Annual Issues Review: MISO Issues Near the PJM Seam MISO-PJM IPSAC 3/30/18

Transcription

1 Annual Issues Review: MISO Issues Near the PJM Seam MISO-PJM IPSAC 3/30/18

2 MTEP17 Report MTEP17 Report and Appendices finalized December 2017 Appendix AB Appendix A: Board approved projects Appendix B: Projects with documented need and effectiveness Bottom-Up projects included in last Annual Issues Review No Top-Down projects near the MISO-PJM seam

3 1 st Round of SPMs Transmission Owner/Market Participant Bottom-Up projects presented at Subregional Planning Meetings (SPMs) December 6, 2017 East SPM 1 December 8, 2017 West SPM 1 December 11, 2017 South SPM 1 December 12, 2017 Central SPM 1 MTEP18 Active Project List

4 MTEP18 Reliability and Economic Planning Processes are closely coordinated on issues and solutions Jun Jul Aug Sept Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec Information Exchange TO models and Planning Criteria Stakeholder Comments Jun Sept TO/MP proposed project submittals for MTEP18 Sept 15th Exchange of TO planning information between TO and Stakeholders Sept - Dec MISO Independent TPL assessment to identify issues Review TO projects and identify gaps Jan - May MISO reviews alternatives and completes gap analysis Jun - July Issues and Solution Development Coordination Project Recommendation for BOD Approval Sept - Dec 5 MTEP18 MCPS Project Candidates Carried Forward Economic Model Building Sept - Dec Flowgate Identification Solution Idea Solicitation Dec - Feb Project Candidate Identification Feb - Jun Robustness Testing Jun-Aug

5 Economic Issues

6 MTEP18 North/Central MCPS MTEP18 includes a North/Central Market Congestion Planning Study (N/C MCPS) focused on identification of Market Efficiency Projects (MEPs) Following 9 slides have MTEP18 N/C MCPS preliminary top binding elements Shared at February 2, 2018 MCPS TSTF Flowgates showing congestion but excluded from study also shown, some linked to PJM RRF wind Nearby PJM economic issues could drive the need for an Interregional MEP

7 MTEP18 MCPS North/Central Top Congested Flowgates ID Monitored Element Area MISO, using Velocity Suite 2018 N-A Big Stone Browns Valley 230kV OTP N-B Hankinson - Wahpeton 230kV OTP N-C Wabaco - Rochester 161kV DPC N-D* Adams Transformer 161/69kV ALTW N-E Wapello County - Appanoose 161kV ALTW N-F Elkhart Lake - Forest Junction 138kV WEC Bluemound - Butler 138kV WEC N-G Granville - Tosa 138kV WEC N-H Raun - Tekamah 161kV MEC-OPPD N-I Council Bluffs S3456(Sarpy County) 345kV MEC-OPPD C-A Bosserman - Trail Creek 138kV AEP-NIPS C-B Goodland - Reynolds 138kV NIPS Matanzas - Wilson 161kV LG&E-BREC C-C Wilson Transformer [2] 345/161kV BREC BRTap - Paradise 161kV BREC-TVA C-D LNG Maple 138kV NIPS *ITCM has plans to improve the Protection and Controls for Adams transformer which would reduce congestion significantly.

8 Northern Indiana Focus Area

9 Northern IN Area Top Congested Flowgates ID Monitored Element Area C-A Bosserman - Trail Creek 138kV AEP - NIPS C-B Goodland - Reynolds 138kV NIPS C-D LNG - Maple 138kV NIPS MISO, using using Velocity Velocity Suite Suite Flowgate C-A Congestion driven by nearby retirements (e.g. Bailly, R M Schahfer, Dresden), which increase east to west flows in Northern Indiana. Flowgate C-B Nearby existing wind farms (Sheldon South, Goodland I, Hoosier Wind, Goodland Wind) driving congestion. Very few generators provide counter-flow. Flowgate C-D Congestion driven by increasing load and new St Joseph Energy Center CC.

10 Northern IN Top Congested Flowgates: MISO Market Congestion (Jan 2015 Jul 2017) ID Monitored Element Area Day-Ahead Binding Hours Day-Ahead Total Shadow Price (k$/mwh) Real-Time Binding Hours Real-Time Total Shadow Price (k$/mwh) C-A Bosserman - Trail Creek 138kV AEP - NIPS C-B Goodland - Reynolds 138kV NIPS 1, , C-D LNG - Maple 138kV NIPS Data source: Day-ahead and real-time binding constraint reports from MISO Market

11 Northern IN Top Congested Flowgates: PROMOD Output ID Monitored Element Contingency Element(s) Area 2027 Total Annual Shadow Price (k$/mwh) AFC CFC DET LFC C-A Bosserman - Trail Creek 138kV Bosserman - Michigan City 138kV AEP - NIPS C-B Goodland - Reynolds 138kV* Goodland - Remington 69kV; Sheldons - Watseka 138kV NIPS C-D LNG - Maple 138kV* Babcock - Stillwell 345kV; Olive 345/138kV Transformer NIPS *Binding for multiple contingencies

