AG2-106 Phase II System Impact Study Report
v1.00 released 2026-06-03 17:44
Marysville-Flatlick 765 kV
150.0 MW Capacity / 0.0 MW Energy
Introduction
This Phase II System Impact Study (SIS) Report has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 310 for New Service Requests (projects) in Transition Cycle 2 (TC2). The Project Developer/Eligible Customer (developer) is Oak Run Solar Project, LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is AEP Ohio Transmission Company, Inc..
Preface
The Phase II 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 Phase II 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 4.5, PJM takes the following actions during the Phase II System Impact Study:
- PJM will retool load flow results from the Phase I System Impact Study (summer peak, winter peak and light load) based on decisions made by Project Developers or Eligible Customers during Decision Point I.
- PJM will conduct any required voltage analyses.
- PJM will perform short circuit and stability analyses as required.
- PJM will coordinate with the Affected System to confirm which projects in the PJM Cycle will require Affected System studies. If the Affected System Operator indicates that an Affected System study is required, PJM will:
- Notify the Project Developer or Eligible Customer of the need for an Affected System study and the requirement to execute an Affected System study agreement with the impacted Affected System Operator, and;
- Include the results of the Affected System Operator’s Affected System Study in the Phase II System Impact Study results, if applicable and available.
- The Phase II 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 II System Impact Study:
- Verify Interconnection Facilities and Network Upgrades required to accommodate the New Service Request.
- Perform a Facilities Study. The Facilities Study in Phase II System Impact Study phase will be for the physical Interconnection Facilities. The Facilities Study requirements are outlined in Attachment C of this manual. The study will be conducted pursuant to Tariff, Part VII, Subpart D, section 307(A)(7) and Tariff, Part VIII, Subpart C, section 404(A)(7).
Decision Point II Requirements
At the close of Phase II System Impact Study, PJM will initiate Decision Point II (DP2). During DP2, 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 311.A. Additional information on these elements is available in PJM Manual 14H sections 4.6, 6, and 7.
Allowable project modifications at Decision Point II are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
Adverse Test Eligibility
This New Service Request does not meet the Adverse Study Impact Criteria and has the option to either move forward in the Cycle process or withdraw at DP2 with Readiness Deposit #1 forfeited. See adverse study impact calculation below.
This section details whether a Project Developer or Eligible Customer qualifies for the Adverse Study Impact clause outlined in the PJM OATT, Part VII, Subpart D, section 311.B and Manual 14H, section 6.2.2. In order to qualify for an Adverse Study Impact at Decision Point II, the Network Upgrade cost from Phase I to Phase II must:
- Increase overall by 25% or more
- Increases by more than $10,000 per MW (Includes Costs identified in Affected System studies)
If a New Service Request meets the criteria above and chooses to withdraw the request, PJM will refund the cumulative Readiness Deposit amounts paid at the Application Phase and at Decision Point I (RD1 and RD2, respectively).
The below calculations show the computation of this New Service Request's Adverse Study Impact
General
The Project Developer has proposed an uprate to a planned/existing Solar facility located in the AEP Ohio Transmission Company, Inc. zone — Madison County, Ohio. This project is an increase to the developer’s AG1-125/AG1-126 project(s), which will share the same Point of Interconnection. The AG2-106 project is a 150.0 MW Capacity only uprate to the previous project(s). The total installed facilities will have a capability of 800.0 MW with 619.8 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
AG2-106 will interconnect on the American Electric Power transmission system by tapping the Marysville-Flatlick 765 kV Line.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. In Phase II SIS, the interconnected Transmission Owner has performed a facilities study for both the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades. The System Reliability Network Upgrade shown in the table are planning level cost estimates which are subject to change as a result of a facility study performed by the TO during Phase III System Impact Study.
Based on the Phase II SIS results, the AG2-106 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit #3 are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AG2-106 | Cost Subject to Readiness* | Cost Subject to Adverse |
| Transmission Owner Interconnection Facilities (TOIF) | $0 | $0 | $0 |
| Other Scope | $232,867 | $0 | $0 |
| Option To Build Oversight | $0 | $0 | $0 |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $0 | $0 | $0 |
| Network Upgrades | $92,761 | $92,761 | $92,761 |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage | $1,160,359 | $1,160,359 | $1,160,359 |
| Transient Stability | $0 | $0 | $0 |
| Short Circuit | $0 | $0 | $0 |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | $0 |
| Distribution | $0 | $0 | $0 |
| Affected System Reinforcements | |||
| AFS - PJM Violations | $0 | $0 | $0 |
| AFS - Non-PJM Violations | $0 | $0 | $0 |
| Total | $1,485,987 | $1,253,120 | $1,253,120 |
* Contributes to calculation for Readiness Deposit #3 (RD3). 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.
Note 4: Please see the ‘Affected Systems Studies’ section of this Phase II SIS report for details on your project’s need for an Affected Systems Study. If your project requires an Affected Systems Study, the Affected Systems impacts may not be available from the Affected System Operator at the time of the PJM Phase II SIS. Therefore, the cost in this section would not reflect any required upgrades by the Affected System until the study is completed. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 311 (Decision Point II) A.1.b and PJM Manual 14H, section 6.2, Readiness Deposit #3 (RD3) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point II (DP2), the Project Developer or Eligible Customer is required to submit Readiness Deposit #3, which is calculated as 20% of cost allocation for required Phase II Network Upgrades minus Readiness Deposit #1 & Readiness Deposit #2.
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) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (RD2) = 10% of cost allocation for required Network Upgrades minus RD1. Readiness Deposit #2 (RD2) can be zero, but may not be a negative number.
Note 4: Readiness Deposit #3 can be zero, but may not be a negative number.
Readiness Deposit #3 Due for Project AG2-106
Readiness Deposit #3 has been calculated for the project based on the Phase II System Impact Study results and is shown in the table below. This Readiness Deposit #3 must be provided at Decision Point II through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
Readiness Deposit #3 Due for AG2-106
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
Transmission Owner Build Option
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | Review and revision of breaker control settings associated with the customer line, as necessary due to the addition of new sources at the customer station. | $44,758 | $12,003 | $28,387 | $7,613 | $92,761 | $92,761 |
| Other | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | Installation of two (2) 34.5 kV auxiliary submeters for AG2-106, with EDG-37 submeter plate. Installation of the auxiliary submeter, procured by AEP and installed by Project Developer, along with the associated fiber optic cabling. | $180,515 | $15,704 | $36,305 | $343 | $232,867 | $232,867 |
Developer Build Option
(No Developer Build Option for this project.)
| Build Option Price Comparison | |||||||
|---|---|---|---|---|---|---|---|
| Build Option | Total Cost | Allocated Cost | |||||
| Transmission Owner Build Option | $325,628 | $325,628 | |||||
| Developer Build Option | (No Developer Build Option) | ||||||
Based on the scope of work for the Interconnection Facilities, it is expected to take 15 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.
