the RC with visibility over the transmission network and multiple TOP and BA in a wide
area, the MISO contributes to reliability and the restoration of normal operations.
As the RC, the MISO helps TOPs and BAs to:








Communicate with participants in neighboring TOP Areas
Identify multiple restoration paths from a limited number of Blackstart Resources
Coordinate the interconnection process for resynchronizing of islands
Coordinate or authorize resynchronization of islands that bridge boundaries between TOPs or
RCs.
Provide a coordinated restoration strategy
Provide a central communications point for participants
Identify “restoration opportunities” – optimal transmission paths during restoration
Evaluate blackstart availability, and coordinate outages of Blackstart Resources
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11 Compliance
This SRP complies with the NERC requirement that the MISO, as a RC, has a restoration plan to
reestablish its electric system in a stable and orderly manner in the event of a partial or total
shutdown of its system, including necessary operating instructions and procedures to cover
emergency conditions, and the loss of vital telecommunications channels.
The MISO plan complies with existing NERC requirements. The compliance requirements
involve MISO, its member utilities, and its responsibilities with respect to non-members, and
neighboring RCs. All entities in the MISO footprint share responsibility together to provide a
sensible and workable regional restoration plan. Compliance for the TOPs, BA/LBAs and GOPs
within MISO’s footprint depends on MISO taking a leading role in organizing a comprehensive
plan, and in providing the training along with drills to support the MISO SRP.
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Attachment A
Transmission Operator System Restoration Plans
MISO is the RC responsible for interconnecting electrical islands in the sub regions and its entire
footprint. The BA and TOP are responsible for using transmission, generation, and distribution
assets in their area to restore power along designated transmission corridors.
The MISO System Restoration Plan provides guidelines and strategies for the restoration of the
electric power system of the MISO and the BA Areas in the footprint and neighbors, under
complete or partial blackout conditions. The MISO System Restoration Manual sets forth the
guidelines for RCs, and provides strategies for system restoration, interconnection, and the
resumption of normal operations.
The strategies for restoration are developed in designated islands, along transmission corridors,
as defined by the TOPs in their individual system restoration plans. These include facilities and
procedures that start generating units, energize transmission corridors, and restore customer
loads. Each TOP is responsible for implementing its restoration plan in coordination with
BAs/LBAs as well as with other power producers.
Generators without on-site blackstart capability must rely on power from the grid to restart.
Internal auxiliary power sources may not be sufficient to protect plant assets over the time
required for system restoration process. Once Blackstart Resources energize the grid, restoring
station power to these plants is a priority for TOPs along with any transmission assets essential to
system restoration. After sufficient loads are established such that the island is stable, startup
power can be provided to power plants.
A distinction must be made between two services: Blackstart Service and planning for system
restoration. Blackstart refers only to a generating unit’s ability to start itself without support
from the grid. System restoration refers to the coordinated effort that uses Blackstart Resources
to energize the grid, start other generators, deliver power to loads, and resynchronize the
interconnection.
The obligation to obtain Blackstart Service is a responsibility that rests with the TOPs.
Blackstart is a service provided by the generation owners. Restoration is an interconnected
operations function provided by TOPs in collaboration with BAs/LBAs, GOPs and MISO.
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Attachment B uu
TOP System Restoration Plan Review Worksheet
Purpose
MISO coordinates the development of system restoration strategy with the entities in its
Reliability Coordinator (RC) Area and reviews the Transmission Operator (TOP) restoration
plans to ensure consistency with the restoration plans of the neighboring entities and MISO.
NERC Standard EOP-006-2 System Restoration Coordination requires that the TOP restoration
plans be approved by the RC. This worksheet identifies the elements that are within the scope of
the review and specifies the criteria for the assessment.
Use
1. The TOP shall submit this worksheet, along with their system restoration plan,
whenever the plan is updated or upon annual review. This worksheet must be
submitted to MISO at least 30 calendar days before the anticipated effective date.
2. The white sections of the form should be completed in entirety by the TOP. Please type
your responses directly into the fields below. The restoration plan should clearly and
comprehensively address all the elements contained in the worksheet with each
supporting section cited in the review worksheet to facilitate the review by MISO.
 Please submit your restoration plan and the completed worksheet to MISO’s
dedicated mailbox: [email protected]
3. MISO will review the TOP plan and the information provided in the review worksheet to
determine if the plan is consistent and compatible with the plans of neighboring TOPs
and the MISO restoration plan.
4. MISO will complete the review within 30 calendar days, documenting any discrepancies
in the worksheet in the tan sections. A copy will be sent to the TOP for resolution.
5. Once the TOP restoration plan has been reviewed and determined to be compatible
with the neighboring TOP plans and the MISO plan, MISO will document the approval of
the plan in the review worksheet and provide a copy to the TOP.
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Plan Review and Approval (Version 3.0)
Plan Approval Status
Status
Date
MISO Reviewer Information
Date Reviewed
Approver Name
Title
Phone
Email
Reviewer Initials
TOP Contact Information
Entity Name
Date Submitted
Plan Effective
Date
Name
Title
Phone
Email
Status (Accept/Reject)
MISO Notes
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Identification of Blackstart Resources
Cranking Paths
Primary Cranking Path is identified and complete from Blackstart Resource to unit(s) to be
started.
Page/section:
If no Blackstart generator is identified, a path is identified from external tie location to the
unit(s) to be started and external entity is identified.
Page/section:
Status(Accept/Reject)
MISO Notes
Blackstart Generation Fuel Sources
Fuel types and availability/duration of fuel supply are specified for Blackstart generators.
Page/section:
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Status(Accept/Reject)
MISO Notes
Nuclear Plant Requirements
Nuclear plant offsite power is identified as a priority objective.
Page/section:
Status(Accept/Reject)
MISO Notes
General Restoration Strategies
Restoration strategy is consistent with MISO restoration philosophy.
Page/section:
Status(Accept/Reject)
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MISO Notes
Procedures for Managing Voltage and Frequency for Islanding Situations
Voltage control considerations and techniques for controlling voltage are included in the plan.
Page/section:
Frequency control considerations and techniques for controlling frequency are included in the
plan. Page/section:
For TOP only entities, the entity responsible for generation control is specified in the plan.
Page/section:
Status(Accept/Reject)
MISO Notes
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Identification of synchronization Points
Plan includes a list of synchronizing locations.
Page/section:
Status(Accept/Reject)
MISO Notes
Procedures for Resynchronization of Islands
The island re-synchronization process described in the plan is consistent with MISO
interconnection process.
Page/section:
The re-synchronization process described in the plan specifies that the RC must be notified
whenever any internal/external islands are resynchronized.
Page/section:
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The re-synchronization process described in the plan specifies that RC approval is required
when tying between neighboring TOPs or the Eastern Interconnection. (Refer to section 3.7.6 of
MISO Restoration Plan for criteria).
Page/section:
Status(Accept/Reject)
MISO Notes
Procedures and Priority for Restoring Load
The plan considers priority loads essential for system restoration. If none exist, then plan should
clearly state “none”.
Page/Section:
Status(Accept/Reject)
MISO Notes
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Communication Procedures
Internal
Plan identifies any internal communications procedures for implementation of restoration plan
activities.
Page/section:
Status(Accept/Reject)
MISO Notes
RC
Plan identifies a requirement to work with MISO RC to assess initial conditions.
Page/section:
Plan includes a requirement to keep the MISO RC informed of progress with key milestones,
load/generation restored and remaining islands not yet synchronized to the Interconnection.
Page/section:
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Plan identifies public telephone as primary voice communications and satellite/VOIP as backup
voice communications when primary system is not available.
Page/section:
Plan identifies blast calls as the primary tool used by the MISO RC to broadcast voice
communications to multiple parties.
Page/section:
