attachment y study report - oatioasis.com · attachment y study report draft february 6, 2017 ......

Cleco Power LLC

Teche Unit #3: 335 MW, Gas

Retirement Date

04/01/2017

ATTACHMENT Y STUDY

REPORT DRAFT

February 6, 2017

Redacted (Public)

DRAFT 2

EXECUTIVE SUMMARY

An Attachment Y notification submitted by Cleco Power LLC was received by MISO on

September 20, 2016. The request was for retirement of the Teche Unit #3 located in Baldwin,

Louisiana effective April 1, 2017.

MISO performed a transmission system reliability assessment that was discussed and reviewed

with the impacted Transmission Owners (TOs): Cleco Power, Lafayette Utility services and

Entergy. The analysis determined that there are four (4) unresolved reliability violations on the

Transmission System that are not addressed by available mitigation measures.

After being reviewed for power system reliability impacts as provided for under Section 38.2.7

of MISO’s Open Access Transmission, Energy, and Operating Reserve Markets Tariff (“Tariff”),

MISO determined that the retirement of Teche Unit 3 will result in violations of applicable

reliability criteria. Therefore, Teche Unit 3 may be designated as a System Support Resource

(“SSR”) unit as defined in the Tariff until previously approved transmission project for

Terrebone-Bayou Vista 230 kV transmission line (MTEP ID: 7988; ISD: 06/01/2018) is in

service.

MISO will initiate the open stakeholder process to review Attachment Y reliability study results

and discuss potential alternatives to avoid the need for an SSR agreement. In the event the open

stakeholder process determines that previously identified mitigation plans are not feasible and

that an appropriate alternative is not identified, Teche Unit 3 will be designated as SSR units.

DRAFT 3

Contents I. Introduction ............................................................................................................................. 4

II. Study objectives ....................................................................................................................... 5

III. Models and Assumptions......................................................................................................... 6

3.1 Study Models ................................................................................................................ 6

3.2 Model Assumptions ...................................................................................................... 6

3.3 Table of Models ............................................................................................................ 7

IV. Steady State Study Criteria and Methodology ........................................................................ 8

4.1. TO Transmission Planning criteria ............................................................................... 8

4.2 MISO Transmission Planning BPM - SSR Criteria ...................................................... 9

4.3 Steady State Performance Analysis Parameters ........................................................... 9

V. Study Results ......................................................................................................................... 10

VI. SSR Alternative Analysis ...................................................................................................... 12

6.1 New Generation or Generation Re-dispatch ............................................................... 12

6.2 System Reconfiguration and Operation Guidelines .................................................... 12

6.3 Demand Response or Load Curtailment ..................................................................... 12

6.4 Transmission Projects ................................................................................................. 12

VII. SSR Agreement Cost allocation ............................................................................................ 14

VIII. Conclusion ...................................................................................................................... 15

IX. Appendices ............................................................................................................................ 16

DRAFT 4

I. INTRODUCTION

On September 20, 2016, Cleco Energy LLC submitted an Attachment Y notice to MISO to retire

the Teche Unit 3 effective April 1, 2017.

Teche Unit 3 is a natural gas fired generator with a capacity of 335 MW interconnected to the

Cleco 138kV transmission system. The plant is located in Baldwin, Louisiana.

Table 1: Units Requesting Retirement

Power Flow Area Unit

Description

Net

Reduction

(MW)

Start Date of

Retirement

Cleco Teche Unit 3 335 04/01/2017

Figure 1: General Location of Teche Unit 3

DRAFT 5

II. STUDY OBJECTIVES

The procedures under Section 38.2.7 of the MISO Tariff provide a mechanism for MISO to

assess reliability impact of retirement or suspension of a Generation Resource or Synchronous

Condenser Unit (SCU) and enter into an agreement with the Market Participants (MP) that own

or operate the Generation Resource or SCU that are required to maintain system reliability.

The principal objective of an Attachment Y reliability study is to determine if the unit(s) for

which a change in status is requested is necessary for system reliability based on the criteria set

forth in the MISO Transmission Planning Business Practice Manual. The study work includes

monitoring and identifying the steady state branch/voltage violations on transmission facilities

due to the unavailability of the Generation Resource or SCU. The relevant MISO Transmission

Owner and/or regional reliability criteria are used for monitoring such violations.

DRAFT 6

III. MODELS AND ASSUMPTIONS

3.1 Study Models

Studies were performed using the following power flow models:

2017 SP (Source: MTEP16 – 2018 Summer Peak model)

2017 SH (Source: MTEP16 – 2021 Summer Shoulder model)

2021 SP (Source: MTEP16 – 2021 Summer Peak model)

The Attachment Y study models were created in accordance with the MISO Transmission

Planning Business Practice Manual (BPM-020-r15) Section 6.2.2. This includes creating a set of

Security Constrained Economic Dispatch (SCED) models from each source model in which the

units being studied are taken out of service to represent the “After” retirement scenario. The

models are used to create “Before” retirement scenario by dispatching the unit under study at

maximum capability and scaling down generation in MISO footprint outside of Cleco area.

3.2 Model Assumptions

a. Generation

Previously approved Generation Retirements and new Generators with signed

Interconnection Agreement were modelled as per their respective effective dates.

b. Load Growth

MTEP16-2021SH case load values were scaled down to create 2017SH case.

Additionally, inputs from TOs were incorporated for load values

c. Transmission

All MTEP Appendix A approved projects were included in the study base case.

d. Monitor

Following areas were monitored for thermal and voltage violations.

EES (351) Area 69 kV – 999 kV and zones 385, 386, 387, 388, 389

CLECO (502) Area 69 kV – 999 kV and zones 500, 501, and 502

LAGN (332) Area 69 kV – 999 kV and zone 310

LAFA Area 503, zone 512

e. Contingencies

NERC Category P1, P2, P4, P5, P7 contingencies and selected P3, P6 contingencies that

were determined to be impacting the study area* in the CLECO, LAFA, and EES areas

were evaluated.

Category P3 and P6 contingencies were created from a subset of Category P1 events in

the nearby area and units above 50MW.

DRAFT 7

3.3 Table of Models

S.no Source Case Teche Unit 3 Contingency Categories

1 2017 SP ON P1, P2, P3, P4, P5, P6, P7

2 2017 SP OFF P1, P2, P3, P4, P5, P6, P7

3 2017 SH ON P1, P2, P3, P4, P5, P6, P7

4 2017 SH OFF P1, P2, P3, P4, P5, P6, P7

5 2021 SP ON P1, P2, P3, P4, P5, P6, P7

6 2021 SP OFF P1, P2, P3, P4, P5, P6, P7

DRAFT 8

IV. STEADY STATE STUDY CRITERIA AND METHODOLOGY

4.1. TO Transmission Planning criteria

Entergy Transmission Owners Planning Criteria

Entergy Transmission Planning Criteria applied for the thermal analysis:

For NERC Category P0 contingencies, all thermal loadings exceeding 100% of the

normal rating for Entergy System

For NERC Category P1 – P7 contingencies, all thermal loadings exceeding 100% of the

normal rating for Entergy System

Entergy Transmission Planning Criteria applied for the voltage analysis:

For NERC Category P0 contingencies

o KV>=300 - all substation voltages less than 97.5% or above 105%

o 100 < KV< 300 – all substation voltages less than 95% or above 105%

For NERC Category P1- P7 contingencies

o KV >300 – all substation voltages less than 95% or above 105%

o 100 < KV< 300 - all substation voltages less than 92% or above 105% for load or

gen bus

o 100 < KV< 300 - all substation voltages less than 90% or above 105% for non

load or non gen bus

o all substation voltages less than 90% or above 105% for non BES facilities

CLECO Transmission Owners Planning Criteria

CLECO Transmission Planning Criteria applied for the thermal analysis:


normal rating for CLECO System


emergency rating for CLECO System

CLECO Transmission Planning Criteria applied for the voltage analysis:

For NERC Category P0 contingencies, all substation voltages less than 95% or above

105%

For NERC Category P1 – P7 contingencies, all substation voltages less than 90% or

above 105%

LAFA Transmission Owners Planning Criteria

LAFA Transmission Planning Criteria applied for the thermal analysis:

DRAFT 9


normal rating for LAFA System


emergency rating for LAFA System

LAFA Transmission Planning Criteria applied for the voltage analysis:

For NERC Category P0 contingencies, all substation voltages less than 95% or above

105%

For NERC Category P1 – P7 contingencies, all substation voltages less than 90% or

above 105%

4.2 MISO Transmission Planning BPM - SSR Criteria

Per MISO BPM-020 r15 under Category P2 through P7 contingencies, for the valid thermal and

voltage violations as specified above, generation re-dispatch, system reconfiguration, and/or load

shedding are considered.