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 AG2-106 was evaluated as a 0.0 MW (150.0 MW Capacity) injection in the AEP area.
AG2-106 was evaluated as part of a plant. The plant consists of AG2-106, AG2-107. The total Energy output of the plant was evaluated at its maximum seasonal capability of 800.0 MW (242.91 MW under study).
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AP_P2-3_PE-765-237806-SB1_SRT-SL_SENS | Breaker | AC | 219.06 % | 1180.0 | B | 2584.92 | 7.6 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AP_P2-3_PE-765-237806-SB2_SRT-SL_SENS | Breaker | AC | 219.06 % | 1180.0 | B | 2584.92 | 7.6 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AP_P1-2_PE-765-237805-237806_SRT-A_SENS | Single | AC | 219.06 % | 1180.0 | B | 2584.91 | 7.6 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AP_P1-2_PE-765-242508-237805_SRT-A_SENS | Single | AC | 219.04 % | 1180.0 | B | 2584.67 | 7.6 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P7-1: LN 2168-555_SRT-A | Tower | AC | 190.42 % | 1180.0 | B | 2246.97 | 6.19 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P7-1: LN 2114-535_SRT-A_SENS | Tower | AC | 186.75 % | 1180.0 | B | 2203.66 | 6.03 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P2-2: BREMO B1_SRT-A | Bus | AC | 182.68 % | 1180.0 | B | 2155.57 | 5.94 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AEP_P2-2_#10265_05LEESVI 138_1_SRT-A | Bus | AC | 182.35 % | 1180.0 | B | 2151.78 | 5.98 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | Base Case | Single | AC | 178.65 % | 1180.0 | A | 2108.09 | 5.95 | |
| GD2 | AEP | 05KAMMER_RG-05KAMMER 765.0 kV Ckt Z1 line | AP_P1-3_MP-765-501T_SRT-A | Single | AC | 104.85 % | 4142.0 | B | 4342.78 | 32.7 | |
| GD2 | AEP | 05KAMMER_RG-05KAMMER 765.0 kV Ckt Z1 line | AEP_P1-2_#706_SRT-A | Single | AC | 104.04 % | 4142.0 | B | 4309.27 | 46.92 | |
| GD2 | AEP | 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | AEP_P1-2_#AG1-125-ADKINS_SRT-A_SENS | Single | AC | 101.48 % | 4571.0 | B | 4638.62 | 59.6 | |
| GD2 | AEP | 05MARYSVL_RM-05MALIS 765.0 kV Ckt 1 line | AEP_P1-2_#AG1-125-ADKINS_SRT-A_SENS | Single | AC | 101.94 % | 4571.0 | B | 4659.48 | 59.6 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | AP | 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | AP_P1-2_MP-500-028_SRT-A | Single | AC | 122.65 % | 3792.0 | B | 4650.99 | 19.37 | |
| GD2 | AP | 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | AP_P1-3_MP-765-502T_SRT-A | Single | AC | 122.64 % | 3792.0 | B | 4650.57 | 19.37 | |
| GD2 | AP | 01FLINTRUN-01HARRSN 500.0 kV Ckt 1 line | AP_P1-3_MP-765-502T_SRT-A | Single | AC | 138.45 % | 3792.0 | B | 5250.02 | 18.85 | |
| GD2 | AP | 01FLINTRUN-01HARRSN 500.0 kV Ckt 1 line | AP_P1-2_MP-500-028_SRT-A | Single | AC | 138.41 % | 3792.0 | B | 5248.4 | 18.85 | |
| GD2 | AP | 01KAMMER-01 502 J 500.0 kV Ckt 1 line | AP_P1-2_MP-500-007A_SRT-A | Single | AC | 131.87 % | 3729.0 | B | 4917.49 | 21.96 | |
| GD2 | AP | 01KAMMER-01 502 J 500.0 kV Ckt 1 line | AP_P1-2_MP-500-008A_SRT-SL | Single | AC | 124.24 % | 3729.0 | B | 4632.89 | 21.2 | |
| GD2 | AEP/AP | 05BELMON-01BELMNT 765.0/500.0 kV Ckt 5 transformer | AP_P1-2_MP-500-028_SRT-A | Single | AC | 100.79 % | 4000.0 | B | 4031.79 | 20.69 | |
| GD2 | AEP/AP | 05BELMON-01BELMNT 765.0/500.0 kV Ckt 5 transformer | AP_P1-3_MP-765-502T_SRT-A | Single | AC | 100.79 % | 4000.0 | B | 4031.62 | 20.69 | |
| GD2 | AEP/AP | 05KAMMER-01KAMMER 765.0/500.0 kV Ckt 1 transformer | AP_P1-2_MP-500-007A_SRT-A | Single | AC | 133.22 % | 3792.0 | B | 5051.83 | 21.96 | |
| GD2 | AEP/AP | 05KAMMER-01KAMMER 765.0/500.0 kV Ckt 1 transformer | AP_P1-2_MP-500-008A_SRT-SL | Single | AC | 125.57 % | 3792.0 | B | 4761.71 | 21.2 | |
| GD2 | AEP | 05MALIS-05VASSEL 765.0 kV Ckt 1 line | AP_P1-3_MP-765-501T_SRT-A | Single | AC | 127.9 % | 4142.0 | B | 5297.56 | 47.51 | |
| GD2 | AEP | 05MALIS-05VASSEL 765.0 kV Ckt 1 line | AEP_P1-2_#706_SRT-A | Single | AC | 108.0 % | 4142.0 | B | 4473.55 | 69.95 | |
| GD2 | AEP | 05MARYSV-05MARYSV 765.0/345.0 kV Ckt 2 transformer | AEP_P1-2_#711_6224_SRT-A | Single | AC | 101.73 % | 3097.0 | B | 3150.57 | 42.14 | |
| GD2 | AEP | 05MARYSV-05MARYSV 765.0/345.0 kV Ckt 2 transformer | AEP_P1-3_#7222_05MALIS 765_1_SRT-A | Single | AC | 101.63 % | 3097.0 | B | 3147.5 | 41.99 | |
| GD2 | AEP | 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | AP_P1-3_MP-765-501T_SRT-A | Single | AC | 126.31 % | 4571.0 | B | 5773.71 | 51.58 | |
| GD2 | AEP | 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | AEP_P1-3_#8072_05MARYSV 765_2_SRT-A | Single | AC | 111.01 % | 4571.0 | B | 5074.41 | 60.48 | |
| GD2 | AEP | 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | Base Case | Single | AC | 110.62 % | 4047.0 | A | 4476.89 | 47.66 | |
| GD2 | AEP | 05MARYSVL_RM-05MALIS 765.0 kV Ckt 1 line | AP_P1-3_MP-765-501T_SRT-A | Single | AC | 126.34 % | 4571.0 | B | 5774.92 | 51.58 | |
| GD2 | AEP | 05MARYSVL_RM-05MALIS 765.0 kV Ckt 1 line | AEP_P1-3_#8072_05MARYSV 765_2_SRT-A | Single | AC | 111.24 % | 4571.0 | B | 5084.88 | 60.48 | |
| GD2 | AEP | 05MARYSVL_RM-05MALIS 765.0 kV Ckt 1 line | Base Case | Single | AC | 110.76 % | 4047.0 | A | 4482.29 | 47.66 | |
| GD2 | AEP | 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | AEP_P1-2_#17217_SRT-A | Single | AC | 116.4 % | 5523.0 | B | 6428.58 | 29.38 | |
| GD2 | AEP | 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | Base Case | Single | AC | 109.18 % | 4558.0 | A | 4976.63 | 17.44 | |
| GD2 | AEP | 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | AEP_P1-2_#7422_16_SRT-A | Single | AC | 106.76 % | 5523.0 | B | 5896.19 | 20.47 |
Winter Peak Analysis
The New Service Request AG2-106 was evaluated as a 0.0 MW (150.0 MW Capacity) injection in the AEP area.
