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2016 EPPSR Drill Report Final

Day 1 ended with an opportunity for a local debriefing session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout)
opportunity to tie small internal islands using their local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the Restoration Tracking Forms and were compiled into overview maps accessed via the MISO Extranet.
is effective practice at utilizing blackstart operating procedures Winter scenario helped operators consider challenges that would not normally be faced during a restoration Operators were engaged in training activities Two-day format provided adequate time for activities and review of procedures Issues/Suggestions: Restoration tracking form needs work-missing facilities,
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20160810 EPPSRWG Item 02 2015 EPPPSR Drill Report

Day 1 ended with a review of load shed directive procedures as well as an opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites.
local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
Local preparation of workstations required Initial assessment period unrealistic Inconsistent publishing of information (LMS vs. Extranet) Use of coordinated simulator would be preferred Additional Interconnection Checklist examples would help clarify the guidelines Lack of participation from some members Suggestion that all members attempt an interconnection at the end
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20160607 EPPSRWG Item 03 Drill Report Draft

Day 1 ended with a review of load shed directive procedures as well as an opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites.
local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
Local preparation of workstations required Initial assessment period unrealistic Inconsistent publishing of information (LMS vs. Extranet) Use of coordinated simulator would be preferred Additional Interconnection Checklist examples would help clarify the guidelines Lack of participation from some members Suggestion that all members attempt an interconnection at the end
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20170517 EPPSRWG Item XX 2016 EP PSR Drill Report Final Draft

Day 1 ended with an opportunity for a local debriefing session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout)
opportunity to tie small internal islands using their local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the Restoration Tracking Forms and were compiled into overview maps accessed via the MISO Extranet.
The drill is effective practice at utilizing blackstart operating procedures Winter scenario helped operators consider challenges that would not normally be faced during a restoration Operators were engaged in training activities Two-day format provided adequate time for activities and review of procedures Issues/Suggestions: Restoration tracking form needs work-missing facilities,
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20170215 EPPSRWG Item 02 2016 EP PSR Drill Report Draft

Day 1 ended with an opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout)
opportunity to tie small internal islands using their local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the Restoration Tracking Forms and were compiled into overview maps accessed via the MISO Extranet.
The drill is effective practice at utilizing blackstart operating procedures Winter scenario helped operators consider challenges that would not normally be faced during a restoration Operators were engaged in training activities Two-day format provided adequate time for activities and review of procedures Issues/Suggestions: Restoration tracking form needs work-missing facilities,
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20150318 EPPSRWG Item 07 PSR Drill Final Report Redline

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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20150318 EPPSRWG Item 07 PSR Drill Final Report Clean (1)

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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2014 EPPSR Drill Report

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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20150217 RSC Item 02ci 2014 EPPSR Drill Report Draft0_7_Clean

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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20130926 Item 02b SOTWG Trainer Development Discussion

(2) work steps for each task, (3) learning Objectives each task, (4) procedures required to perform each task, (5) tools needed for each task, and the (6) conditions in which the task occurs (normal, abnormal, emergency). The Task Details process provides the learning objectives which are required by PER-005 R1.
Since delivery skills alone generally require two days of course work, the entire program would probably require a week. Since most Trainers already have these skills or can readily obtain them, I suggest delivering this course only intermittently. Experienced trainers could use a "Core Instructor" Competency Checklist, based on this course,
reviews procedures, etc.). Evaluator provides criteria and expectations for success (per Evaluator Guide). Evaluator allows a practice JPM (observe, simulation, or discussion) with Operator Is Operator successful at practice JPM? Evaluator conducts the real JPM (observe, simulation, or discussion) with Operator Is Operator successful at real JPM?
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20150421 MTEP Training Presentation

Projects Complete List Suspended Projects Complete List Procedures and Requirements Procedures, Deadlines, and Milestones BPM Tariff IPTF Link FAQs Contour and Other Maps Contour map Active Queue Map GIA Completed Map Generation Interconnection Projects: Overview and Process MTEP Training 57 Generation Interconnection Page Generation Interconnection Projects: Overview and Process
Public Policy 21 Modeling and Stakeholder Coordination All Three Foundational Requirements are Interconnected Models MTEP Training Application Also referred to as Use Steady-State Powerflow, PSS/E, TARA, POM Reliability Dynamic Stability Dynamics (PSS/E, TSAT) Reliability Voltage Stability Voltage Stability (PSS/E, VSAT) Reliability Transfer Analysis Transfer Analysis (PSS/MUST,
Supports documented federal or state policy mandates Exceeds Total MVP Benefit B/C ratio 1.0 (Portfolio Benefits/Portfolio Revenue Requirements) Production cost savings Transmission loss savings Deferred capacity savings Long-term cost savings vs. interim project savings Matches who benefits with who pays over time Costs allocated to those that receive the benefits Multi-
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20151015 MTEP Training

