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AF2-041 Phase I Study Report

v1.00 released 2024-05-16 00:21

Nelson-Electric Junction 345 kV

180.0 MW Capacity / 300.0 MW Energy

Introduction

This Phase I System Impact Study Report (PH1) has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, sections 307 and 308 for New Service Requests (projects) in Transition Cycle #1. The Project Developer/Eligible Customer (developer) is Steward Creek Solar, LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Commonwealth Edison Company.

Preface

The Phase I System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase I System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.

In accordance with PJM Manual 14H, section 4.3, PJM takes the following actions during the Phase I System Impact Study:
  1. PJM studies each New Service Request on a summer peak, winter peak[1] and light load RTEP base case study. The case year is dependent on the new services cycle under study. PJM will identify the base case year to be used in the study of a specific cycle on its website.
  2. PJM will only perform load flow analysis during the Phase I System Impact Study.
  3. In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with Affected System impacts and provides each Affected System Operator with a list of New Service Request in the Cycle with potential impacts to their respective system.
  4. PJM will create both the short circuit and stability base cases to be used in the Phase II System Impact Study.
  5. The Phase I System Impact Study results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase I System Impact Study:
  1. Identify required Interconnection Facilities to accommodate the New Service Request.
  2. Identify required Network Upgrades to mitigate system violations from the Phase I System Impact Study.
  3. Provide planning-level preliminary estimates of Interconnection Facilities and Network Upgrades including scope, cost and elapsed time to complete the work.

Decision Point I Requirements

At the close of Phase I System Impact Study, PJM will initiate Decision Point I (DP1). During DP1, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.A.1. Additional information on these elements is available in PJM Manual 14H sections 4.4, 6, and 7.

Allowable project modifications at Decision Point I are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.

General

The developer has proposed a Solar generating facility located in the Commonwealth Edison Company zone — Lee County, Illinois. The installed facilities will have a total capability of 300.0 MW with 180.0 MW of this output being recognized by PJM as Capacity.

Project Information
New Service Request Number AF2-041
Project Name Nelson-Electric Junction 345 kV
Developer Name Steward Creek Solar, LLC
State Illinois
County Lee
Transmission Owner Commonwealth Edison Company
MFO 300.0 MW
MWE 300.0 MW
MWC 180.0 MW
Fuel Type Solar
Basecase Study Year 2027

Point of Interconnection

AF2-041 will interconnect on the ComEd transmission system by tapping the Nelson to Electric Junction 345 kV line .

Cost Summary

The table below shows a summary of the total planning level cost estimates for this New Service Request project. These network upgrade costs are subject to change as a result of a facility study performed by the TO during the Phase II or Phase III System Impact Study.

Based on the Phase I SIS results, the AF2-041 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit are also shown below.

Cost Summary
Description Cost Allocated to AF2-041 Cost Subject to Readiness*
Transmission Owner Interconnection Facilities (TOIF) $175,943 $0
Physical Interconnection Network Upgrades
Stand Alone Network Upgrades $7,333,782 $7,333,782
Network Upgrades $10,062,996 $10,062,996
System Reliability Network Upgrades
Steady State Thermal & Voltage (SP & LL) $37,040,368 $37,040,368
Transient Stability $0 $0
Short Circuit $0 $0
Transmission Owner Analysis
SubRegional $0 $0
Distribution $0 $0
Affected System Study Reinforcements $0 $0
Total $54,613,089 $54,437,145

* Contributes to calculation for Readiness Deposit #2 (RD2). See Readiness Deposit section of report for additional detail.

Definitions

Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.

Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.

Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.

Notes

Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.

Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.

Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.

Readiness Deposit

Per Tariff Part VII, Subpart D, section 309 (Decision Point I) A.1.a.i and PJM Manual 14H, section 6.2, Readiness Deposit #2 (RD2) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below and not used to fund studies nor to offset Security.

During Decision Point I (DP1), the Project Developer or Eligible Customer is required to submit Readiness Deposit #2, which is calculated as 10% of cost allocation for required Phase I Network Upgrades minus Readiness Deposit #1.

Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.

Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))

Note 3: Readiness Deposit #2 can be zero, but may not be a negative number.

Readiness Deposit #2 Due for Project AF2-041

Readiness Deposit #2 has been calculated for the project based on the Phase I System Impact Study results and is shown in the table below. This Readiness Deposit #2 must be provided at Decision Point I through either a wire transfer or letter of credit per Manual 14H, Section 6.2.

Readiness Deposit
Project ID 10% of cost allocation for Phase I Network Upgrades Readiness Deposit #1 Received (RD1) Readiness Deposit #2 (RD2) for AF2-041 Project due at DP1
A B A - B
AF2-041 $5,443,715 $1,200,000 $4,243,715

Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.

For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.

Transmission Owner Scope of Work

As shown in the one line diagram, this Interconnection Request is sharing the Point of Interconnection (POI) with one or more other Interconnection Requests. Should other requests withdraw from Transition Cycle 1, the cost allocation for Transmission Owner Interconnection Facilities, Stand Alone Network Upgrades, and applicable Network Upgrades identified in the study report will be updated for the remaining project(s). Refer to the one line for other Interconnection Requests at this POI.

The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.

Transmission Owner Interconnection Facilities
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending)

Dead end structure, 345kV MOD, three (3) CT/PT units, three (3) surge arrestors
 
 

$879,716 $175,943 (See Note 1)
Stand-Alone Network Upgrades
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending)

Construction of new interconnection substation TSS934 Herman Rd, transmission line tie ins, and New fiber routing from TSS934 to existing ComEd substations
 
 

Construction of the new Interconnection Substation includes the installation of three 345kV circuit breakers in a "breaker-and-a-half” bus configuration and cutting in the Interconnection Substation to the transmission line(s). The Project Developer is responsible for constructing all of the facilities on the Project Developer's side of the Point of Change of Ownership (“PCO”) outside of the substation. It is assumed for the purposes of this report that the Project Developer will obtain the site for the Interconnection Substation and right-of-way between the Interconnection Substation and the transmission line.

Relay and Communication upgrades may require new fiber optic installation.

The cost and scope will be further evaluated during the Phase 2 Interconnection Facilities Study.

$36,668,908 $7,333,782 (See Note 1)
Network Upgrades
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending)

Remote end work
Communication upgrades may require new fiber optic installation.
The cost and scope will be further evaluated during the Phase 2 Interconnection Facilities Study.
 

$50,314,979 $10,062,996 (See Note 1)

Based on the scope of work for the Interconnection Facilities, it is expected to take 60 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.

The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.

Note 1: A Common Use Upgrade is a Network Upgrade that is needed for the interconnection of Generating Facilities or Merchant Transmission Facilities of more than one Project Developer or Eligible Customer and which is the shared responsibility of each Project Developer or Eligible Customer. If multiple Project Developers request to connect to the same interconnection substation, the Transmission Owner will determine the cost to accommodate all the requests at the substation. The cost for the interconnection will be allocated in proportion to the number of required terminations into the substation.

Notes on Cost Estimate:

  1. These estimates are Order-of-Magnitude estimates of the costs that ComEd would bill to the Project Developer for this interconnection. These estimates are based on a one-line electrical diagram of the project and the information provided by the Project Developer.
  2. There were no site visits performed for these estimates. There may be costs related to specific site related issues that are not identified in these estimates. The site reviews will be performed during the Facilities Study or during detailed engineering.
  3. These estimates are not a guarantee of the maximum amount payable by the Project Developer and the actual costs of ComEd's work may differ significantly from these estimates. The Project Developer will be responsible for paying actual costs of ComEd's work in accordance with the PJM Open Access Transmission Tariff.
  4. The Project Developer is responsible for all engineering, procurement, testing and construction of all equipment on the Project Developer’s side of the Point of Change in Ownership.

These cost estimates do not include cost of acquiring right-of-way for the transmission line and purchasing any additional land, if needed, for the line terminations.

Transmission Owner Analysis

No Transmission Owner impacts identified.

 

 

Developer Requirements

The developer is responsible for all design and construction related activities on the developer’s side of the Point of Interconnection. ComEd interconnection requirements can be found here.

To the extent that these Applicable Technical Requirements and Standards may conflict with the terms and conditions of the Tariff, the Tariff shall control.

Revenue Metering and SCADA Requirements

PJM Requirements
The developer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for their generating Resource. See PJM Manual 01, PJM Manual 14D, and PJM Tariff Part IX, Subpart B, Appendix 2, section 8.
Meteorological Data Reporting Requirement
The solar generation facility shall provide the Transmission Provider with site-specific meteorological data including:
  • Temperature (degrees Fahrenheit)
  • Atmospheric Pressure (hectopascals)
  • Irradiance
  • Forced outage data
Transmission Owner Requirements
The Project Developer will be required to comply with all interconnected Transmission Owner’s revenue metering requirements located at the following link: PJM - Transmission Owner Engineering & Construction Standards.

Summer Peak Analysis

The New Service Request project was evaluated as a 300.0 MW (Capacity 180.0 MW) injection in the ComEd area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential summer peak period network impacts were as follows:

Note: The capacity portion of New Service Requests are evaluated for single or N-1 contingencies. The full energy output of New Service Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).

