AG1-447 Final System Impact Study (Retool 2) Report
v2.00 released 2026-05-14 11:57
Olive-University Park 345 kV
55.0 MW Capacity / 55.0 MW Energy
Introduction
This Final System Impact Study (SIS) Report has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 314 for New Service Requests (projects) in Transition Cycle 1 (TC1). The Project Developer/Eligible Customer (developer) is RWE Solar Development, LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is AEP Indiana Michigan Transmission Company, Inc..
Preface
The Final 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 summary format and (ii) an individual project-level basis. The Final System Impact Study Results (for both the summary and individual reports) will be publicly available on PJM’s website. Project Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 5, Final Agreement Negotiation Phase, the purpose of the Final Agreement Negotiation Phase is to:
- Negotiate, execute and enter into the applicable final interconnection related service agreement found in Tariff, Part IX;
- Conduct any remaining analyses or updated analyses based on New Service Requests withdrawn during Decision Point III (DP3); and
- Adjust the security obligation based on New Service Requests withdrawn during Decision Point III and/or during the Final Agreement Negotiation Phase.
Retool 1:
In accordance with PJM Tariff Part VII.D 314 B(1)(a), Final Agreement Negotiation Phase:
- PJM will perform a retool (Retool 1) after the conclusion of DP3 considering only the projects moving on in the Final Agreement Negotiation Phase (Removes DP3 withdrawals).
- The Final System Impact Study reflecting results from the retooled analysis (Retool 1) will be publicly available on PJM’s website; Project Developers and Eligible Customers must obtain the results from the website.
- PJM will provide updated final electronic agreements to Project Developers and Eligible Customers in the Cycle reflecting updates from the Final System Impact Study after Retool 1 including the adjusted Security requirements.
The AG1-447 Final System Impact Study (Retool 1) Report is available for download here.
Retool 2 (if needed):
If particular New Service Requests do not sign their final agreements after receiving the updated information after Retool 1, there may be the need to run a second retool (Retool 2) to identify if any network upgrades are no longer necessary:
- PJM will perform Retool 2 (if necessary) considering only the removal of projects from the model which chose not to execute their agreements after Retool 1.
- The updated Final System Impact Study reflecting results from Retool 2 will be publicly available on PJM’s website; Project Developers and Eligible Customers must obtain the results from the website.
- If there are any adjustments to the agreements required after Retool 2, the necessary network upgrade or Security changes will be handled via the scope change process post-GIA.
General
The Project Developer has proposed an uprate to a planned/existing Solar facility located in the AEP Indiana Michigan Transmission Company, Inc. zone — LaPorte County, Indiana. This project is an increase to the developer’s AF2-359/AG1-436 project(s), which will share the same Point of Interconnection. The AG1-447 project is a 55.0 MW uprate (55.0 MW Capacity uprate) to the previous project(s). The total installed facilities will have a capability of 305.0 MW with 205.0 MW of this output being recognized by PJM as Capacity.Project Information
Physical Interconnection Facility Study
The transmission owner has completed the Physical Interconnection Facilities Study. This report is available for download.
Point of Interconnection
AG1-447 will interconnect on the AEP Indiana Michigan Transmission Company, Inc. transmission system as an uprate to AF2-359 tapping the Olive to University Park 345 kV line.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. The Facilities Studies for the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades were performed by the Transmission Owner in Phase II. Facilities Studies are available for download on PJM.com (see General Section for document links). The Interconnected Transmission Owner has performed a Facilities Study for the required System Reliability Network Upgrades in Phase III (see System Reinforcement Section for document links).
Based on the Final SIS results, the AG1-447 project has the following allocation of costs for interconnection. The Security amount required after the Final SIS and revised agreements is also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AG1-447 | Cost Subject to Security* | |
| Transmission Owner Interconnection Facilities (TOIF) | $138,247 | $138,247 | |
| Other Scope | $0 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $0 | $0 | |
| Network Upgrades | $60,764 | $60,764 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $0 | $0 | |
| Transient Stability | $0 | $0 | |
| Short Circuit | $0 | $0 | |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | |
| Distribution | $0 | $0 | |
| Affected System Reinforcements | |||
| AFS - PJM Violations | $0 | $0 | |
| AFS - Non-PJM Violations | $284,984 ** | $0 ** | |
| Total | $483,995 | $199,011 | |
* Contributes to calculation for Security. See Security Requirement Section of this report for additional detail.