Plan identifies MISO Communications System (MCS) as the primary electronic messaging tool
used by MISO RC to communicate progress to multiple parties.
Page/section:
Status(Accept/Reject)
MISO Notes
Neighboring TOPS
Plan contains a provision to coordinate with neighbors when tie lines are affected and when
preparing to resynchronize islands.
Page/section:
Status(Accept/Reject)
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MISO Notes
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Impacted Entities
Neighboring TOPs
Plan identifies neighboring TOPs.
Page/section:
Status(Accept/Reject)
MISO Notes
All BAs in TOP Area
Plan identifies all BAs/LBAs within the TOP area.
Page/section:
Status(Accept/Reject)
MISO Notes
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GOPs in TOP Area included in plan
Plan identifies registered GOPs for each unit included in plan as well as indicates which units
(Blackstart or non-Blackstart) are necessary to achieve restoration pursuant to those TOP plans.
Page/section:
Status(Accept/Reject)
MISO Notes
Compatibility With Neighboring TOP Plans
Blackstart assistance that has been identified in the plan is also included in the neighboring TOP
plan and that the point of interconnection for establishing cranking path from the border is
consistent.
Page/section:
Status(Accept/Reject)
MISO Notes
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Emergency Power Supply
Plan includes provisions for emergency power for control center operation.
Page/section:
Status(Accept/Reject)
MISO Notes
Recognition of RC Restoration Plan
Plan contains a reference to the MISO RC restoration plan.
Page/section:
Plan identifies the role of the MISO RC consistent with the role described in the MISO RC
restoration plan.
Page/section:
Status(Accept/Reject)
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MISO Notes
Training Plan/Requirements
Plan contains provisions for TOP operator training in the execution of the plan.
Page/section:
Plan contains a provision for coordinated training with neighbors (e.g. MISO system wide
drills).
Page/section:
Status(Accept/Reject)
MISO Notes
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Attachment C
TOP System Restoration Plan Annual Submission Schedule
Per EOP-005-2 R3, each TOP is required to review its System Restoration Plan and submit to its
RC ‘… annually on a mutually agreed predetermined schedule.’ The table below outlines the
agreed schedule between MISO and its TOPs. If the TOP determines that there are no changes
to a previously submitted and approved plan, the TOP must notify MISO it has reviewed the plan
and found no additional changes according to the schedule below.
The below schedule has been reviewed by the EPPSRWG, any changes to the schedule must be
reviewed at a regularly scheduled EPPSRWG before taking effect.
Changes to the plan outside the below schedule are acceptable, and required as outlined in EOP005-2 R4. However, that does not modify the requirement to review and submit any revisions on
the below schedule.
Month Annual Submission Due
January
February
March
April
May
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TOP
OVEC
SMEPA
HE
ITC
LBWL
MPC
MidAmerican
MP
NSP
Vectren
Wolverine
Ameren
BREC
Cleco
CWLD
CWLP
DPC
IPL
NIPSCO
OTP
SIPC
Public
Month Annual Submission Due
June
LAFA
July
August
September
October
November
Duke
ATC
Entergy
GRE
MDU
MPW
RPU
December
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Attachment D vv
MISO Interconnection Checklist and Example
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1.
INTERCONNECTION CHECKLIST (Rev 9)
Step 1: Island Definition and Contact Info (RC to complete this step)
Island
Island
"A"
"B"
1
Balancing Area(s) (BA)
<--Balancing areas in this island
2
BA Contact Name
<--Who is the BA contact person for this island
3
BA Contact Phone
4
Frequency Control Generator (FCG)
5
FCG Contact name
6
FCG Contact Phone
7
Transmission Operator (s) (TOP)
(If different than BA, otherwise NA)
8
TOP Contact Name
(If different than BA, otherwise NA)
9
TOP Contact Phone
(If different than BA, otherwise NA)
Step 2: Determine Worst Effective Contingency (Loss of MW Output + Loss of Governor Reserve)
*10
Largest effective contingency
<-- Gen w/ highest MW output & governor reserve or total gen on radial transmission
11
Total available gen capacity
<-- Current capacity of unit(s) identified in line 10 (consider mill points, etc.)
12
Total gen MW output
<-- Current MW output of unit(s) identified in line 10
13
Total gen spinning reserve
<-- Difference between capacity and current MW output (line 11 - line 12)
14
Total gen governor reserve
<-- If not available (see instructions), use 20% of spinning reserve as proxy
Step 3: Evaluate Stability of Existing Islands (Each entity provides the following information to the RC)
**15
Frequency range
<--Preferred within 60.0 +/- 0.2 Hz over 10 minutes
16
Voltage range at boundary bus
<--Preferred nominal, within +/- 2% over 10 minutes
17
Total available online capacity
<--Total MW capability of all online units (consider mill points, etc.)
18
Total MW of online units
<--Current total MW loading of all online units
19
Total Spinning Reserves
<--Difference between capacity and current MW (line 17 - line 18)
**20
Governor reserve
<--If not available (see instructions), use 20% of spinning reserve (proxy)
**21
Half of automatic load shed restored
<--use 50% of calculated UFLS restored (0 if not certain)
Total Dynamic Reserve
<--Sum line 20 and 21
**23
Largest effective contingency
<--Sum lines 12 and 14
**24
Verify total Dynamic Reserve (line 22) equals or exceeds the largest effective contingency (line 23)
22
Step 4: Evaluate Interconnect
25
Sync location to be used
<--Substation and breaker ID
26
Automatic reclosing relays off?
<--First tie line associated breakers reclosing relays should be off
27
Relaying or SPS concerns at sync?
<--Hot bus/dead line, hot line/dead bus, SPS, etc.
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**28
Frequency control unit to be used
<--No more than one unit at 0% droop***
AGC control modes (if available)
<--Flat frequency, flat tie, or tie line bias
Step 5: Evaluate Resulting Island
<--Not necessary if interconnecting to Interconnection
30
Total available online capacity
<--Sum of row 17
31
Total MW of online units
<--Sum of row 18
32
Total Spinning Reserves
<--Sum of row 19
33
Governor reserve
<--Sum of row 20
34
Half of automatic load shed restored
<--Sum of row 21
35
Total Dynamic Reserve
<--Sum of row 22
36
Largest effective contingency
<--Greater of row 23
37
Verify total dynamic reserve (line 35) equals or exceeds the largest effective contingency (line 36)
38
Balancing Authorities must agree on scheduled interchange; flow should be maintained near zero if only one tie line
29
Step 6 Approval
39
The Reliability Coordinator(s) approve this interconnection
Time approved
RC initials
Time closed
Date
40
Establish additional ties as soon as possible
41
Each BA (LSE) should not pick up more than 5% of online capacity in their area without notification to the RC
42
As Islands grow, AGC modes, reserves, tie line flows, etc. need to be reviewed with all island Balancing Authorities periodically.
* In addition to generation contingencies, transmission contingencies should also be considered for loss of load, etc. and the effect on voltage
and frequency
** These fields are not required if connecting to the Eastern Interconnection or at RC discretion based on island size
*** Some units cannot return to normal droop without coming
offline
MISO Interconnection Checklist,
Revision 9
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INTERCONNECTION CHECKLIST (Rev 9) - (Completed Example)
Step 1: Island Definition and Contact Info (RC to complete this step)
Island
Island
"A"
"B"
1
Balancing Area(s) (BA)
ALTE
CE
<--Balancing areas in this island
2
BA Contact Name
Will B
Gary B
3
BA Contact Phone
XXX
XXX
4
Frequency Control Generator (FCG)
ROR 5
Rockford 1
5
FCG Contact name
Henry W
Dick W
6
FCG Contact Phone
XXX
XXX
7
Transmission Operator (s) (TOP)
ATC
PJM
(If different than BA, otherwise NA)
8
TOP Contact Name
Roger T
Tom W
(If different than BA, otherwise NA)
9
TOP Contact Phone
XXX
XXX
(If different than BA, otherwise NA)
<--Who is the BA contact person for this island
Step 2: Determine Worst Effective Contingency (Loss of MW Output + Loss of Governor Reserve)
*10
Largest effective contingency
CHA 3
Rockford1
<-- Gen w/ highest MW output & governor reserve or total gen on radial transmission
194
150
<-- Current capacity of unit(s) identified in line 10 (consider mill points, etc.)
11
Total available gen capacity
12
Total gen MW output
65
50
<-- Current MW output of unit(s) identified in line 10
13
Total gen spinning reserve
129
100
<-- Difference between capacity and current MW output (line 11 - line 12)
14
Total gen governor reserve
38.8
30
<-- If not available (see instructions), use 20% of spinning reserve as proxy
Step 3: Evaluate Stability of Existing Islands (Each entity provides the following information to the RC)
**15
Frequency range
60 - 60.5
59.9 - 60.1
<--Preferred within 60.0 +/- 0.2 Hz over 10 minutes
16
Voltage range at boundary bus
347
349
<--Preferred nominal, within +/- 2% over 10 minutes
17
Total available online capacity
621
447
<--Total MW capability of all online units (consider mill points, etc.)
18
Total MW of online units
206
145
<--Current total MW loading of all online units
19
Total Spinning Reserves
415
302
<--Difference between capacity and current MW (line 17 - line 18)
124.2
89.4
<--If not available (see instructions), use 20% of spinning reserve (proxy)
0
3
Total Dynamic Reserve
124.2
92.4
<--Sum line 20 and 21
**23
Largest effective contingency
103.8
80
<--Sum lines 12 and 14
**24
Verify total Dynamic Reserve (line 22) equals or exceeds the largest effective contingency (line 23)