Summer Peak Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Final Cycle Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
AEP/NIPS 17STILLWELL-05DUMONT 345.0 kV Ckt 1 line
255113 to 243219 ckt 1
765-L11215__-S_SRT-A
CONTINGENCY '765-L11215__-S_SRT-A'
 REMOVE SHUNT 1 FROM BUS 270644                    /*WILTON   ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 243206 CKT 1   /*WILTON   ;   765.0 - 05DUMONT     765.0
END
Single AC 176.64 % 1075.0 B 1898.9 24.14
AEP/NIPS 17STILLWELL-05DUMONT 345.0 kV Ckt 1 line
255113 to 243219 ckt 1
AEP_P1-2_#695_1681_SRT-A
CONTINGENCY 'AEP_P1-2_#695_1681_SRT-A'
 OPEN BRANCH FROM BUS 243206 TO BUS 270644 CKT 1   /*05DUMONT     765.0 - WILTON   ;   765.0
END
Single AC 176.64 % 1075.0 B 1898.86 24.14
AEP/CE AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line
960680 to 243229 ckt 1
AEP_P1-2_#695_1681_SRT-A
CONTINGENCY 'AEP_P1-2_#695_1681_SRT-A'
 OPEN BRANCH FROM BUS 243206 TO BUS 270644 CKT 1   /*05DUMONT     765.0 - WILTON   ;   765.0
END
Single AC 145.91 % 971.0 B 1416.77 18.02
AEP/CE AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line
960680 to 243229 ckt 1
765-L11215__-S_SRT-A
CONTINGENCY '765-L11215__-S_SRT-A'
 REMOVE SHUNT 1 FROM BUS 270644                    /*WILTON   ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 243206 CKT 1   /*WILTON   ;   765.0 - 05DUMONT     765.0
END
Single AC 145.91 % 971.0 B 1416.76 18.02
AEP/AMIL J1180 POI-05SULLIVAN 345.0 kV Ckt 1 line
956820 to 247712 ckt 1
Base Case Single AC 142.47 % 1334.0 A 1900.57 9.45
CE GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line
276670 to 270883 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-4
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-4'
 TRIP BRANCH FROM BUS 270916 TO BUS 965550 CKT 1   /*WAYNE    ; B 345.0 - AG1-423 TP   345.0
END
Single AC 130.04 % 1568.0 STE 2039.07 10.55
CE GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line
276670 to 270883 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-3
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-3'
 TRIP BRANCH FROM BUS 962700 TO BUS 965550 CKT 1   /*AG1-119 TP   345.0 - AG1-423 TP   345.0
END
Single AC 128.05 % 1568.0 STE 2007.76 10.55
CE CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line
270694 to 276670 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-4
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-4'
 TRIP BRANCH FROM BUS 270916 TO BUS 965550 CKT 1   /*WAYNE    ; B 345.0 - AG1-423 TP   345.0
END
Single AC 124.17 % 1568.0 STE 1946.94 10.55
CE/NIPS CRETE EC ;BP-17STJOHN 345.0 kV Ckt 1 line
274750 to 255112 ckt 1
AEP_P1-2_#695_1681_SRT-A
CONTINGENCY 'AEP_P1-2_#695_1681_SRT-A'
 OPEN BRANCH FROM BUS 243206 TO BUS 270644 CKT 1   /*05DUMONT     765.0 - WILTON   ;   765.0
END
Single AC 130.55 % 1399.0 B 1826.38 21.86
CE/NIPS CRETE EC ;BP-17STJOHN 345.0 kV Ckt 1 line
274750 to 255112 ckt 1
765-L11215__-S_SRT-A
CONTINGENCY '765-L11215__-S_SRT-A'
 REMOVE SHUNT 1 FROM BUS 270644                    /*WILTON   ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 243206 CKT 1   /*WILTON   ;   765.0 - 05DUMONT     765.0
END
Single AC 130.55 % 1399.0 B 1826.35 21.86
AEP/AMIL J1180 POI-05SULLIVAN 345.0 kV Ckt 1 line
956820 to 247712 ckt 1
348493(7XENIA)-991325(J2033 POI)_1_SRT-A
CONTINGENCY '348493(7XENIA)-991325(J2033 POI)_1_SRT-A'
 OPEN BRANCH FROM BUS 348493 TO BUS 991325 CKT 1   /*7XENIA       345.0 - J2033 POI    345.0
END
Single AC 116.96 % 1635.0 B 1912.22 9.24
AEP/AMIL J1180 POI-05SULLIVAN 345.0 kV Ckt 1 line
956820 to 247712 ckt 1
991170(J1679 POI)-992450(J2661 POI)_1_SRT-A
CONTINGENCY '991170(J1679 POI)-992450(J2661 POI)_1_SRT-A'
 OPEN BRANCH FROM BUS 991170 TO BUS 992450 CKT 1   /*J1679 POI    345.0 - J2661 POI    345.0
END
Single AC 116.96 % 1635.0 B 1912.22 9.24
CE UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line
274804 to 960680 ckt 1
AEP_P1-2_#695_1681_SRT-A
CONTINGENCY 'AEP_P1-2_#695_1681_SRT-A'
 OPEN BRANCH FROM BUS 243206 TO BUS 270644 CKT 1   /*05DUMONT     765.0 - WILTON   ;   765.0
END
Single AC 130.04 % 970.0 STE 1261.35 18.02
CE UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line
274804 to 960680 ckt 1
765-L11215__-S_SRT-A
CONTINGENCY '765-L11215__-S_SRT-A'
 REMOVE SHUNT 1 FROM BUS 270644                    /*WILTON   ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 243206 CKT 1   /*WILTON   ;   765.0 - 05DUMONT     765.0
END
Single AC 130.04 % 970.0 STE 1261.35 18.02
CE CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line
270694 to 276670 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-3
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-3'
 TRIP BRANCH FROM BUS 962700 TO BUS 965550 CKT 1   /*AG1-119 TP   345.0 - AG1-423 TP   345.0
END
Single AC 122.16 % 1568.0 STE 1915.5 10.55
CE BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line
270670 to 934730 ckt 1
765-L11216__-S_SRT-A
CONTINGENCY '765-L11216__-S_SRT-A'
 TRIP BRANCH FROM BUS 270644 TO BUS 270607 CKT 1   /*WILTON   ;   765.0 - COLLINS  ;   765.0
END
Single AC 100.34 % 1837.0 STE 1843.29 13.59
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
Base Case Single AC 119.18 % 1334.0 A 1589.8 97.33
CE/NIPS CRETE EC ;BP-17STJOHN 345.0 kV Ckt 1 line
274750 to 255112 ckt 1
Base Case Single AC 117.92 % 1091.0 A 1286.53 14.44
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
Base Case Single AC 117.14 % 1201.0 A 1406.85 26.33
CE E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line
270728 to 274750 ckt 1
AEP_P1-2_#695_1681_SRT-A
CONTINGENCY 'AEP_P1-2_#695_1681_SRT-A'
 OPEN BRANCH FROM BUS 243206 TO BUS 270644 CKT 1   /*05DUMONT     765.0 - WILTON   ;   765.0
END
Single AC 105.87 % 1483.0 STE 1570.01 22.15
CE E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line
270728 to 274750 ckt 1
765-L11215__-S_SRT-A
CONTINGENCY '765-L11215__-S_SRT-A'
 REMOVE SHUNT 1 FROM BUS 270644                    /*WILTON   ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 243206 CKT 1   /*WILTON   ;   765.0 - 05DUMONT     765.0
END
Single AC 105.86 % 1483.0 STE 1569.97 22.15
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P1-2_345-L11120_R-N_SRT-A
CONTINGENCY 'COMED_P1-2_345-L11120_R-N_SRT-A'
 MOVE 100 PERCENT LOAD FROM BUS 270749 TO BUS 270751   /*ESS W407M; R 345.0 - ESS W407M;9T 345.0
 TRIP BRANCH FROM BUS 270733 TO BUS 270747 CKT 1       /*ELECT JCT;3R 345.0 - ESS W407K;0T 345.0
 TRIP BRANCH FROM BUS 270747 TO BUS 270753 CKT 1       /*ESS W407K;0T 345.0 - ESS W407M;0T 345.0
 TRIP BRANCH FROM BUS 270753 TO BUS 270749 CKT 1       /*ESS W407M;0T 345.0 - ESS W407M; R 345.0
 TRIP BRANCH FROM BUS 270753 TO BUS 270813 CKT 1       /*ESS W407M;0T 345.0 - LOMBARD  ; R 345.0
END
Single AC 105.13 % 1568.0 STE 1648.49 27.2
AEP/NIPS 17STILLWELL-05DUMONT 345.0 kV Ckt 1 line
255113 to 243219 ckt 1
Base Case Single AC 111.11 % 1075.0 A 1194.46 13.82
CE AG1-423 TP-WAYNE ; B 345.0 kV Ckt 1 line
965550 to 270916 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
Single AC 107.34 % 2107.0 STE 2261.62 11.29
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P1-2_345-L10805_B-S_SRT-A
CONTINGENCY 'COMED_P1-2_345-L10805_B-S_SRT-A'
 TRIP BRANCH FROM BUS 270810 TO BUS 274702 CKT 1   /*LOCKPORT ; B 345.0 - KENDALL  ;BU 345.0
END
Single AC 101.98 % 1568.0 STE 1599.08 26.68
CE AG1-423 TP-WAYNE ; B 345.0 kV Ckt 1 line
965550 to 270916 ckt 1
COMED_P1-2_345-L15616__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L15616__-R_SRT-A'
 TRIP BRANCH FROM BUS 270694 TO BUS 276670 CKT 1   /*CHERRY VA; B 345.0 - GARDEN PR; R 345.0
END
Single AC 104.99 % 2107.0 STE 2212.09 11.29
CE AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line
962700 to 965550 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
Single AC 104.05 % 2107.0 STE 2192.37 11.29
CE AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line
962700 to 965550 ckt 1
COMED_P1-2_345-L15616__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L15616__-R_SRT-A'
 TRIP BRANCH FROM BUS 270694 TO BUS 276670 CKT 1   /*CHERRY VA; B 345.0 - GARDEN PR; R 345.0
END
Single AC 101.79 % 2107.0 STE 2144.81 11.29
CE/MEC QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line
270866 to 636610 ckt 1
EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-2
CONTINGENCY 'EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-2'
 OPEN BRANCH FROM BUS 992010 TO BUS 636605 CKT 1   /*J2552 POI    345.0 - MEC CORDOVA3 345.0
END
Single AC 101.25 % 1471.0 B 1489.33 21.37
CE/MEC QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line
270866 to 636610 ckt 1
EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-1
CONTINGENCY 'EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-1'
 OPEN BRANCH FROM BUS 636600 TO BUS 992010 CKT 1   /*SUB 39 3     345.0 - J2552 POI    345.0
END
Single AC 101.25 % 1471.0 B 1489.32 21.37
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P4_006-45-BT3-8___SRT-A
CONTINGENCY 'COMED_P4_006-45-BT3-8___SRT-A'
 TRIP BRANCH FROM BUS 270678 TO BUS 270679 CKT Z1   /*BYRON    ; B 345.0 - BYRON    ; R 345.0
 TRIP BRANCH FROM BUS 274768 TO BUS 270678 CKT 1    /*LEE CO EC;BP 345.0 - BYRON    ; B 345.0
END
Breaker AC 129.37 % 1837.0 STE 2376.53 159.47
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P4_006-45-BT3-4___SRT-A
CONTINGENCY 'COMED_P4_006-45-BT3-4___SRT-A'
 REMOVE UNIT 1 FROM BUS 274656                     /*BYRON    ;1U  25.0
 TRIP BRANCH FROM BUS 274768 TO BUS 270678 CKT 1   /*LEE CO EC;BP 345.0 - BYRON    ; B 345.0
END
Breaker AC 128.96 % 1837.0 STE 2369.08 159.42
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P4_144-45-BT7-8___SRT-A
CONTINGENCY 'COMED_P4_144-45-BT7-8___SRT-A'
 TRIP BRANCH FROM BUS 270916 TO BUS 270900 CKT 1   /*WAYNE    ; B 345.0 - TOLLWAY ; B  345.0
 TRIP BRANCH FROM BUS 275228 TO BUS 270916 CKT 1   /*WAYNE    ;1M 138.0 - WAYNE    ; B 345.0
 TRIP BRANCH FROM BUS 275228 TO BUS 272740 CKT 1   /*WAYNE    ;1M 138.0 - WAYNE    ; B 138.0
 TRIP BRANCH FROM BUS 275228 TO BUS 275328 CKT 1   /*WAYNE    ;1M 138.0 - WAYNE    ;1C  34.5
 TRIP BRANCH FROM BUS 965550 TO BUS 270916 CKT 1   /*AG1-423 TP   345.0 - WAYNE    ; B 345.0
END
Breaker AC 126.17 % 1837.0 STE 2317.77 148.37
CE BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line
270670 to 934730 ckt 1
COMED_P4_023-65-BT3-4___SRT-A
CONTINGENCY 'COMED_P4_023-65-BT3-4___SRT-A'
 TRIP BRANCH FROM BUS 270607 TO BUS 270630 CKT 1   /*COLLINS  ;   765.0 - PLANO    ;   765.0
 TRIP BRANCH FROM BUS 275168 TO BUS 270607 CKT 1   /*COLLINS  ;2M 345.0 - COLLINS  ;   765.0
 TRIP BRANCH FROM BUS 275168 TO BUS 270697 CKT 1   /*COLLINS  ;2M 345.0 - COLLINS  ; R 345.0
 TRIP BRANCH FROM BUS 275168 TO BUS 275268 CKT 1   /*COLLINS  ;2M 345.0 - COLLINS  ;2C  33.0
END
Breaker AC 110.23 % 1837.0 STE 2024.95 21.16
CE BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line
270670 to 934730 ckt 1
COMED_P4_023-65-BT2-3___SRT-A
CONTINGENCY 'COMED_P4_023-65-BT2-3___SRT-A'
 TRIP BRANCH FROM BUS 270607 TO BUS 270630 CKT 1   /*COLLINS  ;   765.0 - PLANO    ;   765.0
 TRIP BRANCH FROM BUS 270644 TO BUS 270607 CKT 1   /*WILTON   ;   765.0 - COLLINS  ;   765.0
END
Breaker AC 110.2 % 1837.0 STE 2024.34 21.16
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P4-6_111-345-R______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-R______SRT-A'
 DISCONNECT BUS 270731   /*ELECT JCT;4R 345.0
 DISCONNECT BUS 270733   /*ELECT JCT;3R 345.0
 DISCONNECT BUS 275183   /*ELECT JCT;3M 138.0
 DISCONNECT BUS 275184   /*ELECT JCT;4M 138.0
END
Breaker AC 124.69 % 1568.0 STE 1955.17 43.71
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P4-6_116-345-R______SRT-A
CONTINGENCY 'COMED_P4-6_116-345-R______SRT-A'
 DISCONNECT BUS 270767                                          /*GOODINGS ;1R 345.0
 DISCONNECT BUS 270769                                          /*GOODINGS ;2R 345.0
 DISCONNECT BUS 275240                                          /*GOODINGS ;1M 138.0
 TRIP BRANCH FROM BUS 270729 TO BUS 271385 TO BUS 275351 CKT 1  /*E FRANKFO; R 345.0 - E FRANKFO; R 138.0 - E FRANKFO;3C  34.5
END
Breaker AC 114.29 % 2297.0 STE 2625.26 25.79
CE AURORA EC;RP-ELECT JCT;4R 345.0 kV Ckt 1 line
274749 to 270731 ckt 1
COMED_P4-6_111-345-B______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-B______SRT-A'
 DISCONNECT BUS 270730                                          /*ELECT JCT; B 345.0
 DISCONNECT BUS 275182                                          /*ELECT JCT;1M 138.0
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Breaker AC 121.02 % 1568.0 STE 1897.54 43.49
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P4_120-45-L12002__SRT-A
CONTINGENCY 'COMED_P4_120-45-L12002__SRT-A'
 DISCONNECT BUS 275198                             /*LOMBARD  ;2M 138.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270753 CKT 1   /*LOMBARD  ; R 345.0 - ESS W407M;0T 345.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270781 CKT 1   /*LOMBARD  ; R 345.0 - ITASCA   ; R 345.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270809 CKT 1   /*LOMBARD  ; R 345.0 - LISLE    ; R 345.0
 TRIP BRANCH FROM BUS 275191 TO BUS 270781 CKT 1   /*ITASCA   ;2M 138.0 - ITASCA   ; R 345.0
 TRIP BRANCH FROM BUS 275191 TO BUS 271735 CKT 1   /*ITASCA   ;2M 138.0 - ITASCA   ; R 138.0
 TRIP BRANCH FROM BUS 275191 TO BUS 275291 CKT 1   /*ITASCA   ;2M 138.0 - ITASCA   ;2C  34.5
END
Breaker AC 120.37 % 1568.0 STE 1887.37 41.18
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P4_155-45-BT5-6___SRT-A
CONTINGENCY 'COMED_P4_155-45-BT5-6___SRT-A'
 TRIP BRANCH FROM BUS 270828 TO BUS 270890 CKT 1   /*NELSON   ; B 345.0 - ESS H471 ;   345.0
 TRIP BRANCH FROM BUS 270828 TO BUS 946150 CKT 1   /*NELSON   ; B 345.0 - AF1-280 TP   345.0
END
Breaker AC 114.65 % 1837.0 STE 2106.1 165.99
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P4_116-45-L11614__SRT-A
CONTINGENCY 'COMED_P4_116-45-L11614__SRT-A'
 DISCONNECT BUS 270769                             /*GOODINGS ;2R 345.0
 TRIP BRANCH FROM BUS 270667 TO BUS 270665 CKT 1   /*BLUE ISL ;RT 345.0 - BLUE ISL ; R 345.0
 TRIP BRANCH FROM BUS 270667 TO BUS 270927 CKT 1   /*BLUE ISL ;RT 345.0 - WILTON   ; R 345.0
 TRIP BRANCH FROM BUS 270769 TO BUS 270667 CKT 1   /*GOODINGS ;2R 345.0 - BLUE ISL ;RT 345.0
END
Breaker AC 109.22 % 2297.0 STE 2508.71 22.33
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P4_116-45-TR82____SRT-A
CONTINGENCY 'COMED_P4_116-45-TR82____SRT-A'
 DISCONNECT BUS 270769                                          /*GOODINGS ;2R 345.0
 TRIP BRANCH FROM BUS 270769 TO BUS 271565 TO BUS 275324 CKT 1  /*GOODINGS ;2R 345.0 - GOODINGS ; R 138.0 - GOODINGS ;2C  34.5
END
Breaker AC 105.87 % 2297.0 STE 2431.75 22.29
CE ELECT JCT;4R-ELECT JCT;3R 345.0 kV Ckt 1 line
270731 to 270733 ckt 1
COMED_P4-6_111-345-B______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-B______SRT-A'
 DISCONNECT BUS 270730                                          /*ELECT JCT; B 345.0
 DISCONNECT BUS 275182                                          /*ELECT JCT;1M 138.0
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Breaker AC 108.35 % 1837.0 STE 1990.39 29.31
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P4_116-45-L0303___SRT-A
CONTINGENCY 'COMED_P4_116-45-L0303___SRT-A'
 DISCONNECT BUS 270769                             /*GOODINGS ;2R 345.0
 REMOVE SWSHUNT FROM BUS 270827                    /*NEVADA   ; R 345.0
 TRIP BRANCH FROM BUS 936290 TO BUS 270827 CKT 1   /*AD2-038 TP   345.0 - NEVADA   ; R 345.0
END
Breaker AC 105.1 % 2297.0 STE 2414.16 22.3
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P4_112-45-BT4-5___SRT-A
CONTINGENCY 'COMED_P4_112-45-BT4-5___SRT-A'
 TRIP BRANCH FROM BUS 270666 TO BUS 270664 CKT 1   /*BLUE ISL ;BT 345.0 - BLUE ISL ; B 345.0
 TRIP BRANCH FROM BUS 270666 TO BUS 270926 CKT 1   /*BLUE ISL ;BT 345.0 - WILTON   ; B 345.0
 TRIP BRANCH FROM BUS 270770 TO BUS 270666 CKT 1   /*GOODINGS ;4B 345.0 - BLUE ISL ;BT 345.0
 TRIP BRANCH FROM BUS 270852 TO BUS 270704 CKT 1   /*PONTIAC  ; B 345.0 - LORETTO  ; B 345.0
END
Breaker AC 101.52 % 2297.0 STE 2331.94 28.16
CE WAYNE ; R-ESS W407M;9T 345.0 kV Ckt 1 line
270917 to 270751 ckt 1
COMED_P4-6_111-345-B______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-B______SRT-A'
 DISCONNECT BUS 270730                                          /*ELECT JCT; B 345.0
 DISCONNECT BUS 275182                                          /*ELECT JCT;1M 138.0
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Breaker AC 105.62 % 1568.0 STE 1656.05 43.97
CE ELECT JCT;4R-ELECT JCT;3R 345.0 kV Ckt 1 line
270731 to 270733 ckt 1
COMED_P4_167-45-BT8-9___SRT-A
CONTINGENCY 'COMED_P4_167-45-BT8-9___SRT-A'
 TRIP BRANCH FROM BUS 270802 TO BUS 270846 CKT 1                /*LASCO STA; B 345.0 - PLANO    ; B 345.0
 TRIP BRANCH FROM BUS 270846 TO BUS 270730 CKT 1                /*PLANO    ; B 345.0 - ELECT JCT; B 345.0
 TRIP BRANCH FROM BUS 270846 TO BUS 270847 CKT 1                /*PLANO    ; B 345.0 - PLANO    ; R 345.0
 TRIP BRANCH FROM BUS 270846 TO BUS 272278 TO BUS 275354 CKT 1  /*PLANO    ; B 345.0 - PLANO;1I     138.0 - PLANO;1C      34.5
 TRIP BRANCH FROM BUS 272250 TO BUS 272278 CKT 2                /*PLANO    ; B 138.0 - PLANO;1I     138.0
 TRIP BRANCH FROM BUS 272250 TO BUS 272278 CKT Z1               /*PLANO    ; B 138.0 - PLANO;1I     138.0
END
Breaker AC 100.78 % 1837.0 STE 1851.29 25.58
CE ESS W407M;9T-ESS W407K;9T 345.0 kV Ckt 1 line
270751 to 270743 ckt 1
COMED_P4-6_111-345-B______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-B______SRT-A'
 DISCONNECT BUS 270730                                          /*ELECT JCT; B 345.0
 DISCONNECT BUS 275182                                          /*ELECT JCT;1M 138.0
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Breaker AC 105.39 % 1568.0 STE 1652.47 43.97
CE ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line
270743 to 274749 ckt 1
COMED_P4-6_111-345-B______SRT-A
CONTINGENCY 'COMED_P4-6_111-345-B______SRT-A'
 DISCONNECT BUS 270730                                          /*ELECT JCT; B 345.0
 DISCONNECT BUS 275182                                          /*ELECT JCT;1M 138.0
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Breaker AC 104.91 % 1568.0 STE 1644.95 43.97
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P2-2_111_EJ-345R__3_SRT-A
CONTINGENCY 'COMED_P2-2_111_EJ-345R__3_SRT-A'
 DISCONNECT BUS 270733   /*ELECT JCT;3R 345.0
 DISCONNECT BUS 275183   /*ELECT JCT;3M 138.0
END
Bus AC 120.57 % 1568.0 STE 1890.53 40.62
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P2-2_120_LO-345R__2_SRT-A
CONTINGENCY 'COMED_P2-2_120_LO-345R__2_SRT-A'
 DISCONNECT BUS 275198                             /*LOMBARD  ;2M 138.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270753 CKT 1   /*LOMBARD  ; R 345.0 - ESS W407M;0T 345.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270781 CKT 1   /*LOMBARD  ; R 345.0 - ITASCA   ; R 345.0
 TRIP BRANCH FROM BUS 270813 TO BUS 270809 CKT 1   /*LOMBARD  ; R 345.0 - LISLE    ; R 345.0
END
Bus AC 120.01 % 1568.0 STE 1881.8 41.15
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
COMED_P2-2_116_GG-345R__2_SRT-A
CONTINGENCY 'COMED_P2-2_116_GG-345R__2_SRT-A'
 DISCONNECT BUS 270769   /*GOODINGS ;2R 345.0
END
Bus AC 105.87 % 2297.0 STE 2431.81 22.29
CE AURORA EC;RP-ELECT JCT;4R 345.0 kV Ckt 1 line
274749 to 270731 ckt 1
COMED_P2-2_111_EJ-345B__2_SRT-A
CONTINGENCY 'COMED_P2-2_111_EJ-345B__2_SRT-A'
 DISCONNECT BUS 275239                                          /*ELECT JCT;2M 138.0
 TRIP BRANCH FROM BUS 270730 TO BUS 270846 CKT 1                /*ELECT JCT; B 345.0 - PLANO    ; B 345.0
 TRIP BRANCH FROM BUS 270730 TO BUS 270916 CKT 1                /*ELECT JCT; B 345.0 - WAYNE    ; B 345.0
 TRIP BRANCH FROM BUS 270730 TO BUS 270928 CKT 1                /*ELECT JCT; B 345.0 - WOLFS    ; B 345.0
 TRIP BRANCH FROM BUS 270928 TO BUS 272794 TO BUS 275334 CKT 1  /*WOLFS    ; B 345.0 - WOLFS    ; B 138.0 - WOLFS    ;1C  34.5
END
Bus AC 103.43 % 1568.0 STE 1621.81 27.5
CE BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line
270670 to 934730 ckt 1
COMED_P7-1_345-L2001__B-S_+_345-L2003__R-S_SRT-A-1
CONTINGENCY 'COMED_P7-1_345-L2001__B-S_+_345-L2003__R-S_SRT-A-1'
 TRIP BRANCH FROM BUS 270671 TO BUS 270729 CKT 1   /*BRAIDWOOD; R 345.0 - E FRANKFO; R 345.0
 TRIP BRANCH FROM BUS 270728 TO BUS 270766 CKT 1   /*E FRANKFO; B 345.0 - GOODINGS ;3B 345.0
 TRIP BRANCH FROM BUS 270728 TO BUS 274750 CKT 1   /*E FRANKFO; B 345.0 - CRETE EC ;BP 345.0
 TRIP BRANCH FROM BUS 270728 TO BUS 958020 CKT 1   /*E FRANKFO; B 345.0 - AF2-096 TP   345.0
END
Tower AC 102.04 % 2397.0 ALDR 2445.85 13.81
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
COMED_P7-1_345-L13821_R-R_+_345-L18502AB-N_SRT-A
CONTINGENCY 'COMED_P7-1_345-L13821_R-R_+_345-L18502AB-N_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 270807 CKT 1   /*SILVER LK; R 345.0 - LIBERTYVI; R 345.0
 TRIP BRANCH FROM BUS 270900 TO BUS 270806 CKT 1   /*TOLLWAY ; B  345.0 - LIBERTYVI; B 345.0
END
Tower AC 100.41 % 2033.0 ALDR 2041.32 43.29
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P7-1_345-L13817TR-R_+_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P7-1_345-L13817TR-R_+_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270851 TO BUS 270883 CKT 1                /*PL VALLEY; R 345.0 - SILVER LK; R 345.0
 TRIP BRANCH FROM BUS 270851 TO BUS 272257 TO BUS 275309 CKT 1  /*PL VALLEY; R 345.0 - PL VALLEY; R 138.0 - PL VALLEY;1C  34.5
 TRIP BRANCH FROM BUS 270883 TO BUS 270807 CKT 1                /*SILVER LK; R 345.0 - LIBERTYVI; R 345.0
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1                /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
Tower AC 113.8 % 1912.0 C 2175.8 147.51
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
COMED_P7-1_345-L15616__-R_+_138-L15627_R-R_SRT-A-1
CONTINGENCY 'COMED_P7-1_345-L15616__-R_+_138-L15627_R-R_SRT-A-1'
 TRIP BRANCH FROM BUS 270694 TO BUS 276670 CKT 1   /*CHERRY VA; B 345.0 - GARDEN PR; R 345.0
 TRIP BRANCH FROM BUS 271193 TO BUS 271581 CKT 1   /*CHERRY VA; R 138.0 - ESS B200 ; R 138.0
 TRIP BRANCH FROM BUS 271581 TO BUS 962710 CKT 1   /*ESS B200 ; R 138.0 - AG1-120 TP   138.0
END
Tower AC 113.64 % 1912.0 C 2172.71 147.64