** This value reflects the results at the time of the report posting and it is subject to change. AFS – Non-PJM Violations are not subject to Security. For latest AFS – Non-PJM Violations, please refer to the latest Affected System Study Report for your project.
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, 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 deliverability 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.
Security Requirement
Per Tariff Part VII, Subpart D, section 314 (Final Agreement Negotiation Phase) A.1 and PJM Manual 14H, Section 5, if a Transition Cycle 1 New Service Request is withdrawn during Decision Point III and/or the Final Agreement Negotiation Phase, PJM shall remove the New Service Request from the Cycle and adjust the Security obligations of other New Service Requests based on the withdrawal. The Final System Impact Study results will reflect the updated Security amount for this project. Security may be in the form of cash, letter of credit, or other form of Security acceptable to PJM (see PJM M14H, Section 6.4).
Security is calculated for a New Service Request based on the Network Upgrade costs allocated pursuant to the Final System Impact Study results.
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.
Security Due for AF2-359/AG1-436/AG1-447
Security has been calculated for the AF2-359/AG1-436/AG1-447 project(s) based on the Final System Impact Study results and is shown in the table below. This Security must be provided at Final SIS through either a wire transfer or letter of credit or other form of Security deemed acceptable by PJM per Manual 14H, Section 6.4.
Security Due for AF2-359/AG1-436/AG1-447
In accordance with Tariff, Part VII, Subpart D, section 314(B)(4)(a) (Final Agreement Negotiation Phase) failure to provide any required adjustments to Security within the 15 Business Day period will result in the New Service Request project being terminated and withdrawn.
Please see the cover letter for more details on Letter of Credit/Wire details to satisfy the additional Security requirement.
If no additional Security is required, please coordinate with your assigned Project Manager to initiate any refunds of Security reductions.
Transmission Owner Scope of Work
AG1-447 will interconnect with the AEP transmission system as an uprate to a previous interconnection at the Olive - University Park 345 kV Station. The estimates provided in this report are preliminary in nature, as they were determined without the benefit of detailed engineering studies. Final estimates will require an on-site review and coordination to determine final construction requirements.
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 Scope
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| n9567.0 | Proposed AF2-359 345 kV Station: Review and revise the protective relay settings at the AF2-359 proposed 345 kV Station to account for the additional generation of AG1-436. o Settings will need to be revised for each generation project (AG1-436 & AG1-447) unless they share an in-service date. | $36,901 | $7,080 | $14,081 | $2,702 | $60,764 | $30,382 (See Note 1) |
| n9566.0 | Proposed AF2-359 345 kV Station: Review and revise the protective relay settings at the AF2-359 proposed 345 kV Station to account for the additional generation of AG1-447. o Settings will need to be revised for each generation project (AG1-436 & AG1-447) unless they share an in-service date. | $36,901 | $7,080 | $14,081 | $2,702 | $60,764 | $30,382 (See Note 1) |
| Transmission Owner Interconnection Facilities | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | AG1-436 Transmission Owner Interconnection Facilities. • IMTCo will procure one (1) metering panel with three (3) primary meters and two (2) ethernet switches to be installed by the Project Developer in the AG1-436 and AG1-447 Project Developer's collector stations. • IMTCo will procure one (1) connected grid router ("CGR") to be installed by the Project Developer in the Project Developer's originating project collector station (AF2-359). | $106,608 | $51,442 | $23,199 | $12,553 | $193,802 | $96,901 (See Note 1) |
| (Pending) | AG1-447 Transmission Owner Interconnection Facilities. • IMTCo will procure one (1) metering panel with three (3) primary meters and two (2) ethernet switches to be installed by the Project Developer in the AG1-436 and AG1-447 Project Developer's collector stations. • IMTCo will procure one (1) CGR to be installed by the Project Developer in the Project Developer's originating project collector station (AF2-359). | $48,465 | $21,971 | $8,433 | $3,823 | $82,692 | $41,346 (See Note 1) |
Based on the scope of work for the Interconnection Facilities, it is expected to take 4 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.