Projects Complete List Suspended Projects Complete List Procedures and Requirements Procedures, Deadlines, and Milestones BPM Tariff IPTF Link FAQs Contour and Other Maps Contour map Active Queue Map GIA Completed Map Generation Interconnection Projects: Overview and Process MTEP Training 57 Generation Interconnection Page Generation Interconnection Projects: Overview and Process
Public Policy Modeling and Stakeholder Coordination 21 All Three Foundational Requirements are Interconnected Models MTEP Training Application Also referred to as Use Steady-State Powerflow, PSS/E, TARA, POM Reliability Dynamic Stability Dynamics (PSS/E, TSAT) Reliability Voltage Stability Voltage Stability (PSS/E, VSAT) Reliability Transfer Analysis Transfer Analysis (PSS/MUST,
Supports documented federal or state policy mandates Exceeds Total MVP Benefit B/C ratio 1.0 (Portfolio Benefits/Portfolio Revenue Requirements) Production cost savings Transmission loss savings Deferred capacity savings Long-term cost savings vs. interim project savings Matches who benefits with who pays over time Costs allocated to those that receive the benefits Multi-
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20170803 RSC Item 02 FERC-NERC Report Planning Restoration Absent SCADA or EMS

and generation plants to gain understanding of local and surrounding system conditions. 15 ICS is a management system designed to enable effective and efficient domestic incident management by integrating a combination of facilities, equipment, personnel, procedures, and communications operating within a common organizational structure.
Transmission Operator: The entity responsible for the reliability of its "local" transmission system, and that operates or directs the operations of the transmission facilities. The transmission operator is required to have a restoration plan, in accordance with EOP-005-2.
may not involve dispatching field personnel to every substation on their system, and may not require field personnel initially dispatched to certain substations to remain there for the entire restoration plan implementation. All participants stated that they have qualified field personnel who would be dispatched to restoration paths, e.
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2011-01-20 134 FERC 61045 Docket No. RD10-6-000, et al

possible base penalty range for a violation of a Reliability Standard Requirement. NERC stated that Requirements that were not changed in the transition to the Version 2 CIP Reliability Standards carry forward the Version 1 VRFs and VSLs for those Requirements. NERC further requested that the Commission approve the proposed VRFs and VSLs to be effective upon issuance of this order.
state, provincial, and local laws, and subject to existing collective bargaining unit agreements, as stated in R3, for personnel having authorized cyber or authorized unescorted physical access, but the program is not documented. The Responsible Entity has a personnel risk assessment program as stated in R3,
state, provincial, and local laws, and subject to existing collective bargaining unit agreements, as stated in R3, for personnel having authorized cyber or authorized unescorted physical access. OR The Responsible Entity did not conduct the personnel risk assessment pursuant to that program for personnel granted such access except in specified circumstances such as an emergency.
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2010-08-24 Docket No. RM09-25-000

given that training requirements exist and this appears to be a proposal for new training requirements), yet the Commission is addressing transmission requirements, but again, this is unclear. Thus, there is concern for the use of the term "local control center" without clear distinction what the scope of operations is involved,
and writing clear, unambiguous requirements. The Commission's intended use of the term "local control center" is unclear and this portion of the NOPR is further unclear as to which registered entity the proposed requirement should apply. Transmission Operators have an existing training requirement for operators.
without clear distinction what the scope of operations is involved, what authority a local control center operator would have, what knowledge skills and 11 abilities are required, and to which established functional entity such a requirement applies. Absent such distinctions, the term is likely to be applied in different ways by different compliance entities.
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2010-08-23 Docket No. RM09-25-000

given that training requirements exist and this appears to be a proposal for new training requirements), yet the Commission is addressing transmission requirements, but again, this is unclear. Thus, there is concern for the use of the term "local control center" without clear distinction what the scope of operations is involved,
and writing clear, unambiguous requirements. The Commission's intended use of the term "local control center" is unclear and this portion of the NOPR is further unclear as to which registered entity the proposed requirement should apply. Transmission Operators have an existing training requirement for operators.
without clear distinction what the scope of operations is involved, what authority a local control center operator would have, what knowledge skills and 11 abilities are required, and to which established functional entity such a requirement applies. Absent such distinctions, the term is likely to be applied in different ways by different compliance entities.
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20140513 RSC Item 02bi Phase Angle Monitoring and Control Whitepaper_Draft_V0 5