Summer Potential Congestion due to Local Energy Deliverability

PJM also studied the delivery of the energy portion of this interconnection request. Any problems identified below are likely to result in operational restrictions to the project under study. The developer can proceed with network upgrades to eliminate the operational restriction at their discretion by submitting an Upgrade Request into the New Service Request process.

Note: Only the most severely overloaded conditions are listed below. There is no guarantee of full delivery of energy for this project by fixing only the conditions listed in this section. With an Upgrade Request, a subsequent analysis will be performed which shall study all overload conditions associated with the overloaded element(s) identified.

Summer Potential Congestion due to Local Energy Deliverability
Area Facility Description Contingency Name Contingency Type DC|AC Final Cycle Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
CE GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line
276670 to 270883 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-4
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-4'
 TRIP BRANCH FROM BUS 270916 TO BUS 965550 CKT 1   /*WAYNE    ; B 345.0 - AG1-423 TP   345.0
END
OP AC 165.0 % 1479.0 B 2440.29 15.82
CE CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line
270694 to 276670 ckt 1
COMED_P1-2_345-L0626__B-R_SRT-A-4
CONTINGENCY 'COMED_P1-2_345-L0626__B-R_SRT-A-4'
 TRIP BRANCH FROM BUS 270916 TO BUS 965550 CKT 1   /*WAYNE    ; B 345.0 - AG1-423 TP   345.0
END
OP AC 154.7 % 1479.0 B 2288.06 15.82
CE AF2-041 TP-ELECT JCT; B 345.0 kV Ckt 1 line
957470 to 270730 ckt 1
Base Case OP AC 147.99 % 1334.0 A 1974.12 146.0
CE ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line
270730 to 270812 ckt 1
Base Case OP AC 133.91 % 1201.0 A 1608.29 39.5
CE AG1-423 TP-WAYNE ; B 345.0 kV Ckt 1 line
965550 to 270916 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
OP AC 128.39 % 2058.0 B 2642.19 16.93
CE LEE CO EC;BP-BYRON ; B 345.0 kV Ckt 1 line
274768 to 270678 ckt 1
COMED_P1-2_345-L15502_B-R_SRT-A-3
CONTINGENCY 'COMED_P1-2_345-L15502_B-R_SRT-A-3'
 TRIP BRANCH FROM BUS 957470 TO BUS 270730 CKT 1   /*AF2-041 TP   345.0 - ELECT JCT; B 345.0
END
OP AC 125.04 % 1726.0 B 2158.19 103.59
CE/MEC QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line
270866 to 636610 ckt 1
EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-2
CONTINGENCY 'EXT_636600 SUB 39 3 345 636605 MEC CORDOVA3 345 1 _SRT-S-2'
 OPEN BRANCH FROM BUS 992010 TO BUS 636605 CKT 1   /*J2552 POI    345.0 - MEC CORDOVA3 345.0
END
OP AC 124.54 % 1471.0 B 1831.95 32.06
CE AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line
962700 to 965550 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
OP AC 122.85 % 2058.0 B 2528.34 16.93
CE AF1-280 TP-LEE CO EC;BP 345.0 kV Ckt 1 line
946150 to 274768 ckt 1
COMED_P1-2_345-L15502_B-R_SRT-A-3
CONTINGENCY 'COMED_P1-2_345-L15502_B-R_SRT-A-3'
 TRIP BRANCH FROM BUS 957470 TO BUS 270730 CKT 1   /*AF2-041 TP   345.0 - ELECT JCT; B 345.0
END
OP AC 120.0 % 1479.0 B 1774.84 104.61
CE AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line
930480 to 962700 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
OP AC 115.17 % 2058.0 B 2370.13 16.93
CE ELECT JCT; B-PLANO ; B 345.0 kV Ckt 1 line
270730 to 270846 ckt 1
COMED_P1-2_345-L16703_R-S_SRT-A
CONTINGENCY 'COMED_P1-2_345-L16703_R-S_SRT-A'
 TRIP BRANCH FROM BUS 270846 TO BUS 270847 CKT 1   /*PLANO    ; B 345.0 - PLANO    ; R 345.0
 TRIP BRANCH FROM BUS 270847 TO BUS 270733 CKT 1   /*PLANO    ; R 345.0 - ELECT JCT;3R 345.0
END
OP AC 105.04 % 1341.0 B 1408.52 44.38
CE GOODINGS ;4B-GOODINGS ;3B 345.0 kV Ckt 1 line
270770 to 270766 ckt 1
Base Case OP AC 104.29 % 1754.0 A 1829.31 20.68
CE LEE CO EC;BP-BYRON ; B 345.0 kV Ckt 1 line
274768 to 270678 ckt 1
Base Case OP AC 103.88 % 1334.0 A 1385.74 39.51
CE BYRON ; B-AB1-089 TP 345.0 kV Ckt 1 line
270678 to 930480 ckt 1
COMED_P1-2_345-L97104__-R_SRT-A
CONTINGENCY 'COMED_P1-2_345-L97104__-R_SRT-A'
 TRIP BRANCH FROM BUS 270883 TO BUS 276670 CKT 1   /*SILVER LK; R 345.0 - GARDEN PR; R 345.0
END
OP AC 103.49 % 2058.0 B 2129.81 16.93
CE LASCO STA; B-BRAIDWOOD; B 345.0 kV Ckt 1 line
270802 to 270670 ckt 1
COMED_P1-2_345-L0103__R-S_SRT-A
CONTINGENCY 'COMED_P1-2_345-L0103__R-S_SRT-A'
 TRIP BRANCH FROM BUS 270803 TO BUS 270671 CKT 1   /*LASCO STA; R 345.0 - BRAIDWOOD; R 345.0
END
OP AC 102.08 % 1528.0 B 1559.72 16.44
CE LASCO STA; R-BRAIDWOOD; R 345.0 kV Ckt 1 line
270803 to 270671 ckt 1
COMED_P1-2_345-L0104__B-S_SRT-A
CONTINGENCY 'COMED_P1-2_345-L0104__B-S_SRT-A'
 TRIP BRANCH FROM BUS 270802 TO BUS 270670 CKT 1   /*LASCO STA; B 345.0 - BRAIDWOOD; B 345.0
END
OP AC 101.77 % 1528.0 B 1555.06 16.38

Winter Peak Analysis

PJM will start performing Winter Peak analysis in Transition Cycle #2.