Note that the TO findings were made from a conceptual review of this project. A more detailed review of the connection facilities and their cost will be identified in a future study phase. Further note that the cost estimate data provided should be considered high level estimates since it was produced without a detailed engineering review. The Project Developer will be responsible for the actual cost of construction. TO herein reserves the right to return to any issues in this document and, upon appropriate justification, request additional monies to complete any reinforcements to the transmission systems.
Remote Terminal Work: During Phase II of the PJM interconnection process, TO’s System Protection Engineering Department will review transmission line protection as well as anti-islanding required to accommodate the new generation and interconnection substation. System Protection Engineering will determine the minimal acceptable protection requirements to reliably interconnect the proposed generating facility with the transmission system. The review is based on maintaining system reliability by reviewing TO’s protection requirements with the known transmission system configuration which includes generating facilities in the area. This review may determine that transmission line protection and communication upgrades are required at remote substations.
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.
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 Change in Ownership. AEP 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
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.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 AG1-447 was evaluated as a 55.0 MW (55.0 MW Capacity) injection in the AEP area.
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The full energy output of Generation Interconnection Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).
The following flowgates remain after considering the topology reinforcements required by the cycle.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | AEP | 05DUMONT-05SORENS 765.0 kV Ckt 1 line | AEP_P4_#7334_05JEFRSO 765_A2_SRT-A | Breaker | AC | 111.58 % | 4142.0 | B | 4621.49 | 12.78 | |
| GD1 | AEP | 05DUMONT-05SORENS 765.0 kV Ckt 1 line | AEP_P4_#6189_05HANG R 765_D1_SRT-A | Breaker | AC | 100.3 % | 4142.0 | B | 4154.54 | 11.54 | |
| GD1 | AEP | 05SORENS-05MARYSV 765.0 kV Ckt 1 line | AEP_P4_#7334_05JEFRSO 765_A2_SRT-A | Breaker | AC | 102.72 % | 4142.0 | B | 4254.71 | 13.88 | |
| GD1 | ATSI/METC | 18MOROCCO-02ALLEN 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-022T_SRT-A-1_SENS | Tower | AC | 111.53 % | 1793.0 | B | 1999.7 | 4.81 |
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | AEP | 05DUMONT-05SORENS 765.0 kV Ckt 1 line | AEP_P7-1_#11046___SRT-A | Tower | AC | 100.51 % | 4142.0 | B | 4163.06 | 12.24 | |
| GD1 | AEP | 05OLIVE-05NEW CARLI1 138.0 kV Ckt 1 line | AEP_P4_#9247_05OLIVE 138_R1_SRT-SL | Breaker | AC | 113.25 % | 337.0 | B | 381.65 | 2.83 | |
| GD1 | ATSI/METC | 18MOROCCO-02ALLEN 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-022T_SRT-A-1 | Tower | AC | 111.69 % | 1793.0 | B | 2002.62 | 5.05 | |
| GD1 | ATSI/METC | 18MOROCCO-02ALLEN 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-022T_SRT-A-2 | Tower | AC | 109.25 % | 1793.0 | B | 1958.92 | 5.05 | |
| GD1 | ATSI/ITCT | 19MON12-02LALLENDORF 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-025T_SRT-A-1 | Tower | AC | 114.15 % | 1660.0 | B | 1894.94 | 4.5 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | AEP_P4_#2978_05DUMONT 765_B_SRT-A | Breaker | AC | 146.62 % | 971.0 | B | 1423.72 | 46.75 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | COMED_P4_112-65-BT3-4___SRT-A | Breaker | AC | 146.52 % | 971.0 | B | 1422.69 | 46.9 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | COMED_P4_112-65-BT4-5___SRT-A | Breaker | AC | 146.52 % | 971.0 | B | 1422.69 | 46.9 | |
| GD1 | ATSI/ITCT | J1062 POI-02LEMOYN 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-032T_SRT-A-1 | Tower | AC | 103.43 % | 852.0 | B | 881.21 | 2.98 |
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.
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
(No flowgates were eliminated after considering the topology reinforcements required by the cycle.)
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
The New Service Request AG1-447 was evaluated as a 55.0 MW injection and 55.0 MW withdrawal in the AEP area.