12 Top Congested Flowgates Excluded from MTEP18 MCPS

13 Flowgates that meet the selection threshold but have been excluded Monitored Element Contingency Element(s) Area 2027 Total Annual Shadow Price (k$/mwh) AFC CFC DET LFC Reason for Potential Exclusion in MTEP18 Analysis McHenry - Voltair 115kV* Balta - Rugby 230kV; McHenry - Balta 230kV; McHenry - Coal Tap 230kV GRE-BEPC Driven by future wind sited at McHenry Devils - Sweet Water 115kV Langdon Hensel 115kV OTP-MPC Langdon Wind SPS can fix the issue Devils - Devils Junction 115kV* Petenwell - ACEC Badger West 138kV Ramsey Prairie 230kV; Balta - Rugby 230kV; Ramsey - RamseyCB 230kV OTP Driven by future wind sited at Ramsey Eau Claire Arpin 345kV ALTE-WPS Eden - Wyoming Valley 138kV Eden Cardinal 345kV ALTE Pere Marquette - Lake County 138kV Caniff - Cortland 120kV* Bismark to East Bismark 115kV* *Binding for multiple contingencies SPS (Monroe County Council Creek) will trip the line under specific contingency Driven by future wind sited at Eden and Hickery Creek Amber - Pere Marquette 138kV CONS Project in process to rebuild the line Bristol - Frisbie 120kV; Caniff - Bristol 120kV Collins - Heskett 115kV; Rough Rider - Mandan Jct 230kV DECO Purely driven by one future (AFC) WAUE-MDU Driven by Heskett retirement. Identified replacement of the retirement would fix the issue

14 Flowgates that meet the selection threshold but have been excluded (Cont d-1) Monitored Element Contingency Element(s) Area 2027 Total Annual Shadow Price (k$/mwh) AFC CFC DET LFC Reason for Potential Exclusion in MTEP18 Analysis 4LTV - Princeton 138kV Kewanee 13 - Kewanee N 138kV AMIL Fargo Transformer 345/138kV Tazewell - Maple Ridge 345kV AMIL Driven by one external RRF wind unit sited at northern IL Driven by assumed retirements located at central Illinois Goose Creek - Rising 345kV Dumont - Wilton 765kV AMIL Driven by nearby external RRF Wind units Cyrene - Pike 161kV* Henderson Transformer 138kV - 161kV Montgomery - Spencer 345kV; Maywood - Spencer 345kV AECI-AMMO Driven by one future (AFC) AB Brown - Reid 345kV BREC Driven by RRF CC sited at A B Brown site Kewanee N - Kewanee S 138kV Kewanee 13 - Kewanee N 138kV AMIL Fredericktown - Fredericktown 161kV Driven by one external RRF wind unit sited at northern IL Lutesville - St Francois 345kV AECI-AMMO Driven by nearby assumed retirements Decatur Junction - Main St 138kV ADM North - Mt Zion 138kV AMIL *Binding for multiple contingencies Driven by external RRF Wind units sited at northern IL

15 Flowgates that meet the selection threshold but have been excluded (Cont d-2) Monitored Element Contingency Element(s) Area 2027 Total Annual Shadow Price (k$/mwh) AF C CFC DET LFC Reason for Potential Exclusion in MTEP18 Analysis Spaulding - Hannibal 161kV* Maywood - Spencer 345kV; Montgomery - Spencer 345kV AECI-AMMO Binds heavily only in AFC. Farmington - Rivermines 161kV Lutesville - St Francois 345kV AMMO Driven by nearby assumed retirements Overton Transformer 345kV - 161kV McCredie - Overton 345kV AMMO Binds heavily only in AFC Mobtap - Moberly 161kV Thomas Hill - Salisbury 161kV AECI-AMMO Big Creek Warrenton 161kV* Montgomery Spencer 345kV; Belleau Enon 345kV; Enon - Montgomery Driven by one external RRF CC sited at Kentucky AECI-AMMO Purely driven by one future (AFC) *Binding for multiple contingencies

16 Reliability Issues

17 Selected MTEP18 Reliability Projects Following 28 slides have MTEP18 Appendix A Baseline Reliability Projects (BRPs) near the MISO-PJM border Nearby PJM reliability issues could drive the need for an Interregional Reliability Project

18 METC: 2 Target Appendix A Projects are proposed as BRP projects with new system topology changes 3135Airport Long Rapids kv line 12/31/ Campbell to Tyler 345 kv 12/31/2021