System Support Resource criteria for determining if an identified facility is impacted by the

generator change of status are:

Under Category P0 (system intact) and Category P1 (single event) contingencies, branch

thermal violations are only valid if the flow increase on the element in the “after”

retirement scenario is equal to or greater than:

a) Five percent (5%) of the “to-be-retired” unit(s) MW amount (i.e. 5% PTDF) for a

“base” violation compared with the “before” retirement scenario, or

b) Three percent (3%) of the “to-be-retired” unit(s) amount (i.e. 3% OTDF) for a

“contingency” violation compared with the “before” retirement scenario.

Under Category P0 (system intact) and Category P1 (single event) contingencies, high

and low voltage violations are only valid if the change in voltage is greater than 1% as

compared to the “before” retirement voltage calculation.

4.3 Steady State Performance Analysis Parameters

PSSE and TARA were used to perform steady state AC contingency analysis. Cases were solved

with automatic control of LTCs, phase shifters, DC taps, switched shunts enabled (regulating),

and area interchange disabled. Contingency analysis was performed on before and after cases.

The results were compared to find if there were any criteria violations due to the unit(s) change

of status

DRAFT 10

V. STUDY RESULTS

Thermal Results (Appendix A)

Appendix A shows contingent conditions causing branch criteria violations without Teche

Unit 3 where the unit impact on the affected facilities exceeded 3% OTDF or 5% PTDF.

2017 Summer Peak

Three (3) NERC Category P4 contingencies result in overloading of eight (8) Transmission

System facilities. Category P4 contingencies are not mitigated by SSR Unit since no

requirement exists for pre-commitment of generation for operational reliability. Hence, these

contingencies are not contributing to Teche Unit 3 designation as SSR.

Forty-two (42) NERC Category P6 contingencies result in thermal overloading of 16

Transmission System facilities. The thermal overloading caused by thirty-nine (39) of the

Category P6 events is addressed by available generation redispatch and load shedding

mitigation that is permitted by the applicable planning criteria (NERC and Transmission

Owner’s planning criteria).

Two NERC Category P6 contingencies result in severe thermal violations (>125%) for

MEAUX to ABBEVILLE 138 kV line which cannot be mitigated sufficiently with available

generation redispatch and presents a significant risk of potential cascading. These

contingencies require Teche Unit 3 to be available for dispatch and are contributing for

Teche 3 to be on SSR. Terrebonne to Bayou Vista 230 kV project (MISO MTEP ID: 7988 In

Service date 06/01/2018) reduces these violations below the limit where load shed is

permitted by the applicable planning criteria (NERC and Transmission Owner’s planning

criteria).

One NERC Category P6 contingencies result in severe thermal violations for MORILSPLT

to DUBOIN to BAYOU_WHSE to IVANHOE4 138kV circuits which cannot be adequately

alleviated with available generation redispatch. These contingency requires Teche Unit 3 to

be available for dispatch and is contributing for Teche 3 to be on SSR. Terrebonne to Bayou

Vista 230 kV project (MISO MTEP ID: 7988 In Service date 06/01/2018) reduces these

violations below the limit where load shed is permitted by the applicable planning criteria

(NERC and Transmission Owner’s planning criteria).

2017 Shoulder Peak

Three (3) NERC Category P4 contingencies result in overloading of seven (7) Transmission

System facilities. NERC Category P4 events are not mitigation by the SSR Unit since no

requirement exists for pre-commitment of the generation. Hence, these contingencies are not

contributing to Teche Unit 3 designation as SSR.

Eighteen (18) NERC Category P6 contingencies results in thermal overloading of twelve (12)

Transmission System facilities. The resulting overloads are mitigated by available generation

re-dispatch and load shedding that is permitted by the applicable planning criteria (NERC

and Transmission Owner’s planning criteria).

DRAFT 11

2021 Summer Peak

Two (2) NERC Category P4 contingencies result in overloading of one (1) thermal overload:

NERC Category P4 events are not mitigation by the SSR Unit since no requirement exists for

pre-commitment of the generation. Hence, these contingencies are not contributing to Teche

Unit 3 designation as SSR.

Twenty-two (24) NERC Category P6 contingencies result in overloading of eleven (11)

facility overloads which are mitigated by available generation re-dispatch option and load

shedding that is permitted by the applicable planning criteria (NERC and Transmission

Owner’s planning criteria).

Further details of the thermal results can be found in Appendix A Table 1.

Bus voltage results (Appendix A)

Appendix A shows contingent conditions causing voltage violations without Teche Unit 3

where the unit impact on the affected facilities exceeded 1% of pre-retirement voltage.

2017 Summer Peak

Two (2) NERC Category P6 contingencies cause voltage violations on area 138 kV

Transmission System buses. These overloads can be mitigated by allowable load shedding

that is permitted by the applicable planning criteria (NERC and Transmission Owner’s

planning criteria).

2017 Shoulder Peak

Two (2) NERC Category P6 contingencies result in voltage violations on 138 kV

Transmission System buses. These violations can be mitigated by allowable generation re-

dispatch of nearby generation resources.

2021 Summer Peak

Two (2) NERC Category P6 contingencies cause voltage violations on 138 kV Transmission

System buses. These violations can be mitigated by allowable load shedding actions. One (1)

NERC Category P6 contingency results in voltage violations on area 115kV Transmission

System buses. These violations can be mitigated by allowable generation re-dispatch of

nearby generation resources.

Further details of the voltage results can be found in Appendix A table 2.

DRAFT 12

VI. SSR ALTERNATIVE ANALYSIS

6.1 New Generation or Generation Re-dispatch

The re-dispatch of available generation resources was evaluated as an alternative solution to

mitigate the identified NERC Category P6 events. The proposed re-dispatch plan was shown to

be effective in reducing thermal overloads for many of the constraints with further mitigating

actions required to completely relieve the constraints. However, generation redispatch did not

fully address the excessive thermal overloading observed for the three (3) contingent events

which remain unresolved and require the need for the SSR Unit. Details about the re-dispatch

can be found in Appendix A table 1.

6.2 System Reconfiguration and Operation Guidelines

No existing operating guide will alleviate the unresolved thermal overloading caused by the three

NERC Category P6 events. System reconfiguration and switching options were investigated in

coordination with participating TOs and confirmed that the excessive overloads caused by the

three (3) contingent events cannot be successfully mitigated by any reconfiguration or switching

option.

Teche Unit 3 resource is a gas fired unit, which needs 18 to 22 hours of notification time. During

normal system operations, any of the first element outages from the set of identified

contingencies will require the unit to be committed to protect against the overloading that results

from the second event. Due to longer notification time, unit commitment needs to be done ahead

of time in anticipation of first element outage for higher load level. Hence, an operating guide is

being developed to commit Teche Unit 3 based on the load levels in the area around Teche plant

(Acadiana load pocket).

6.3 Demand Response or Load Curtailment

No contracted demand response alternative exists to provide load curtailment relief for the

reliability issues identified in the study. Load curtailment analysis was performed to estimate the

maximum amount of load shedding required to alleviate the overloads due to NERC Category P6

contingent events that requires Teche Unit 3 as an SSR Unit. This amount of contracted demand

response needed to provide comparable relief to the SSR Unit was estimated to be 134 MW and

would be required following the first event to avoid risk of cascading outages and resulting

voltage collapse. The results of the analysis are included in Appendix B.