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The full energy output of Generation Interconnection Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | AEP_P1-2_#695_1681_SRT-A | Single | AC | 122.26 % | 971.0 | B | 1187.12 | 46.68 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | 765-L11215__-S_SRT-A | Single | AC | 122.21 % | 971.0 | B | 1186.7 | 46.68 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | COMED_P4_112-65-BT4-5___SRT-A | Breaker | AC | 108.87 % | 971.0 | B | 1057.12 | 46.68 | |
| GD1 | AEP/CE | AF2-359 TP-05OLIVE 345.0 kV Ckt 1 line | COMED_P4_112-65-BT3-4___SRT-A | Breaker | AC | 108.87 % | 971.0 | B | 1057.11 | 46.68 | |
| GD1 | CE | UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | 765-L11215__-S_SRT-A | Single | AC | 119.44 % | 970.0 | STE | 1158.61 | 8.32 | |
| GD1 | CE | UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | AEP_P1-2_#695_1681_SRT-A | Single | AC | 119.42 % | 970.0 | STE | 1158.42 | 8.32 | |
| GD1 | CE | UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | COMED_P4_112-65-BT4-5___SRT-A | Breaker | AC | 105.94 % | 970.0 | STE | 1027.6 | 8.32 | |
| GD1 | CE | UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | COMED_P4_112-65-BT3-4___SRT-A | Breaker | AC | 105.94 % | 970.0 | STE | 1027.59 | 8.32 |
Light Load 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.
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
(No flowgates were eliminated after considering the topology reinforcements required by the cycle.)
Short Circuit Analysis
Based on PJM’s Short Circuit Analysis, this project did not contribute >1% fault duty to previously identified overdutied breakers, nor did it cause any new overdutied breakers.
Stability Analysis
Analysis Complete - No Issues
Executive Summary
New Service Requests (AG1-436, and AG1-447) in PJM Transition Cycle 1, Cluster 58 are listed in Table 1 below. This report will cover the dynamic analysis of Cluster 58 projects.
This analysis is effectively a screening study to determine whether the addition of the cluster 58 projects will meet the dynamics requirements of the NERC, AEP and PJM reliability standards.
The load flow scenario for the analysis was based on the RTEP 2027 summer peak load case, modified to include applicable projects. Cluster 58 projects have been dispatched online at maximum power output, with 1.0 voltage at the terminal bus.
Cluster 58 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. Steady-state condition and 56 contingencies were studied, each with a 20 second simulation time period. Studied faults included:
a) Steady-state operation (20 second run),
a) Three-phase faults with normal clearing time; (and with unsuccessful high-speed reclosing),
b) Single-phase bus faults with normal clearing time,
c) Single-phase faults with stuck breaker,
d) Three-phase faults with loss of multiple-circuit tower line; (and with unsuccessful high-speed reclosing).
There are no delayed (Zone 2) clearing faults due to dual primary relays being employed in the AEP 345 kV transmission system.
For all simulations, the queue project under study along with the rest of the PJM system were required to maintain synchronism and with all states returning to an acceptable new condition following the disturbance.
For all of the fault contingencies tested on the 2027 peak load case:
a) Cluster 58 projects were able to ride through the faults (except for faults where protective action trips a generator(s)),
b) The system with Cluster 58 projects included is transiently stable and post-contingency oscillations were positively damped with a damping margin of at least 3% for interarea modes and for local modes.
c) Following fault clearing, all bus voltages recovered to a minimum of 0.7 per unit after 2.5 seconds (except where protective action isolates that bus).
d) No transmission element tripped, other than those either directly connected or designed to trip as a consequence of that fault.
AG1-447 and AG1-436 meet the 0.95 leading and lagging PF requirement.
AG1-436 GEN exhibited slow reactive power recovery within the 20 second simulation window for several contingencies. This issue was mitigated by increasing Kc value in REPCA1 dynamic model from 0 to 0.1. This change has been confirmed by the developer and included in the latest data submission.