19 METC: 2 Target Appendix A Projects are proposed as BRP projects with new system topology changes Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost 3135 Airport Long Construct Row 4 at the Long Low voltage is projected to occur in Rapids kv line Rapids 138 kv switchyard and install the necessary 138 kv station equipment to terminate the Airport kv line at Pos. BM4. The summer emergency rating of all new 138 kv equipment should be no less than the summer emergency rating of 477 ACSR conductor (260/1088 Amps). Rebuild the Airport Long Rapids 138 kv line. the northeastern region of the lower peninsula of Michigan for shutdown plus contingency scenarios involving the Airport Alpena 138 kv line and another transmission facility along a ~200 mile-long 138 kv path from Karn to Riggsville. The voltage violations were identified in the 2019, 2022, and 2027 peak load models with the Ludington units generating for any directional flow along the ITCT-IESO interface. Construct the new Airport Long Rapids kv line Campbell to Tyler 345 kv Build approximately 4 miles of The Campbell 345/138 kv 345kV line from Campbell to transformer #5 is projected to be Tyler. Also install a 345/138 kv overloaded in all cases for many transformer at Tyler. This project different contingencies in the 2017 will require new line terminating assessment. Most of the equipment and protection contingencies that cause the devices at both stations. overloads are involving the loss of Relocate the Campbell-Tyler kV lines, and or the Campbell kv line termination from position generation unit connected to its 8MB to position 6MB. 138kV bus. Relocate the Black River-Tyler The existing special protection 138kV line termination from scheme at Campbell has limitation. position 6MB to position 8MB. 12/31/2021 $21,000,000 12/31/2021 $22,500,000

20 METC: 2 Target Appendix A Projects are proposed as BRP projects with adding new transformer or replace existing transformer Keystone 345/138 kv Transformer #2 Replacement 12/31/ Pere Marquette 345/138 kv Transformer #1 and Station Expansion 12/31/2021

21 METC: 2 Target Appendix A Projects are proposed as BRP projects with adding new transformer or replace existing transformer Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Pere Marquette 345/138 kv Transformer #1 and Station Expansion Keystone 345/138 kv Transformer #2 Replacement Install a second 345/138 kv transformer at Pere Marquette facilitated through the construction of a new 345 kv switchyard and terminate this transformer along with the existing Ludington Pere Marquette 345 kv line and 345/138 kv Transformer #2 at it. Install a new Row 9 at the 138 kv switchyard and terminate the new 345/138 kv Transformer #1 and Lake County Pere Marquette 138 kv line in it. Replace the Keystone 345/138 kv Transformer #2 to increase the facility s summer emergency rating to 478 MVA/2000 Amps. Numerous pieces of equipment, including the 345/138 kv Transformer #2, at the Pere Marquette station are projected to become overloaded for various single and double contingency scenarios. The overloads were identified in the 2019, 2022, and 2027 peak and shoulder peak load models with the Ludington units generating for any directional flow along the Michigan- Ontario interface. 12/31/2021 $22,600,000 The proposed solution is to replace the Keystone 345/138 kv Transformer #2 to increase the facility s summer emergency rating to 478 MVA/2000 Amps and avoid unplanned outages caused by equipment failure. 12/31/2020 $3,700,000

22 METC: 2 Line rebuild and 5 sag remediation BRP projects targeted as Appendix A in MTEP Riggsville - Vanderbilt 138 kv Rebuild 12/31/ Alpena - Rockport 138 kv Sag Remediation 12/31/ Airport - Hillman Tap 138 kv Sag Remediation 12/31/ MCV - Tittabawassee kv Sag Remediation 12/31/ Bauer - Hampton kv Sag Remediation 12/31/ Cobb-Meyer 138kV Sag Remediation 6/1/ Battle Creek Verona #1 138kV Rebuild 6/1/2020

23 METC: 2 Line rebuild BRP projects targeted as Appendix A in MTEP18 Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Battle Creek Verona #1 138kV Rebuild Riggsville - Vanderbilt 138 kv Rebuild The proposed solution is to rebuild approximately 3.35 miles of 795 ACSR from Battle Creek- Verona #1 138kV circuit using 1431 ACSR on new future double circuit structures constructed to 230kV standards operated at 138kV. Rebuild the Riggsville Vanderbilt 138 kv portion (~30.4 miles) of the Livingston Riggsville 138 kv line (~40.1 miles) utilizing.230 kv double circuit construction. Battle Creek-Verona #1 138kV line is projected to be overloaded for contingency scenarios that involve the loss of Battle Creek-Verona #2 138kV line. 6/1/2020 $ 6,554,000 The Riggsville Vanderbilt 138 kv portion of the Livingston Riggsville 138 kv line is projected to become overloaded for shutdown plus contingencies involving the Emmett Livingston 138 kv line and another element. 12/31/2021 $42,000,000