AG2-106 was evaluated as part of a plant. The plant consists of AG2-106, AG2-107. The total Energy output of the plant was evaluated at its maximum seasonal capability of 800.0 MW (300.0 MW under study).
Note: The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for single or N-1 contingencies and multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P1-2: LN 553_SRT-A_SENS | Single | AC | 191.57 % | 1180.0 | B | 2260.48 | 6.38 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P4-2: 542T553_SRT-W_SENS | Breaker | AC | 189.18 % | 1180.0 | B | 2232.37 | 6.4 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P4-2: 553T564_SRT-W_SENS | Breaker | AC | 188.14 % | 1180.0 | B | 2220.0 | 6.41 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AP_P1-2_PE-765-242508-237805_SRT-A_SENS | Single | AC | 183.41 % | 1180.0 | B | 2164.27 | 7.86 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P7-1: LN 2168-555_SRT-A | Tower | AC | 163.69 % | 1180.0 | B | 1931.54 | 6.38 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P7-1: LN 2114-535_SRT-A_SENS | Tower | AC | 161.65 % | 1180.0 | B | 1907.5 | 6.21 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P2-2: BREMO B1_SRT-A | Bus | AC | 157.54 % | 1180.0 | B | 1859.01 | 6.12 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AEP_P2-2_#10265_05LEESVI 138_1_SRT-A | Bus | AC | 157.24 % | 1180.0 | B | 1855.41 | 6.16 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | Base Case | Single | AC | 152.92 % | 1180.0 | A | 1804.49 | 6.13 |
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.)
Light Load Analysis
The New Service Request AG2-106 was evaluated as a 0.0 MW injection and 150.0 MW withdrawal in the AEP area.
AG2-106 was evaluated as part of a plant. The plant consists of AG2-106, AG2-107. The total Energy output of the plant was evaluated at its maximum seasonal capability of 800.0 MW (300.0 MW under study).
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AEP_P1-2_#7422_16_SRT-A | Single | AC | 101.08 % | 1180.0 | B | 1192.76 | 8.47 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | AEP_P4_#7422_05CLOVRD 500_EE2_SRT-A | Breaker | AC | 101.08 % | 1180.0 | B | 1192.76 | 8.47 | |
| IPD | AEP | 05CLOVRD_RJO-05JOSHUA 765.0 kV Ckt 1 line | DVP_P4-2: 56602_SRT-A | Breaker | AC | 101.07 % | 1180.0 | B | 1192.65 | 8.47 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | AEP | 05BOKESCRK-05MARYSV 345.0 kV Ckt 1 line | AEP_P1-2_#7441_100545_SRT-A | Single | AC | 111.71 % | 1301.0 | B | 1453.37 | 9.97 | |
| GD2 | AEP | 05GUNN RD SW-05BOKESCRK 345.0 kV Ckt 1 line | AEP_P1-2_#7441_100545_SRT-A | Single | AC | 100.53 % | 1301.0 | B | 1307.92 | 9.67 | |
| GD2 | AEP | 05HYATT-05VASSEL 345.0 kV Ckt 1 line | AEP_P1-3_#7222_05MALIS 765_1_SRT-A | Single | AC | 101.52 % | 1409.0 | B | 1430.39 | 8.22 | |
| GD2 | AEP | 05HYATT-05VASSEL 345.0 kV Ckt 1 line | AEP_P4_#9728_05MALIS 138_L1_SRT-A | Breaker | AC | 101.22 % | 1409.0 | B | 1426.24 | 6.71 | |
| GD2 | AEP | 05HYATT-05VASSEL 345.0 kV Ckt 1 line | AEP_P4_#9730_05MALIS 138_P1_SRT-A | Breaker | AC | 100.94 % | 1409.0 | B | 1422.27 | 6.69 | |
| GD2 | AEP | 05HYATT-05VASSEL 345.0 kV Ckt 1 line | AEP_P2-2_#7222_05MALIS 765_1_SRT-A | Bus | AC | 100.44 % | 1409.0 | B | 1415.21 | 6.66 |
Short Circuit Analysis
Analysis Complete - No Issues
Based on PJM’s TC2 Phase II Short Circuit Analysis, this project did not contribute >1% fault duty to any previously identified overdutied breakers, nor did it cause any new overdutied breakers.
Please note that in TC2 Phase III, PJM will perform additional analysis including the evaluation of impacts from topology upgrades which may have potential effects on breaker duties not seen in the Phase II analysis.
Stability Analysis
Analysis Complete - No Issues
Executive Summary
New Service Request AG2-106 in PJM Transition Cycle 2, is listed in Table 1 below. This report will cover the dynamic analysis of AG2-106 project.
This analysis is effectively a screening study to determine whether the addition of the AG2-106 project will meet the dynamics requirements of the NERC, AEP and PJM reliability standards.
Since AG2-106 serves as a CIRs-only uprate to AG1-125, AG2-106 was dispatched for stability analysis according to the following scenarios:
a) Scenario 1: AG2-106 dispatched at full MFO injection at the POI with PV MW contribution maxed out and no/reduced MW contribution from BESS.
b) Scenario 2: AG2-106 dispatched at full MFO injection at the POI with BESS MW contribution maxed out, and no/reduced PV MW injection.
c) Scenario 3: AG2-106 dispatched at full MFO injection at the POI with PV and BESS MW contribution proportional to their capacity.
d) Scenario 4: AG2-106 dispatched to full capacity with PV and BESS MW injection maxed out.
This report describes a dynamic simulation analysis of TC2 AG2-106 for dispatch Scenario 3 as part of the overall system impact study.