Winter Potential Congestion due to Local Energy Deliverability

PJM will start performing Winter Peak analysis in Transition Cycle #2.

Light Load Analysis

At this time light load analysis not required for this project.

Light Load Potential Congestion due to Local Energy Deliverability

At this time light load analysis not required for this project.

Short Circuit Analysis

Short Circuit analysis is not performed as part of the Phase I System Impact Study. Short Circuit analysis will commence in the Phase II System Impact Study.

Stability Analysis

Stability analysis is not performed as part of the Phase I System Impact Study. Stability analysis will commence in the Phase II System Impact Study.

Reactive Power Analysis

Reactive Power analysis is not performed as part of the Phase I System Impact Study. Reactive Power analysis will commence in the Phase II System Impact Study.

Steady-State Voltage Analysis

Steady State Voltage analysis is not performed as part of the Phase I System Impact Study. Steady State Voltage analysis will commence in the Phase II System Impact Study.

New Service Request Dependencies

The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.

New Service Requests Dependencies
Project ID Project Name Status
AA1-018 Powerton-Goodings Grove In Service
AA1-146 Nelson In Service
AA2-030 Nelson In Service
AA2-123 Marengo 34kV In Service
AB1-089 Byron-Wayne 345kV #1 Suspended
AB1-122 Kendall-Tazewell & Dresden-Mole Creek In Service
AB2-047 Brokaw-Pontiac Midpoint In Service
AB2-070 Mt. Pulaski-Brokaw In Service
AC1-033 Kewanee 138 kV In Service
AC1-053 Lanesville-Brokaw Under Construction
AC1-168 Kewanee-Streator Suspended
AC1-204 Elwood In Service
AC1-214 Crescent Ridge In Service
AC2-154 Davis Creek 138kV Suspended
AC2-157 Sullivan 345 kV Engineering & Procurement
AD1-013 Twombly Road 138kV Engineering & Procurement
AD1-016 Marengo Suspended
AD1-031 Kewanee - E.D. Edwards 138 kV Engineering & Procurement
AD1-100 Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV Engineering & Procurement
AD1-129 Belvidere 34 kV Suspended
AD1-148 Brokaw-Lanesville In Service
AD2-038 Powerton-Nevada 345 kV Engineering & Procurement
AD2-047 Davis Creek 138 kV Engineering & Procurement
AD2-060 Davis Creek 138kV Suspended
AD2-066 Mazon-Crescent Ridge 138 kV Engineering & Procurement
AD2-100 Kincaid-Pana 345 kV Engineering & Procurement
AD2-131 Kincaid-Pana 345kV Engineering & Procurement
AD2-134 Shady Oaks Partially in Service - Under Construction
AD2-172 Lena 138kV In Service
AD2-194 Elwood 345 kV Under Construction
AE1-070 Elwood 345 kV Active
AE1-113 Mole Creek 345 kV Engineering & Procurement
AE1-114 Maryland-Lancaster 138 kV Active
AE1-134 Nelson 345 kV In Service
AE1-163 Powerton-Nevada 345 kV Engineering & Procurement
AE1-166 Loretto-Wilton & Braidwood-Davis Creek Active
AE1-172 Loretto-Wilton Center Active
AE1-205 McLean 345 kV Active
AE2-035 Lena 138 kV In Service
AE2-062 Romeoville 12 kV In Service
AE2-107 Haumesser Road 138 kV Active
AE2-152 Loretto-Wilton & Braidwood-Davis Creek Active
AE2-173 McLean 345 kV Active
AE2-223 McLean 345 kV Active
AE2-255 Molecreek 345 kV Engineering & Procurement
AE2-261 Kincaid-Pana 345 kV Active
AE2-281 Powerton-Nevada 345 kV Engineering & Procurement
AE2-321 Belvidere-Marengo 138 kV Active
AE2-341 Sandwich-Plano 138 kV Active
AF1-030 Sandwich-Plano 138 kV Active
AF1-048 Belvidere-Marengo Active
AF1-088 Sullivan 345 kV Active
AF1-090 Kincaid-Pana Active
AF1-200 Plano 345 kV Active
AF1-252 Kincaid-Pana Active
AF1-253 Kincaid-Pana Active
AF1-280 Nelson-Lee County Active
AF1-281 Nelson-Lee County Active
AF1-296 Garden Plain 138 kV Active
AF1-314 Lena - Lancaster 138 kV Active
AF1-318 Crescent Ridge-Corbin Active
AF1-330 Marengo 34.5 kV Active
AF1-331 Twombley Road Active
AF2-027 Zion Energy Center 345 kV Active
AF2-031 Calumet Active
AF2-032 Kincaid 345 kV Active
AF2-034 Kendall 345kV Active
AF2-069 Crescent Ridge 138 kV Active
AF2-070 Crescent Ridge 138 kV Active
AF2-095 Davis Creek 138 kV Active
AF2-096 Braidwood-East Frankfort 345 kV Active
AF2-128 Crescent Ridge-Corbin 138 kV Active
AF2-142 Nevada 345 kV Active
AF2-143 Powerton-Nevada 345 kV Active
AF2-182 Nelson-Lee County 345 kV II Active
AF2-183 Nelson-Lee County 345 kV Active
AF2-199 Nelson-Electric Junction 345 kV Active
AF2-200 Nelson-Electric Junction 345 kV Active
AF2-201 Lena - Lancaster 138 kV Active
AF2-225 McLean 345 kV Active
AF2-226 Katydid Road 345 kV Active
AF2-252 Blue Mound 345 kV Active
AF2-317 Hill Topper 345 kV In Service
AF2-319 Katydid Road 345 kV Active
AF2-329 Sandwich-Plano 138 kV Active
AF2-349 SILVER LAKE- CHERRY VALLEY 345 KV Active
AF2-350 Kensington 138 kV Active
AF2-351 Kensington 138 kV Active
AF2-352 Blue Mound 345 kV Active
AF2-359 Olive-University Park 345 kV Active
AF2-363 Cherry Valley-Glidden 138 kV Active
AF2-366 Crego Rd 138 kV Active
AF2-392 Nelson-Dixon 138 kV Active
AF2-393 Nelson-Dixon 138 kV Active
AF2-394 Nelson-Dixon 138 kV Active
AF2-441 Burnham 138kV Active
AG1-005 Corbin-Crescent Ridge 138 kV Active
AG1-044 Whiteside County In Service
AG1-118 Sugar Grove-Waterman 138kV Active
AG1-119 Wayne-Byron 345 kV Active
AG1-120 Glidden-Cherry Valley 138 kV Active
AG1-121 Kewanee-Streator 138 kV Active
AG1-127 Crego Rd 138 kV Active
AG1-236 Lanesville-Brokaw 345 kV Active
AG1-298 Calumet-Burnham 345 kV Active
AG1-321 Dresden-Pontiac Midpoint 345 kV Active
AG1-371 Nelson-Electric Junction 345 kV Active
AG1-373 Nelson-Electric Junction 345 kV Active
AG1-374 Blue Mound 345 kV Active
AG1-379 Minonk 345 kV Active
AG1-398 Brokaw-Lanesville 345 kV In Service
AG1-399 Blue Mound-Chestnut 345 kV Active
AG1-400 Blue Mound-Chestnut 345 kV Active
AG1-402 Blue Mound-Chestnut 345 kV Active
AG1-404 Blue Mound-Chestnut 345 kV Active
AG1-423 Byron-Wayne 345 kV Active
AG1-434 Electric Junction-Nelson 345 kV Active
AG1-435 Kewanee-Hennepin 138 kV Active
AG1-436 Olive-University Park 345 kV Active
AG1-447 Olive-University Park 345 kV Active
AG1-460 Kincaid-Pana 345 kV Active
AG1-462 Cordova 345 kV Active
AG1-478 Wilmington 34.5 kV Engineering & Procurement
AG1-512 University Park North 345 kV Active
AG1-513 Aurora 138 kV Suspended
AG1-535 State Line-S. Chicago Properties 138 kV Active
AG1-553 Cordova 345 kV Active
X3-005 Wildwood 12kV In Service
Z1-073 Mendota Hills In Service
Z1-108 McHenry 34kV In Service
Z2-081 Streator 34.5kV In Service

Affected Systems

In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with potential Affected System impacts. PJM initiates coordination with each Affected System Operator by providing a list of New Service Requests in the Cycle with potential impacts to their respective system. If the Affected System Operator indicates an Affected System Study is required, PJM will notify the Project Developer or Eligible Customer of the need for an Affected System Study. See below if any Affected System Operator requires a study for this project:

Midcontinent Independent System Operator (MISO) Study Pending
New York Independent System Operator (NYISO) Not required
Tennessee Valley Authority (TVA) Not required
Louisville Gas & Electric (LG&E) Not required
Duke Energy Carolinas (DUKE) Not required
Duke Energy Progress – East (CPLE) Not required
Duke Energy Progress – West (CPLW) Not required

System Reinforcements

Based on the Phase I analysis results, this project has potential cost responsibility for the following System Reinforcements:

AF2-041 System Reinforcements Cost Breakdown:
TO RTEP ID / TO ID Title MW Impact Percent Allocation Allocated Cost ($USD)
ComEd n6639.2 / CE_NUN_L15502_4 Electric Junction 345kV line reconductor, upgrade 1-34kV Circuit Breaker (CB) & associated motor operated disconnect switches, replace station conductor at both terminals. 97.3 MW 8.4% $11,852,899
ComEd n6639 / CE_NUN_15502 Re-conductor ComEd L15502 345 kV Line and station work. 97.3 MW 8.4% $6,124,984
ComEd (Pending) / CE_NUN_L15502.2 L15502 reconductor and station upgrades 97.3 MW 6.1% $5,181,833
MEC (Pending) / MEC_TC1_13804 Reconductor line with structure replacements as required and substation terminal equipment upgrades. 21.4 MW 11.7% $3,506,291
ComEd n7023.1 / CE_NUN_L11124.1 Reconductor Electric Junction - Lombard L11124 345 kV Line, station condctor work and 345KV CB replacement. 26.3 MW 5.9% $2,736,688
ComEd n6639.1 / CE_NUN_L15502_3 Replace station conductor at TSS111 EJ, replace MOD. Relay upgrades, re-conductor part of the line. 97.3 MW 8.4% $1,883,960
ComEd n6262 / CE_NUN_L2002_1 Re-conductor the 345kV line, upgrade station conductor at line terminals and upgrade 2-345kV CB’s at Station 20 Braidwood 21.2 MW 3.6% $1,882,149
AEP (Pending) / AEPIMJMS01 Rebuild Olive - AF2-359 345kV 18.0 MW 2.0% $689,400
AEP n5769.4 / AEPI0066a Rebuild/Recondutor 8.6 miles of ACSR ~ 954 ~ 45/7 ~ RAIL conductor to mitigate the overload 24.1 MW 2.8% $634,805
ComEd n7023.2 / CE_NUN_L11124_2 Replace 2-345 kV CB and Station conductor - Electric Junction - Lombard L11124 345 kV Line 26.3 MW 5.9% $411,975
ComEd n6279 / CE_NUN_116BT3-4 TSS 116 Replace 345 kV Circuit Breaker 25.8 MW 11.3% $363,082
ComEd n8414 / CE_NUN_11119.1 Electric Junction - Aurora 345 kV line - Re-conductor the line and upgrade station conductor 43.5 MW 4.7% $350,797
ComEd n8414.1 / CE_NUN_11119 Replacement of motor operated 345kV disconnect switches on L11119 at TSS 111 Electric Junction along with a new 345kV Circuit Breaker. 43.5 MW 4.7% $336,766
ComEd (Pending) / CE_NUN_L11124_3 Upgrade Disconnect Switches on Electric Junction - Lombard 345 kV 26.3 MW 5.9% $176,561
ComEd n8429 / CE_NUN_L14419_4 Reconductor ESS W407K - ESS W407M 345 kV line 44.0 MW 4.7% $155,498
ComEd n8430 / CE_NUN_L14419_2 Reconductor ESS W407M - Wayne 345 kV line 44.0 MW 4.7% $155,498
ComEd (Pending) / CE_NUN_L15502.1 Station reconductor upgrades. 97.3 MW 8.4% $152,069
ComEd (Pending) / CE_NUN_TSS 111 BT 3-4.1 Station conductor and switch upgrades at TSS 111 Electric Junction 29.3 MW 3.5% $133,867
ComEd n8389 / CE_NUN_116BT3-4_1 TSS 116 Replace Station Conductor 25.8 MW 11.3% $113,463
AEP n5769.5 / AEP_AD2_REF_r0001 Replace 4 Dumont switches (3000 A). 24.1 MW 2.8% $88,577
ComEd n8428 / CE_NUN_L14419_1 Reconductor the Auora EC - ESS W407K 345 kV Line. 44.0 MW 4.7% $51,833
AEP (Pending) / AEPIMJMS02 Replace 2156 KCM ACSR 84/19 at Olive 18.0 MW 2.0% $22,430
AEP n5769.1 Perform engineering study for CT limits , and and relay compliance trip limits at Dumont substation 13.8 MW 2.0% $15,271
AEP n5769.3 Replace 11 jumpers/risers at Dumont substation 24.1 MW 2.8% $10,149
AEP (Pending) / AEPIMJMS04 Replace 2874 KCM ACSR 72/7 at Olive 18.0 MW 2.0% $9,031
AEP (Pending) / AEPIMJMS03 Adjust Relay Compliance Trip Limit at Olive 18.0 MW 2.0% $492
Grand Total: $37,040,368
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n6639.2 / CE_NUN_L15502_4 Electric Junction 345kV line reconductor, upgrade 1-34kV Circuit Breaker (CB) & associated motor operated disconnect switches, replace station conductor at both terminals. $140,300,000 $11,852,899 36 to 42 Months