6.4 Transmission Projects

Following planned projects will help removing all the constraints identified in the study.

Terrebone-Bayou Vista 230 kV transmission line (MTEP ID: 7988; ISD: 06/01/2018): This

project provides sufficient mitigation to bring the overloading to levels where further load

shedding is permissible by the applicable planning criteria and eliminate the need for Teche 3

SSR.

DRAFT 13

Hopkins (Cleco) Breaker Addition (MTEP ID: 10983; ISD: 05/01/2017): This project will

eliminate Category P4 contingencies resulting in constraints MORILSPLT to DUBOIN to

BAYOU_WHSE to IVANHOE4. This project need is not a requirement to avoid the Teche 3

SSR.

North ALP (MTEP ID: 12112; ISD: 12/1/2021), East ALP (MTEP ID: 12101; ISD: 06/01/2023):

These projects will help eliminate some of the constraints caused by Category P6 contingencies

in Appendix A table 1 for year 2021. This project need is not a requirement to avoid the Teche 3

SSR.

Segura (Cleco) Bus re-configuration (ISD: TBD): This project will eliminate Category P4

contingencies resulting in constraints MORIL to KIRK to CECILIA to BONIN 4 and MEAUX

to ABBEVILLE to LEBLANC. This project need is not a requirement to avoid the Teche 3

SSR. Cleco will submit this project in the next MTEP cycle.

DRAFT 14

VII. SSR AGREEMENT COST ALLOCATION

MISO conducted preliminary cost allocation analysis in accordance with the approved SSR Cost

Allocation Methodology. Costs for maintaining the SSR generation are allocated to LSE’s that

benefit from the operation of the SSR Unit. Analysis is performed to identify the loads that

contribute to constraints identified in the Attachment Y reliability study, and the associated

LSE’s are assigned a share of the cost responsibility based on their monthly peak energy

withdrawals. The method for cost allocation is filed with the associated SSR Agreement for

approval by FERC.

The methodology addresses the thermal and voltage related reliability issues that require the

continued operation of the SSR unit. Each of the unresolved constraints was evaluated to

determine the cost responsibility and allocation of the costs to the loads based on the calculation

of load distribution factors using linear power flow techniques. Voltage issues require additional

steps to analyzed the voltage constrained area and establish an appropriate proxy interface that

represents a constraint for the import of replacement power to the area of voltage decline.

The three (3) NERC Category P6 events identified in the reliability study were determined to

cause severe thermal overloads (>125) with a potential risk of cascading outages that result in

voltage collapse of the area. Cascading analysis indicated that following the contingent event,

the subsequent trip of the overloaded facility due to the excessive overloading causes further

cascading overloads and a decline of area voltages due to heavy import of power into the load

pocket. With the severity of the overloading and consequential risk of voltage instability

following the cascading trip, the cost allocation was based on the analysis of voltage constraints.

The affected area was determined by conducting voltage stability analysis and identifying

separation points in the transmission system to define the proxy interface. Load distribution

factors were calculated for the interface and mapped to the associated EPNodes defined in the

MISO Commercial Model.

The results of the preliminary SSR Cost allocation identifying the impacted EPNodes are

contained in Appendix C.

DRAFT 15

VIII. CONCLUSION

The results of Attachment Y reliability study for retirement of the Teche Unit 3 were assessed for

potential reliability impacts on the Transmission System and documented in this report.

Constraints were found in the models with the Teche Unit 3 offline. Some of the identified

overloads can be mitigated through existing generation re-dispatch and planned projects in

future. There are four (4) unresolved thermal violations on the Transmission System caused by

the retirement of Teche Unit 3.

After review of the power system reliability impacts as provided for under Section 38.2.7 of the

MISO’s Open Access Transmission, Energy & Operating Reserve Markets Tariff (“Tariff”),

MISO has determined that Teche Unit 3 will be required as an SSR unit until the completion of

the Terrebone-Bayou Vista project unless feasible alternative(s) are identified and implemented

prior to the retirement date.

MISO will initiate the open stakeholder process to review Attachment Y reliability study results

and previously identified solutions to avoid the need for an SSR agreement. If the open

stakeholder process determines that a feasible alternative solution can be implemented prior the

retirement date, Teche Unit 3 will not be designated as SSR unit.

DRAFT 16

IX. APPENDICES

Appendix A: Steady-State AC Contingency Results

Table 1 Thermal violations

Table 2 Voltage violations

Appendix B: SSR alternative analysis for Demand Response

Appendix C: SSR Cost allocation

Cleco Power LLC

Teche Unit #3: 335 MW, Gas

Attachment Y Study Report

Appendix A

AC Contingency Analysis Results

Table 1 Thermal Violations

Table 2 Voltage Violations

Appendix A, Table 1 ‐ Thermal Analysis Results

MISO Attachment Y Study Results ‐ Teche 3 ‐ Thermal Violations

Redacted

Contingency

Year Load Contingency Description ** From bus ** ** To bus ** CKT Rating MVA ContMW BaseFlow Loading% ContMW BaseFlow Loading%

MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments

2017SP [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 312.3 124 134.03 203.8 87 87.47 108.5 35.46

SSR Needed;Post re‐dispatch Overload >125 %. Terrebonne ‐

Bayou Vista 230 kV project is needed to reduce overloads below

125%




125%

2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335394 4MORILSPLT! 138 1 112 216 74.8 192.86 31.2 20.3 27.86 184.8 60.39



125%

2017SP [REDACTED] 335390 4BAYOU_WHSE!138 ‐ 500440 IVANHOE4 138 1 145 191 54.2 131.72 46.4 34.9 32 144.6 47.25



125%

2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 193.9 57.4 173.12 41.2 29.4 36.79 152.7 49.9



125%

2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 162.1 95.6 111.79 116.6 76.2 80.41 45.5 14.87

Not SSR issue; Redispatch Morgan City 4 & Acadia, and load shed

of [REDACTED] MW

2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 168.4 61 111.52 96.5 34.1 63.91 71.9 23.5

Not SSR issue; Redispatch Morgan City 4 & Acadia, and load shed

of [REDACTED] MW

2021SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 309 116.4 128.22 304.6 98.5 126.39 4.4 1.44 Not SSR Issue; Teche 3 does not help in reducing the overload.

2021SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 309 116.4 128.22 304.5 98.5 126.35 4.5 1.47 Not SSR Issue; Teche 3 does not help in reducing the overload.

2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 165.8 57.8 109.8 91 31.9 60.26 74.8 24.44

Not SSR Issue, Breaker contingencies are typically not used for

commitment and dispatch in Day‐Ahead and Real‐time. Cleco to

reconfigure line position at Segura.

2017SH [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 281.4 117.4 120.77 173.1 80.2 74.29 108.3 35.39




2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 156.9 37 103.91 75.1 25.2 49.74 81.8 26.73




2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 161.8 89.5 111.59 113.8 70.4 78.48 48 15.69




Limiting Element Teche 3 OFF Teche 3 ON Unit Impact

Page 1 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 161.6 89.5 111.45 114 70.4 78.62 47.6 15.56




2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 165.2 57.8 109.4 90.6 31.9 60 74.6 24.38




2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 156 37 103.31 74.4 25.2 49.27 81.6 26.67








2017SH [REDACTED] 335389 4DUBOIN! 138 ‐ 335394 4MORILSPLT! 138 1 112 205.7 69.8 183.66 22.4 15.1 20 183.3 59.9

Not SSR Issue;MISO Project 10983 ISD‐06/01/2017. N/A , Breaker

contingencies are typically not used for commitment and dispatch

in Day‐Ahead and Real‐time.