The load flow scenario for the analysis was based on the RTEP 2028 Summer Peak, modified to include applicable project. AG2-106 project has been dispatched online at maximum power output, with 1.01 p.u. and 1.0 p.u. voltage at the terminal buses of AG2-106 GEN1 and GEN2.
Transition Cycle 2 AG2-106 will be tested for compliance with NERC, PJM and other applicable criteria. The contingencies will be studied with a 20 second simulation time. Contingencies to be studied include:
a. Steady-state operation (Category P0);
b. Three-phase faults with normal clearing time (and with unsuccessful high-speed reclosing) (Category P1);
c. Single-phase bus faults with normal clearing time (Category P2);
d. Single-phase faults with stuck breaker (Category P4);
e. Single-phase faults placed at 80% of the line with delayed (Zone 2) clearing at line end remote from the fault due to primary communications/relay failure (Category P5);
f. Three-phase faults with loss of multiple-circuit tower line; (and with unsuccessful high-speed reclosing) (Category P7).
High Speed Reclosing (HSR) facilities were found in the vicinity of TC2 AG2-106 project.
Prior outage scenarios will not be considered for this study.
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 the fault contingencies tested on the 2028 peak load case:
a) AG2-106 project was able to ride through the faults (except for faults where protective action trips a generator(s)),
b) The system with AG2-106 project included is transiently stable and post-contingency oscillations were positively damped with a damping margin of at least 3% for interarea modes and 4% 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 because of that fault.
In P1.38, multiple unit trips were observed following a fault at the Logtown 138 kV bus. Further investigation determined that all tripping events were associated with T1-131 units, listed below, which belong to a legacy wind facility:
a) TR3_G114 with ID: ‘W1’ (PSS/E Bus# 270191),
b) TR4_S_V150 with ID: ‘W1’ (PSS/E Bus# 270246),
c) TR4_N_V150 with ID: ‘W3’ (PSS/E Bus# 270247),
d) TR4_N_V136 with ID: ‘W2’ (PSS/E Bus# 247521).
Additional analysis indicated that these units were operating at relatively low output levels (approximately 15% of their Pmax), while the system strength in the area remained adequate. This raised concerns regarding the accuracy of the dynamic model for T1-131. Sensitivity testing using alternative generic dynamic models resulted in no observed tripping.
Given the limited contribution of the T1-131 units, they were subsequently g-netted, and no further issues were identified. PJM will consider the latest as-built model of T1-131 for validation in TC2 Phase 3 studies.
The IPCMD and IQCMD states in the REGCA1 model of AG2-106 showed erratic behavior for some contingencies in which AG2-106 has been disconnected as part of the contingency event. Since the machines are 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: Transition Cycle 2 AG2-106 Projects |
|
|
|
|
|
Project | Fuel Type | Transmission Owner | MFO (MW) | CIR (MW) | Point of Interconnection |
AG2-106 | Battery | AEP | 0 | 150 | Marysville – Flatlick 765 kV |
Reactive Power Analysis
Analysis Complete - No Issues
The reactive power capability of AG2-106 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
Steady-State Voltage Analysis
Analysis Complete - No Issues
Steady State Voltage Analysis complete, no voltage issues identified.
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 |
| AB1-006 | Meadow Lake 345kV | In Service |
| AB2-067 | Kammer-Vassell 765kV | In Service |
| AB2-070 | Mt. Pulaski-Brokaw | In Service |
| AB2-170 | East Lima-Marysville 345kV | In Service |
| AC1-001 | Delano 138kV | In Service |
| AC1-033 | Kewanee 138 kV | In Service |
| AC1-044 | Kammer-Vassell 765kV | In Service |
| AC1-053 | Lanesville-Brokaw | In Service |
| AC1-068 | Atlanta 69kV I | In Service |
| AC1-069 | Atlanta 69kV II | In Service |
| AC1-078 | Beatty-London 138kV | In Service |
| AC1-085 | Stuart-Clinton 345kV | In Service |
| AC1-111 | Aurora 138kV | In Service |
| AC1-141 | Cook-East Elkhart 345kV | In Service |
| AC1-165 | Atlanta 69kV III | In Service |
| AC1-166 | Atlanta 69kV IV | In Service |
| AC1-167 | Platter Creek 69kV | Under Construction |
| AC1-168 | Kewanee-Streator | Suspended |
| AC1-174 | Losantville 345kV | In Service |
| AC1-175 | Losantville 345kV | In Service |
| AC1-214 | Crescent Ridge | In Service |
| AC2-029 | Circleville 138kV | Suspended |
| AC2-044 | Maddox Creek 345kV | Suspended |
| AC2-059 | Biers Run-Circleville 138kV | In Service |
| AC2-060 | Buckskin 69kV | In Service |
| AC2-061 | Hillsboro-Clinton 138kV | In Service |
| AC2-067 | Camden-Crystal I 69kV | Engineering & Procurement |
| AC2-068 | Camden-Crystal II 69kV | Engineering & Procurement |
| AC2-088 | S. Bethel-Brown 69kV | In Service |
| AC2-090 | Losantville 345kV | In Service |
| AC2-154 | Davis Creek 138kV | Engineering & Procurement |
| AC2-157 | Sullivan 345 kV | Partially in Service - Under Construction |
| AC2-168 | Clinton 23kV | In Service |
| AC2-176 | Jay 138 kV | In Service |
| AC2-195 | Galion-Roberts South 138 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 |
| AD1-101 | Continental 69 kV | In Service |