Contributor

Description: Replace existing 345kV line conductor and possibly tower structures for approx. 27 miles, Sag mitigation on existing 345kV line conductor for up to 13 miles, Upgrade station 345kV conductor and motor operated switches, Upgrade 345kV relay scheme at one terminal substation. Tower work will be identified during the Facility Study Phase.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (Any)
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) A 1683.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) B 2068.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) C 2564.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) STE 2367.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) A 1683.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) B 2068.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) C 2564.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) STE 2367.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 22.1 MW 1.9% $2,687,979
AF1-280 55.1 MW 4.8% $6,710,631
AF1-296 49.0 MW 4.3% $5,966,940
AF1-314 28.5 MW 2.5% $3,476,362
AF2-041 97.3 MW 8.4% $11,852,899
AF2-182 137.1 MW 11.9% $16,696,449
AF2-183 26.9 MW 2.3% $3,276,770
AF2-199 53.2 MW 4.6% $6,473,166
AF2-200 118.1 MW 10.3% $14,384,760
AF2-201 26.8 MW 2.3% $3,263,131
AF2-349 32.4 MW 2.8% $3,942,645
AF2-392 53.1 MW 4.6% $6,464,155
AG1-119 42.3 MW 3.7% $5,147,870
AG1-121 27.7 MW 2.4% $3,371,512
AG1-371 16.2 MW 1.4% $1,975,463
AG1-423 28.2 MW 2.4% $3,431,913
AG1-434 121.9 MW 10.6% $14,839,718
AG1-435 19.7 MW 1.7% $2,402,899
AG1-462 87.5 MW 7.6% $10,658,512
AG1-553 109.0 MW 9.5% $13,276,226
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n6639 / CE_NUN_15502 Re-conductor ComEd L15502 345 kV Line and station work. $72,500,000 $6,124,984 30 Months

Contributor

Description: The upgrade will be to re-conductor a portion of the line, 1-345kV circuit breaker and associated switches and upgrade of station conductor, TSS 155 Nelson Bus Tie 3 & -4 disconnect switches.Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (Any)
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) ALDR 2801.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) ALDR 2801.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) C 2436.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 22.1 MW 1.9% $1,389,013
AF1-280 55.1 MW 4.8% $3,467,717
AF1-296 49.0 MW 4.3% $3,083,415
AF1-314 28.5 MW 2.5% $1,796,409
AF2-041 97.3 MW 8.4% $6,124,984
AF2-182 137.1 MW 11.9% $8,627,887
AF2-183 26.9 MW 2.3% $1,693,270
AF2-199 53.2 MW 4.6% $3,345,008
AF2-200 118.1 MW 10.3% $7,433,322
AF2-201 26.8 MW 2.3% $1,686,222
AF2-349 32.4 MW 2.8% $2,037,361
AF2-392 53.1 MW 4.6% $3,340,351
AG1-119 42.3 MW 3.7% $2,660,161
AG1-121 27.7 MW 2.4% $1,742,228
AG1-371 16.2 MW 1.4% $1,020,820
AG1-423 28.2 MW 2.4% $1,773,441
AG1-434 121.9 MW 10.6% $7,668,422
AG1-435 19.7 MW 1.7% $1,241,698
AG1-462 87.5 MW 7.6% $5,507,784
AG1-553 109.0 MW 9.5% $6,860,487
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_L15502.2 L15502 reconductor and station upgrades $85,500,000 $5,181,833 24 to 36 Months

Contributor

Description: Reconductor ~ 57 miles of overhead conductor, transmission tower replacement might be required. This will be determined during the network upgrade Facility Study per the PJM process. The estimate provided here does not include the tower work. Station conductor and 1-345KV BT 3-4 CB switch upgrade.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) STE 2385.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 44.1 MW 2.7% $2,350,253
AF1-280 82.7 MW 5.1% $4,400,616
AF1-296 98.0 MW 6.1% $5,217,236
AF1-314 28.5 MW 1.8% $1,519,791
AF2-041 97.3 MW 6.1% $5,181,833
AF2-182 238.0 MW 14.8% $12,671,328
AF2-183 53.8 MW 3.4% $2,865,066
AF2-199 53.2 MW 3.3% $2,829,929
AF2-200 118.1 MW 7.4% $6,288,708
AF2-201 26.8 MW 1.7% $1,426,571
AF2-349 32.4 MW 2.0% $1,723,640
AF2-392 106.2 MW 6.6% $5,651,979
AG1-119 42.3 MW 2.6% $2,250,538
AG1-121 53.9 MW 3.4% $2,867,995
AG1-371 16.2 MW 1.0% $863,630
AG1-423 28.2 MW 1.8% $1,500,359
AG1-434 121.9 MW 7.6% $6,487,606
AG1-435 39.5 MW 2.5% $2,100,992
AG1-462 148.3 MW 9.2% $7,894,798
AG1-553 176.7 MW 11.0% $9,407,135
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
MEC (Pending) / MEC_TC1_13804 Reconductor line with structure replacements as required and substation terminal equipment upgrades. $30,000,000 $3,506,291 36 Months

Contributor

Description: Reconductor line with structure replacements as required and substation terminal equipment upgrades.

Flowgates Addressed by this Reinforcement
Facility Contingency
QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line (All) A 1740.0 MVA
QUAD 6-7-SUB 91 3 345.0 kV Ckt 1 line (All) B 1740.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n7023.1 / CE_NUN_L11124.1 Reconductor Electric Junction - Lombard L11124 345 kV Line, station condctor work and 345KV CB replacement. $46,500,000 $2,736,688 30 to 36 Months

Contributor

Description: The upgrade will be to reconductor the line along with station conductor work at both line terminals and 2-345KV BT Circuit Breakers to be upgraded. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.Upgrade 345KV disconnect switches at both terminals.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) A 1334.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) ALDR 2396.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) B 1726.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) C 2084.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) STE 1837.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-341 16.7 MW 3.7% $1,735,841
AF1-200 155.4 MW 34.7% $16,151,988
AF1-280 17.6 MW 3.9% $1,833,743
AF2-041 26.3 MW 5.9% $2,736,688
AF2-182 13.2 MW 2.9% $1,369,903
AF2-200 32.4 MW 7.2% $3,364,946
AF2-349 18.1 MW 4.0% $1,883,110
AF2-392 17.5 MW 3.9% $1,822,207
AG1-118 38.2 MW 8.5% $3,967,948
AG1-119 28.3 MW 6.3% $2,938,105
AG1-423 18.9 MW 4.2% $1,963,968
AG1-434 28.9 MW 6.5% $3,007,114
AG1-462 17.0 MW 3.8% $1,762,031
AG1-553 18.9 MW 4.2% $1,962,409
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n6639.1 / CE_NUN_L15502_3 Replace station conductor at TSS111 EJ, replace MOD. Relay upgrades, re-conductor part of the line. $22,300,000 $1,883,960 36 Months

Contributor

Description: SSTE is 1837MVA. Replace station conductor at TSS111 EJ, replace MOD. Relay upgrades, re-conductor part of the line.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (Any)
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) A 1683.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) B 2068.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) C 2308.0 MVA
ELECT JCT; B-AF2-041 TAP 345.0 kV Ckt 1 line (All) STE 2172.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) A 1683.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) B 2068.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) C 2308.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) STE 2172.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 22.1 MW 1.9% $427,241
AF1-280 55.1 MW 4.8% $1,066,622
AF1-296 49.0 MW 4.3% $948,416
AF1-314 28.5 MW 2.5% $552,551
AF2-041 97.3 MW 8.4% $1,883,960
AF2-182 137.1 MW 11.9% $2,653,819
AF2-183 26.9 MW 2.3% $520,827
AF2-199 53.2 MW 4.6% $1,028,878
AF2-200 118.1 MW 10.3% $2,286,387
AF2-201 26.8 MW 2.3% $518,659
AF2-349 32.4 MW 2.8% $626,664
AF2-392 53.1 MW 4.6% $1,027,446
AG1-119 42.3 MW 3.7% $818,229
AG1-121 27.7 MW 2.4% $535,885
AG1-371 16.2 MW 1.4% $313,990
AG1-423 28.2 MW 2.4% $545,486
AG1-434 121.9 MW 10.6% $2,358,701
AG1-435 19.7 MW 1.7% $381,929
AG1-462 87.5 MW 7.6% $1,694,119
AG1-553 109.0 MW 9.5% $2,110,191
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n6262 / CE_NUN_L2002_1 Re-conductor the 345kV line, upgrade station conductor at line terminals and upgrade 2-345kV CB’s at Station 20 Braidwood $52,400,000 $1,882,149 24 to 30 Months

Contributor

Description: The upgrade will be to replace 2-345kV Circuit Breakers, station conductor and L2002 re-conductoring required. Possible tower replacement required. The estimate provided does not include the potential tower replacement cost. This cost will be determined during the network upgrade Facility Study. A preliminary 30-36 month timeline contingent upon outage coordination with Dresden Nuclear Station.

Flowgates Addressed by this Reinforcement
Facility Contingency
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (Any)
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) A 1826.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) ALDR 2748.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) B 2070.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) C 2390.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) STE 2385.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) A 1826.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) ALDR 2748.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) B 2070.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) C 2390.0 MVA
BRAIDWOOD; B-AD1-100 TAP 345.0 kV Ckt 1 line (All) STE 2385.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AF1-200 339.3 MW 57.6% $30,184,843
AF2-041 21.2 MW 3.6% $1,882,149
AF2-096 134.3 MW 22.8% $11,951,948
AF2-182 20.1 MW 3.4% $1,789,892
AF2-349 23.0 MW 3.9% $2,047,179
AG1-118 27.2 MW 4.6% $2,419,143
AG1-119 23.9 MW 4.1% $2,124,846
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP (Pending) / AEPIMJMS01 Rebuild Olive - AF2-359 345kV $35,000,000 $689,400 30 to 36 Months

Contributor

Description: Rebuild the ~7.3 mile 345 kV line section between Olive and AF2-359 POI. The standard conductor for 345kV lines is 2-bundle 954 ACSR 45/7 RAIL.

Flowgates Addressed by this Reinforcement
Facility Contingency
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM A 1025.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM B 1318.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN A 1298.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN B 1370.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 15.0 MW 1.6% $575,361
AE1-114 11.2 MW 1.2% $429,990
AE1-172 19.6 MW 2.1% $748,275
AE2-321 10.3 MW 1.1% $394,604
AE2-341 16.1 MW 1.8% $617,595
AF1-030 10.8 MW 1.2% $411,743
AF1-200 222.8 MW 24.4% $8,525,135
AF1-296 14.4 MW 1.6% $552,408
AF1-314 16.1 MW 1.8% $615,912
AF1-318 21.2 MW 2.3% $809,484
AF2-041 18.0 MW 2.0% $689,400
AF2-095 22.3 MW 2.4% $851,756
AF2-096 42.5 MW 4.6% $1,624,553
AF2-142 17.1 MW 1.9% $653,478
AF2-143 16.3 MW 1.8% $623,410
AF2-200 12.0 MW 1.3% $459,600
AF2-201 12.8 MW 1.4% $490,434
AF2-349 18.4 MW 2.0% $702,445
AF2-350 11.1 MW 1.2% $425,897
AF2-392 14.6 MW 1.6% $559,294
AF2-441 17.3 MW 1.9% $661,436
AG1-118 31.3 MW 3.4% $1,195,978
AG1-119 18.4 MW 2.0% $705,812
AG1-121 20.7 MW 2.3% $790,356
AG1-127 9.9 MW 1.1% $377,389
AG1-298 43.9 MW 4.8% $1,680,941
AG1-379 14.0 MW 1.5% $534,810
AG1-423 20.5 MW 2.2% $784,694
AG1-434 15.2 MW 1.7% $582,247
AG1-435 13.9 MW 1.5% $533,663
AG1-436 106.5 MW 11.6% $4,075,919
AG1-447 46.7 MW 5.1% $1,784,996
AG1-553 13.9 MW 1.5% $530,985
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n5769.4 / AEPI0066a Rebuild/Recondutor 8.6 miles of ACSR ~ 954 ~ 45/7 ~ RAIL conductor to mitigate the overload $22,360,000 $634,805 24 to 36 Months

Contributor

Description: The existing 2-954 45/7 (Rail) ACSR has SN/SE ratings of 1409/1888 MVA if no clearance issues are identified. This conductor is the maximum the present structure class was intended to carry. It may be possible to install larger or higher-tensioned conductor without rebuilding the entire line, but detailed mechanical loading analysis will be required to determine if (or how many of) the existing structures could be re-used. Cost estimate is $22.3 M assuming a complete wreck and rebuild of the AEP owned portion of the line. Using 2-954 ACSS, the new conductor rating will be 2650 MVA for both SN and SE. New overall AEP end line ratings after upgrade: S/N: 1740 MVA S/E: 2034 MVA. PJM Network Upgrade N5769.4.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1740.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 2034.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 20.0 MW 2.3% $524,683
AE1-114 15.1 MW 1.8% $397,575
AE1-172 26.8 MW 3.2% $704,433
AE2-341 14.4 MW 1.7% $379,484
AF1-200 296.9 MW 34.9% $7,807,478
AF1-280 17.6 MW 2.1% $462,680
AF1-314 21.6 MW 2.5% $568,753
AF2-041 24.1 MW 2.8% $634,805
AF2-095 21.4 MW 2.5% $561,732
AF2-096 38.1 MW 4.5% $1,002,719
AF2-142 12.7 MW 1.5% $333,837
AF2-143 12.4 MW 1.5% $325,396
AF2-182 23.1 MW 2.7% $607,905
AF2-200 16.1 MW 1.9% $423,212
AF2-349 24.5 MW 2.9% $645,401
AF2-392 19.7 MW 2.3% $517,741
AF2-441 14.9 MW 1.7% $390,554
AG1-118 25.1 MW 2.9% $658,733
AG1-119 24.7 MW 2.9% $648,452
AG1-298 92.4 MW 10.9% $2,429,492
AG1-321 17.0 MW 2.0% $445,930
AG1-379 18.7 MW 2.2% $492,709
AG1-423 16.4 MW 1.9% $432,468
AG1-434 20.5 MW 2.4% $538,251
AG1-535 16.2 MW 1.9% $425,578
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n7023.2 / CE_NUN_L11124_2 Replace 2-345 kV CB and Station conductor - Electric Junction - Lombard L11124 345 kV Line $7,000,000 $411,975 30 Months