2017SH [REDACTED] 335390 4BAYOU_WHSE!138 ‐ 500440 IVANHOE4 138 1 145 177.9 47.8 122.69 41.5 31.8 28.62 136.4 44.58




2017SH [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 183.2 51.7 163.57 35.4 25.5 31.61 147.8 48.3




2017SH [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 188.9 47.9 102.11 136.9 33.3 74 52 16.99

Not SSR Issue;Turn Teche 4 to [REDACTED] MW, Morgan city to

[REDACTED] MW and reduce generation at Bonin 3 by the same.

2017SH [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 289.6 145.5 100.91 237.9 131.1 82.89 51.7 16.9



2017SH [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 249.7 106 103.61 197.2 85.1 81.83 52.5 17.16



2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 152.2 89.5 104.97 112.7 70.4 77.72 39.5 12.91




Not SSR Issue;Reduce Bonin3 by [REDACTED] MW and shed

[REDACTED] MW load at ABBEVILLE.


Not SSR Issue;Redispatch Teche4 to [REDACTED] MW Morgancity

to [REDACTED] MW and reduce Bonin 3 by the same.

Page 2 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments











2017SH [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 147.8 56 113.69 103.9 39.8 79.92 43.9 14.35

Not SSR Issue;Redispatch Tech 4 to [REDACTED] MW, Bonin 3 to

[REDACTED] MW, Morgan City to [REDACTED] MW; Shed load at

Cecelia, Parks and Loanfl2.


Not SSR Issue;Turn on Teche 4 to [REDACTED] MW; Morgan city to

[REDACTED] MW and reduce Bonin 3 by the same.










2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 174.5 57.8 115.56 98.2 31.9 65.03 76.3 24.93



Abbeville and Delcrambre.









2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 167 89.5 115.17 119.3 70.4 82.28 47.7 15.59




2017SH [REDACTED] 335386 4ABBEVILLE 138 ‐ 303150 4LEBLANC! 138 1 251 253.5 84.5 101 145.6 48.7 58.01 107.9 35.26




Page 3 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments



Not SSR Issue;Redispatch Tech 4 to [REDACTED] MW, Bonin 3 and

Labbe1 to [REDACTED] MW, Morgan City to [REDACTED] MW;

Shed load at Abbeville.









2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 165.8 57.8 109.8 91 31.9 60.26 74.8 24.44




2017SH [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 147.9 56 113.77 104 39.8 80 43.9 14.35



Cecelia, Parks and Longfl2.

2017SH [REDACTED] 335386 4ABBEVILLE 138 ‐ 303150 4LEBLANC! 138 1 251 253.4 84.5 100.96 145.5 48.7 57.97 107.9 35.26



Abbeville and Delcamgre.



















[REDACTED] MW, Labbe 1 to [REDACTED] MW and Morgan city to

[REDACTED] MW; Shed load of [REDACTED] MWat Abbeville.

2017SH [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 281.2 117.4 120.69 173 80.2 74.25 108.2 35.36







[REDACTED] MW; Shed load at Abbeville.

Page 4 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments





[REDACTED] MW; Shed load of [REDACTED] MW at Abbeville.

2017SH [REDACTED] 335390 4BAYOU_WHSE!138 ‐ 500440 IVANHOE4 138 1 145 171.8 47.8 118.48 46.1 31.8 31.79 125.7 41.08

Not SSR Issue;Redispatch Tech 4 to [REDACTED] MW, Hargis 1 and

2 to [REDACTED] MW, Bonin 2 and 3 to [REDACTED] MW, and

Morgan city to [REDACTED] MW; Shed load of [REDACTED] MW at

Duboin, Bayou Whesel, Ivanhoe, and Julien.

2017SH [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 176.8 51.7 157.86 39.3 25.5 35.09 137.5 44.93





2017SH [REDACTED] 335389 4DUBOIN! 138 ‐ 335394 4MORILSPLT! 138 1 112 199.1 69.8 177.77 21.7 15.1 19.38 177.4 57.97






Not SSR Issue;Redispatch Tech 4 to [REDACTED] MW, Acadia 1 to

[REDACTED] MW, and Morgan city to [REDACTED] MW; Shed load

of [REDACTED] MW at Delcambre, texas_erath, Jungle gard,

internatial, new iberia, billeaud, St Martin, longfl2.




















2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 156 37 103.31 74.4 25.2 49.27 81.6 26.67




2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 161.6 89.5 111.45 114 70.4 78.62 47.6 15.56




2017SH [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 165.2 57.8 109.4 90.6 31.9 60 74.6 24.38




2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 152.2 89.5 104.97 112.7 70.4 77.72 39.5 12.91 Not SSR Issue; Shed [REDACTED] MW at Leblanc 138kV.

Page 5 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2017SH [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 249.7 106 103.61 197.2 85.1 81.83 52.5 17.16 Not SSR Issue; Shed [REDACTED] MW at Leblanc 138kV.




2017SH [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 188.8 47.9 102.05 136.9 33.3 74 51.9 16.96




Not SSR Issue;Decrease Bonin 3 by [REDACTED] MW and shed load

at Abbeville by the same.




2017SH [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 146.6 89.5 101.1 110.1 70.4 75.93 36.5 11.93 Not SSR Issue; Shed [REDACTED] MW at Leblanc 138kV.

2017SH [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 262.1 106 108.76 197.6 85.1 81.99 64.5 21.08 Not SSR Issue; Shed [REDACTED] MW at Leblanc 138kV.

2017SH [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 202 47.9 109.19 136.6 33.3 73.84 65.4 21.37

Not SSR Issue;Turn on Morgan City Unit 4 to [REDACTED] MW and

reduce Coughlin unit 6 by same amount. Shed [REDACTED] MW

load at Leblanc 138kV, [REDACTED] MW at Morilsplit and

[REDACTED]MW at Delcambre 138kV to remove violation. .

2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 167.2 39.6 110.73 85.8 27.5 56.82 81.4 26.6








2017SP [REDACTED] 335386 4ABBEVILLE 138 ‐ 303150 4LEBLANC! 138 1 251 262.4 91.7 104.54 156.8 56.5 62.47 105.6 34.51












Page 6 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments






2017SP [REDACTED] 335386 4ABBEVILLE 138 ‐ 303150 4LEBLANC! 138 1 251 262.5 91.7 104.58 156 56.5 62.15 106.5 34.8




2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 178.3 61 118.08 102 34.1 67.55 76.3 24.93








2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 170.5 39.6 112.91 85 27.5 56.29 85.5 27.94




2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335394 4MORILSPLT! 138 1 112 223.7 74.8 199.73 34.2 20.3 30.54 189.5 61.93


commitment and dispatch in Day‐Ahead and Real‐time. MISO

Project 10983‐ ISD 06/01/2017 mitigates the issue.





2017SP [REDACTED] 335390 4BAYOU_WHSE!138 ‐ 500440 IVANHOE4 138 1 145 197.8 54.2 136.41 42.6 34.9 29.38 155.2 50.72




2017SP [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 201.2 48 108.76 149.1 33.1 80.59 52.1 17.03

Not SSR Issue;Redispatch Morgan City 4 & Acadia. Load shed of

[REDACTED] MW at Leroy, Delcambre, Duboin, Cecelia, Moril,

Hopkins 138 kV mitigates the violations.

2017SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 268.4 111.8 111.37 216 91.4 89.63 52.4 17.12




2017SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 312.7 155.1 108.95 260.4 139.7 90.73 52.3 17.09








2017SP [REDACTED] 335413 4YOUNGSVIL% 138 ‐ 500330 FLANDR 4 138 1 289 290.6 132.5 100.55 192.7 84.6 66.68 97.9 31.99

Not SSR Issue;Redispatch Morgan City 4 & Acadia. Shed

[REDACTED] MW of load at Judice, Leroy, Abbeville,Cecelia, Moril,

Hopkins 138 kV.