| AD1-106 | North Waldo-Wild Creek 138 kV | Withdrawn |
| AD1-119 | Payne 69 kV | In Service |
| AD1-128 | Modoc-Delaware 138 kV | In Service |
| AD1-130 | Hardin Switch 345 kV | In Service |
| AD1-136 | South Bethel-Brown 69 kV | In Service |
| AD1-140 | Greene-Clark 138 kV | Engineering & Procurement |
| AD2-016 | Biers Run-Circleville 138 kV | In Service |
| AD2-020 | Valley 138 kV | Engineering & Procurement |
| AD2-031 | Martinsville-Wilmington 69 kV | In Service |
| 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 |
| AD2-067 | Centerburg 138kV | Engineering & Procurement |
| AD2-071 | Strawton-Deer Creek 138 kV | Suspended |
| AD2-079 | Capitol Ave 34.5kV | In Service |
| AD2-086 | Hardin Switch 345 kV | In Service |
| AD2-091 | Hardin Tap 345kV | Suspended |
| AD2-092 | Marysville 345kV | Withdrawn |
| AD2-093 | Marysville 345kV | Partially in Service - Under Construction |
| AD2-096 | Marysville 345kV | Suspended |
| AD2-100 | Kincaid-Pana 345 kV | Suspended |
| AD2-131 | Kincaid-Pana 345kV | Suspended |
| AD2-133 | Eagle Valley 115kV | In Service |
| AD2-134 | Shady Oaks | Partially in Service - Under Construction |
| AD2-163 | Broadview-Tangy 138 kV | In Service |
| AD2-180 | Elk Garden-Parr Run 138kV | In Service |
| AE1-040 | Greenfield 69 kV | In Service |
| AE1-079 | Maysville-Sharon 69 kV | Under Construction |
| AE1-090 | Hardin Switch 345 kV | In Service |
| AE1-091 | West Newton-Lynn 138 kV | Suspended |
| AE1-092 | Blue Jacket-Kirby 138 kV | Engineering & Procurement |
| AE1-102 | Maddox Creek 345 kV | Suspended |
| AE1-113 | Mole Creek 345 kV | Under Construction |
| AE1-114 | Maryland-Lancaster 138 kV | Engineering & Procurement |
| 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 |
| AE1-172 | Loretto-Wilton Center | Withdrawn |
| AE1-183 | Maysville-McDowell 69 kV | Under Construction |
| AE1-205 | McLean 345 kV | Engineering & Procurement |
| AE1-207 | Mississinewa-Gaston 138 kV | Suspended |
| AE1-208 | Delaware-Van Buren 138 kV | Suspended |
| AE1-209 | Desoto 345 kV | Suspended |
| AE1-210 | Desoto 345 kV | Suspended |
| AE1-237 | Andover (Maysville) 69kV I | Under Construction |
| AE1-245 | Haviland 138 kV | Partially in Service - Under Construction |
| AE2-045 | Olive-Reynolds 345 kV | Engineering & Procurement |
| AE2-072 | East Leipsic-Richland 138 kV | In Service |
| AE2-074 | Potter 46 kV | Under Construction |
| AE2-089 | Pennville-Adams 138 kV | Suspended |
| AE2-113 | Farmers Valley-Ridgeway 115 kV | Under Construction |
| AE2-114 | Midland 23 kV I | In Service |
| AE2-115 | Midland 23 kV II | In Service |
| AE2-125 | Stahlstown-Ligonier 25 kV | In Service |
| AE2-126 | Dubois-Curwensville 34.5 kV | In Service |
| AE2-129 | Philipsburg-Clarence 34.5 kV | In Service |
| AE2-131 | Philipsburg-Karthaus 34.5 | Under Construction |
| AE2-139 | East Towanda-Grover 230 kV | Engineering & Procurement |
| AE2-148 | Beatty-Greene 345 kV | In Service |
| AE2-152 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE2-169 | Delaware-Van Buren 138 kV | Suspended |
| AE2-172 | Mississinewa-Gaston 138 kV | Suspended |
| AE2-206 | East Sidney-Quincy 138 kV | In Service |
| AE2-214 | Cole 345 kV | Under Construction |
| AE2-216 | Hardin Switch 345 kV | Suspended |
| AE2-217 | East Springfield-London 138 kV | Engineering & Procurement |
| AE2-219 | Bluff Point-Randolph 138 kV | Suspended |
| AE2-220 | Losantville 345 kV | Engineering & Procurement |
| AE2-221 | Clinton-Stuart 345 kV | Under Construction |
| AE2-223 | McLean 345 kV | Engineering & Procurement |
| AE2-224 | Bear Rock-Johnstown 230 kV | In Service |
| AE2-234 | Liberty Center-Buckeye Tap 69 kV | Engineering & Procurement |
| AE2-236 | Columbia-Northeast 138 kV | Suspended |
| AE2-255 | Molecreek 345 kV | Under Construction |
| AE2-261 | Kincaid-Pana 345 kV | Engineering & Procurement |
| AE2-285 | Maysville 69 kV | Under Construction |
| AE2-297 | Madison-Tanners Creek 138 kV | In Service |
| AE2-298 | Cavett Switch - West Van Wert 69 kV | Withdrawn |
| AE2-305 | Givens-Mechanicsburg 138 kV | Withdrawn |
| AE2-306 | Gunn Road 345 kV | Under Construction |
| AE2-309 | Carlos Junction-Lonaconing 34.5 kV | In Service |
| AE2-315 | Yankee Tap 69 kV | In Service |
| AE2-318 | Ford-Cedarville 138 kV | Suspended |
| AE2-322 | Platter Creek 69kV | Under Construction |
| AE2-323 | Twin Branch-Guardian 138 kV | Partially in Service - Under Construction |
| AE2-325 | Valley 138 kV | Withdrawn |
| AE2-341 | Sandwich-Plano 138 kV | Engineering & Procurement |
| AE2-342 | Woodstock 69 kV | Suspended |
| AE2-343 | Andover (Maysville) 69 kV II | Under Construction |
| AF1-006 | Fairview East 34.5 kV | In Service |
| AF1-021 | Bethelboro-Connellsville #1 25 kV | In Service |
| AF1-022 | Lake Lynn-Uniontown 25 kV | In Service |
| AF1-030 | Sandwich-Plano 138 kV | Engineering & Procurement |
| AF1-039 | Listonburg-Highpoint 24.9 kV | In Service |
| AF1-045 | Cedarville-Ford 138 kV | Suspended |
| AF1-053 | Givens-Mechanicsburg 138 kV | Withdrawn |
| AF1-054 | Givens-Mechanicsburg 138 kV | Withdrawn |
| AF1-062 | Jug Street 138 kV | Engineering & Procurement |
| AF1-078 | East Sidney-Quincy 138 kV | In Service |
| AF1-084 | Hartford-Almena 69 kV | Under Construction |