Contributor

Description: In addition to CE_NUN_11124_1, the upgrade will be to replace 2-345kV Circuit Breakers and station conductor. Upon completion of the upgrade the ratings will be 1461/1656/1909/1912 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) A 1461.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) ALDR 2198.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) B 1656.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) C 1912.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) STE 1909.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-341 16.7 MW 3.7% $261,309
AF1-200 155.4 MW 34.7% $2,431,482
AF1-280 17.6 MW 3.9% $276,047
AF2-041 26.3 MW 5.9% $411,975
AF2-182 13.2 MW 2.9% $206,222
AF2-200 32.4 MW 7.2% $506,551
AF2-349 18.1 MW 4.0% $283,479
AF2-392 17.5 MW 3.9% $274,311
AG1-118 38.2 MW 8.5% $597,326
AG1-119 28.3 MW 6.3% $442,295
AG1-423 18.9 MW 4.2% $295,651
AG1-434 28.9 MW 6.5% $452,684
AG1-462 17.0 MW 3.8% $265,252
AG1-553 18.9 MW 4.2% $295,416
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n6279 / CE_NUN_116BT3-4 TSS 116 Replace 345 kV Circuit Breaker $3,200,000 $363,082 24 Months

Contributor

Description: The upgrade will be to replace the 345kV BT3-4 circuit breaker at TSS 116. A preliminary estimate for the upgrade is $3.2M. A preliminary construction timeline id 24 months. Upon completion of the upgrade the ratings will be 1754/2246/2297/2488 MVA (SN/SLTE/SSTE/SLD.

Flowgates Addressed by this Reinforcement
Facility Contingency
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) A 1754.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) B 2246.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) C 2488.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AF2-041 25.8 MW 11.3% $363,082
AF2-182 28.0 MW 12.3% $394,584
AF2-349 32.0 MW 14.1% $451,100
AG1-119 31.6 MW 13.9% $445,174
AG1-121 24.1 MW 10.6% $339,856
AG1-379 32.6 MW 14.4% $459,222
AG1-462 25.1 MW 11.0% $353,397
AG1-553 28.0 MW 12.3% $393,585
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8414 / CE_NUN_11119.1 Electric Junction - Aurora 345 kV line - Re-conductor the line and upgrade station conductor $7,500,000 $350,797 30 to 36 Months

Contributor

Description: Re-conductor the line, upgrade station conductor at TSS 111 Electric Junction, upgrade 345KV L11119 circuit breaker TSS 111 - 345KV disconnect switches. The potential for tower replacement for the reconductoring is possible. This will not be identified until the Network Upgrade Facility Study is performed. If tower replacement is required, the estimate and timeline will be amended.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) A 1334.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) B 1726.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) C 2084.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) STE 1837.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 27.4 MW 2.9% $221,157
AE2-321 24.9 MW 2.7% $201,055
AF1-200 188.2 MW 20.2% $1,518,528
AF1-280 36.4 MW 3.9% $293,556
AF1-296 28.2 MW 3.0% $227,352
AF1-314 42.8 MW 4.6% $345,006
AF2-041 43.5 MW 4.7% $350,797
AF2-182 54.6 MW 5.9% $440,338
AF2-200 32.2 MW 3.5% $259,845
AF2-201 40.1 MW 4.3% $323,847
AF2-349 73.6 MW 7.9% $593,622
AF2-392 31.1 MW 3.3% $250,819
AG1-118 28.0 MW 3.0% $226,086
AG1-119 95.0 MW 10.2% $766,201
AG1-120 17.7 MW 1.9% $142,442
AG1-423 63.5 MW 6.8% $512,616
AG1-434 32.2 MW 3.5% $260,047
AG1-462 33.2 MW 3.6% $268,097
AG1-553 37.0 MW 4.0% $298,590
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8414.1 / CE_NUN_11119 Replacement of motor operated 345kV disconnect switches on L11119 at TSS 111 Electric Junction along with a new 345kV Circuit Breaker. $7,200,000 $336,766 30 Months

Contributor

Description: This upgrade will require replacement of motor operated 345kV disconnect switches on L11119 at TSS 111 Electric Junction along with a new 345kV Circuit Breaker. . Upon completion of the upgrade he ratings will be 1754/2246/2297/2488 MVA (SN/SLTE/SSTE/SLD) .

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) A 1754.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) B 2246.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) C 2488.0 MVA
ELECT JCT;4R-AURORA EC;RP 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 27.4 MW 2.9% $212,311
AE2-321 24.9 MW 2.7% $193,013
AF1-200 188.2 MW 20.2% $1,457,787
AF1-280 36.4 MW 3.9% $281,814
AF1-296 28.2 MW 3.0% $218,258
AF1-314 42.8 MW 4.6% $331,205
AF2-041 43.5 MW 4.7% $336,766
AF2-182 54.6 MW 5.9% $422,724
AF2-200 32.2 MW 3.5% $249,451
AF2-201 40.1 MW 4.3% $310,893
AF2-349 73.6 MW 7.9% $569,877
AF2-392 31.1 MW 3.3% $240,786
AG1-118 28.0 MW 3.0% $217,043
AG1-119 95.0 MW 10.2% $735,553
AG1-120 17.7 MW 1.9% $136,744
AG1-423 63.5 MW 6.8% $492,111
AG1-434 32.2 MW 3.5% $249,645
AG1-462 33.2 MW 3.6% $257,374
AG1-553 37.0 MW 4.0% $286,646
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_L11124_3 Upgrade Disconnect Switches on Electric Junction - Lombard 345 kV $3,000,000 $176,561 24 Months

Contributor

Description: Upgrade 345Kv motor operated disconnect switches at both line terminals. Upon completion the limit ratings will be 1560/1802/2083/2477 MVA (SN/ALTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) A 1560.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) B 1802.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) C 2477.0 MVA
ELECT JCT; B-LOMBARD ; B 345.0 kV Ckt 1 line (All) STE 2083.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-341 16.7 MW 3.7% $111,990
AF1-200 155.4 MW 34.7% $1,042,064
AF1-280 17.6 MW 3.9% $118,306
AF2-041 26.3 MW 5.9% $176,561
AF2-182 13.2 MW 2.9% $88,381
AF2-200 32.4 MW 7.2% $217,093
AF2-349 18.1 MW 4.0% $121,491
AF2-392 17.5 MW 3.9% $117,562
AG1-118 38.2 MW 8.5% $255,997
AG1-119 28.3 MW 6.3% $189,555
AG1-423 18.9 MW 4.2% $126,708
AG1-434 28.9 MW 6.5% $194,007
AG1-462 17.0 MW 3.8% $113,679
AG1-553 18.9 MW 4.2% $126,607
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8429 / CE_NUN_L14419_4 Reconductor ESS W407K - ESS W407M 345 kV line $3,300,000 $155,498 30 Months

Contributor

Description: ComEd 345kV L14419_1 SSTE rating is 1568 MVA. The upgrade will be to reconductor the line. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.A preliminary estimate for the upgrade is $3.3M with a estimated construction timeline of 30 months. Upon completion of the upgrade the rating limit will be 1334/1726/1837/2084 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
ESS W407K;9T-ESS W407M;9T 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ESS W407K;9T-ESS W407M;9T 345.0 kV Ckt 1 line (All) A 1334.0 MVA
ESS W407K;9T-ESS W407M;9T 345.0 kV Ckt 1 line (All) B 1726.0 MVA
ESS W407K;9T-ESS W407M;9T 345.0 kV Ckt 1 line (All) C 2084.0 MVA
ESS W407K;9T-ESS W407M;9T 345.0 kV Ckt 1 line (All) STE 1837.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 27.7 MW 3.0% $97,908
AE2-321 25.1 MW 2.7% $88,774
AF1-200 184.5 MW 19.8% $652,381
AF1-280 36.8 MW 3.9% $129,962
AF1-296 28.6 MW 3.1% $101,013
AF1-314 43.1 MW 4.6% $152,591
AF2-041 44.0 MW 4.7% $155,498
AF2-182 55.1 MW 5.9% $194,943
AF2-200 32.6 MW 3.5% $115,184
AF2-201 40.5 MW 4.3% $143,234
AF2-349 74.1 MW 7.9% $262,145
AF2-392 31.5 MW 3.4% $111,226
AG1-118 28.6 MW 3.1% $101,020
AG1-119 95.5 MW 10.2% $337,802
AG1-120 17.9 MW 1.9% $63,199
AG1-423 63.9 MW 6.8% $225,996
AG1-434 32.6 MW 3.5% $115,268
AG1-462 33.7 MW 3.6% $119,151
AG1-553 37.5 MW 4.0% $132,703
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8430 / CE_NUN_L14419_2 Reconductor ESS W407M - Wayne 345 kV line $3,300,000 $155,498 30 Months

Contributor

Description: The upgrade will be to reconductor the line. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.A preliminary estimate for the upgrade is $3.3M with a estimated construction timeline of 30 months. Upon completion of the upgrade the rating limit will be 1334/1726/1837/2084 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
ESS W407M;9T-WAYNE ; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ESS W407M;9T-WAYNE ; R 345.0 kV Ckt 1 line (All) A 1334.0 MVA
ESS W407M;9T-WAYNE ; R 345.0 kV Ckt 1 line (All) B 1726.0 MVA
ESS W407M;9T-WAYNE ; R 345.0 kV Ckt 1 line (All) C 2084.0 MVA
ESS W407M;9T-WAYNE ; R 345.0 kV Ckt 1 line (All) STE 1837.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 27.7 MW 3.0% $97,908
AE2-321 25.1 MW 2.7% $88,774
AF1-200 184.5 MW 19.8% $652,381
AF1-280 36.8 MW 3.9% $129,962
AF1-296 28.6 MW 3.1% $101,013
AF1-314 43.1 MW 4.6% $152,591
AF2-041 44.0 MW 4.7% $155,498
AF2-182 55.1 MW 5.9% $194,943
AF2-200 32.6 MW 3.5% $115,184
AF2-201 40.5 MW 4.3% $143,234
AF2-349 74.1 MW 7.9% $262,145
AF2-392 31.5 MW 3.4% $111,226
AG1-118 28.6 MW 3.1% $101,020
AG1-119 95.5 MW 10.2% $337,802
AG1-120 17.9 MW 1.9% $63,199
AG1-423 63.9 MW 6.8% $225,996
AG1-434 32.6 MW 3.5% $115,268
AG1-462 33.7 MW 3.6% $119,151
AG1-553 37.5 MW 4.0% $132,703
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_L15502.1 Station reconductor upgrades. $1,800,000 $152,069 20 to 24 Months

Contributor

Description: Terminal stataion conductor work at the two line terminals and motor operated disc switch upgrades

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
ELECT JCT; B-AF2-041 TP 345.0 kV Ckt 1 line (All) STE 2107.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 22.1 MW 1.9% $34,486
AF1-280 55.1 MW 4.8% $86,095
AF1-296 49.0 MW 4.3% $76,554
AF1-314 28.5 MW 2.5% $44,601
AF2-041 97.3 MW 8.4% $152,069
AF2-182 137.1 MW 11.9% $214,210
AF2-183 26.9 MW 2.3% $42,040
AF2-199 53.2 MW 4.6% $83,048
AF2-200 118.1 MW 10.3% $184,551
AF2-201 26.8 MW 2.3% $41,865
AF2-349 32.4 MW 2.8% $50,583
AF2-392 53.1 MW 4.6% $82,933
AG1-119 42.3 MW 3.7% $66,045
AG1-121 27.7 MW 2.4% $43,255
AG1-371 16.2 MW 1.4% $25,344
AG1-423 28.2 MW 2.4% $44,030
AG1-434 121.9 MW 10.6% $190,388
AG1-435 19.7 MW 1.7% $30,828
AG1-462 87.5 MW 7.6% $136,745
AG1-553 109.0 MW 9.5% $170,329
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_TSS 111 BT 3-4.1 Station conductor and switch upgrades at TSS 111 Electric Junction $3,800,000 $133,867 24 to 28 Months

Contributor

Description: Upgrade station conductor 345KV bus 3 & bus4 at TSS 111 Electric Junction. Upgrade 345KV Bus Tie 3-4 bus 3 & bus 4 disconnect sdwitches at TSS 111 Electric Junction.

Flowgates Addressed by this Reinforcement
Facility Contingency
ELECT JCT;4R-ELECT JCT;3R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ELECT JCT;4R-ELECT JCT;3R 345.0 kV Ckt 1 line (All) STE 2083.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AF1-200 383.2 MW 46.1% $1,750,398
AF1-280 24.2 MW 2.9% $110,588
AF1-296 19.4 MW 2.3% $88,583
AF1-314 27.7 MW 3.3% $126,464
AF2-041 29.3 MW 3.5% $133,867
AF2-182 36.3 MW 4.4% $165,880
AF2-200 21.7 MW 2.6% $99,161
AF2-201 26.0 MW 3.1% $118,709
AF2-349 46.5 MW 5.6% $212,297
AF2-392 21.0 MW 2.5% $96,082
AG1-118 21.4 MW 2.6% $97,749
AG1-119 62.8 MW 7.5% $286,799
AG1-423 42.0 MW 5.1% $191,913
AG1-434 21.7 MW 2.6% $99,238
AG1-462 23.0 MW 2.8% $105,157
AG1-553 25.6 MW 3.1% $117,115
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8389 / CE_NUN_116BT3-4_1 TSS 116 Replace Station Conductor $1,000,000 $113,463 24 Months

Contributor

Description: ComEd 345kV BT3-4 at TSS 116 SSTE rating is 2083 MVA. The upgrade will be to replace the station conductor at TSS 116. A preliminary estimate for the upgrade is $1M. A preliminary construction timeline is 24 months. Upon completion of the upgrade the ratings will be 2236/2874/3009/3358 MVA (SN/SLTE/SSTE/SLD.