This approach places additional resource requirements on individual TOPs. Study results will be available at varying times making it harder to manage operating procedures affected by the studies. MISO Assessment: This option requires that a system assessment be conducted by MISO to determine the lines with a risk of experiencing a large phase angle difference.
informational purposes only as procedural actions or guidance on how to mitigate following a trip may not be available during the one-year period. Could potentially distract operators from other real-time functions. Individual TOP Assessment: This option requires the individual TOPs within MISO to conduct their own analysis to assess the lines at risk of large phase angle differences.
MISO should be required to coordinate actions with the affected TOPs. 3.2. Transmission Operators Transmission Operators (TOPs) in MISO's RC area are responsible for operating their individual systems and for managing reliability within their local footprint.
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20140916 PSC Item 06 MOD-032 Manual Version 3_Clean

and Resource Planners (RP) currently do not have any data submittal requirements. Additionally, the Planning Coordinator (PC) and Transmission Planners (TP) would be responsible for developing modeling data requirements and reporting procedures. The PC is also responsible for submitting models for its planning area to the ERO or designee.
state model outlined in Section 3. If changes are required to the power flow data for dynamics they should be reflected in the steady-state power flow cases and the appropriate changes entered in MOD. Dynamics Representation Generators At a minimum, all generators with a nameplate greater than 20 MVA or a facility with an aggregated nameplate greater than 75 MVA must be modeled
MISO MOD-032 Model Data Requirements & Reporting Procedures Version 3 September 9, 2014 This Page Left Intentionally Blank Contents 1 Introduction1 1.1Purpose1 1.2Process Overview1 1.3Responsible Entities2 2 Data Submission Requirement3 2.1Load Serving Entity3 2.2Generator Owner3 2.
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20141014 PSC Item 06 MOD-032 Manual

and Resource Planners (RP) currently do not have any data submittal requirements. Additionally, the Planning Coordinator (PC) and Transmission Planners (TP) are responsible for developing modeling data requirements and reporting procedures. The PC is also responsible for submitting models for its planning area to the ERO or designee.
state model outlined in Section 3. If changes are required to the power flow data for dynamics they should be reflected in the steady-state power flow cases and the appropriate changes entered in MOD. Dynamics Representation Generators At a minimum, all generators with a nameplate greater than 20 MVA or a facility with an aggregated nameplate greater than 75 MVA must be modeled
MISO MOD-032 Model Data Requirements & Reporting Procedures Version 4 October 10, 2014 This Page Left Intentionally Blank Contents 1 Introduction1 1.1Purpose1 1.2Process Overview1 1.3Responsible Entities2 2 Data Submission Requirement3 2.1Load Serving Entity3 2.2Generator Owner3 2.
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20150120 MUG Item 03 MOD-032 Manual Input 20141230

and Resource Planners (RP) currently do not have any data submittal requirements. Additionally, the Planning Coordinator (PC) and Transmission Planners (TP) are responsible for developing modeling data requirements and reporting procedures. The PC is also responsible for submitting models for its planning area to the ERO or designee.
1 Power Flow Representation The dynamics model will use a power flow model consistent with the steady-state model outlined in Section 3. If changes are required to the power flow data for dynamics they should be reflected in the steady-state power flow cases and the appropriate changes entered in MOD. MISO 15 4.2.2 Dynamics Representation 4.2.
i MISO MOD-032 Model Data Requirements & Reporting Procedures Version 45 October 10December 18, 2014 MISO ii This Page Left Intentionally Blank MISO i Contents 1 Introduction .............................................................................................
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20141014 PSC Item 06 MOD-032 Manual - Redline