24 METC: 5 sag remediation BRP projects targeted as Appendix A in MTEP18 Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Bauer - Hampton kv Sag Remediation Alpena - Rockport 138 kv Sag Remediation Remediate the sag limit on the Bauer - Hampton kv line to a minimum of 1179 MVA/1973 Amps. Remediate the sag limit on the Alpena - Rockport 138 kv line to a minimum of 145 MVA/607 Amps. The Bauer Hampton kv line is 12/31/2020 $365,000 projected to become overloaded for either the DCT outage or shutdown plus contingency scenario The Alpena Rockport 138 kv line is 12/31/2021 $250,000 projected to become overloaded for shutdown plus contingency scenarios MCV - Tittabawassee kv Sag Remediation Airport - Hillman Tap 138 kv Sag Remediation Cobb-Meyer 138kV Sag Remediation Remediate the sag limit on the entire The MCV Tittabawassee kv line 12/31/2020 $900,000 ~2.4 mile-long length of 2156 ACSR is projected to become overloaded for the conductor of the MCV Tittabawassee kv line and replace station equipment at both ends of the line to achieve at least the planned target summer emergency rating of 1687 MVA (2823 Amps). line outage and numerous shutdown plus contingencies involving this line and another transmission element. In addition, the Tittabawassee 345 kv Position 36F7 and 36H9 breaker failure contingencies are also projected to cause thermal violations. Remediate the sag limit on ~17.0 The Airport Hillman Tap 138 kv section 12/31/2021 $400,000 miles of 266 ACSR conductor of the of the Airport Mio 138 kv line is ~21.3 mile-long Airport - Hillman projected to become overloaded for Tap 138 kv section of the Airport - shutdown plus contingency scenarios Mio 138 kv line to at least the planned target summer normal/summer emergency rating of 133 MVA/556 Amps. The proposed solution is to remediate the sag limit on the Cobb Meyer 138kV line to the full conductor summer emergency limit of 260 MVA (1088 A). The Cobb Meyer 138kV line is projected to become overloaded for shutdown plus contingency scenarios 6/1/2020 TBD

25 METC: 2 Terminal equipment upgrade and 6 Substation equipment upgrade BRP projects targeted as Appendix A in MTEP Keystone 138 kv Station Equipment Upgrades 12/31/ MCV - Tittabawassee kv Station Equipment Upgrades 12/31/ Blendon 138kV-Station Equipment Upgrade 6/1/ Gaines 138kV Station Equipment Upgrade 6/1/ Argenta 138kV Terminal Equipment Upgrade 6/1/ Battle Creek 138kV - Terminal Equipment Upgrade 6/1/ Morrow 138kV Station Equipment Upgrade 6/1/ Goss 138 kv Station Equipment Upgrades 12/31/2020

26 METC: 2 Terminal equipment upgrade and 4 Substation equipment upgrade BRP projects targeted as Appendix A in MTEP18 Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Argenta 138kV Upgrade relaying at Argenta The Argenta 345/138 kv Terminal Equipment 138kV to meet or exceed Transformers 1 and 2 are projected Upgrade summer emergency rating of 602 to become overloaded for MVA/2520 Amps. contingency scenarios involving the loss of one Argenta Transformer in Battle Creek 138kV - Terminal Equipment Upgrade Gaines 138kV Station Equipment Upgrade Blendon 138kV- Station Equipment Upgrade Upgrade relaying at Battle Creek Positions 9MB and 9M9 to meet or exceed 574 MVA/2400 Amps. The proposed solution is to replace breakers at the Gaines 138kV station. Also increase CTs ratio so that the CTs have a minimum summer emergency rating of 647 MVA/2706 Amps (summer emergency). The proposed solution is to upgrade the relay and the CT at Blendon to meet or exceed 351 MVA/1469 Amps (summer emergency). However, in order to upgrade the CTs with a rating greater than 1200 amps, it is also required to replace breaker 177 at Blendon. peak cases. The Battle Creek 345/138 kv Transformers 3 is projected to become overloaded for in peak cases.. 6/1/2020 $ 126,000 6/1/2020 TBD The Gaines 345/138 kv Transformers 6/1/2020 $ 718,000 1 and 2 are projected to become overloaded for P13 event in peak cases. The Bilmar Jct. Blendon 138kV section is projected overload for a shutdown-plus-contingency in different cases. 6/1/2020 $508,000

27 METC: 4 Substation equipments upgrade BRP projects targeted as Appendix A in MTEP18 Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Morrow 138kV Station Equipment Upgrade MCV - Tittabawassee kv Station Equipment Upgrades Keystone 138 kv Station Equipment Upgrades Goss 138 kv Station Equipment Upgrades The proposed solution is to upgrade the station equipment at Morrow position 500 to meet or exceed 338 MVA/1413 Amps (summer emergency). Replace station equipment at both ends of the line to increase its summer emergency rating to 1687 MVA (2823 Amps). Upgrade station equipment on the low-side of the Keystone 345/138 kv Transformer #1 to achieve the transformer s summer emergency rating of 441 MVA/1843 Amps. Upgrade station equipment at Positions 11W8 and 13W8 at Goss to increase the open breaker summer emergency rating to 585 MVA/2447 Amps and account for open breaker scenarios at each position. The 138kV bus-tie at Morrow is projected to overload for a shutdown plus contingency in the peak cases. The MCV Tittabawassee kv line is projected to become overloaded for the P12 event and numerous shutdown plus contingencies. Station equipment at Keystone on the low-side of the 345/138 kv Transformer #1 is projected to become overloaded for several shutdown plus contingency scenarios Station equipment at Positions 11W8 and 13W8 at Goss is projected to become overloaded for shutdown plus contingency scenarios 6/1/2020 $31,000 12/31/2020 $ 850,000 12/31/2020 $12,000 12/31/2020 $475,000