Flowgates Addressed by this Reinforcement
Facility Contingency
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) A 2236.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) B 2874.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) C 3358.0 MVA
GOODINGS ;3B-GOODINGS ;4B 345.0 kV Ckt 1 line (All) STE 3009.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AF2-041 25.8 MW 11.3% $113,463
AF2-182 28.0 MW 12.3% $123,308
AF2-349 32.0 MW 14.1% $140,969
AG1-119 31.6 MW 13.9% $139,117
AG1-121 24.1 MW 10.6% $106,205
AG1-379 32.6 MW 14.4% $143,507
AG1-462 25.1 MW 11.0% $110,437
AG1-553 28.0 MW 12.3% $122,995
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n5769.5 / AEP_AD2_REF_r0001 Replace 4 Dumont switches (3000 A). $3,120,000 $88,577 TBD

Contributor

Description: Replace 4 Dumont switches (3000 A). Estimated cost is $2,400,000.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 2387.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 2387.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 20.0 MW 2.3% $73,212
AE1-114 15.1 MW 1.8% $55,476
AE1-172 26.8 MW 3.2% $98,293
AE2-341 14.4 MW 1.7% $52,951
AF1-200 296.9 MW 34.9% $1,089,416
AF1-280 17.6 MW 2.1% $64,560
AF1-314 21.6 MW 2.5% $79,361
AF2-041 24.1 MW 2.8% $88,577
AF2-095 21.4 MW 2.5% $78,381
AF2-096 38.1 MW 4.5% $139,914
AF2-142 12.7 MW 1.5% $46,582
AF2-143 12.4 MW 1.5% $45,404
AF2-182 23.1 MW 2.7% $84,824
AF2-200 16.1 MW 1.9% $59,053
AF2-349 24.5 MW 2.9% $90,056
AF2-392 19.7 MW 2.3% $72,243
AF2-441 14.9 MW 1.7% $54,496
AG1-118 25.1 MW 2.9% $91,916
AG1-119 24.7 MW 2.9% $90,482
AG1-298 92.4 MW 10.9% $338,999
AG1-321 17.0 MW 2.0% $62,223
AG1-379 18.7 MW 2.2% $68,750
AG1-423 16.4 MW 1.9% $60,344
AG1-434 20.5 MW 2.4% $75,105
AG1-535 16.2 MW 1.9% $59,383
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n8428 / CE_NUN_L14419_1 Reconductor the Auora EC - ESS W407K 345 kV Line. $1,100,000 $51,833 30 Months

Contributor

Description: The upgrade will be to reconductor the line. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.A preliminary estimate for the upgrade is $1.1M with a estimated construction timeline of 30 months. Upon completion of the upgrade the rating limit will be 1334/1726/1837/2084 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line (All) A 1334.0 MVA
ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line (All) B 1726.0 MVA
ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line (All) C 2084.0 MVA
ESS W407K;9T-AURORA EC;RP 345.0 kV Ckt 1 line (All) STE 1837.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-114 27.7 MW 3.0% $32,636
AE2-321 25.1 MW 2.7% $29,591
AF1-200 184.5 MW 19.8% $217,460
AF1-280 36.8 MW 3.9% $43,321
AF1-296 28.6 MW 3.1% $33,671
AF1-314 43.1 MW 4.6% $50,864
AF2-041 44.0 MW 4.7% $51,833
AF2-182 55.1 MW 5.9% $64,981
AF2-200 32.6 MW 3.5% $38,395
AF2-201 40.5 MW 4.3% $47,745
AF2-349 74.1 MW 7.9% $87,382
AF2-392 31.5 MW 3.4% $37,075
AG1-118 28.6 MW 3.1% $33,673
AG1-119 95.5 MW 10.2% $112,601
AG1-120 17.9 MW 1.9% $21,066
AG1-423 63.9 MW 6.8% $75,332
AG1-434 32.6 MW 3.5% $38,423
AG1-462 33.7 MW 3.6% $39,717
AG1-553 37.5 MW 4.0% $44,234
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP (Pending) / AEPIMJMS02 Replace 2156 KCM ACSR 84/19 at Olive $1,130,000 $22,430 18 to 24 Months

Contributor

Description: Replace five (5) instances of 2156 KCM ACSR 84/19 station conductor at Olive

Flowgates Addressed by this Reinforcement
Facility Contingency
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (All) B 1370.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM A 1188.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN A 1370.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 15.0 MW 1.7% $18,720
AE1-114 11.2 MW 1.2% $13,990
AE1-172 19.6 MW 2.2% $24,345
AE2-321 10.3 MW 1.1% $12,839
AE2-341 16.1 MW 1.8% $20,094
AF1-030 10.8 MW 1.2% $13,396
AF1-200 215.8 MW 23.8% $268,633
AF1-296 14.4 MW 1.6% $17,973
AF1-314 16.1 MW 1.8% $20,039
AF1-318 21.2 MW 2.3% $26,337
AF2-041 18.0 MW 2.0% $22,430
AF2-095 22.3 MW 2.5% $27,712
AF2-096 42.5 MW 4.7% $52,855
AF2-142 17.1 MW 1.9% $21,261
AF2-143 16.3 MW 1.8% $20,283
AF2-200 12.0 MW 1.3% $14,953
AF2-201 12.8 MW 1.4% $15,956
AF2-349 18.4 MW 2.0% $22,854
AF2-350 11.1 MW 1.2% $13,857
AF2-392 14.6 MW 1.6% $18,197
AF2-441 17.3 MW 1.9% $21,520
AG1-118 31.3 MW 3.4% $38,911
AG1-119 18.4 MW 2.0% $22,964
AG1-121 20.7 MW 2.3% $25,714
AG1-127 9.9 MW 1.1% $12,278
AG1-298 43.9 MW 4.8% $54,690
AG1-379 14.0 MW 1.5% $17,400
AG1-423 20.5 MW 2.3% $25,530
AG1-434 15.2 MW 1.7% $18,944
AG1-435 13.9 MW 1.5% $17,363
AG1-436 106.5 MW 11.7% $132,611
AG1-447 46.7 MW 5.1% $58,075
AG1-553 13.9 MW 1.5% $17,276
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n5769.1 Perform engineering study for CT limits , and and relay compliance trip limits at Dumont substation $780,000 $15,271 12 to 18 Months

Contributor

Description: An Engineering study will need to be conducted to determine if the Dumont CT Thermal Limit settings can be adjusted to mitigate the overload. New relay package will be required if the settings cannot be adjusted, Estimated Cost: $600,000. New AEP ratings: 1409/1868 MVA SN/SE.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1409.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1868.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 12.0 MW 1.7% $13,285
AE1-114 15.1 MW 2.1% $16,710
AE1-172 26.8 MW 3.8% $29,606
AE2-223 11.1 MW 1.6% $12,245
AE2-341 14.4 MW 2.0% $15,949
AF1-200 150.3 MW 21.3% $166,062
AF1-280 17.6 MW 2.5% $19,446
AF1-296 19.5 MW 2.8% $21,583
AF1-314 21.6 MW 3.1% $23,904
AF1-318 28.6 MW 4.0% $31,551
AF2-041 13.8 MW 2.0% $15,271
AF2-095 13.6 MW 1.9% $15,010
AF2-096 23.0 MW 3.3% $25,416
AF2-142 12.7 MW 1.8% $14,031
AF2-143 12.4 MW 1.8% $13,676
AF2-182 13.3 MW 1.9% $14,736
AF2-200 16.1 MW 2.3% $17,787
AF2-349 14.1 MW 2.0% $15,624
AF2-392 19.7 MW 2.8% $21,760
AF2-441 10.9 MW 1.5% $12,051
AG1-118 14.2 MW 2.0% $15,674
AG1-119 14.1 MW 2.0% $15,617
AG1-121 27.9 MW 4.0% $30,811
AG1-298 68.0 MW 9.6% $75,095
AG1-321 17.0 MW 2.4% $18,742
AG1-379 11.3 MW 1.6% $12,444
AG1-423 16.4 MW 2.3% $18,176
AG1-434 20.5 MW 2.9% $22,622
AG1-435 18.8 MW 2.7% $20,821
AG1-535 12.3 MW 1.7% $13,552
AG1-553 18.8 MW 2.7% $20,743
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n5769.3 Replace 11 jumpers/risers at Dumont substation $357,500 $10,149 18 to 24 Months

Contributor

Description: PJM Network Upgrade n5769.3. Replace 11 jumpers/risers at Dumont substation. The network project had an projected in-service date of 06/01/2021 and an estimated cost of $275,000.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 2056.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 2255.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 20.0 MW 2.3% $8,389
AE1-114 15.1 MW 1.8% $6,357
AE1-172 26.8 MW 3.2% $11,263
AE2-341 14.4 MW 1.7% $6,067
AF1-200 296.9 MW 34.9% $124,829
AF1-280 17.6 MW 2.1% $7,398
AF1-314 21.6 MW 2.5% $9,093
AF2-041 24.1 MW 2.8% $10,149
AF2-095 21.4 MW 2.5% $8,981
AF2-096 38.1 MW 4.5% $16,032
AF2-142 12.7 MW 1.5% $5,338
AF2-143 12.4 MW 1.5% $5,203
AF2-182 23.1 MW 2.7% $9,719
AF2-200 16.1 MW 1.9% $6,766
AF2-349 24.5 MW 2.9% $10,319
AF2-392 19.7 MW 2.3% $8,278
AF2-441 14.9 MW 1.7% $6,244
AG1-118 25.1 MW 2.9% $10,532
AG1-119 24.7 MW 2.9% $10,368
AG1-298 92.4 MW 10.9% $38,844
AG1-321 17.0 MW 2.0% $7,130
AG1-379 18.7 MW 2.2% $7,878
AG1-423 16.4 MW 1.9% $6,914
AG1-434 20.5 MW 2.4% $8,606
AG1-535 16.2 MW 1.9% $6,804
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP (Pending) / AEPIMJMS04 Replace 2874 KCM ACSR 72/7 at Olive $455,000 $9,031 18 to 24 Months

Contributor

Description: Replace two (2) instances of 2874 KCM ACSR 72/7 station conductor at Olive

Flowgates Addressed by this Reinforcement
Facility Contingency
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM A 1521.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM B 1718.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN A 1685.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN B 1864.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 15.0 MW 1.7% $7,538
AE1-114 11.2 MW 1.2% $5,633
AE1-172 19.6 MW 2.2% $9,803
AE2-321 10.3 MW 1.1% $5,170
AE2-341 16.1 MW 1.8% $8,091
AF1-030 10.8 MW 1.2% $5,394
AF1-200 215.8 MW 23.8% $108,166
AF1-296 14.4 MW 1.6% $7,237
AF1-314 16.1 MW 1.8% $8,069
AF1-318 21.2 MW 2.3% $10,605
AF2-041 18.0 MW 2.0% $9,031
AF2-095 22.3 MW 2.5% $11,158
AF2-096 42.5 MW 4.7% $21,282
AF2-142 17.1 MW 1.9% $8,561
AF2-143 16.3 MW 1.8% $8,167
AF2-200 12.0 MW 1.3% $6,021
AF2-201 12.8 MW 1.4% $6,425
AF2-349 18.4 MW 2.0% $9,202
AF2-350 11.1 MW 1.2% $5,579
AF2-392 14.6 MW 1.6% $7,327
AF2-441 17.3 MW 1.9% $8,665
AG1-118 31.3 MW 3.4% $15,668
AG1-119 18.4 MW 2.0% $9,246
AG1-121 20.7 MW 2.3% $10,354
AG1-127 9.9 MW 1.1% $4,944
AG1-298 43.9 MW 4.8% $22,021
AG1-379 14.0 MW 1.5% $7,006
AG1-423 20.5 MW 2.3% $10,280
AG1-434 15.2 MW 1.7% $7,628
AG1-435 13.9 MW 1.5% $6,991
AG1-436 106.5 MW 11.7% $53,397
AG1-447 46.7 MW 5.1% $23,384
AG1-553 13.9 MW 1.5% $6,956
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP (Pending) / AEPIMJMS03 Adjust Relay Compliance Trip Limit at Olive $25,000 $492 18 to 24 Months

Contributor

Description: Adjust Relay Compliance Trip Limit at Olive

Flowgates Addressed by this Reinforcement
Facility Contingency
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM A 1188.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line SUM B 1539.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN A 1506.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line WIN B 1777.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE1-070 15.0 MW 1.6% $411
AE1-114 11.2 MW 1.2% $307
AE1-172 19.6 MW 2.1% $534
AE2-321 10.3 MW 1.1% $282
AE2-341 16.1 MW 1.8% $441
AF1-030 10.8 MW 1.2% $294
AF1-200 222.8 MW 24.4% $6,089
AF1-296 14.4 MW 1.6% $395
AF1-314 16.1 MW 1.8% $440
AF1-318 21.2 MW 2.3% $578
AF2-041 18.0 MW 2.0% $492
AF2-095 22.3 MW 2.4% $608
AF2-096 42.5 MW 4.6% $1,160
AF2-142 17.1 MW 1.9% $467
AF2-143 16.3 MW 1.8% $445
AF2-200 12.0 MW 1.3% $328
AF2-201 12.8 MW 1.4% $350
AF2-349 18.4 MW 2.0% $502
AF2-350 11.1 MW 1.2% $304
AF2-392 14.6 MW 1.6% $399
AF2-441 17.3 MW 1.9% $472
AG1-118 31.3 MW 3.4% $854
AG1-119 18.4 MW 2.0% $504
AG1-121 20.7 MW 2.3% $565
AG1-127 9.9 MW 1.1% $270
AG1-298 43.9 MW 4.8% $1,201
AG1-379 14.0 MW 1.5% $382
AG1-423 20.5 MW 2.2% $560
AG1-434 15.2 MW 1.7% $416
AG1-435 13.9 MW 1.5% $381
AG1-436 106.5 MW 11.6% $2,911
AG1-447 46.7 MW 5.1% $1,275
AG1-553 13.9 MW 1.5% $379
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP b3775.7 Upgrade limiting element at Dumont substation on the Stillwell-Dumont 345 kV line. $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Upgrade the limiting element at Dumont substation to increase the rating of the Stillwell-Dumont 345 kV line to match conductor rating. This includes replacement of the 2500A wavetrap and breakers F and F1.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1408.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1887.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1408.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1887.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP b3775.11 Upgrade the limiting element at Stillwell substation to increase the rating of the Stillwell-Dumont 345 kV line to match conductor rating. NIPS SN/SE ratings of 1525/1832 MVA post upgrade. $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Upgrade the limiting element at Stillwell substation to increase the rating of the Stillwell-Dumont 345 kV line to match conductor rating. NIPS SN/SE ratings of 1525/1832 MVA post upgrade.