AG1-447 GEN exhibited slow reactive power recovery within the 20 second simulation window for several contingencies. ETERM of AG1-447 GEN went outside the range of 0.95 pu ~1.05 pu in post fault for several contingencies. These issues were mitigated by changing VCFlag from 1 to 0, increasing Kc from 0 to 0.08, and Ki from 0.5 to 3.5 in the REPCA1 model. These changes have been confirmed by the developer in correspondence.
The IPCMD and IQCMD states in the REGCA1 model of AG1-447 GEN, and AG1-436 GEN showed erratic behavior for some contingencies in which these generators have been disconnected as part of the contingency event. Since the machine is disconnected and no active or reactive power is injected into the system, this behavior is likely fictitious and a limitation of the software. This does not cause instability in the system.
No mitigations were found to be required.
Table 1: TC1 Cluster 58 Projects
Cluster | Project | Fuel Type | Transmission Owner | MFO | MWE | MWC | Point of Interconnection |
58 | AG1-436 | Solar | AEP | 125 | 125 | 75 | Olive-University Park 345 kV |
AG1-447 | Battery | AEP | 55 | 55 | 55 | Olive-University Park 345 kV |
Reactive Power Analysis
The reactive power capability of AG1-447 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
Steady-State Voltage Analysis
Steady State Voltage Analysis is Not Required.
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 |
| AA2-116 | Cook-East Elkhart 345kV | In Service |
| AA2-123 | Marengo 34kV | In Service |
| AB1-006 | Meadow Lake 345kV | In Service |
| AB1-080 | Dumont-Olive 345kV | In Service |
| AB1-087 | Sullivan 345kV #1 | Under Construction |
| AB1-088 | Sullivan 345kV #2 | Engineering & Procurement |
| AC1-168 | Kewanee-Streator | Suspended |
| AC2-154 | Davis Creek 138kV | Engineering & Procurement |
| AC2-157 | Sullivan 345 kV | Partially in Service - Under Construction |
| AD1-013 | Twombly Road 138kV | Engineering & Procurement |
| AD1-100 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Under Construction |
| AD2-020 | Valley 138 kV | Engineering & Procurement |
| AD2-038 | Powerton-Nevada 345 kV | Under Construction |
| AD2-047 | Davis Creek 138 kV | Suspended |
| AD2-060 | Davis Creek 138kV | Engineering & Procurement |
| AD2-066 | Mazon-Crescent Ridge 138 kV | Under Construction |
| AD2-079 | Capitol Ave 34.5kV | In Service |
| AD2-134 | Shady Oaks | Partially in Service - Under Construction |
| AE1-113 | Mole Creek 345 kV | Under Construction |
| AE1-146 | Ebersole #2-Fostoria Central 138 kV | Under Construction |
| AE1-163 | Powerton-Nevada 345 kV | Under Construction |
| AE1-166 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE1-170 | Kenzie Creek-Colby 138 kV | Suspended |
| AE1-205 | McLean 345 kV | Engineering & Procurement |
| AE2-045 | Olive-Reynolds 345 kV | Engineering & Procurement |
| AE2-062 | Romeoville 12 kV | In Service |
| AE2-152 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE2-181 | Snyder 69kV | In Service |
| AE2-223 | McLean 345 kV | Engineering & Procurement |
| AE2-236 | Columbia-Northeast 138 kV | Suspended |
| AE2-255 | Molecreek 345 kV | Under Construction |
| AE2-267 | Woodsdale 345 kV | Engineering & Procurement |
| AE2-276 | Sullivan 345kV | Engineering & Procurement |
| AE2-281 | Powerton-Nevada 345 kV | Under Construction |
| AE2-323 | Twin Branch-Guardian 138 kV | Partially in Service - Under Construction |
| AE2-341 | Sandwich-Plano 138 kV | Engineering & Procurement |
| AF1-030 | Sandwich-Plano 138 kV | Engineering & Procurement |
| AF1-064 | Weston 69 kV | Under Construction |
| AF1-084 | Hartford-Almena 69 kV | Under Construction |
| AF1-092 | Huntington Jct. 138 kV | Withdrawn |
| AF1-158 | Edison-Gravel Pit 138 kV | In Service |