28 Geographical Location of ITCT s Proposed MTEP18-Target A Projects Most projects are concentrated around Detroit Area

29 ITCT Baseline Reliability (Line Rebuild and Sag Remediation) MTEP18-Target A Projects ITCT [6/1/2020]: Adams Burns kv Sag Remediation ($0.222M) ITCT [6/1/2020]: Northeast Stephens 230 kv Sag Remediation ($0.37M) ITCT 4515 [12/31/2020]: Quaker Sunset 120 kv Rebuild ($1.49M) ITCT [6/1/2020]: Bismarck Jewell 345 kv Sag Remediation ($0.34M) ITCT [12/31/2020]: Pioneer Superior 120 kv Rebuild ($4.94M) ITCT [12/31/2020]: River Rouge Zug B 120 kv Rebuild ($0.581M) Baseline Reliability Line Rebuild Baseline Reliability Sag Remediation

30 ITCT: 3 Target Appendix A Projects are proposed as Baseline Reliability Projects Line Rebuild to address thermal violations Line Rebuild Project ID Project Name Project Description Preliminary System Need In- Service Date Quaker Sunset 120 kv Rebuild (*) Pioneer Superior 120 kv Rebuild River Rouge Zug B 120 kv Rebuild * Identified in MTEP17. Rebuild miles of 1431 ACSR using 1431 ACSR X2 and replace limiting station equipment at Quaker and Sunset 120 kv stations. Rebuild approximately 3.16 miles of 477 ACSR to 954 ACSR from Pioneer to McAuley to Superior on double-circuit, 120 kv towers. Upgrade station equipment at Superior to 954 ACSR. Also, 3.16 miles of 477 ACSR conductor of the Noble to Superior 120 kv line that shares common structure with Pioneer Superior 120 kv will be upgraded to 954 ACSR. Install OPGW on the rebuilt section. Rebuild approximately 0.5 mile of 795 ACSR to 954 ACSR and upgrade station equipment at River Rouge position JB to at least 371 MVA (1785 Amp). The Quaker Sunset 120 kv line is projected to be heavily overloaded for many different contingencies, most of which involve the loss of the Quaker Southfield 120 kv line or Wixom 345/120kV transformer #301. The Pioneer McAuley Superior 120 kv circuit is projected to overload in the 5 and 10 year cases. The thermal violation occurs in different contingencies with most of them involving the loss of Milan 345/120 kv transformer or Milan Pioneer 120 kv line. The River Rouge Zug 120 kv circuit is projected to overload in the 5 and 10 year cases. The thermal violation occurs on open-breaker and breaker failure contingencies along the buses that connect River Rouge generator unit #3 to the equalizer bus. These breaker contingencies trip two of the three 120 kv outlets for the River View generator (#3) unit as well as its connection to the equalizer bus at River Rouge This causes remaining River Rouge Zug 120 kv line to absorb all the generation output from River Rouge unit #2 and consequently overloads this circuit. Dec 2020 Dec 2020 Dec 2020 Estimate d Cost $1.49M $4.94M $0.581M

31 ITCT: 3 Target Appendix A Projects are proposed as Baseline Reliability Projects Sag Remediation to address thermal violations Project ID Project Name Project Description Preliminary System Need In- Service Date Estimate d Cost Sage Remediation Adams Burns kv Sag Remediation Bismarck Jewell 345 kv Sag Remediation (*) Northeast Stephens 230 kv Sag Remediation Remediate the sag limit on the Adams Burns2 120 kv section to the conductor summer emergency rating of 314 MVA (1512 Amp). Raise the sag limit on the Bismarck Jewell 345 kv line to at least 1661 MVA (2780 Amp) summer emergency. Also upgrade the station equipment at Bismarck BQ position to at least 1661 MVA summer emergency. Raise the Sag Limit on the Northeast Stephens 230 kv line to at least 700 MVA (1757 Amp) summer emergency. The 120 kv section between Adams to Burns2 tap is projected to be overloaded for several shutdown-plus-contingency scenarios. All of the N-1-1 contingencies that caused thermal violations involve the loss of Jewell St. Clair #2 120 kv line. The Bismarck Jewell 345 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The thermal violation occurs in shutdown-pluscontingency and double-circuit tower (DCT) outage that take out the Jewell-Stephens 345 kv and St. Clair-Stephens 345 kv lines. The Northeast Stephens 230 kv line is projected to be heavily loaded for several shutdown-pluscontingency scenarios that involve the loss of Caniff Stephens 345 kv circuit. Jun 2020 Jun 2020 Jun 2020 $0.222M $0.34M $0.37M * Identified in MTEP17.