Page 7 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2017SP [REDACTED] 335388 4MORIL! 138 ‐ 500774 SEGURA4 138 1 458 486.4 231 106.2 323.6 181.4 70.66 162.8 53.2


[REDACTED] MW of load at Delcambre.

2017SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 275.7 111.8 114.4 269.1 91.4 111.66 6.6 2.16

Not SSR Issue; Shed [REDACTED] MW of load at Leroy, Abbeville &

Leblanc to mitigate the violations.


Not SSR Issue;Redispatch Bonin 2 and 3 to [REDACTED] MW,

Houma 3 to [REDACTED] MW and Morgan city to [REDACTED]

MW; Shed load of [REDACTED] MW at Scott.


Not SSR Issue;Redispatch Bonin 2 to [REDACTED] MW, Houma 3 to

[REDACTED] MW and Morgan city to [REDACTED] MW; Shed load

of [REDACTED] MWat Duboin and Bayou whse.




of [REDACTED] MWat Duboin and Bayou whse.

2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 150.1 57.4 134.02 66.1 29.4 59.02 84 27.45



at Duboin and Bayou whse.


Not SSR Issue;Redispatch Morgancity 4 & Acadia. Shed

[REDACTED] MW of load at Duboin, Bayou Warehouse 138 kV

substations.




substations.




substations.

2017SP [REDACTED] 335390 4BAYOU_WHSE!138 ‐ 500440 IVANHOE4 138 1 145 188 54.2 129.66 47.2 34.9 32.55 140.8 46.01


Hargis 1 to [REDACTED] MW, Houma 3 to [REDACTED] MW and

Morgan city to [REDACTED] MW; Shed load at Duboin, Ivanhoe 4,

Julien 4, Morbhan, Teche 1, and Bayou whse.






2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335394 4MORILSPLT! 138 1 112 212.4 74.8 189.64 28.8 20.3 25.71 183.6 60








Hopkins 138 kV.

Page 8 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2017SP [REDACTED] 335413 4YOUNGSVIL% 138 ‐ 500330 FLANDR 4 138 1 289 290.7 132.5 100.59 192.7 84.6 66.68 98 32.03



Hopkins 138 kV.




Hopkins 138 kV.




Hopkins 138 kV.




Hopkins 138 kV.

2017SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 158.8 60.3 122.15 114.9 44.4 88.38 43.9 14.35




Julien 4, Morbhan, Teche 1, New Iberia, 2billeaud, dixe, 2parks, St

martin and Bayou whse.








Not SSR Issue;Redispatch Bonin 3 to [REDACTED] MW, Labbe 1 to


at Abbeville.

2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 151.3 95.6 104.34 113.3 76.2 78.14 38 12.42

Not SSR Issue;Redispatch Bonin 3 to [REDACTED] MW, Labbe 1 to


at Abbeville.

2017SP [REDACTED] 335413 4YOUNGSVIL% 138 ‐ 500330 FLANDR 4 138 1 289 290.7 132.5 100.59 192.7 84.6 66.68 98 32.03

Not SSR Issue;Redispatch Acadia & Morgan City 4 generation.Shed

[REDACTED] MW of load at Judice, Leblanc, Leroy, Abbeville,

Cecelia 138 kV substations.

















Page 9 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments



Not SSR Issue;redispatch Bonin 3 to [REDACTED] MW and Morgan

city to [REDACTED] MW; Shed load at Abbeville and holiday.


Not SSR Issue;Redispatch Acadia 1 to [REDACTED] MW and

Morgan city to [REDACTED] MW; Shed load at Abbeville.

2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 186.6 61 123.58 109.6 34.1 72.58 77 25.16

Not SSR Issue;Redispatch Bonin 2 and 3 to [REDACTED] MW, Labbe

1 to [REDACTED] MW, and Morgan city to [REDACTED] MW; Shed

load at Abbeville, Delcambre, Moril split, Texas_erath, Youngsvil,

and Hopkins.





and Hopkins.





and Hopkins.





and Hopkins.



Houma 3 to [REDACTED] MW, and Morgan city to [REDACTED]

MW; Shed load at Abbeville, Delcambre, Moril split, Texas_erath,

and Hopkins.





and Hopkins.


Not SSR Issue;Redispatch Morgan City 4 & Acadia. Load Shed of

[REDACTED] MW at Leblanc, Abbeville, Duboin, Cecelia, Hopkins

138 kV. N/A ‐ Mitigation is acceptable





and Hopkins.





and Hopkins.

2017SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 158.9 60.3 122.23 115 44.4 88.46 43.9 14.35







Not SSR Issue; Redispatch Morgan City 4 & Acadia generation.

Shed [REDACTED] MW of load at Semere, Cecelia 138 kV.

Page 10 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments
























































2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 174 95.6 120 126.6 76.2 87.31 47.4 15.49














[REDACTED] MW of load at Leblanc, Abbeville, Duboin,Cecelia,

Moril 138 kV. N/A ‐ Mitigation is acceptable

2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 149.1 95.6 102.83 111.1 76.2 76.62 38 12.42 Not SSR Issue;Redispatch Morgan City 4 & Acadia.

Page 11 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments




[REDACTED] MW of load at Cecelia & Abbeville 138 kV.


Not SSR Issue;Redispatch Acadia 1 to [REDACTED] MW, Labbe 1 to

[REDACTED] MW, Morgan city4 to [REDACTED] MW, and Bonin 3

to [REDACTED] MW; Shed load at Abbeville.

2017SP [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 252.2 124 108.24 172.2 87 73.91 80 26.14

Not SSR Issue;Redispatch Acadia 1 to [REDACTED] MW, Labbe 1 to

[REDACTED] MW, Morgan city4 to [REDACTED] MW, and Bonin 3

to [REDACTED] MW; Shed load at Abbeville.



[REDACTED] MW of load at Abbeville & Cecelia.

2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 150.8 95.6 104 109.1 76.2 75.24 41.7 13.63


[REDACTED] MW of load at Abbeville & Cecelia.


Not SSR Issue;Rediaptch Labbe 1 to [REDACTED] MW, Morgan

city4 to [REDACTED] MW, and Bonin 3 to [REDACTED] MW; Shed

load at Abbeville.


Not SSR Issue;Rediaptch Labbe 1 to [REDACTED] MW, Morgan

city4 to [REDACTED] MW, and Bonin 3 to [REDACTED] MW; Shed

load at Abbeville.

2017SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 116.5 57.4 104.02 33.5 29.4 29.91 83 27.12

Not SSR Issue;Rediaptch Morgan city4 to [REDACTED] MW, and

Bonin 3 to [REDACTED] MW; Shed load at Duboin.


Not SSR Issue;Rediaptch Morgan city4 to [REDACTED] MW, and

Bonin 3 to [REDACTED] MW; Shed load at Duboin.


Not SSR Issue;Rediaptch Acadia 1 to [REDACTED] MW, Morgan city

4 to [REDACTED] MW; Shed load at Abbeville.



4 to [REDACTED] MW; Shed load at Abbeville.


Not SSR Issue; Redispatch Morgan City 4 & Acadia and load shed

of [REDACTED] MW at Holiday , [REDACTED] MW at Cecelia.


Not SSR Issue;Redispatch Morgan City 4 & Acadia and load shed of

[REDACTED] MW at Holiday , [REDACTED] MW at Cecelia.

Page 12 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments




4 to [REDACTED] MW; Shed load at Delcambre, Duboin, Moril

Split, Texas Erath, Jungle gard, Internatial, New Iberia, Billeaud, St

Martin, Hopkins4 and Longfl 2.
















2017SP [REDACTED] 500410 HOPKINS4 138 ‐ 500774 SEGURA4 138 1 382 446.6 184.8 116.91 290.1 85.9 75.94 156.5 51.14

Not SSR Issue;Rediaptch Acadia 1 to [REDACTED] MW, Labbe 1 to

[REDACTED] MW, Morgan city4 to [REDACTED] MW; Shed load at

Hopkins.





and Hopkins.





and Hopkins.