**20
Governor reserve
**21
Half of automatic load shed restored
22
<--use 50% of calculated UFLS restored (0 if not certain)
Step 4: Evaluate Interconnect
25
Sync location to be used
26
Automatic reclosing relays off?
Yes
<--First tie line associated breakers reclosing relays should be off
27
Relaying or SPS concerns at sync?
No
<--Hot bus/dead line, hot line/dead bus, SPS, etc.
**28
Frequency control unit to be used
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PAD 2222-S
ROR 5
<--Substation and breaker ID
<--No more than one unit at 0% droop***
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AGC control modes (if available)
NA
Step 5: Evaluate Resulting Island
<--Flat frequency, flat tie, or tie line bias
<--Not necessary if interconnecting to Interconnection
30
Total available online capacity
1068
<--Sum of row 17
31
Total MW of online units
351
<--Sum of row 18
32
Total Spinning Reserves
33
Governor reserve
34
Half of automatic load shed restored
35
717
<--Sum of row 19
213.6
<--Sum of row 20
3
<--Sum of row 21
Total Dynamic Reserve
216.6
<--Sum of row 22
36
Largest effective contingency
103.8
<--Greater of row 23
37
Verify total dynamic reserve (line 35) equals or exceeds the largest effective contingency (line 36)
38
Balancing Authorities must agree on scheduled interchange; flow should be maintained near zero if only one tie line
Step 6 Approval
39
The Reliability Coordinator(s) approve this interconnection
Time approved
0719
Time closed
0721
Date
RC initials
DS(MISO)
HJ(PJM)
6/15/2011
40
Establish additional ties as soon as possible
41
Each BA (LSE) should not pick up more than 5% of online capacity in their area without notification to the RC
42
As Islands grow, AGC modes, reserves, tie line flows, etc. need to be reviewed with all island Balancing Authorities periodically.
* In addition to generation contingencies, transmission contingencies should also be considered for loss of load, etc. and the effect on voltage
and frequency
** These fields are not required if connecting to the Eastern Interconnection or at RC discretion based on island size
*** Some units cannot return to normal droop without coming offline
MISO Interconnection Checklist,
Revision 9 (Checklist same as Rev 8. Rev
9 included revised sample calculation)
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Attachment E
Eastern Interconnection RC
Interconnection Checklist
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Attachment F ww
MISO
PSR Philosophy Document
Version 1.4
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Contents
Section 1: MISO PSR Plan Procedures
o 1.01 Definition of a Restoration Event
o 1.02 MISO’s Primary Role during Restoration
o 1.03 MISO Regions
o 1.04 MISO Restoration Plans and Procedures
 1.04.01 Assessment of System Conditions
 1.04.02 Communications between Operating Authorities and RCs
 1.04.03 Evaluation of Impacts to the “Standards of Conduct”
 1.04.04 System Restoration Plan Preparation
 1.04.05 Plan Implementation
 1.04.06 System Restoration Strategies
 1.04.07 Interconnection and Synchronization
 1.04.08 Re-Synchronizing Islands
 1.04.09 Interconnection Checklist
 1.04.10 Interchange Schedule
 1.04.11 Load Shedding
 1.04.12 Tying Sub-Systems or Islands within a TOP Area
 1.04.13 Tying Sub-Systems between TOP Areas
 1.04.14 Resumption of Normal Operations
o 1.05 Telecommunications
Section 2: Restoration Procedure Recommendations (for Transmission Operators, Local Balancing
Authorities, Balancing Authorities, and Generator Operators)
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o
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2.01 Power System Assessment
2.02 Generating Facility Procedures
2.03 Communicate With DOE, NERC, and Regional Entities
2.04 Plan the Response
2.05 Human Resources
 2.05.01 Staffing Plan
 2.05.02 Operator Reaction
 2.05.03 Limit Access to Control Room
2.06 Initiate Restoration Plans
2.07 Switching Strategies
2.08 Cranking Paths
2.09 Use of Generation Resources during System Restoration
 2.09.01 Operation of Black-Start Units
 2.09.02 Fast Start Generating Units
 2.09.03 Re-Start Coordination of Base Load Generation
2.10 Nuclear Plants
2.11 Parallel Restoration
2.12 Blackstart Island Components
2.13 Load as a Start-Up Tool
2.14 Voltage Control
2.15 Frequency Control
2.16 Responsive Reserves Criteria
2.17 Developing Strong Islands before Synchronizing
2.18 Synchronizing Adjacent Systems
 2.18.01 Considerations for Synchronizing
 2.18.02 MISO Requirements for Synchronizing (Internal Synch Points)
 2.18.03 MISO Synchronizing with Neighboring Systems
2.19 Operating Reserves
2.20 Documentation of Events
Section 3: Post-Event Reporting and Analysis
o 3.01 Final Reports (DOE, NERC, etc.)
o 3.02 Sequence of Events Analysis
o 3.03 Lessons Learned
o 3.04 Recommend Procedural Changes
o 3.05 Recommend Training
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Section 1: MISO PSR Plan Procedures
1.01 Definition of a Restoration Event
Under EOP-006-2 R1, the scope of an RC’s restoration plan starts when:
1)
Blackstart Resources are utilized to re-energize a shutdown area of the BES; or
2)
Separation has occurred between neighboring RCs; or
3)
An energized island has been formed on the BES within the RCs area.
Power systems occasionally experience the failure of individual elements. Typically, although some operating
security limit violations occur, the remainder of the power system stays intact following the loss of individual
elements. MISO does not consider events of this nature as restoration events.
In some instances, a disturbance may result in large portions of the power system collapsing, losing both voltage and
frequency. Following these type disturbances, the power system must be restored to an energized and
interconnected state through the use of synchronizing equipment. MISO considers an event of this nature as a
restoration event.
Total System Blackout
A total system blackout is a post-disturbance condition in which the entire bulk electric power system of a particular
entity is de-energized. In a total system blackout all pre-disturbance on-line generating units have tripped off-line.
1.02 MISO’s Primary Role during Restoration
As the RC, MISO’s primary role is to serve as a facilitator during the restoration process: coordinating, exchanging
information, and maintaining stability. During interconnection, MISO’s role becomes central in order to facilitate
and advance the restoration of the system while maintaining stability so as to prevent a re-collapse of the system.
1.03 MISO Regions
MISO operates as a single Reliability Coordination (RC) Area. For purposes of restoration planning, MISO divides
the facilities under its control into smaller reliability-monitoring areas, called sub-regions. The sub-regions are
currently divided as follows:
MISO Central Region:
Wisconsin and Upper Michigan sub-region
Lower Michigan, Northern Indiana sub-region
Southern Indiana and Southern Ohio sub-region
Missouri and Southern Illinois sub-region
MISO North Region:
Dakotas sub-region
Minnesota/Western Wisconsin sub-region
Iowa sub-region
Manitoba, Canada sub-region
MISO South Region:
Arkansas, Louisiana, Mississippi, Texas sub-region
The sub-regions are divided along electrical boundaries and may change as new members join, new transmission
lines are built, electrical interconnections change, or additional restoration opportunities are identified across the
Balancing Authority (BA)/Local Balancing Authority (LBA) Areas. The individual Operating Authorities within
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MISO’s operational regions are organized into sub-regions. During the restoration process, the sub-regions
eventually interconnect to fully restore the grid throughout the MISO footprint. MISO views the system restoration
plans of the TOPs from a transmission corridor perspective. Transmission corridors (sometimes referred to as
cranking paths) extend from black-start generating plants to the targeted facilities needing off site power. As these
transmission corridors are energized during restoration they are then interconnected to other TOP Areas to restore
the entire grid. The interconnections are not meant to be made sequentially or by completing sub-regions but made
whenever conditions permit.
MISO is the RC responsible for coordinating the interconnection of electrical islands within its entire footprint. The
TOPs are responsible for using transmission, generation, and distribution assets in their respective areas to restore
power along designated transmission corridors.
The transmission corridor perspective recognizes the role of a transmission provider in the system restoration
process. System restoration plans within individual TOP Areas typically match Blackstart Resources with larger
power plants. In its footprint MISO is the RC monitoring 100kV and higher lines (69kV in some areas). With the
objective of restoring the Bulk Electric System, MISO provides coordination of restoration plans along with island
interconnection and monitors transmission corridor energizing, load pick-up, voltage and frequency on a wide area
basis.
A transmission corridor perspective allows for islands to be built with different combinations of Blackstart
Resources, power plants, and load areas within the individual TOPs. These may also cross TOP boundaries. This
approach optimizes the deployment of existing Blackstart Resources throughout the MISO footprint. By taking a
wide area view, the MISO can identify hot busses and inter-ties to increase the probability of identifying
interconnection opportunities as restoration progresses.
1.04 MISO Restoration Plans and Procedures
NERC Power System Restoration Requirements
NERC Standard EOP-005-2 R1 establishes the requirements for TOP System Restoration Plans. NERC Standard