| AF1-161 | Valley 138 kV | Engineering & Procurement |
| AF1-176 | Corey 138 kV | Engineering & Procurement |
| AF1-204 | Eugene 345 kV | Engineering & Procurement |
| AF1-207 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF1-215 | Olive-Reynolds 345 kV | In Service |
| AF1-229 | Galion-South Berwick 345 kV | Under Construction |
| AF1-322 | Meadow Lake 345 kV | Engineering & Procurement |
| AF1-331 | Twombley Road | Engineering & Procurement |
| AF2-027 | Zion Energy Center 345 kV | Engineering & Procurement |
| AF2-031 | Calumet | Engineering & Procurement |
| AF2-041 | Nelson-Electric Junction 345 kV | Engineering & Procurement |
| AF2-078 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF2-083 | Kenzie Creek-Stone Lake 69 kV | Under Construction |
| AF2-095 | Davis Creek 138 kV | Engineering & Procurement |
| AF2-132 | Reynolds-Olive #1 345 kV | Under Construction |
| AF2-133 | Reynolds-Olive #2 345 kV | Under Construction |
| AF2-134 | Olive-Reynolds #2 345 kV | In Service |
| AF2-142 | Nevada 345 kV | Engineering & Procurement |
| AF2-143 | Powerton-Nevada 345 kV | Engineering & Procurement |
| AF2-199 | Nelson-Electric Junction 345 kV | Engineering & Procurement |
| AF2-200 | Nelson-Electric Junction 345 kV | Engineering & Procurement |
| AF2-205 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AF2-225 | McLean 345 kV | Engineering & Procurement |
| AF2-226 | Katydid Road 345 kV | Engineering & Procurement |
| AF2-252 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-319 | Katydid Road 345 kV | Engineering & Procurement |
| AF2-349 | SILVER LAKE- CHERRY VALLEY 345 KV | Engineering & Procurement |
| AF2-350 | Kensington 138 kV | Engineering & Procurement |
| AF2-352 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-359 | Olive-University Park 345 kV | Engineering & Procurement |
| AF2-366 | Crego Rd 138 kV | Engineering & Procurement |
| AF2-375 | Ebersole-Fostoria 138 kV | Engineering & Procurement |
| AF2-396 | Stinger 138 kV | Engineering & Procurement |
| AF2-441 | Burnham 138kV | Engineering & Procurement |
| AG1-109 | Valley 138 kV | Engineering & Procurement |
| AG1-118 | Sugar Grove-Waterman 138kV | Engineering & Procurement |
| AG1-127 | Crego Rd 138 kV | Engineering & Procurement |
| AG1-226 | Dequine-Eugene 345 kV | Engineering & Procurement |
| AG1-237 | Dequine-Eugene 345 kV | Engineering & Procurement |
| AG1-302 | Olive-Reynolds #1 345 kV | Under Construction |
| AG1-349 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AG1-374 | Blue Mound 345 kV | Engineering & Procurement |
| AG1-436 | Olive-University Park 345 kV | Engineering & Procurement |
| AG1-478 | Wilmington 34.5 kV | Engineering & Procurement |
| AG1-513 | Aurora 138 kV | Suspended |
| AG1-555 | Dequine 345 kV | Engineering & Procurement |
| X1-042 | Watervliet | In Service |
| X3-005 | Wildwood 12kV | In Service |
| Y1-054 | Rochelle 138kV | In Service |
| Y3-023 | Country Side 12kV | In Service |
| Z1-073 | Mendota Hills | In Service |
| Z1-108 | McHenry 34kV | In Service |
| Z2-116 | Twin Branch 12.47kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, PJM evaluated the potential impacts on tie line facilities between PJM and an affected system entity, which were identified per PJM planning analysis criteria. This upgrade may be required on the affected system portion of the tie line along with cost allocation of such upgrade if applicable, in coordination with the affected system. Depending on the affected system, this project may not be contingent on upgrade based on PJM planning analysis criteria, but may be contingent on this upgrade based on the Affected System Operator's planning criteria, provided in the Affected Systems Study Section, herein.