2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 178.3 61 118.08 102 34.1 67.55 76.3 24.93




and Hopkins.

2017SP [REDACTED] 335386 4ABBEVILLE 138 ‐ 303150 4LEBLANC! 138 1 251 262.5 91.7 104.58 156 56.5 62.15 106.5 34.8




and Hopkins.

2017SP [REDACTED] 335384 4KIRK! 138 ‐ 335388 4MORIL! 138 1 151 170.5 39.6 112.91 85 27.5 56.29 85.5 27.94




and Hopkins.


Not SSR Issue;Redispatch Acadia 1 to [REDACTED] MW, Morgan

city4 to [REDACTED] MW and Labee1 to [REDACTED] MW; Shed

load at Hopkins4.


Not SSR Issue;Redispatch Acadia 1 to [REDACTED] MW, Morgan

city4 to [REDACTED] MW and Labee1 to [REDACTED] MW; Shed

load at Hopkins4.


Not SSR Issue;Shed [REDACTED] MW load at Cecilia, Moril, Duboin,

Leroy, Abbeville 138 kV stations. Increase Morgan City 4 &

Decrease Acadia generation.

Page 13 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


















2017SP [REDACTED] 335388 4MORIL! 138 ‐ 500774 SEGURA4 138 1 458 486.3 231 106.18 323.6 181.4 70.66 162.7 53.17

Not SSR Issue;Shed [REDACTED] MW load at Hopkins 138 kV &

[REDACTED] MW load at Moril 138 kV.



[REDACTED] MW of load at Judice, Leroy, Abbeville 138 kV.



[REDACTED] MW at Judice.



[REDACTED] MW of load at Holiday & Abbeville.

2017SP [REDACTED] 335060 4CARLYSS! 138 ‐ 335070 6CARLYSS% 230 1 243 274.9 125.9 113.13 261.2 124.6 107.49 13.7 4.48

Not SSR Issue;Shed [REDACTED] MW of load at Citgo 138 kV,

Arizona 138 kV, Certainteed 138 kV, Citcon 138 kV.



[REDACTED] MW of load at Judice, Leblanc, Leroy, Abbeville 138

kV substations.




kV substations.

2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 157.4 95.6 108.55 121 76.2 83.45 36.4 11.9



kV substations.




kV substations.

Page 14 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2017SP [REDACTED] 335391 4CECELIA! 138 ‐ 502404 BONIN 4 138 1 145 155 95.6 106.9 108.5 76.2 74.83 46.5 15.2 Not SSR Issue;Redispatch Morgan City 4 & Acadia.



[REDACTED] MW of load at Cecelia 138 kV.

2021SP [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 263.7 119.9 113.18 183 88.7 78.54 80.7 26.37




2021SP [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 262.1 119.9 112.49 182.2 88.7 78.2 79.9 26.11




2021SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303132 4JUDICE! 138 1 241 268.9 116.4 111.58 227.4 98.5 94.36 41.5 13.56 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .

2021SP [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 190.9 41.5 103.19 149.8 28.6 80.97 41.1 13.43 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .

2021SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 314.4 162 109.55 273 147.4 95.12 41.4 13.53 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .

2021SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 325.6 162 113.45 298.3 147.4 103.94 27.3 8.92

Not SSR Issue;Shed [REDACTED] MW load at SEMERE and

[REDACTED] MW load at JUDICE.


Not SSR Issue;Turn on Houma to [REDACTED] MW. Turn on

Morgan City U4 to [REDACTED] MW. Reduce Panda by

[REDACTED] MW. Shed [REDACTED] MW load at DUBOIN.


2021SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 314.5 162 109.58 272.9 147.4 95.09 41.6 13.59 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .


2021SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 153.9 60.3 118.38 117.9 46.8 90.69 36 11.76



[REDACTED] MW. Load shed [REDACTED] MW load at 4SEMERE .

Page 15 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments


2021SP [REDACTED] 335380 4MEAUX! 138 ‐ 335386 4ABBEVILLE 138 1 233 238.3 119.9 102.27 174.3 88.7 74.81 64 20.92



[REDACTED] MW. Load shed [REDACTED] MW load at Hopkins.

2021SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 314.5 162 109.58 272.9 147.4 95.09 41.6 13.59 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .






[REDACTED] MW. Load shed [REDACTED] MW load at Hopkins

and [REDACTED] MW load at Youngsville .

2021SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 156.1 51.4 103.38 97.2 29.6 64.37 58.9 19.25










2021SP [REDACTED] 335379 4SCOTT_1! 138 ‐ 303152 4SEMERE 138 1 130 154 60.3 118.46 117.9 46.8 90.69 36.1 11.8





2021SP [REDACTED] 335384 4KIRK! 138 ‐ 335391 4CECELIA! 138 1 151 156.1 51.4 103.38 97.2 29.6 64.37 58.9 19.25















2021SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 112.7 39 100.63 55.4 36 49.46 57.3 18.73








Page 16 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments





[REDACTED] MW. Load shed 30 MW load at Hopkins.

2021SP [REDACTED] 500410 HOPKINS4 138 ‐ 500774 SEGURA4 138 1 382 415.8 149.9 108.85 285 73.5 74.61 130.8 42.75



[REDACTED] MW. Load shed 60 MW load at Hopkins .




[REDACTED] MW. Load shed [REDACTED] MW load at Hopkins .




[REDACTED] MW. Shed [REDACTED] MW load at Hopkins .


2021SP [REDACTED] 335378 4SCOTT_2! 138 ‐ 335379 4SCOTT_1! 138 Z1 287 314.3 162 109.51 273 147.4 95.12 41.3 13.5 Not SSR Issue; [REDACTED] MW Load Shed at Leblanc .





[REDACTED] MW. Shed [REDACTED] MW load at Judice.


Not SSR Issue; Turn on Morgan City U4 to [REDACTED] MW, Turn

on Houma to [REDACTED] MW. Reduce Panda by [REDACTED]

MW. Load Shed of [REDACTED] MW.


Not SSR Issue;Turn on Morgan City U4 to [REDACTED] MW, Turn


MW.

2021SP [REDACTED] 335389 4DUBOIN! 138 ‐ 335390 4BAYOU_WHSE!138 1 112 157.4 39 140.54 48.9 36 43.66 108.5 35.46



MW.




[REDACTED] MW. [REDACTED] MW Load Shed at Leblanc .

2021SP [REDACTED] 335383 4MEAUXSPLT! 138 ‐ 303132 4JUDICE! 138 1 185 196 41.5 105.95 145 28.6 78.38 51 16.67




Page 17 of 20



Redacted

Contingency


MW_Off‐

MW_On

PTDF

(>5 %)

OTDF (>3

%) Comments






2021SP [REDACTED] 336042 6RACLND! 230 ‐ 336154 6WATFRD% 230 1 535 635.8 390.4 118.84 569.3 349.5 106.41 66.5 21.73



MW. Load shed [REDACTED] MW at 6RACLND, [REDACTED] MW at

3RACLND, [REDACTED] MW AT 6LANDRY.