EOP-006-2 R1 defines the requirements for the MISO RC System Restoration Plan.
MISO System Restoration Process:
1.04.01 Assessment of System Conditions
The MISO RC works with the TOP to determine the status of the system and assess the need for
system restoration.
1.04.02 Communications between RCs and affected entities
The RC should notify each affected TOP and BA/LBA of the BES status. The preferred method to
complete this notification is to initiate a blast call, followed by a notification via the MISO
Communications System (MCS).
1.04.03 Evaluation of Impacts to the “Standards of Conduct” (SRP 3.3)
When conditions are determined to require regional restoration actions, the RC will refer to its internal
procedures, and make appropriate notifications. All entities are individually responsible for their own
Standards of Conduct.
1.04.04 System Restoration Plan Preparation (SRP 3.4)
The TOPs, working in conjunction with the RC, should determine the extent and condition of the
isolated area(s). TOPs will take necessary action to restore frequency to normal, including
instructions to BAs/LBAs to adjust generation, place additional generators on line, or shed load. The
MISO BA will assist affected LBAs and BA’s in reviewing the interchange schedules within the
separated area and make all attempts to maintain adjusted interchange schedules.
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1.04.05 Plan Implementation (SRP 3.5)
The RC should monitor conditions, communicate and coordinate with affected entities and adjacent
RCs during implementation of the System Restoration Plan. The RC will pay particular attention to
the restoration priorities and insure that the priorities are respected as the restoration progresses. These
priorities are:
 The RCs, TOs, LBAs and BAs will implement restoration strategies.
 The TOP shall give high priority to restoration of off-site power to nuclear power generating
stations.
 Restoration priority will be given to the station auxiliary supply of power plants, substations
essential to restoration and inter-ties.
 Cranking power to neighboring power plants should have a priority over restoring internal
customer load in a BA/LBA Area (once sufficient load is established in an island).
 Customer load should be restored as generation and transmission equipment becomes available.
1.04.06 System Restoration Strategies (SRP 3.6)
Restoration strategies identified in the TOP’s restoration plan are coordinated and compatible with the
strategies identified in the MISO System Restoration. Restoration plans are coordinated with
neighboring RCs, TOPs, and BAs/LBAs. These plans identify major transmission corridors and most
likely interconnection points. If the restoration plan cannot be executed as expected the TOP will
utilize its restoration strategies to facilitate restoration.
The RC is expected to follow policies and procedures to ensure the operational reliability of the
interconnections. These include reliability analyses and identifying special operating procedures,
analyzing current operating conditions, and implementing procedures to mitigate System Operating
Limit (SOL) and Interconnection Reliability Operating Limit (IROL) violations on the transmission
system.
1.04.07 Interconnection and Synchronization (SRP 3.7)
During interconnection stage of restoration, especially while re-synchronizing islands, the RC should
make every effort to ensure that the TOPs maintain their transmission systems to prevent IROLs.
1.04.08 Re-Synchronizing Islands (SRP 3.7.1)
When voltage, frequency, and phase angle permit, the TOP may resynchronize the isolated area(s) with
the surrounding area(s), upon notification to or authorization from the RC. The RC shall coordinate or
authorize resynchronizing islanded areas that bridge boundaries between TOPs or RCs. The size of the
area being reconnected and the capacity of the transmission lines affecting the reconnection should be
taken into account and be known. The RC provides a set of guidelines for interconnection process to
evaluate the readiness for resynchronization.
1.04.09 Interconnection Checklist (SRP 3.7.2)
The MISO RC has developed a set of guidelines for the interconnection process that is defined in the
Interconnection Checklist. The checklist contains a set of criteria for evaluating the stability of islands
prior to re-synchronization.
For interconnections that require RC authorization per the MISO RC criteria, the RC will confirm with
the interconnecting entities that the items on the Interconnection Checklist are cross-checked and
completed satisfactorily. The following items require special attention:
 Systems to be interconnected are stable.
 Operators for each of the TOP Areas to be inter-tied agree on the synchronization points,
synchrocheck relays or manual synchronizing methods to be used to tie the systems together.
 Frequency control assignment is agreed.
 Contingency reserves are sufficient to cover the most severe single contingency in each system.
 Direct communications are established with entities involved in the interconnection activities.
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1.04.10 Interchange Schedule (SRP 3.7.3)
Prior to interconnecting the BA/LBA Areas, an interchange schedule between the BAs/LBAs
should be planned. This interchange schedule should be agreed to and be utilized by the sending
and receiving BAs/LBAs.
1.04.11 Load Shedding (SRP 3.7.4)
The TOP or MISO RC may direct that load shall be shed in affected entity areas, where required, to
permit successful interconnected system restoration.
1.04.12 Tying Sub-Systems or Islands within a TOP Area (SRP 3.7.5)
Once two or more operating islands within a TOP Area have been established, plans should be made to
connect them even if most of the load in the islands have not been restored.
Synchronization of islands should be done as soon as possible on a controlled and coordinated basis in
order to help speed up the restoration process. The MISO RC shall be notified prior to interconnecting
islands within a TOP area.
1.04.13 Tying Sub-Systems between TOP Areas (SRP 3.7.6)
Once transmission corridors within or across TOP areas have been formed, preparations should made
to tie these operating islands together within the TOP area or with neighboring islands. RC approval of
the interconnection may be required depending on criteria set out in the plan. In these cases, the RC
will confirm which unit is assigned flat frequency control and which units will be manually adjusted to
maintain governor and operating reserves as load is restored. The RC will approve the interconnection
of TOP areas only when they are considered stable. The criteria for island stability prior to
interconnection are defined in the Interconnection Checklist. Once the RC confirms the TOP areas are
tied, internal system restoration within the areas may proceed.
1.04.14 Resumption of Normal Operations (SRP 3.8)
The RC should take actions to restore normal operations once an operating emergency has been
alleviated in accordance with its operation plan. The TOP and MISO RC will confirm that acceptable
voltage and frequency is maintained while load is being restored. Once tied, TOPs need to coordinate
load pick-up Load increments should not be larger than the spinning reserve capability of the system
from which the area is being energized. BAs in coordination with TOPs should disperse their reserves
and not pick up loads greater than 3 to 5 percent of synchronized capacity. Once the inter-tie has been
established, the RC, TOP, and BAs/LBAs should carefully track generator reserves, frequency,
voltage, and tie flow. Governor reserves should continue to be maintained in the two former islands
until two or more ties have been established. Frequencies should be monitored and load block sizes
selected to prevent excessive frequency excursions in the islands or BA/LBA areas.
As restoration proceeds, BAs/LBAs should continue to carry at least enough Contingency Reserve to
cover the most severe single contingency and maintain generating capacity (regulating reserves)
sufficient to maintain a stable frequency.
The RC should prescribe operating criteria for system configurations that will ensure reliable
operations as normal operations are resumed. Once operating guides are established, the RC should
monitor them closely. As the restoration effort reaches a conclusion, the RC should constantly be alert
for any conditions that may cause the system to re-collapse due to IROL violations.
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1.05 Telecommunications
Telecommunication is an essential service for system restoration. It is important to establish
communications between the RC and affected entities as well as between RCs in adjacent areas. The
MISO WAN should be used to supply connectivity to members and non-members and provide VoIP
communications independently of the Public Switched Telephone Network (PSTN). MISO WAN is a
secure alternative to the PSTN and provides the necessary redundancy.
Voice communications is critically important. The MISO Turret system provides functionality in terms of
speed dialing and blast calls; external conferencing services are available as well. Conferencing
capabilities with enhanced functionality using the MISO turret over the MISO WAN are the primary means
of establishing and maintaining conference calls during emergencies. The system restoration plan relies on
the connectivity and functionality of the communications system, and it will be maintained and tested semiannually.
Reliability of telecommunication infrastructure and support services is a prerequisite for a successful
system restoration plan. Telecommunication services are available to MISO from multiple sources. Among
these are:






VoIP over the MISO WAN
MCN over the MISO WAN
Public Switched Telephone Network
Commercial Internet
Cell Phones
Satellite Phones
Reliability Coordinators will be familiar with the services provided by support personnel for
telecommunications equipment on-site and external commercial providers. Training will be provided by
contacting the support personnel and obtaining their services in the occurrence of a restoration event.
Reliability Coordinators will be aware of the telecommunication infrastructure that supports
communications during restoration. Key elements are:






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Redundant networks between control centers
Redundant networks between Reliability Coordinators, Transmission Operators, Balancing
Authorities, and Local Balancing Authorities.
Field devices (sync scopes; Blackstart Resources)
Back up for communications facilities and devices for duration of restoration
Multiple communications links to neighboring utilities
Conferencing calling capabilities of Operating Authorities
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Section 2: Restoration Recommendations (for Transmission
Operators, Local Balancing Authorities, Balancing Authorities, and
Generator Operators)
2.01 Power System Assessment
Following a BES disturbance, the Transmission System Operators, Local Balancing Authorities, Balancing
Authorities, and Generator Operators should review alarm records and system indicators to determine the nature and
extent of the system disruption. When a reasonable assessment has been formulated, contact the Reliability
Coordinator and communicate the state of your system. Reliability Coordinator will assemble the assessments and
communicate as necessary to the affected TOP and neighboring RC areas.
Scenario: A system disturbance occurs in mild weather conditions.
Circuit breaker positions and relay targets cannot be relied on to determine equipment serviceability. If a relay is so
equipped, an out of step relay target is an indication that system power swings – not a system fault – likely initiated
breaker operation. Searching for faulted equipment is generally not an efficient use of the operator's time under
these conditions. The operator should proceed with system restoration assuming that all equipment in service prior
to the initiating event is still available, unless there is equipment which has been field verified to be faulted.
Scenario: A system disturbance occurs in severe weather conditions (ice storms, tornado sightings, etc.)
System operators should proceed cautiously. Circuit breaker positions and relay targets are accurate indicators of
faulted equipment in these types of situations.
The TOP has the responsibility of building islands to designated synchronizing locations within the TOP boundary.
2.02 Generating Facility Procedures
It is the responsibility of each GOP to ensure the generating units are placed in a safe shutdown condition.
The GOP should initiate or request from the proper switchyard controlling authority an inspection of the Facility
switchyard for damage or request repair of damage that prevents the Facility from returning to service.
The GOP should configure the plant and assist in coordination of the switchyard in preparation for energizing the
Facility with offsite power.
The GOP should prepare the generating units for restart as soon as practicable.
During the restoration process, the GOP should maintain contact with and inform the TOP regarding the status and
condition of the generating units.
In general, the GOP should not permit the starting of large motors or energizing of large transformers unless
expressly permitted to do so by the TOP and BA/LBA.
GOP should staff and ready the Blackstart Resources for service.
If requested by the TOP, BA, LBA or RC the GOP should be prepared to staff Generating Units that were not on
line at the time of the black out as these units may be called on during the restoration process.
2.03 Communicate with DOE, NERC, and Regional Entities
The TOPs, BAs/LBAs and RC should file the appropriate disturbance reports with DOE, NERC, Regional Entities
and other authorities with jurisdiction.
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2.04 Plan the Response
Based on the system conditions that are present and the assessment of the event, the TOPs should plan their
responses using their respective System Restoration Plans.
2.05 Human Resources
2.05.01 Staffing Plan
Transmission Operators, Balancing Authorities, Local Balancing Authorities and Reliability Coordinators
should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the
affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration,
and will ensure the requisite resources are made available to realize these objectives.
During the restoration effort, it is advisable to make periodic assessments of the staff required to optimize the
response to the event.
2.05.02 Operator Reaction
Be observant of the behavior of others under emergency conditions. The public, other system control operators,
power plant operators, etc. will react differently to the situation. Prepare to be the calming influence.
2.05.03 Minimize Distractions in the Control Room
It is recommended that Transmission Operators, Local Balancing Authorities and Balancing Authorities and
Reliability Coordinator minimize distractions in the control rooms for the duration of the emergency to reduce
noise and confusion.
2.06 Initiate Restoration Plans
When the TOPs have completed their assessment of conditions, they should initiate their restoration plans. TOP
should notify the MISO RC of their activities and provide ongoing updates on restoration progress.
2.07 Switching Strategies
For placing substation in a state of readiness, the "controlled open" strategy is recommended for two reasons:
o
o
Requires fewer switching steps than the "all open" strategy.
Minimizes use of stored energy (e.g. batteries, compressed gas, etc.)
If feasible, configure the substation so that when energizing the first bus in the station, the auxiliary power supply is
energized and that battery bank chargers can power DC systems.
The "all open" strategy is acceptable if analysis by the TOP, have previously agreed that is better than the
“controlled open” strategy for specific path or subsystem and this finding appears in the TOP’s restoration plan
accepted by MISO.
2.08 Cranking Paths
When restoring islands MISO recommends adhering to the restoration plan when determining cranking paths unless
the desired cranking path has been determined to be out of service or has sustained equipment damage. If an
alternate path is required, a pre-determined back up cranking path should be used that has been studied and
determined to be a good option. If neither primary nor backup paths are available, the TOP should use its restoration
strategies to facilitate restoration. MISO should be informed if deviation from the primary restoration plan is
eminent.
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2.09 Use of Generation Resources During System Restoration
As much as possible, the TOP should be aware of the actual capabilities and settings of units used during a
restoration (ie, droop settings, deadbands, governor availability, AVR capability, etc..). To the extent
actual data is not available, this philosophy document contains guidelines and assumptions. GOPs should
notify the TOP and LBA/BA of any abnormal operational status that may impact the restoration
assumptions.
2.09.01 Operation of Black-Start Unit
In an islanded mode, during initial restoration, select one unit to control the frequency (0% droop,
isochronous or isolated precise) and set any other generators at normal (parallel, 5%) droop.
Place the generator power controls (MW) in automatic operation and enable the Automatic Voltage
Regulator (AVR) if they are available.
Maintain adequate reserves on the "swing" unit for load pickup or rejection.
Ensure that available cranking capacity (in KVA) of unit(s) is approximately 10 times the HP rating of the
largest motor to be started and the cranking unit(s) should also be loaded (in KW) to 5 times the HP rating
of the motor being started.
2.09.02 Fast Start Generating Units
Along the cranking path, it may be advantageous to fire fast start units like single cycle combustion
turbines. As these units come on line, be mindful of the regulation mode. Only one unit in the island
should be in zero droop mode. All other units should be placed in parallel mode. If the fast start unit has a
good regulation range and is designed to operate in zero droop mode, it may be the unit selected to regulate
frequency in the island. Moving the island frequency control function from one unit to another should
generally be done in an “open” transition manner that is to have only one frequency controlling unit on at a
time, not both in parallel.
2.09.03 Re-Start Coordination of Base Load Generation
An optimized start-up approach is necessary to establish the order in which cranking power and station
auxiliary should be delivered to the individual plants. The delivery of cranking power and station
auxiliaries should be given to units that can return to service as quickly as possible. Some units that tripped
hot may require a minimum off-line time before they can return to service and in other cases, some units
will cool off rapidly and delays of cranking power may extend start-ups. Some plants have no emergency
back-up and will need station power as soon as possible to prevent severe damage or a prolonged off line
period. When providing substations with power, re-establish the substation auxiliary supply as soon as
practical. This will allow for operation of equipment without concern for battery power availability.
When initiating the cranking phase of a plant start-up, place some stable load on the blackstart unit initially,
then add motor load at the plant starting with the largest essential motors (note large motor starts should be
pre-approved by the TOPs, working toward the smaller motors in a descending order. Allow time for the
unit/plant supplying the cranking power to stabilize between the motor starts. Communications will be
essential at this stage, thus operators in control at both the receiving and delivering sites should keep each
other updated and informed at all times during restart.
When steam generation is synchronized on line, add load to the steam unit within Unit Starting and
Loading Instruction while staying within the unit ramping capability. This will help to prevent a
steam/temperature mismatch and ensures that minimum generation is reached as quickly as possible
enabling the steam unit controls to be placed in their automatic mode. If additional load is needed the
Blackstart Resource or rapidly responding unit output can be reduced. Steam units will need to be at their
specified minimum load to be stable.
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Individual units should not be loaded to more than 75% of their capability when multiple units are in
service. Considerations should be taken when loading unit to consider the loss of the largest unit in the
island being a limiting consideration.
Generation with the lowest under frequency trip setting should be considered for frequency control when
practical.
Loads should be restored; first, to stabilize generation and second, for interconnecting stations and
subsystems and lastly for priority load customers. System stability and reliability are more important than
priority customer loads.
2.10 Nuclear Plants
Each TOP with nuclear facilities shall place a high priority for the establishment of off-site station auxiliary power
for those nuclear facilities in their restoration plans. Actual receipt and use of station power supplied from sources
external to the plant will depend on the individual requirements of the nuclear plant and the condition of their on-site
emergency sources of power. However, consideration should be given to the preparation of configurations that
would permit off-site sources to be readily available and transferable to the nuclear station buses should the plant
initiate the request.
2.11 Parallel Restoration
Due to the size of the MISO system, the number of TOPs involved, and the diversity of Blackstart Resources, a
parallel restoration method is recommended versus a sequential method. Numerous electrical islands will be
developed concurrently in order to expedite the restoration of important station service loads and ultimately the bulk
transmission network. Initiating restoration in multiple islands in the early phases of restoration will minimize the
possibility that an additional single event will cause the entire system shutdown several hours into the restoration
process.
As the restoration within the MISO BA progresses, many of these small islands will begin to merge and the islands
will begin to span multiple TOPs and LBAs and grow too large for any individual TOP or LBA to monitor directly.
The MISO BA will take an increasing role in the monitoring and coordination of these islands.
2.12 Blackstart Island Components
In order to rebuild a viable island, the following criteria should be met:
o
o
o
o
o
o
Each Blackstart island should have at least one unit with black-start capability. All Blackstart Resources in
each area should be identified in the individual TOP restoration plan.
Each Blackstart island should have at least one drum-type boiler with hot restart capability. An alternate is
a large combustion turbine (CT) or hydro unit (50 MW or larger). In the case of a CT, it should have
sufficient fuel available to run until the subsystem can be synchronized to another subsystem.
The black-start site should have sufficient capacity to provide cranking power to the targeted units listed in
the TOP restoration plan. Furthermore, it should have sufficient reactive power absorption and supply
capability to maintain stable voltage levels during re-energizing of important transmission paths to the
targeted generating units.
Each Blackstart Island should have sufficient generating capacity and voltage controls to maintain an
acceptable voltage profile during restoration (generally 90-110% of nominal).
All Blackstart Island tie points should have synchronizing capability. These should be listed in the
individual restoration plans of each TOP.
Each Blackstart Island should have sufficient information on frequency at a facility or substation linked to a
Control Center.
2.13 Load as a Start-Up Tool
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During the early stages of restoration, load is used to assist in stabilizing generation and in voltage control. As the
process continues, load is used for interconnecting islands. In the final stages of restoration, load should be restored
based on the priority of the load.
A possibility exists for loads to be energized and subsequently interrupted as the system restoration progresses. This
may occur several times to the same loads.
2.14 Voltage Control
Transmission system voltages should be maintained in the 90-110% range during restoration. Generators,
synchronous condensers, reactors, static var compensators and other devices should be used in conjunction with load
and line charging capacitance to control system voltages.
Generator excitation can be adjusted to the lower end of the acceptable range for voltage prior to energizing a
transmission line segment. This technique reduces line charging and decreases the likelihood of exceeding
transmission system equipment voltage ratings. Capacitors should be disconnected as part of the selective open
restoration process.
Prior to energizing an HV or EHV line, determine the total absorption reserves of the generation on-line considering
any minimum excitation limits. This should be at least 160% of the nominal line charging for the line to be
energized. This is a conservative value meant to address uncertainties such as higher voltage than anticipated and
thus higher VARs generated by the line.
In general, place transformer LTC to neutral and on manual control prior to energization. This will allow the
transformer to be sourced either from the low side or the high side without causing voltage violations.
Utilize transformers with Load Tap Changers (LTCs) to minimize charging currents. In some areas inductive load
(e.g., to increase reactive reserves on the system) can be increased by placing LTCs on parallel transformers on
different taps to cause circulating currents which consume reactive power. Note: Beware of directional overcurrent
relays that may inhibit low to high side flow and extreme caution should be used when using this technique as
circulating currents can rapidly exceed thermal ratings at some locations.
When energizing a transformer, its base rating should not be greater than 10 times the on-line generating capacity.
This will ensure that sufficient reactive support is available to supply the inrush magnetization current.
2.15 Frequency Control
Listed below are rules of thumb to ensure that frequency stability is maintained during load restoration:
Try to maintain frequency in the target range of 59.5-61.0 Hertz (Hz).
Adjust generator controls to raise frequency to maintain frequency at or slightly above 60.00 Hz prior to load
pickup.
A load block to be restored should not exceed 3-5% of the total synchronized generating capability. Estimate prime
mover response at 10% per Hz. For example, for a 100 MW of synchronized generating capability, an additional 10
MW of load would cause the frequency to drop about 1 Hz. Five percent is used to avoid dropping below 59.5 Hz,
above the first stage of under-frequency (in most areas 59.3 Hz, can be as high as 59.5 Hz) load shedding. Until
under-frequency load shedding feeders are placed in service, the generating unit(s) under-frequency trip point should
be the lowest frequency to avoid.
Prior to synchronizing between BA/LBAs use of Automatic Generation Control (AGC) in flat frequency mode
should be deferred as long as possible. During restoration, reliance on governor action of the isochronous unit is the
preferred method for maintaining the island frequency. The decision to utilize AGC will be at the discretion of each
BA/LBA. If operating in flat frequency mode, ensure that the frequency reference is within the island being
controlled by AGC.
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When two or more islands are interconnected, one island should control frequency, and all system operators should
adjust generation to coordinate tie line flows.
Listed below are key points to consider regarding the use of AGC during a power system restoration event:




Review the conditions that cause AGC to automatically disable and determine if temporary adjustments to
the disable feature (if any) need to be made. Examples include deviations to frequency and/or Area Control
Error (ACE) above specified limits
Place the generator being used to control frequency in zero droop or isochronous mode to control island
frequency to 60.00 Hz.
When two or more BAs/LBAs are interconnected, the BA/LBA not controlling frequency may initially use
the flat tie-line mode until such time when energy scheduling between areas can be reinstated.
Alternatively, the BA/LBA not controlling frequency may manually control generation in their area.
All tie lines must be entirely within an island for AGC in flat tie line mode to perform correctly. Tie lines
not entirely inside the island should be removed from the AGC calculation prior to converting the AGC
control system to flat tie line mode. To accomplish this objective, override all tie lines flows outside the
island with a value of 0 (zero.) .
Dynamic scheduling should NOT be enabled until such time that the Balancing Authority resumes normal
operations and conditions permit.
2.16 Responsive Reserves
Generators normally have protective relays to trip them off-line if the frequency is out of safe operating range typically 58.0 to 63 Hz. The purpose of maintaining Responsive Reserves is to provide a level of security against
frequency instability in the event of a generator contingency. This bandwidth may be reduced depending on
terminal volt per hertz relay setting or Special Protection Schemes (SPSs).
Responsive Reserve can be defined as the amount of reserve available to preserve system frequency. It consists of
two components:


Reserves available due to generator governor action (governor status should always be verified)
Restored system load equipped with under frequency relays.
The amount of response from generator governor action could be determined by individual unit tests. Early in a
restoration, the governor response can also be determined through direct observation. In the absence of such tests,
the following guidelines are recommended:
Type
Steam
Combustion Turbine
Hydro-Turbine
Under Frequency Load Shed
Percent of Rating
5
25
15
50
This means that a hydro unit at 60 Hz can respond to a load pick-up equal to 15% of remaining unit capacity without
the frequency dropping below 57.5 Hz. A conservative 50% rating for under-frequency load shedding is a used for
this type of protection due to its course nature. The Operating Reserve available from generator governor action is
preferred to that from load shed relaying because it is much smoother acting and does not risk repeated outages to
restored load. The governor reserve on a unit that is operating below its rated minimum load is considered zero
since the unit has not been stabilized.
The following is an example of a Responsive Reserve calculation.
Example: Responsive Reserve Calculation
Unit Type
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Unit
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Unit Total
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Steam
CT
Hydro
Totals
Available Available Load Load
Capacity Capacity (MW) (MW)
(MW)
(MW)
1
250
250 115 115
1
70
70
50
50
1
50
50
30
30
2
20
40
10
20
5
70
350
30 150
2
30
60
5
10
2
10
20
5
10
10
6
60
1
10
900
Factor
Per Unit
Total (MW)
(MW)
0.05
0.05
0.05
0.05
0.25
0.15
0.15
0.15
12.5
3.5
2.5
1
17.5
4.5
1.5
.9
280
129
Critical
Contingency:
U/F Load
Shed
100
12.5
3.5
2.5
2
87.5
9
3
9
12.5
0.5
Total:
Total – Critical
Contingency:
50.0
179
166.5
Assume all units are operated above minimum load. The contingency is the 115 MW steam unit, and the associated
12.5 MW of dynamic reserve. This 12.5 MW should be subtracted from the total reserve, as it could be the critical
contingency. In this example, the 250 MW steam unit would be limited to 166.5 MW. Maximum load pick-up
without under-frequency load shedding is 5% of the total synchronized capacity or 45 MW (900 x 0.05 = 45).
When two or more islands have combined with two or more interconnections between each, Operating Reserves
should be recalculated for the new system. At this point, the coordinating company may not have the real-time data
sufficient to compute Operating Reserves for the combined island. The Reliability Coordinator will determine the
maximum unit loading based on 7% of the total on-line generating capacity. Exceptions to this limit are:
o
o
If the minimum stable operating point is above the MISO specified maximum value, run at the minimum
stable operating point.
All units within the combined island should not exceed 75% of the maximum operating limit.
2.17 Developing Strong Islands before Synchronizing
Subsystems should be developed with the goal of making them firm as soon as possible. In some cases, this will not
be feasible until subsystems can be interconnected into a larger network. A system or subsystem is firm if it can
withstand the loss of any single generator, transmission line, or transformer without splitting or collapsing. In order
to have a firm system, the following criteria should be met:
o
o
o
o
o
Dual transmission lines to all (major) in-service generating stations, unless normally served by a single
radial line.
Sufficient transmission reserve capacity to withstand a single contingency.
Sufficient governor reserve.
Stable frequency (60 +/- 0.25% Hz)
Adequate voltage profiles (1.0 +/-.05 p.u.) volts
2.18 Synchronizing Adjacent Systems
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2.18.01 Considerations for Synchronizing
Prior to synchronizing, the following criteria for interconnecting adjacent Subsystem A to Subsystem B
should be considered to ensure a successful interconnection:

Island identification
Frequency control generator for each subsystem should be identified and TOPs, BA/LBAs and
GOPs for the frequency control generator for each of the subsystems should be identified and
involved in the interconnection process.

Stability assessment of the existing islands
A review of the frequency and voltage ranges, generation output and capacity, restored load
with underfrequency relays should be performed to determine if responsive reserves are
sufficient to cover the largest single contingency.

Evaluation of the interconnection facilities
The synchronization point should be identified and a review of the status of automatic
reclosing and protection systems performed. The frequency control strategies for the resulting
island should be agreed upon. This shall include designation of the entity responsible for
frequency control after interconnection is established.

Evaluation of the resulting subsystem
The resulting subsystem should be evaluated to determine if the sum of the responsive reserves
is sufficient to cover the largest contingency of the combined subsystem.
2.18.02 MISO Requirements for Synchronizing (Internal Synch Points)
TOPs in the MISO RC Footprint have restoration plans that list of synchronizing points for tying two or
more islands. MISO RC shall be notified when two or more islands are synchronized. All
synchronizing of islands across TOP boundaries, where one island is at least 1000 MW, must be
approved by the RC and the MISO “Interconnection Checklist” shall be used prior to synchronizing.
However, if the smaller island has less than 3% of the load of the larger island, this can be considered
load pickup for larger island and an “Interconnection Checklist” is not required unless tying across RC
boundaries. All interconnections crossing an RC boundary require approval from both RCs. On the
MISO side an “Interconnection Checklist” must be used.
MISO Interconnection Recommendations
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
Establish agreement on the tie-line flow range. Minimize tie-line flows where possible and
use internal generation to build and serve load.

When synchronizing, the TOPs, BA/LBAs and frequency control Generator Operators should
be in direct communication.

When SCADA control of the synchronizing point is unavailable, the controlling TOP should
be in direct communication with field personnel.

Both islands should be able to absorb the reactive power of the tie-line.

The two islands should confirm with each other and the TOP (and RC if crossing TOP
boundaries) the conditions of the interconnection to be established. Each subsystem is
expected to maintain its voltage and frequency as close as possible to these conditions
following the recommendations in section 2.14 and 2.15.

Disable all auto-reclosing relays in the open tie-line between connecting ends.
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
Closing of tie-breakers should occur as near 12:00 as possible and with a stationary or slowly
rotating synchroscope needle. Caution -- beware of SCADA scan time delays if monitoring
system remotely.

If interconnect separation is desired, the real and reactive power flow through the interconnect
should be "zeroed out" before opening the interconnect.

After the first tie is made between two subsystems, each subsystem should continue to
compute their governor reserves as if the tie did not exist. The primary benefit of the first tie
will be for frequency stability, reserving the tie for generation contingencies only. The flow
across the first tie should be maintained at or near zero. The range should correspond to the
maximum load pick-up by both subsystems. The second tie should be established as soon as
possible. When accomplished, the governor reserve can be computed on the basis of the
combined subsystem.

A second or back-up tie-line connection should be created soon after the first connection is
established.

After the interconnection is established, all entities should coordinate actions with the entity
responsible for frequency to ensure frequency remains stable. The actions to coordinate
include, but are not limited to, load restoration, generation schedule changes, and interchange
across the ties.
2.18.03 MISO Synchronizing with Neighboring Systems
When interconnecting with any entity outside the MISO RC footprint, all actions must
be coordinated and approved by both the MISO RC and the neighboring RC prior to
interconnection.
2.19 Operating Reserves
MISO will determine when system restoration has sufficiently progressed such that the normal operating reserve
requirements can be reestablished. Prior to such time, entities shall maintain Responsive Reserve as specified in
section 2.16.
2.20 Documentation of Events
Record keeping and sequence-of-events logs are important documents for personnel to maintain at all locations.
Personnel working in restoration teams should assign one person to be responsible for documenting activities and
decisions as they occur.
Section 3: Post-Event Reporting and Analysis
3.01 Final Reports (DOE, NERC, etc.)
The MISO Reliability Coordinator, Transmission Operators. Local Balancing Authorities and Balancing Authorities
will prepare final reports and submit them to DOE, NERC, Regional Entities and others as appropriate or required.
3.02 Sequence of Events Analysis
The MISO Emergency Preparedness and Power System Restoration Working Group (EP/PSRWG) may form an Ad
Hoc committee as necessary, to review the event details from the MISO Reliability Coordinator and others as
appropriate
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3.03 Lessons Learned
The EP/PSRWG will analyze the Restoration Event to determine if there are appropriate “Lessons Learned” to be
shared with MISO member entities.
3.04 Recommend Procedural Changes
Based on analysis of the event and the Sequence of Event logs, the EP/PSRWG may recommend that the MISO
procedures be revised to better address Restoration Events.
3.05 Recommend Training
The EP/PSRWG may coordinate with SOTWG to recommend training for MISO Reliability Coordinators or MISO
member entities.
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Compliance References
a
EOP-006-2:R3
EOP-001-2.1b:R5
c
EOP-006-2:R1
d
EOP-006-2:R8
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EOP-001-2.1b:R4 Attachment 1-EOP-001 Element 9
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