| AF1-086 | Madera-Westover South 115 kV | Partially in Service - Under Construction |
| AF1-090 | Kincaid-Pana | Engineering & Procurement |
| AF1-091 | Varner - Sowers 138 kV | Engineering & Procurement |
| AF1-092 | Huntington Jct. 138 kV | Withdrawn |
| AF1-093 | Henderson-Stoneboro 69 kV | Under Construction |
| AF1-094 | Union City-Cambridge Springs 34.5 kV | Engineering & Procurement |
| AF1-098 | Four Mile Jct-Corry East 115 kV | Suspended |
| AF1-118 | Sorenson-Desoto 345 kV | Withdrawn |
| AF1-119 | Keystone-Desoto 345 kV | Engineering & Procurement |
| AF1-122 | Cardington-Liberty 69 kV | Suspended |
| AF1-134 | Philipsburg-Madera 34.5 kV | Under Construction |
| AF1-140 | Claysburg 23 kV | Engineering & Procurement |
| AF1-158 | Edison-Gravel Pit 138 kV | In Service |
| AF1-161 | Valley 138 kV | Engineering & Procurement |
| AF1-176 | Corey 138 kV | Engineering & Procurement |
| AF1-202 | Keystone-Desoto 345 kV | Under Construction |
| AF1-204 | Eugene 345 kV | Engineering & Procurement |
| AF1-207 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF1-215 | Olive-Reynolds 345 kV | In Service |
| AF1-223 | Keystone-Desoto 345 kV | Under Construction |
| AF1-227 | Marysville – Gunn Road 345 kV | In Service |
| AF1-228 | Beatty-Greene 345 kV | Under Construction |
| AF1-249 | Nickel 12.47 kV | In Service |
| AF1-268 | Desoto-Jay 138 kV | Engineering & Procurement |
| AF1-272 | Lucerne 115 kV | Engineering & Procurement |
| AF1-275 | Cole 345 kV | Under Construction |
| AF1-282 | Stuart-Clinton 345 kV | Engineering & Procurement |
| AF1-283 | Stuart-Clinton 345 kV | Engineering & Procurement |
| AF1-285 | Gunn Road 345 kV | Under Construction |
| AF1-296 | Garden Plain 138 kV | Engineering & Procurement |
| AF1-302 | Brookville-Squab Hollow 138 kV | Under Construction |
| AF1-322 | Meadow Lake 345 kV | Under Construction |
| AF1-331 | Twombley Road | Engineering & Procurement |
| AF2-014 | Maddox Creek 345 kV | Under Construction |
| AF2-032 | Kincaid 345 kV | Withdrawn |
| AF2-039 | Shawville-Clearfield 34.5 kV | Under Construction |
| AF2-041 | Nelson-Electric Junction 345 kV | Engineering & Procurement |
| AF2-068 | Jay 138 kV | Engineering & Procurement |
| AF2-078 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF2-083 | Kenzie Creek-Stone Lake 69 kV | Under Construction |
| AF2-088 | Shawville-Clearfield 34.5 kV II | Under Construction |
| AF2-095 | Davis Creek 138 kV | Engineering & Procurement |
| AF2-103 | Haviland 138 kV | In Service |
| AF2-111 | North Clark-Spurlock 345 kV | Engineering & Procurement |
| AF2-122 | Kirk 138 kV | Partially in Service - Under Construction |
| AF2-130 | Cobalt Corners 34.5 kV | In Service |
| 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 |
| AF2-149 | Sharp Road 69 kV | Engineering & Procurement |
| AF2-162 | Keystone-Desoto 345 kV | Engineering & Procurement |
| AF2-177 | Sorenson-DeSoto #2 345 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 |
| AF2-224 | Allen 345 kV | Engineering & Procurement |
| AF2-225 | McLean 345 kV | Engineering & Procurement |
| AF2-252 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-298 | Crown-New Lebanon 69 kV | Engineering & Procurement |
| AF2-350 | Kensington 138 kV | Engineering & Procurement |
| AF2-352 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-356 | Albright-Mt. Zion 138 kV | Partially in Service - Under Construction |
| AF2-359 | Olive-University Park 345 kV | Engineering & Procurement |
| AF2-366 | Crego Rd 138 kV | Engineering & Procurement |
| AF2-371 | Harrison-Good Hope 138 kV | Engineering & Procurement |
| AF2-388 | Keystone-Desoto 345 kV | Engineering & Procurement |
| AF2-396 | Stinger 138 kV | Engineering & Procurement |
| AG1-017 | Jay 138 kV | In Service |
| AG1-024 | Centerburg 138 kV | Engineering & Procurement |
| AG1-034 | Centerburg 138 kV | Engineering & Procurement |
| AG1-040 | Morgan Street-Mount Hope 34.5 kV | Engineering & Procurement |
| AG1-047 | Jay 138 kV | Engineering & Procurement |
| AG1-054 | Potter-Harlan 69 kV | Engineering & Procurement |
| AG1-100 | Venango-Saegertown 34.5 kV | Engineering & Procurement |
| AG1-107 | Hillsboro-Middleboro 138 kV | Under Construction |
| AG1-109 | Valley 138 kV | Engineering & Procurement |
| AG1-118 | Sugar Grove-Waterman 138kV | Engineering & Procurement |
| AG1-125 | Marysville-Flatlick 765 kV | Engineering & Procurement |
| AG1-126 | Marysville-Flatlick 765 kV | Engineering & Procurement |
| AG1-127 | Crego Rd 138 kV | Engineering & Procurement |
| AG1-198 | Union City 34.5 kV | In Service |
| AG1-226 | Dequine-Eugene 345 kV | Engineering & Procurement |
| AG1-232 | Magley 138 kV | Engineering & Procurement |
| AG1-237 | Dequine-Eugene 345 kV | Engineering & Procurement |
| AG1-281 | Claysburg-HCR Tap 46 kV | Engineering & Procurement |
| AG1-302 | Olive-Reynolds #1 345 kV | Under Construction |
| AG1-324 | Jay-Desoto 138 kV | Engineering & Procurement |
| AG1-349 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AG1-351 | Harrison-Good Hope 138 kV | Engineering & Procurement |
| AG1-363 | Black Oak-Hatfield 500 kV | Engineering & Procurement |
| AG1-365 | Allen 345 kV | Engineering & Procurement |
| AG1-366 | Allen 345 kV | Engineering & Procurement |