Page 18 of 20

Appendix A, Table 2 ‐ Voltage Analysis Results

MISO Attachment Y Study Results ‐ Teche 3 ‐ Voltage Violations

Redacted

Unit Impact

Year Load Contingency Description Bus Number Bus Name Area Low Limit High Limit Cont. Volt Base Volt Cont. Volt Base Volt

Voff‐Von (< ‐

1%) Comments

2021SP [REDACTED] 335380 4MEAUX! 138.00 351 0.92 1.05 0.8753 0.9826 0.8995 0.9914 ‐2.42 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 335385 4LEROY 138.00 351 0.92 1.05 0.8718 0.9795 0.8962 0.9883 ‐2.44 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 303150 4LEBLANC! 138.00 332 0.92 1.05 0.9028 0.9645 0.9316 0.9784 ‐2.88 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 335386 4ABBEVILLE 138.00 351 0.92 1.05 0.8894 0.975 0.9161 0.9866 ‐2.67 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 303132 4JUDICE! 138.00 332 0.92 1.05 0.8588 0.9801 0.8836 0.9856 ‐2.48 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 335395 4CONRAD 138.00 351 0.92 1.05 0.9029 0.9645 0.9317 0.9784 ‐2.88 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 335383 4MEAUXSPLT! 138.00 351 0.92 1.05 0.8753 0.9826 0.8995 0.9914 ‐2.42 Shed [REDACTED] Load at Judice

2021SP [REDACTED] 335387 4DELCAMBRE 138.00 351 0.92 1.05 0.9102 0.9669 0.9393 0.9812 ‐2.91 Shed [REDACTED] Load at Judice


2021SP [REDACTED] 335395 4CONRAD 138.00 351 0.92 1.05 0.9025 0.9645 0.9316 0.9784 ‐2.91 Shed [REDACTED] Load at Judice




2021SP [REDACTED] 335387 4DELCAMBRE 138.00 351 0.92 1.05 0.9097 0.9669 0.9392 0.9812 ‐2.95 Shed [REDACTED] Load at Judice


2021SP [REDACTED] 303150 4LEBLANC! 138.00 332 0.92 1.05 0.9023 0.9645 0.9315 0.9784 ‐2.92 Shed [REDACTED] Load at Judice


2017SH [REDACTED] 303132 4JUDICE! 138.00 332 0.92 1.05 0.9047 0.9888 0.9289 0.9961 ‐2.42

Redispatch Morgan city and Neson unit 6

by [REDACTED]

2017SH [REDACTED] 335383 4MEAUXSPLT! 138.00 351 0.92 1.05 0.9171 0.9933 0.9408 1.0038 ‐2.37


by [REDACTED]

2017SH [REDACTED] 335385 4LEROY 138.00 351 0.92 1.05 0.9144 0.9908 0.9383 1.0014 ‐2.39


by [REDACTED]

2017SH [REDACTED] 335380 4MEAUX! 138.00 351 0.92 1.05 0.9171 0.9933 0.9408 1.0038 ‐2.37


by [REDACTED]



by [REDACTED]

2017SH [REDACTED] 303132 4JUDICE! 138.00 332 0.92 1.05 0.9046 0.9888 0.9288 0.9961 ‐2.42


by [REDACTED]



by [REDACTED]

2017SH [REDACTED] 335383 4MEAUXSPLT! 138.00 351 0.92 1.05 0.9169 0.9933 0.9407 1.0038 ‐2.38


by [REDACTED]

2017SH [REDACTED] 335385 4LEROY 138.00 351 0.92 1.05 0.9143 0.9908 0.9382 1.0014 ‐2.39


by [REDACTED]


Teche 3 OFF Teche 3 ONLimiting ElementContingency

Page 19 of 20

Appendix A, Table 2 ‐ Voltage Analysis Results

MISO Attachment Y Study Results ‐ Teche 3 ‐ Voltage Violations

Redacted

Unit Impact

Year Load Contingency Description Bus Number Bus Name Area Low Limit High Limit Cont. Volt Base Volt Cont. Volt Base Volt

Voff‐Von (< ‐

1%) Comments

Teche 3 OFF Teche 3 ONLimiting ElementContingency




2017SP [REDACTED] 303132 4JUDICE! 138.00 332 0.92 1.05 0.8837 0.986 0.9237 0.9912 ‐4 Shed [REDACTED] Load at Judice







Page 20 of 20

Cleco Power LLC Teche Unit #3: 335 MW, Gas


Appendix B

SSR Alternative Analysis - Demand Response

Appendix B SSR Alternative analysis Demand Response needed

1

Load curtailment analysis was performed to estimate the maximum amount of load shedding required

to alleviate some of the overloads due to NERC Category P6 contingent events. Following three

contingencies were used to identify the need of contracted load curtailment to reduce the loading on

the constrained elements below allowable system adjustment limits

1. Contingency 1 – Curtailing load at ABBEVILLE reduces the overload on the branch MEAUX to

ABBEVILLE, where further system adjustments are applicable.

SENSITIVITY FACTORS OF BRANCH FLOW (MW) ON 335380 4MEAUX! 138.00 TO 335386

4ABBEVILLE 138.00

<----- - LOAD BUS -------> LOAD(MW) MW-SENS Flow Impact

335386 4ABBEVILLE 138.00 34.01 -0.6201 -21.089601

335387 4DELCAMBRE 138.00 23.5 -0.3606 -8.4741

335388 4MORIL! 138.00 0 -0.141 0

335389 4DUBOIN! 138.00 26.04 -0.1398 -3.640392

335390 4BAYOU_WHSE!138.00 7.16 -0.1345 -0.96302

335394 4MORILSPLT! 138.00 14.04 -0.141 -1.97964

335395 4CONRAD 138.00 0 -0.4118 0

500030 BELPLA 4 138.00 14.25 -0.134 -1.9095

500050 BSALES 4 138.00 0 -0.114 0

500060 BVISTA 4 138.00 42.7 -0.1016 -4.33832

500290 ELPTAP 4 138.00 15 -0.1067 -1.6005

500410 HOPKINS4 138.00 94.37 -0.1353 -12.768261

500440 IVANHOE4 138.00 6.37 -0.1318 -0.839566

500450 JULIEN 4 138.00 0.1 -0.1299 -0.01299

500460 JULTAP 4 138.00 0 -0.1299 0

500580 MORBHAN4 138.00 53.85 -0.134 -7.2159

500630 N.BEND 4 138.00 14.91 -0.1142 -1.702722

500660 PATOUT 4 138.00 5.44 -0.1315 -0.71536

500774 SEGURA4 138.00 0 -0.1322 0

500820 TECHE 4 138.00 0 -0.1266 0

500890 WAXLAKE4 138.00 17.86 -0.1085 -1.93781

335275 2LAKE_ARTHUR69.000 6.76 0.1462 0.988312

335276 2KLONDIKE 69.000 2.94 0.1453 0.427182

335330 2LINE-270_TP69.000 0 0.1432 0

335331 2GUEYDAN 69.000 5.38 0.1434 0.771492

335332 2MORSE 69.000 1.99 0.1436 0.285764

335333 2CAMPBELL 69.000 5.7 0.1429 0.81453

335334 2LINE-610_TP69.000 0 0.1368 0

335335 2DUHON 69.000 22.7 0.139 3.1553

335336 2HUNTER 69.000 1.57 0.1371 0.215247

335337 2MEAUX! 69.000 0 0.1307 0

335342 2AVERICO_TP 69.000 0 0.1013 0

335343 2AVERICO 69.000 7.99 0.1018 0.813382

335380 4MEAUX! 138.00 1.8 0.1782 0.32076

335383 4MEAUXSPLT! 138.00 0 0.1782 0

335385 4LEROY 138.00 20.7 0.1789 3.70323

2. Contingency 2 - Curtailing loads at IVANHOE, JULIEN MORBHAN, BELPLA, PATOUT, and TECHE 1

reduces overloads on branches DUBOIN to BAYOU_WHSE, DUBOIN to MORILSPLT, and

BAYOU_WHSE to IVANHOE, where further system adjustments are applicable.