32 ITCT Baseline Reliability (Terminal/Internal Equipment Upgrade) MTEP18- Target A Proj. ITCT [12/31/2020]: St. Clair 120 kv Reactors upgrade ($2.23M) ITCT [6/1/2020]: Belle River St. Clair 345 kv Station Equipment Upgrade ($0.274M) ITCT [6/1/2020]: Jewell St. Clair 345 kv Station Equipment Upgrades ($0.36M) ITCT [6/1/2020]: Golf St. Clair 120 kv Station Equipment Upgrades ($0.123M) ITCT [6/1/2020]: Elm 120 kv - Upgrade HF Station Equipment ($0.073M) ITCT [6/1/2020]: St. Clair 120 kv Upgrade HF-GU-JD Station Equipment ($0.835M) ITCT [12/31/2020]: Wayne 120 kv Breakers GS and GZ Replacement ($0.931M) ITCT [6/1/2020]: Stephens 345 kv Upgrade DM & DT Station Equipment ($0.845M) ITCT [6/1/2020]: St. Clair Stephens #2 345 kv Station Equipment Upgrade ($0.714M) ITCT [6/1/2020]: Riverview 120 kv Upgrade Switches and Trainer ($0.191M) ITCT [6/1/2020]: Monroe Wayne 345 kv Station Equipment Upgrades ($0.58M) ITCT [6/1/2020]: Brownstown Monroe #1 345 kv Station Equipment Upgrades ($1.076M) ITCT [6/1/2020]: Monroe Lallendorf 345 kv Station Equipment Upgrades ($0.763M) ITCT [6/1/2020]: Trenton Channel 120 kv Upgrade HJ-IM-IQ Station Equipment ($0.986M) Baseline Reliability Terminal Equipment Baseline Reliability Internal Equipment

33 ITCT: 14 Target Appendix A Projects are proposed as Baseline Reliability Projects Terminal/Internal Equipment Replacement to address thermal violations (1/3) Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Wayne 120 kv Breakers GS and GZ Replacement Replace breakers GS and GZ with 50kA interrupting capability. These breakers are at risk of having to interrupt faults as high as 103% for GS and 102% for GZ. (Short Circuit violations) Dec 2018 $0.931M (Withdrawn) Terminal/Internal Equipment Replacement Belle River St. Clair 345 kv Station Equipment Upgrade Stephens 345 kv Upgrade DM & DT Station Equipment Elm 120 kv - Upgrade HF Station Equipment Brownstown Monroe #1 345 kv Station Equipment Upgrades Upgrade the station equipment at St. Clair to a minimum rating of 2200 MVA (3682 Amp) summer emergency. Upgrade station equipment at Stephens 345 kv position DM and DT to at least 1540 MVA (2577 Amp) summer emergency. Upgrade station equipment at Elm s position HF to at least 314 MVA (1511 Amp) summer emergency. Upgrade 345 kv station equipment at Brownstown and Monroe so that the summer emergency rating meets or exceeds 2000 MVA (3347 Amp). The Belle River St. Clair 345 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The thermal violation occurs in many different contingencies, most of them involve the loss of Belle River Lenox 345 kv or Jewell St. Clair #1 345 kv line. The Jewell Stephens 345 kv line is projected to be overloaded in the 2 and 5 year cases. The overload happens in a shutdown-plus-contingency that takes out Bismarck Jewell 345 kv and St. Clair Stephens #2 345 kv lines. The Brock Elm 120 kv line is projected to be marginally overloaded in the 2 and 5 year cases. The thermal violation occurs in a shutdown-pluscontingency that takes out both of the Wayne Newburg 120 kv (#1 and #2) circuits. The Brownstown Monroe #1 345 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The thermal violation occurs in many generator-plus-line and shutdown-plus-contingency that involve the loss of Monroe Wayne 345 kv line. Jun 2020 Jun 2020 Jun 2020 Jun 2020 $0.274M $0.845M $0.073M $1.076M