| AG1-368 | Tillman 138 kV | Engineering & Procurement |
| AG1-369 | Logtown 138 kV | Engineering & Procurement |
| AG1-374 | Blue Mound 345 kV | Engineering & Procurement |
| AG1-386 | Smith-Francis Junction 25 kV | In Service |
| AG1-410 | Maddox Creek-RP Mone 345 kV | Engineering & Procurement |
| AG1-411 | Maddox Creek-RP Mone 345 kV | Engineering & Procurement |
| AG1-414 | Mississinewa 138 kV | Engineering & Procurement |
| AG1-433 | Keystone-DeSoto 345 kV | Engineering & Procurement |
| AG1-436 | Olive-University Park 345 kV | Engineering & Procurement |
| AG1-447 | Olive-University Park 345 kV | Engineering & Procurement |
| AG1-460 | Kincaid-Pana 345 kV | Engineering & Procurement |
| AG1-462 | Cordova 345 kV | Engineering & Procurement |
| AG1-478 | Wilmington 34.5 kV | Engineering & Procurement |
| AG1-554 | South Kenton 138 kV | Engineering & Procurement |
| AG1-555 | Dequine 345 kV | Engineering & Procurement |
| AG2-029 | Forest G. Hipple-Dunton Lake 345 kV | Active |
| AG2-057 | Cardington-Liberty 69 kV II | Active |
| AG2-061 | Dana 345 kV | Active |
| AG2-072 | Rockport 765 kV | Active |
| AG2-104 | Marysville-Flatlick 765 kV | Active |
| AG2-107 | Marysville-Flatlick 765 kV | Active |
| AG2-114 | Dresden-Pontiac Midpoint 345 kV | Active |
| AG2-119 | Galion-Roberts South 138 kV II | Active |
| AG2-125 | Camden-Crystal 69 kV | Active |
| AG2-126 | Eugene 345 kV | Active |
| AG2-163 | Dequine-Eugene 345 kV | Active |
| AG2-191 | Mississinewa 138 kV | Active |
| AG2-192 | Mississinewa 138 kV | Active |
| AG2-216 | East Sidney-Quincy 138 kV | Active |
| AG2-230 | Dumont 345 kV | Active |
| AG2-245 | Olive - Reynolds #1 345 kV | Active |
| AG2-332 | East Elkhart - Elcona Tap 138 kV | Active |
| AG2-363 | Powerton 345 kV | Active |
| AG2-364 | Powerton 345 kV | Active |
| AG2-401 | Losantville 345 kV | Active |
| AG2-405 | Continental 69 kV | Active |
| AG2-406 | Payne 69 kV | Active |
| AG2-453 | Lasalle - Plano 345 kV | Active |
| AG2-487 | Madison - Tanners Creek 138 kV | Active |
| AG2-491 | Meadow Lake 345 kV | Active |
| AG2-516 | Pecatonica 138kV | Active |
| AG2-519 | Royerton - Desoto 138 kV | Active |
| AG2-524 | LaSalle Station - Mazon 138 kV | Active |
| AG2-550 | Bluff Point - Randolph 138 kV | Active |
| AG2-551 | Bluff Point - Randolph 138 kV | Active |
| AG2-585 | Kensignton 138kV | Active |
| AG2-637 | Randolph - Hodgin 138 kV | Active |
| AG2-660 | Nelson-Electric Junction 345 kV | Active |
| AG2-675 | Cordova 345 kV | Active |
| AH1-044 | Nelson - Electric Junction 345 kV | Active |
| AH1-059 | Sharp Road 69 kV | Active |
| AH1-060 | Cardington-Liberty 69 kV III | Active |
| AH1-150 | Nelson-Electric Junction 345 kV | Active |
| AH1-151 | Nelson-Electric Junction 345 kV | Active |
| AH1-153 | Dumont 345 kV | Active |
| AH1-196 | Silver Lake - Cherry Valley 345 kV | Active |
| AH1-272 | Argenta - Twin Branch 345 kV | Active |
| AH1-292 | Sullivan 345 kV | Active |
| AH1-302 | Olive - Reynolds 345 kV | Active |
| AH1-304 | Delaware-Van Buren 138 kV | Active |
| AH1-305 | Olive - Reynolds 345 kV | Active |
| AH1-306 | Mississinewa-Gaston 138 kV | Active |
| AH1-327 | Hardin Switch 345 kV | Active |
| AH1-328 | Blue Jacket - Kirby 138 kV | Active |
| AH1-338 | New Sub S2354 138kV | Active |
| AH1-341 | ESS-H445 3B 138kv | Active |
| AH1-392 | Gravel Pit-Kankakee 138 kV | Active |
| AH1-482 | Olive - Reynolds #2 345 kV | Active |
| AH1-541 | Chestnut 345 kV | Active |
| AH1-542 | Crissinger-Delaware Business Park 138kV | Active |
| AH1-543 | Mulberry - Tazewell 345 kV | Active |
| AH1-567 | University Park 138 kV | Active |
| AH1-661 | Cannelville 12.47 kV | Active |
| AH1-698 | Braidwood 345 kV | Active |
| AH1-702 | Byron 345 kV | Active |
| AH1-714 | Lasalle 345 kV | Active |
| AH1-718 | Nelson 345 kV | Active |
| U2-030 | Four Mile Ridge Wind 138kV | In Service |
| U2-072 | East Lima-Marysville 345kV | In Service |
| U2-073 | Frostburg 138kV II | In Service |
| V1-011 | Haviland 138kV | In Service |
| V3-007 | Desoto-Tanners Creek #1 345kV | In Service |
| V4-073 | Yankee 12.5kV | In Service |
| W2-048 | Brokaw-Lanesville | In Service |
| X2-022 | Brokaw-Lanesville | In Service |
| X2-052 | Dumont-Olive 345kV | In Service |
| X3-005 | Wildwood 12kV | In Service |
| Y1-033 | Penn Mar-Rock Wood 115kV | In Service |
| Y3-023 | Country Side 12kV | In Service |
| Y3-024 | Bluff Point 12kV | In Service |
| Z2-087 | Pontiac MidPoint-Brokaw 345kV | In Service |
| Z2-115 | Deer Creek 12.47kV | In Service |
| Z2-116 | Twin Branch 12.47kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, per Tariff Part VII.G.336 & Manual 14H, Section 13, 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.
Affected System - Non-PJM Identified Violations
In accordance with PJM Tariff Part VII, Subpart D, section 310.A and as outlined in PJM Manual 14H, Sections 4.5 and 13, in Phase II of the Cycle, PJM provides the Affected System Operator any updates on the PJM projects that require an Affected Systems Study based on their response at DP1. New Service Requests that require an Affected Systems Study are required to enter into an Affected Systems Study Agreement with the Affected System Operator, as applicable, prior to the close of DP2 or they will be withdrawn from the Cycle.