SENSITIVITY FACTORS OF BRANCH FLOW (MW) ON 335389 4DUBOIN 138.00 TO 335394

4MORILSPLT! 138.00 1

<----- - LOAD BUS -- -----> LOAD(MW)MW-SENS Flow Impact

500440 IVANHOE4 138 6.37 -0.6984 -4.448808

Appendix B SSR Alternative analysis Demand Response needed

2

500450 JULIEN 4 138 0.1 -0.6696 -0.06696

500580 MORBHAN4 138 53.85 -0.6227 -33.532395

500030 BELPLA 4 138 14.25 -0.6227 -8.873475

500660 PATOUT 4 138 5.44 -0.6205 -3.37552

500830 TECHE 1 34.5 51.78 -0.6199 -32.098422

500630 N.BEND 4 138 14.91 -0.56 -8.3496

500890 WAXLAKE4 138 17.86 -0.5324 -9.508664

500050 BSALES 4 138 0 -0.5591 0

500290 ELPTAP 4 138 15 -0.5237 -7.8555

500060 BVISTA 4 138 42.7 -0.4994 -21.32438

500090 BERWIC 4 138 0.1 -0.4761 -0.04761

500100 BERWKTP4 138 0 -0.4761 0

500740 RAMOS 4 138 23.08 -0.4343 -10.023644

336030 4GIBSON 138 0 -0.3897 0

336031 3GIBSON 115 13.32 -0.3481 -4.636692

336032 3HUMPHY! 115 6.23 -0.2298 -1.431654

336033 3TEREBN! 115 33.68 -0.1136 -3.826048

335389 4DUBOIN! 138 0 0.1315 0

335390 4BAYOU_WHSE! 138 7.16 0.2601 1.862316

3. Contingency 3– Curtailing load at ABBEVILLE reduces the overload on the branch MEAUX to

ABBEVILLE, where further system adjustments are applicable.

SENSITIVITY FACTORS OF BRANCH FLOW (MW) ON 335380 4MEAUX! 138.00 TO 335386

4ABBEVILLE 138.00 1

<----- - LOAD BUS -------> LOAD(MW) MW-SENS Flow Impact

335386 4ABBEVILLE 138.00 34.01 -0.6201 -21.089601

335387 4DELCAMBRE 138.00 23.5 -0.3606 -8.4741

335388 4MORIL! 138.00 0 -0.141 0

335389 4DUBOIN! 138.00 26.04 -0.1398 -3.640392

335390 4BAYOU_WHSE!138.00 7.16 -0.1345 -0.96302

335394 4MORILSPLT! 138.00 14.04 -0.141 -1.97964

335395 4CONRAD 138.00 0 -0.4118 0

500030 BELPLA 4 138.00 14.25 -0.134 -1.9095

500050 BSALES 4 138.00 0 -0.114 0

500060 BVISTA 4 138.00 42.7 -0.1016 -4.33832

500290 ELPTAP 4 138.00 15 -0.1067 -1.6005

500410 HOPKINS4 138.00 94.37 -0.1353 -12.768261

500440 IVANHOE4 138.00 6.37 -0.1318 -0.839566

500450 JULIEN 4 138.00 0.1 -0.1299 -0.01299

500460 JULTAP 4 138.00 0 -0.1299 0

500580 MORBHAN4 138.00 53.85 -0.134 -7.2159

500630 N.BEND 4 138.00 14.91 -0.1142 -1.702722

500660 PATOUT 4 138.00 5.44 -0.1315 -0.71536

500774 SEGURA4 138.00 0 -0.1322 0

500820 TECHE 4 138.00 0 -0.1266 0

500890 WAXLAKE4 138.00 17.86 -0.1085 -1.93781

335275 2LAKE_ARTHUR69.000 6.76 0.1462 0.988312

335276 2KLONDIKE 69.000 2.94 0.1453 0.427182

335330 2LINE-270_TP69.000 0 0.1432 0

335331 2GUEYDAN 69.000 5.38 0.1434 0.771492

335332 2MORSE 69.000 1.99 0.1436 0.285764

335333 2CAMPBELL 69.000 5.7 0.1429 0.81453

335334 2LINE-610_TP69.000 0 0.1368 0

335335 2DUHON 69.000 22.7 0.139 3.1553

335336 2HUNTER 69.000 1.57 0.1371 0.215247

335337 2MEAUX! 69.000 0 0.1307 0

335342 2AVERICO_TP 69.000 0 0.1013 0

335343 2AVERICO 69.000 7.99 0.1018 0.813382

335380 4MEAUX! 138.00 1.8 0.1782 0.32076

335383 4MEAUXSPLT! 138.00 0 0.1782 0

335385 4LEROY 138.00 20.7 0.1789 3.70323

Cleco Power LLC Teche Unit #3: 335 MW, Gas


Appendix C

SSR Cost Allocation

SSR Cost Allocation EPNode Distribution FactorsTeche Unit 3 ‐ Preliminary

The information contained in this document has been redacted to remove Critical Energy Infrastructure (CEII)

Information for public posting.

Full details of the analysis are available on the MISO secure FTP site which is subject to appropriate NDA

restrictions.

Column descriptions:

EP Node ‐ Registered load EP Node name in the MISO Commercial model for the period analyzed

Season ‐ Seasonal conditions (eg. Summer, Shoulder) for which the constraint occurs

Constraint ‐ Thermal or voltage proxy constraint which was identified to require the need for the SSR unit

Ctg Type ‐ The contingency category defined by NERC Reliability Standards

Ctg ‐ The contingency event causing the thermal or voltage constraint ‐ REDACTED for public posting

Dist Factor ‐ The load distribution factor calculated for the load EP Node

Teche 3 (Preliminary Cost Allocation EP Nodes)

EPnode Season Constraint Ctgtype Ctg Dist Factor

L CLEC BERWIC T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC BUVIS LT2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC BUVIS T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC DUBON7 T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC ELPTAP4 T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC ERATH_CL ERATH_CL 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L CLEC ERATH_CL ERATH_CL 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L CLEC GEYD_C GEYD_C 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L CLEC GEYD_C GEYD_C 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L CLEC HOPKIN HOPKN_XFMR1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L CLEC IVANHO T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L CLEC JULIEN4 T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC LNGFLW T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L CLEC MORBHN 4A 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC MORBHN 4B 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC MORBHN BELPLA_4 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC NORBND C_CARBON 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC NORBND S_BEND 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC PATOUT T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L CLEC RAMOS XFLD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC TECHE1 BALDWIN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994





L CLEC TECHE1 FRANKLIN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC TECHE1 GEN_AUX1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L CLEC TECHE1 JEANETTE 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC TECHE1 N_BEND 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L CLEC WAXLKE T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L EES ABBEVL T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES ANSELA T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES ANSELA T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES AVERIC T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES AVERIC T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES BILEAU T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES BWH T2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L EES CECELA T2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES CLN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES CLN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES DELCAM T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES DUB T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L EES DXB T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES DXB T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES FPT T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES FPT T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES GIBSN4 S4175_LOAD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994






L EES HLA T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES HLA T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994



L EES HUMPY4 T2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L EES HUN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES HUN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES INN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES INN T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES JUNGRD T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES JUNGRD T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES LFB T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES LKA T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES MAU T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994




L EES MOR T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES MOR T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES MORIL 1B 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES MORIL 1B 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES NEWIBE T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES NEWIBE T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES PARKS T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES PARKS T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES ST_MAR T2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES ST_MAR T2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES TXE T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES TXE T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L EES YOUNGV T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L EES YOUNGV T1 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN BLOU BLOU 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L LAGN DUHN DUHN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN DUHN DUHN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN GEKO GEKO 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN GEKO GEKO 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN GEYD GEYD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN GEYD GEYD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN GRWD GRWD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L LAGN KLON KLON 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN KLON KLON 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN KPL2 KPL2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN KPL2 KPL2 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN LBLK LBLK 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN LBLK LBLK 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN LEBL LEBL 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN LEBL LEBL 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN MELC MELC 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN MELC MELC 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN RAMO RAMO 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L LAGN SEMR SEMR 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994

L LAGN SEMR SEMR 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LAGN STJN STJN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



L LAGN STJN STJN 2017 Summer Peak 9997‐TECHESSR_VoltageStability_2 P6 [REDACTED] 0.9994

L LEPA MRGNCTY4 MRGNCTY_LD 2017 Summer Peak 9997‐TECHESSR_VoltageStability_1 P6 [REDACTED] 0.9994



attachment y study report - oatioasis.com · attachment y study report draft february 6, 2017 ......

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