34 ITCT: 14 Target Appendix A Projects are proposed as Baseline Reliability Projects Terminal/Internal Equipment Replacement to address thermal violations (2/3) Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Terminal/Internal Equipment Replacement Monroe Wayne 345 kv Station Equipment Upgrades Monroe Lallendorf 345 kv Station Equipment Upgrades (*) Upgrade 345 kv station equipment at Monroe and Wayne so that the summer emergency rating meets or exceeds 1714 MVA (2868 Amp). The Monroe Wayne 345 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The thermal violation occurs in many generator-plus-line and shutdown-plus-contingency that involve the loss of Brownstown Monroe #1 345 kv line. The Monroe Lallendorf 345 kv tie-line to First Energy is projected to be overloaded in the 2, 5, and 10 year cases. The overload happens in a shutdown-pluscontingency that takes out Brownstown Monroe #1 345 Upgrade Monroe 345 kv station equipment so that the summer emergency kv and Monroe Wayne 345 kv lines. This contingency rating meets or exceeds 2000 MVA trips two of the three 345 kv outlets at Monroe12 station, (3347 Amp). causing the only remaining line (Monroe Lallandorf 345 kv) to absorb all the generation outputs from Monroe generator unit #1 and #2. Upgrade 120 kv station equipment at Riverview 120 kv Riverview position HB to meet or Upgrade Switches exceed 424 MVA (2040 Amp) summer and Trainer emergency. Jewell St. Clair 345 kv Station Equipment Upgrades (*) * Identified in MTEP17. The proposed solution is to upgrade station equipment at St. Clair 345 kv position CM to at least 2000 MVA (3347 Amp) summer emergency. The Riverview Adelaide 120 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The overload happens in a shutdown-plus-contingency that takes out Navare 230/120kV transformer and Riverview Tandem 120 kv line. The Jewell St. Clair 345 kv line is projected to be overloaded in the 2, 5, and 10 year cases. The thermal violation occurs in shutdown-plus-contingency and double-circuit tower (DCT) that involve the loss of St. Clair Stephens 345 kv or Belle River Lenox 345 kv line. Dec 2018 Jun 2020 Jun 2020 Jun 2020 $0.58M $0.763M $0.191M $0.36M

35 ITCT: 14 Target Appendix A Projects are proposed as Baseline Reliability Projects Terminal/Internal Equipment Replacement to address thermal violations (3/3) Projec t ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost Terminal/Internal Equipment Replacement St. Clair Stephens #2 345 kv Station Equipment Upgrade Golf St. Clair 120 kv Station Equipment Upgrades St. Clair 120 kv Upgrade HF-GU-JD Station Equipment Trenton Channel 120 kv Upgrade HJ- IM-IQ Station Equipment ( ) Upgrade station equipment at Stephens 345 kv and St. Clair 345kV stations to at least 1786 MVA (2989 Amp) summer emergency. Upgrade station equipment at St. Clair 120 kv position JE to at least 314 MVA (1512 Amp) summer emergency. Upgrade station equipment at position HF to at least 417 MVA (2004 Amp). Upgrade station equipment at position GU to at least 557 MVA (2680 Amp). Upgrade station equipment at position JD to at least 450 MVA (2165 Amp). Upgrade station equipment at positions HJ, IM, and IQ to at least 747 MVA (3594 Amp). Replace St. Clair 120 kv reactors HA St. Clair 120 kv and JG at with new ones that meet or Reactors Upgrade ( ) exceed the summer emergency rating of 220 MVA (1058 Amp). Some of these listed internal equipment were identified in MTEP17 analysis. The St. Clair Stephens #2 345 kv line is projected to be overloaded in the 2 and 5 year cases. The thermal violation occurs in shutdown-plus-contingency and double-circuit tower (DCT) that involve the loss of Jewell St. Clair #1 345 kv line. The 120 kv section between St. Clair and Houston 2 tap (toward Golf) is projected to be overloaded in the 2 year cases. The thermal violation occurs in a shutdownplus-contingency that takes out Jacob St. Clair and Boyne St. Clair 120 kv lines. Three 120 kv bus-tie branches at St. Clair are projected to be overloaded in the 2, 5, and 10 year cases. The contingencies that cause these thermal violations are breaker failure and shutdown-plus-contingency, most of which involves the loss of Jacob St. Clair 120 kv or Jacob Victor 120 kv line. Three 120 kv bus-tie branches at Trenton Channel are projected to be overloaded in the 2, 5, and 10 year cases. The contingencies that cause these thermal violations are open-breaker and breaker failure occurring at Trenton Channel station. The two 120 kv reactors at St. Clair are projected to be overloaded in shutdown-plus-contingency that takes out one of them (reactors) plus Jacob St. Clair or Jacob Victor 120 kv line. The thermal violation only occurs in the 70%-peak cases with Ludington units pumping. Jun 2020 Jun 2020 Jun 2020 Jun 2020 Dec 2020 $0.714M $0.123M $0.835M $0.986M $2.23M

36 3 BES Asset replacement and one GI upgrade projects are proposed 13796:Cayuga CT 345kV Ring Bus Expansion 13844:Washington Muni. 138kV Ring Bus 13772: Seymour 138 Reliability Upgrades 13775: Gallagher 230 Reliability Upgrades