| AG1-447 System Reinforcements: | TO | Trans Owner ID | Title | Category | Allocated Cost ($USD) | |||||
|---|---|---|---|---|---|---|---|---|---|---|
| METC | METC_TC1_16078 | Perform sag mitigation on Allen Junction - Morocco 345kV line | Informational | $0 | ||||||
| ITCT | ITCT_TC1_13866 | MTEP #25223/#25224 - Lulu Sub. Construct the Lulu switching station. Cut in the Lemoyne-Maple and Milan-Monroe-Morocco lines into the new station (Projected ISD 6/11/2027) | Informational | $0 | ||||||
| Grand Total: | $0 | |||||||||
System Reinforcement
- Type
- Load Flow
- TO
- METC
- RTEP ID / TO ID
- (Pending) / METC_TC1_16078
- Title
- Perform sag mitigation on Allen Junction - Morocco 345kV line
- Description
- Perform sag mitigation on Allen Junction - Morocco 345kV line. New ratings will be 1776/2040 MVA SN/SE. Upgrades is required along with ATSI-2025-005 (Supplemental) to increase the rating of the tie line between ATSI and MISO.
- Total Cost ($USD)
- $792,500
- Allocated Cost ($USD)
- $0
- Time Estimate
- 18 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-447 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-447 could receive cost allocation. Although AG1-447 may not presently have cost responsibility for this upgrade, AG1-447 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 02ALLEN-18MOROCCO 345.0 kV Ckt 1 line | (Any) |
|
System Reinforcement
- Type
- Load Flow
- TO
- ITCT
- RTEP ID / TO ID
- (Pending) / ITCT_TC1_13866
- Title
- MTEP #25223/#25224 - Lulu Sub. Construct the Lulu switching station. Cut in the Lemoyne-Maple and Milan-Monroe-Morocco lines into the new station (Projected ISD 6/11/2027)
- Description
- Construct the Lulu switching station. Cut in the Lemoyne-Maple and Milan-Monroe-Morocco lines into the new station. This project is a DPP 2020 Network Upgrade associated with the J1516, J1525, J1526, J1527, J1550, J1553, J1557, J1571, J1586, J1587, J1603, J1614, J1635, J1658, J1659, J1663, and J1664 projects. Projected In-Service 6/1/2027
- Total Cost ($USD)
- $29,916,928
- Allocated Cost ($USD)
- $0
- Time Estimate
- TBD
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-447 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-447 could receive cost allocation. Although AG1-447 may not presently have cost responsibility for this upgrade, AG1-447 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 02ALLEN-18MOROCCO 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | ||||||||||
| 02LALLENDORF-19MON12 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | ||||||||||
| 02LEMOYN-J1062 POI 345.0 kV Ckt 1 line | (Any) |
|
Affected System - Non-PJM Identified Violations
In coordination with other Affected System Operators, PJM has determined that the Affected System Operator for this project that requires an Affected System Study. For the latest Affected System Study results pertaining this project, please refer to your Affected System Study report by the Affected System Operator. If the Affected System Operator identified the need for a system reinforcement on their system due to their planning criteria, Project Developer must follow the Affected System Operator Tariff for construction of the network upgrade. PJM lists any required network upgrades identified by the Affected System Operator in the PJM Project Developer’s GIA under Schedule F.