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1525.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1832.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1525.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1832.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP b3775.6 Perform sag study mitigation work on the Dumont-Stillwell 345 kV line $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Perform sag study mitigation work on the Dumont-Stillwell 345 kV line (remove a center-pivot irrigation system from under the line, allowing for the normal and emergency ratings of the line to increase, replace two structures and modify a third structure).

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1408.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1887.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 1408.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 1887.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
NIPS (Pending) / NIPS_TC1_15480 Station equipment upgrade and reconductor to achieve NIPS SN/SE ratings of 2807/2807. $12,700,000 $0 TBD

Contingent

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: NIPS SN/SE ratings of 2807/2807 achieved by changeout of wavetrap to 5000A, change out of 3000 AL substation conductor drop to 2-3000 AAC, changeout of 2.9 miles of 2-900 ACSR overhead line conductor to 2-954 ACSS @ 250C, replacement of 2 Breakers and 5 Switches. $12.7M

Flowgates Addressed by this Reinforcement
Facility Contingency
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) A 2807.0 MVA
05DUMONT-17STILLWELL 345.0 kV Ckt 1 line (All) B 2807.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
NextEra s2509 / (Pending) NextEra review required: Acquired from ComEd. NextEra section SE rating is 1091 MVA $0 $0 Dec 31 2023

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Rebuild the (L97008: Univ. Park S/S-Olive S/S 345 kV) of the ~20 mile double-circuit line withmonopoles and new conductor utilizing existing ROW ( Univ. Park S/S-Olive S/S 345 kV) .

Flowgates Addressed by this Reinforcement
Facility Contingency
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (All) B 2495.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) B 2495.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP b3775.10 Sag study on the Olive – University Park $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Perform a sag study on the Olive – University Park 345kV line to increase the operating temperature to 225 F. Remediation work includes two tower replacements on the line.

Flowgates Addressed by this Reinforcement
Facility Contingency
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AMIL (Pending) / AMIL_TC1_15167 AMIL is 1793MVA, limited by switch and bus conductor at Snyder.in that case the mitigation is to build a second 345 kV line between Snyder (J1180 POI) and Sullivan, it is 5 miles long $15,000,000 $0 TBD

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: AMIL is 1793MVA, limited by switch and bus conductor at Snyder.in that case the mitigation is to build a second 345 kV line between Snyder (J1180 POI) and Sullivan, it is 5 miles long

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (All) A 9999.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (All) B 9999.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n7925.1 / AEPI0010a Reconductor/rebuild 0.17 miles of ACAR ~ 1024.5 ~ 30/7 ~ conductor section 5 $2,132,000 $0 24 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: Reconductor/rebuild 0.17 miles of ACAR ~ 1024.5 ~ 30/7 ~ conductor section 5

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (All) A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (All) B 1942.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (All) A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (All) B 1942.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL B 1942.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM B 1942.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN A 2022.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN B 2237.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (All) A 1754.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (All) B 1942.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n7925.4 / AEPI0010d Replace three 2-2000 AAC 91 Str $390,000 $0 18 to 24 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: Replace three 2-2000 AAC 91 Str

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line LL B 2369.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL B 2369.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM B 2369.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN A 2219.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN B 2468.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line WIN A 2219.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line WIN B 2468.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n7925.5 / AEPI0010e Reconductor/rebuild 0.2 miles of ACAR ~ 1315.5 ~ 45/7 ~ DIPPER conductor sec 3, 1 $520,000 $0 24 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM A 3113.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM B 3113.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line WIN A 3581.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line WIN B 3581.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL A 3113.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL B 3113.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN A 3581.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN B 3581.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line LL A 3113.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line LL B 3113.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n7925.3 / AEPI0010c Replace two sullivan 3000A Wavetrap $520,000 $0 18 to 24 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM B 2246.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line LL B 2246.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL B 2246.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM B 2246.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN A 2219.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN B 2672.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
AEP n7925.2 / AEPI0010b Reconductor/rebuild 1 miles of ACAR ~ 1024.5 ~ 30/7 ~ RAIL1 conductor section 6 $2,600,000 $0 24 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: Reconductor/rebuild 1 miles of ACAR ~ 1024.5 ~ 30/7 ~ RAIL1 conductor section 6

Flowgates Addressed by this Reinforcement
Facility Contingency
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line (Any)
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J1180 TAP 345.0 kV Ckt 1 line SUM B 2062.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line LL B 2062.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM A 1754.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line SUM B 2062.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN A 2219.0 MVA
05SULLIVAN-J2170 POI 345.0 kV Ckt 1 line WIN B 2237.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line WIN A 2219.0 MVA
05SULLIVAN-J1180 POI 345.0 kV Ckt 1 line WIN B 2237.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
NIPS b3775.8 Upgrade existing terminal equipment at St. John on the existing Crete to St. John 345 kV line $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Part of b3375 Baseline project. Upgrade the existing terminal equipment (substation conductor) at St. John on the existing Crete to St. John 345 kV line with bundled 2x1590 ACSR Lapwing

Flowgates Addressed by this Reinforcement
Facility Contingency
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) C 2280.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) STE 2107.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd b3775.3 Rebuild ComEd’s section of 345 kV double circuit in IL from St. John to Crete $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Part of b3775 baseline. Rebuild ComEd’s section of 345 kV double circuit in IL from St. John to Crete (5 miles) with twin bundled 1277 ACAR conductor.

Flowgates Addressed by this Reinforcement
Facility Contingency
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) C 2280.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) STE 2107.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
NextEra b3775.2 Reconductor NEET’s section of Crete(IN/IL border)-St. John 345 kV line (6.95 miles). $0 $0 May 09 2023

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Reconductor NEET’s section of Crete(IN/IL border)-St. John 345 kV line (6.95 miles).

Flowgates Addressed by this Reinforcement
Facility Contingency
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) C 2280.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) STE 2107.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_L0626.1 L0626 reconductor & station terminal upgrades. $54,000,000 $0 30 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: Reconductor a portion of L0626, Byron station conductor upgrade and 345Kv L0626 Circuit Breaker replacement. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.

Flowgates Addressed by this Reinforcement
Facility Contingency
AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line (Any)
WAYNE ; B-AG1-423 TP 345.0 kV Ckt 1 line (Any)
AB1-089 POI-AG1-119 TAP 345.0 kV Ckt 1 line (Any)
AB1-089 TAP-AG1-119 TAP 345.0 kV Ckt 1 line (Any)
AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
AB1-089 POI-AG1-119 TAP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
AB1-089 POI-AG1-119 TAP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
AB1-089 POI-AG1-119 TAP 345.0 kV Ckt 1 line (All) C 2436.0 MVA
AB1-089 POI-AG1-119 TAP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
AB1-089 TAP-AG1-119 TAP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
AB1-089 TAP-AG1-119 TAP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
WAYNE ; B-AG1-423 TP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
WAYNE ; B-AG1-423 TP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
WAYNE ; B-AG1-423 TP 345.0 kV Ckt 1 line (All) C 2436.0 MVA
WAYNE ; B-AG1-423 TP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line (All) C 2436.0 MVA
AB1-089 TP-AG1-119 TP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line (All) A 2293.0 MVA
AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line (All) B 2293.0 MVA
AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line (All) C 2436.0 MVA
AG1-119 TP-AG1-423 TP 345.0 kV Ckt 1 line (All) STE 2293.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd b3775.5 Replace E. Frankfort 345 kV circuit breaker “9-14” with 3150A SF6 circuit breaker. $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Part of b3775 baseline. Replace E. Frankfort 345 kV circuit breaker “9-14” with 3150A SF6 circuit breaker.

Flowgates Addressed by this Reinforcement
Facility Contingency
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n3515.1 / ce-017 Cherry Valley - Garden Prarie 345 kV line - reconductoring and sag mitigation. $19,400,000 $0 30 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: L15616 SSTE rating is 1568 MVA. The upgrade will be to re-conductor a portion of the line, perform sag mitigation on another portion of the line and station conductor upgrade at a line terminal. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.Upon completion the rating swill be 1248/1441/1667/1982 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1248.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 1441.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 1982.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 1667.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1248.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 1441.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 1982.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 1667.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n3515.2 / (Pending) Cherry Valley - Garden Prarie 345 kV Line Circuit Breaker Replacement $3,000,000 $0 TBD

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: The upgrade required on 345kV L15616 will require a 345kV Circuit Breaker replacement of BT CB 4-7 at TSS 156 Cherry Valley.

Flowgates Addressed by this Reinforcement
Facility Contingency
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1809.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 1809.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 1922.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 1809.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1809.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 1809.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 1922.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 1809.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n3515.3 13.8 miles of rebuild plus 1 CB, station conductor, and relays at Cherry Valley $88,000,000 $0 TBD

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: 13.8 miles of rebuild plus 1 CB, station conductor, and relays at Cherry Valley

Flowgates Addressed by this Reinforcement
Facility Contingency
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
CHERRY VA; B-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd b3775.4 Rebuild 345 kV double circuit extending from Crete to E. Frankfort. $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Part of b3775 baseline. Rebuild 12.7 miles of 345 kV double circuit extending from Crete to E. Frankfort with twin bundled 1277 ACAR conductor.

Flowgates Addressed by this Reinforcement
Facility Contingency
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (All) A 1679.0 MVA
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (All) B 2058.0 MVA
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (All) C 2280.0 MVA
E FRANKFO; B-CRETE EC ;BP 345.0 kV Ckt 1 line (All) STE 2017.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n5318.1 / ce-012a Garden Prarie - Silver Lake R 345 kV Line - Reconductor and Station Bus Work $45,700,000 $0 30 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: ComEd 345kV L15616 SN rating is 1201 MVA. The upgrade will be to re-conductor the line and station bus work. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.Upon completion of the upgrade the ratings will be 1248/1441/1667/1982 MVA SN/SLTE/SSTE/SLD.

Flowgates Addressed by this Reinforcement
Facility Contingency
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (Any)
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) A 1248.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) B 1441.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) C 1982.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) STE 1667.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1248.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 1441.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 1982.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 1667.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd n5318.2 / ce-012 Reconductor 26.7 miles of 2338 kcmil. Mitigate sag limits. Upgrade relay package. Replace station conductor at both line terminals. Replace 2-345 kV breakers and CT's at TSS 138 Silver Lake. $170,000,000 $0 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: L15616 SSTE rating is 1568 MVA. Reconductor 26.7 miles of 2338 kcmil. Mitigate sag limits. Potential transmission tower replacement required with line reconductor. The estimate for this work will not be known until the Phase 3 system upgrade Facility Study is completed per the PJM process.Upgrade relay package. Replace station conductor at both line terminals. Replace 2-345 kV breakers and CT's at TSS 138 Silver Lake. Upon completion of all upgrades the new ratings will be 1754/2246/2297/2488 MVA (SN/SLTE/SSTE/SLD).

Flowgates Addressed by this Reinforcement
Facility Contingency
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (Any)
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) A 1754.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) B 2246.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) C 2488.0 MVA
GARDEN PR; R-SILVER LK; R 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) A 1754.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) B 2246.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) C 2488.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (All) STE 2297.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd (Pending) / CE_NUN_L15616.1 L15616 Line & terminal upgrades. $72,000,000 $0 28 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AF2-041 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AF2-041 could receive cost allocation. Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 is a potential Aggregate Pool Contributor.

Description: Reconductor L15616 - TSS 156 Cherry Valley - TSS 138 Silver Lake note- Transmission tower replacement might be required. This will be determined during the network upgrade Facility Study per the PJM process. The estimate provided here does not include the tower work., station conductor upgrades at both terminals, upgrade 345KV Bus Tie Cicrcuit Breaker 3-4 at TSS 138 Silver Lake, upgrade 345KV Bus Tie Circuit Breaker 4-7 at TSS 156 Cherry Valley along with associated BT CB 3-4 disconnect switches. Upgrade 345KV Motor operated disc. Switch at TSS 138 Silver Lake.

Flowgates Addressed by this Reinforcement
Facility Contingency
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line SUM A 1754.0 MVA
SILVER LK; R-GARDEN PR; R 345.0 kV Ckt 1 line SUM STE 2297.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
ComEd b3775.1 Swap the NIPSCO Green Acre Tap towers from the St. John-Green Acres-Olive 345 kV line $0 $0 Dec 01 2026

Contingent

Note: Although AF2-041 may not presently have cost responsibility for this upgrade, AF2-041 may need this upgrade in-service to be deliverable to the PJM system. If AF2-041 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Outside of the Green Acres substation, swap the NIPSCO Green Acre Tap towers from the St. John-Green Acres-Olive 345 kV line to the University Park N-Olive 345 kV line to create a University Park N-Green Acres-Olive and St. John-Olive 345 kV lines.

Flowgates Addressed by this Reinforcement
Facility Contingency
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (Any)
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (Any)
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (Any)
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) ALDR 9999.0 MVA
17STJOHN-CRETE EC ;BP 345.0 kV Ckt 1 line (All) STE 9999.0 MVA
05OLIVE-AF2-359 TAP 345.0 kV Ckt 1 line (All) B 9999.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) A 9999.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) ALDR 9999.0 MVA
UNIV PK N;RP-AF2-359 TAP 345.0 kV Ckt 1 line (All) STE 9999.0 MVA
05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line (All) A 9999.0 MVA
UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line (All) A 9999.0 MVA

Attachments


[1]Winter load flow analysis will be performed starting in Transition Cycle #2.