37 DEI: BES Projects Target Appendi x ID Project Name Description Preliminary System Needs A Gallagher 230 Reliability Upgrades Gallagher 230 Reliability Upgrades: Replace The assets being misc. relays; (4) 230kV breakers 23004, addressed in this project 23005, , 230kV TR; (11) misc. fall under one or more of 230kV switches; (4) 138kV breakers 13827, the system programs as 13885, 13822, 138TR; (3) wave traps - outlined in TDSIC Plan 13852, 23004, Expected ISD Cost 12/31/2018 $4,072, Cayuga CT 345kV Ring Bus Expansion - to A Cayuga CT 345kV Ring Bus Expansionaccommodate wind farm connection - J515 J515 Gen Queue - IA executed 6/1/2019 $3,511, A Washington Muni. 138kV Ring Bus A Seymour 138 Reliability Upgrades Washington Muni. 138kV Ring Bus: add 2 breakers and replace 1; relocate metering; add control building; install wave traps on the and line terminals The assets being addressed in this project fall under one or more of the system programs as outlined in TDSIC Plan f The assets being addressed in this project Seymour 138 Reliability Upgrades: Replace fall under one or more of (3) 138kV circuit switchers , the system programs as 2; (12) 138kV line CCVTs; and outlined in TDSIC Plan wave traps; & MOLB Sw's; filed with Indiana Utility switch 2000 amp load break; Add new Regulatory Commission ctrl bldg; Misc relay upgrades; Replace (3) Exhibit 3-B - Substation 69kv breakers and main bus (954acsr) Programs Summary. 12/31/2019 $3,882, /31/2019 $4,508,000.00

38 3 BES Asset replacement projects are proposed 14097: Dubois 138 kv OCB 2000 & : Grimm Rd. 69/12 kv T : Z85-2 Heidelbach to Angel Mounds

39 SIGE: BES Projects Target Appendi x ID Project Name Description Preliminary System Needs Expected ISD Cost A Z85-2 Heidelbach - Angel Mounds Rebuild ~6.7 miles of 138 kv line between Heidelbach & Angel Mounds stations Aging Infrastructure. 12/31/2019 $6,263, A Grimm Rd. 138/12 kv T1 Replace 138/12 kv T1 at Grimm Rd. Aging Infrastructure. 12/31/2020 $1,138, A Dubois 138 kv OCB 2000 & 3000 Replace two oil circuit breakers (OCB) 2000 & 3000 at Dubois station Aging Infrastructure. 12/31/2020 $582,000.00

40 1 Asset replacement and 1line retirement projects are proposed 13608: Southeast #9 Breaker Replacement 13924: 138 kv Line from East to Ford getting retired

41 IPL: BES Projects Target Appendi x A ID Project Name Description Preliminary System Needs Southeast #9 Breaker Replacement Replacement of one (1) 138 kv breaker at Southeast, #9 A Retirement line retirement Reliability need resulting from the annual short circuit analysis as required by NERC TPL R2.3 & R2.8. None. Line retirement. Expected ISD Cost 12/31/2020 $300,000 1/1/2019 $0 *Cost shown in the table above estimates developed by MISO

42 Ameren: Three (3) BRP Target A Projects are proposed to address reliability a Three (3) Projects: 1) P13570, AMIL 2) P13689, AMIL 3) P13691, AMIL

43 Ameren: Three (3) BRP Target A Projects are proposed to address reliability. MTEP ID P13570 P13689 Project Name Description System Need ISD Cost Reconductor Cahokia- Baldwin 345 kv line Upgrade Louisville South- Newton 138 kv line New Albion South 138 kv P13691 substation capacitor bank (60 Mvar) In the Cahokia-Baldwin 345 kv line 4511, reconductor 0.83 miles of 1113 kcmil ACSR/T2 Finch conductor from structures 148 to 153 with conductor capable of carrying 3000 A under summer emergency conditions. Increase ground clearance for 20 miles of 954 ACSR rail in order to permit operation at 120 degrees C. Replace 954 ACSR rail bus conductor at both Louisville South and Newton Install 138 kv capacitor bank on the North Bus at Albion South. P6-1-1 event: For expected 2021 summer peak conditions, the coincident outages of the Baldwin-Turkey Hill 345 kv line 4521 and Prairie State- Stallings 345 kv line 4531 would cause the section of conductor between structures 148 to 153 in the Cahokia-Baldwin 345 kv line 4511 to be loaded up to 120% of its 1322 MVA summer emergency rating. This project is required to meet Ameren's Transmission Planning Criteria. P6-1-1 Event: Loading greater than 100% for an outage of Mt. Vernon-Xenia 345 kv line and Casey-Newton 345 kv line. P6-1-1 Event: Voltages below 0.95 per unit with outage of Albion-Gibson 345 kv line and West Frankfort East-Norris City North 345 kv line. 10/1/2019 TBD 6/1/2020 TBD 6/1/2019 TBD project is MTEP18 Target A project proposal

44 MEC: Target Appendix A Projects by Location Baseline Reliability Generator Interconnection Other

45 MEC: 2 Target Appendix A Projects are proposed as Baseline Reliability Projects to address thermal loading Project ID Project Name Project Description Preliminary System Need In-Service Date Estimated Cost 2937 Sub 39: Second kv Xfmr Add a second kv xfmr. Expand 345 kv and 161 kv buses. Thermal loading during P6 events Dec 2019 $11.6M 2938 Uprate Sub 39 - Change out structures to increase rating. Cordova 345 kv Line Thermal loading during P6 events Dec 2019 $1.3M

46 Adam Solomon