System Reinforcements
Based on the Final System Impact Study analysis results, this project is contingent on and may have cost responsibility for the following System Reinforcements:
| TO | RTEP ID | Title | Category | Allocated Cost ($USD) | Facilities Study |
|---|---|---|---|---|---|
| ComEd | b3775.1 | Swap the NIPSCO Green Acre Tap towers from the St. John-Green Acres-Olive 345 kV line | Contingent | $0 | N/A |
| ComEd | b3775.4 | Rebuild 345 kV double circuit extending from Crete to E. Frankfort. | Contingent | $0 | N/A |
| Grand Total: | $0 | ||||
PJM evaluated the impact of topology changing reinforcements to mitigate the impacts driven by New Service Requests. PJM determined which reinforcements were eliminated as a result of modeling the topology changing reinforcements. PJM then grouped the topology changing and eliminated reinforcements by region and computed a discount factor to apply to reinforcements to reduce the cost of all these reinforcements down to the cost of contstructing only the topology changing reinforcements. For additional details, please click the icon below
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / ATSI-2025-005 (Supplemental)
- Title
- Lallendorf & Allen Jct Substation Upgrades (Projected ISD 6/1/2032) - s3845.1
- Description
- 1) At Lallendorf Substation: Substation: Replace line relaying. Install new seven-mile ADSS fiber line from Lallendorf Substation to Toledo Edison regional services territory boundary. 2) At Allen Junction Substation: replace disconnect switches, breaker leads, metering, and transmission line drops. Cost Est: $7.21 mil Allen Junction – Morocco 345 kV Line ratings: - Before Proposed Solution: 1517 / 1793 / 1759 / 1793 MVA (SN/SE/WN/WE) - After Proposed Solution: 1868 / 2249 / 2340 / 2535 MVA (SN/SE/WN/WE) Laplaissance Creek 345kV sub involves tapping the Lemoyne-Maple (J1062 POI) 345kV line & Lallendorf-Monroe 345kV line https://www.pjm.com/-/media/DotCom/committees-groups/committees/teac/2025/20251208/20251208-item-04---atsi-supplemental-projects.pdf
- Total Cost ($USD)
- $0
- Discounted Total Cost ($USD)
- $0
- Allocated Cost ($USD)
- $0
- Time Estimate
- TBD
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-447 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) AG1-447 could receive cost allocation. Although AG1-447 may not presently have cost responsibility for this upgrade, AG1-447 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 02ALLEN-18MOROCCO 345.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: s3442.26
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- s3442.26
- Title
- Dumont 765 kV: Replace 3000 A circuit breaker at Dumont
- Description
- Dumont 765 kV: Replace 3000 A circuit breaker at Dumont to address a generation deliverability violation on the Dumont – Sorenson 765 kV branch related to the new customer interconnections in the area. Projected in service date 3/5/2027
- Cost Information
- Time Estimate
- Dec 01 2026
Not Contingent Note: AG1-447 contributes to the loading of an overloaded facility that is being mitigated by a planned supplemental project. AG1-447 is not contingent on this supplemental project as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05DUMONT-05SORENS 765.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: n3985
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- n3985 / AEPO0036a
- Title
- Upgrade three Marysville Wavetraps ( 3000A)
- Description
- Replace 3 Marysville 765 kV wave traps. Costs updated to $705,368 from Facility Study
- Total Cost ($USD)
- $900,000
- Discounted Total Cost ($USD)
- $900,000
- Allocated Cost ($USD)
- $0
- Time Estimate
- Jul 16 2026
Not Contingent Note: AG1-447 contributes to the loading of an overloaded facility that is being mitigated by a network upgrade that was securitized by a prior Queue/Cycle. AG1-447 is not contingent on this network upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05MARYSV-05SORENS 765.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3775.1
- Type
- Load Flow
- TO
- ComEd
- RTEP ID / TO ID
- b3775.1
- Title
- Swap the NIPSCO Green Acre Tap towers from the St. John-Green Acres-Olive 345 kV line
- 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.
- Cost Information
- Time Estimate
- Mar 30 2027
Contingent Note: Although AG1-447 may not presently have cost responsibility for this upgrade, AG1-447 may need this upgrade in-service to be deliverable to the PJM system. If AG1-447 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.
| Facility | Contingency | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 05OLIVE-05NEW CARLI1 138.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |||||||
| 05OLIVE-AF2-359 TP 345.0 kV Ckt 1 line | (Any) |
| |||||||
| UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3775.10
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b3775.10
- Title
- Perform sag study mitigation work on Olive – University Park
- 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.
- Cost Information
- Time Estimate
- Dec 01 2026
Not Contingent Note: AG1-447 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG1-447 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| UNIV PK N;RP-AF2-359 TP 345.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3775.4
- Type
- Load Flow
- TO
- ComEd
- RTEP ID / TO ID
- b3775.4 / CE_B3775.4
- Title
- Rebuild 345 kV double circuit extending from Crete to E. Frankfort.
- 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.
- Cost Information
- Time Estimate
- Jun 01 2026
Contingent Note: Although AG1-447 may not presently have cost responsibility for this upgrade, AG1-447 may need this upgrade in-service to be deliverable to the PJM system. If AG1-447 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.
| Facility | Contingency | ||
|---|---|---|---|
| (Any) | 765-L11215__-S_SRT-A | No new ratings for this Flowgate. |
Attachments
AG1-447 One Line Diagram