and Resource Planners (RP) currently do not have any data submittal requirements. Additionally, the Planning Coordinator (PC) and Transmission Planners (TP) would beare responsible for developing modeling data requirements and reporting procedures. The PC is also responsible for submitting models for its planning area to the ERO or designee.
1 Power Flow Representation The dynamics model will use a power flow model consistent with the steady-state model outlined in Section 3. If changes are required to the power flow data for dynamics they should be reflected in the steady-state power flow cases and the appropriate changes entered in MOD. MISO 15 4.2.2 Dynamics Representation 4.2.
i MISO MOD-032 Model Data Requirements & Reporting Procedures Version 34 September 9October 10, 2014 MISO ii This Page Left Intentionally Blank MISO i Contents 1 Introduction .............................................................................................
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20140918 SOTWG Item 07 PER-005-2

of predefined operating procedures. In all cases, the Commission continued, the local transmission control center personnel must understand what they are required to do in the performance of their duties to perform them effectively on a timely basis. Thus, omitting such local transmission control center personnel from the PER-005-1 training requirements creates a reliability gap.
the FERC directive that the ERO develop formal training requirements for local transmission control center operator personnel. In Order No. 742 at P 62, the Commission clarified its understanding that local control center personnel "exercise control over a significant portion of the Bulk-Power System under the supervision of the personnel of the registered transmission operator.
been added to the PER standard and are subject to Requirements R2, R3 and R4 of PER-005-2. The reason for adding Transmission Owners is to address Order No. 693 and Order No. 742 FERC directives to include local transmission control center operator personnel. Rationale for R3: This Requirement was brought forward from the previous version with the addition of Transmission Owners.
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20150325 QF Training Outage Coordination

Operating Procedures https://www.misoenergy.org/MarketsOperations/ReliabilityOperatingProcedures/ RTO-OP-051 -AVR Procedure (NOP) RTO-OP-052 -Outage Operations Procedure (NOP) -Procedures Accessible via the MISO Extranet RTO-RA-OP-006 -Facility Ratings Change Procedure TP-OP-008 -Operating Guide Procedure -MISO Tariff (EMT) https:
MISO Outage Schedule Change AuthorityYes if required for system security and reliability reasonsYes if required for system security and reliability reasons. QF Outage Coordination Training 10 Generation Outage Information Reporting Requirements by Outage Type TypeGeneration Facility OutagesTransmission Facility OutagesPlanned Outage SchedulesMinimum Rolling 24 months (
Networked serving and local load Class III Non-networked serving and or local load Does not qualify as Class1 or Class II Class IV Non-MISO facility QF Outage Coordination Training All facilities 100 kV or under MISO functional control Facilities < 100 kV and not under MISO functional control if they are modeled in MISO's Network Model Class I 30-
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20140916 PSC Item 06 MOD-032 Presentation

Appendix MOD-032 Requirements R1: Each Planning Coordinator and each of its Transmission Planners shall jointly develop steady-state, dynamics, and short circuit modeling data requirements and reporting procedures for the Planning Coordinator's planning area R2: Each Balancing Authority, Generator Owner, Load Serving Entity,
state, dynamics, and short circuit modeling data to its Transmission Planner(s) and Planning Coordinator(s) according to the data requirements and reporting procedures developed by its Planning Coordinator and Transmission Planner in Requirement R1 R3: Upon receipt of written notification from its Planning Coordinator or Transmission Planner regarding technical concerns with the
As stated in the standard the purpose is: To establish consistent modeling data requirements and reporting procedures for developing of planning horizon cases necessary to support analysis of the reliability of the interconnected transmission system.
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2012-09-21 Docket Nos. RM12-6-000 and RM12-7-000

served a copy of this document upon all parties listed on the official service list compiled by the Secretary in the above-captioned proceeding, in accordance with the requirements of Rule 2010 of the Commission's Rules of Practice and Procedure (18 C.F.R. $ 385.2010). Dated this 21st day of September, 2012 in Carmel, Indiana. /s/Gregory A. Troxell Gregory A. Troxell
UNITED STATES OF AMERICA BEFORE THE FEDERAL ENERGY REGULATORY COMMISSION ) Revision to Electric Reliability Organization ) Docket Nos. RM12-6-000 Definition of Bulk Electric System ) RM12-7-000 And Rules of Procedure ) ____________________________________ ) REPLY OF MIDWEST ISO TO COMMENTS OF CONSUMERS ENERGY COMPANY Midwest Independent Transmission System Operator,
While it may be true that in most cases, these local distribution facilities will not be part of the BES, or have an impact on the BES, the case cited by Consumers illustrates the dangers of creating an automatic exemption for facilities identified as local distribution under the seven factor test.
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