If the Project Developer already entered into the necessary agreement and the results are available, PJM will supply them in the Phase II SIS report. See below for the status of any required Affected Systems Study. A status of “Pending” means that the study is not yet completed by the Affected System Operator. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
System Reinforcements
Based on the Phase II 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 |
|---|---|---|---|---|---|
| AEP | n9767.0 | 05KAMMER_RG 765.0 kV to 05KAMMER 765.0 kV ckt Z1 - Replace Wavetraps | Cost Allocated | $580,123 | N/A |
| AEP | n9786.0 | 05MARYSVL_RM 765.0 kV to 05MALIS 765.0 kV ckt 1 - Replace Wave Traps | Cost Allocated | $424,563 | N/A |
| AEP | n9766.0 | 05MARYSV 765.0 kV to 05MARYSVL_RM 765.0 kV ckt Z1 - Replace Wavetrap | Cost Allocated | $155,673 | N/A |
| APS | b4000.11 | Expand Black Oak Substation & Loop in the 502 Jct-Woodside 500 kV line (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| AEP | b4000.1 | Add two 765 kV breakers at Amos Substation to expand the breaker and a half scheme to accommodate the new Amos-Welton Spring 765 kV line (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.2 | Construct a new 175 miles Amos to Welton Spring 765 kV line - AEP Section of the line is 30 miles (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.3 | Construct a new 175 miles Amos to Welton Spring 765 kV line - APS/FE Section of the line is 145 miles (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.4 | Construct a new 765 kV switchyard - Welton Spring (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.5 | Install four 250 MVAR shunt capacitors, and a +/-500 MVAR STATCOM at Welton Spring 765 kV substation | Contingent | $0 | N/A |
| APS | b4000.6 | Construct a new 86 miles Welton Spring to Rocky Point 765 kV line (Welton Spring to DVP local area, roughly 21 miles) (VA Portion) | Contingent | $0 | N/A |
| APS | b4000.7 | Construct a new 86 miles Welton Spring to Rocky Point 765 kV line - in DVP local area/Millville to Lovettsville section, roughly 10.5 miles (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.8 | Construct a new 86 miles Welton Spring to Rocky Point 765 kV line (DVP local area to Rocky Point, roughly 4.8 miles) | Contingent | $0 | N/A |
| APS | b4000.9 | Construct a new substation called Rocky Point with a 765 kV and a 500 kV yard (Projected ISD 6/1/2029) | Contingent | $0 | N/A |
| APS | b4000.10 | Install four 250 MVAR cap banks (two on 765 and two on 500 kV side) and a +/-500 MVAR STATCOM on the 765 kV Rocky Point yard | Contingent | $0 | N/A |
| AEP | b4068.1 | b4068: Greentown 765 kV - Teddy 765kV - Marysville 765 kV - Greenfield Line - AEP Proposal 570 | Contingent | $0 | N/A |
| AEP | b3919.1 | Reconfigure Maliszewski 765 kV station and establish 345 kV breaker yard | Contingent | $0 | N/A |
| AEP | b4000.251 | Replace the wave trap and upgrade the relay at Cloverdale 765kV substation | Contingent | $0 | N/A |
| AEP | b4000.252 | Replace the wave trap and upgrade the relay at Joshua Falls 765kV substation | Contingent | $0 | N/A |
| AEP | b3919.5 | Reconductor 4.75-miles of the existing Bokes Creek-Marysville 345 kV circuit. | Contingent | $0 | N/A |
| Grand Total: | $1,160,359 | ||||
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement: n9767.0
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- n9767.0 / AEP-TC2-19068
- Title
- 05KAMMER_RG 765.0 kV to 05KAMMER 765.0 kV ckt Z1 - Replace Wavetraps
- Description
- Replace the existing 3000A wave trap at Kammer 765 station towards Guernsey with a 5000A wave trap. Additionally, replace the 3000A circuit breaker QQ1 with a 5000A circuit breaker. Disconnect switches and a relays will be upgraded as well.
- Total Cost ($USD)
- $4,500,000
- Discounted Total Cost ($USD)
- $4,500,000
- Allocated Cost ($USD)
- $580,123
- Time Estimate
- 48 to 54 Months
Contributor
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AG2-072 | 52.6 MW | 20.7% | $933,153 |
| AG2-104 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 37.2 MW | 14.7% | $660,025 |
| AG2-106 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 32.7 MW | 12.9% | $580,123 |
| AG2-107 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 32.7 MW | 12.9% | $580,123 |
| AG2-363 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 26.1 MW | 10.3% | $462,168 |
| AG2-364 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 17.4 MW | 6.8% | $308,112 |
| AG2-660 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 2.9 MW | 1.1% | $51,376 |
| AH1-044 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 17.4 MW | 6.9% | $308,307 |
| AH1-150 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 17.4 MW | 6.9% | $308,307 |
| AH1-151 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 17.4 MW | 6.9% | $308,307 |
System Reinforcement: n9786.0
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- n9786.0 / AEP-TC2-19161
- Title
- 05MARYSVL_RM 765.0 kV to 05MALIS 765.0 kV ckt 1 - Replace Wave Traps
- Description
- Replace wave tap at Maliszewski towards Marysville
- Total Cost ($USD)
- $3,000,000
- Discounted Total Cost ($USD)
- $3,000,000
- Allocated Cost ($USD)
- $424,563
- Time Estimate
- 24 to 36 Months
Contributor
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05MALIS-05MARYSVL_RM 765.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AG2-072 | 75.4 MW | 20.7% | $620,901 |
| AG2-104 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 59.0 MW | 16.2% | $485,654 |
| AG2-106 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 51.6 MW | 14.2% | $424,563 |
| AG2-107 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 51.6 MW | 14.2% | $424,563 |
| AG2-363 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 30.8 MW | 8.5% | $253,734 |
| AG2-364 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 20.6 MW | 5.6% | $169,150 |
| AG2-660 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 2.8 MW | 0.8% | $23,187 |
| AH1-044 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $199,416 |
| AH1-150 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $199,416 |
| AH1-151 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $199,416 |
System Reinforcement: n9766.0
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- n9766.0 / AEP-TC2_19067
- Title
- 05MARYSV 765.0 kV to 05MARYSVL_RM 765.0 kV ckt Z1 - Replace Wavetrap
- Description
- Replace 4000A Wavetrap towards Maliszewski with 5000A equivalent
- Total Cost ($USD)
- $1,100,000
- Discounted Total Cost ($USD)
- $1,100,000
- Allocated Cost ($USD)
- $155,673
- Time Estimate
- 36 to 48 Months
Contributor
| Facility | Contingency | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AG2-072 | 75.4 MW | 20.7% | $227,664 |
| AG2-104 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 59.0 MW | 16.2% | $178,073 |
| AG2-106 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 51.6 MW | 14.2% | $155,673 |
| AG2-107 ⧉ New AG1-125 swyd (Marysville - Flatlick 765 kV) (AEP): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-104, AG2-106, AG2-107 | 51.6 MW | 14.2% | $155,673 |
| AG2-363 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 30.8 MW | 8.5% | $93,036 |
| AG2-364 ⧉ Powerton ;B 345 kV (ComEd): This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-363, AG2-364 | 20.6 MW | 5.6% | $62,022 |
| AG2-660 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 2.8 MW | 0.8% | $8,502 |
| AH1-044 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $73,119 |
| AH1-150 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $73,119 |
| AH1-151 ⧉ Nelson-Electric Junction 345kV - ComEd: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG2-660, AH1-044, AH1-150, AH1-151 | 24.2 MW | 6.6% | $73,119 |
System Reinforcement: b4000.11
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.11
- Title
- Expand Black Oak Substation & Loop in the 502 Jct-Woodside 500 kV line (Projected ISD 6/1/2029)
- Description
- Expand Black Oak Substation to accommodate the connection of the 502 Jct-Woodside 500 kV line and loop the 502 Jct-Woodside 500 kV line into the Black Oak substation by constructing ~0.85 miles of new 500 kV line into and out of Black Oak 500 kV substation
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.1
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b4000.1
- Title
- Add two 765 kV breakers at Amos Substation to expand the breaker and a half scheme to accommodate the new Amos-Welton Spring 765 kV line (Projected ISD 6/1/2029)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.2
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.2
- Title
- Construct a new 175 miles Amos to Welton Spring 765 kV line - AEP Section of the line is 30 miles (Projected ISD 6/1/2029)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.3
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.3
- Title
- Construct a new 175 miles Amos to Welton Spring 765 kV line - APS/FE Section of the line is 145 miles (Projected ISD 6/1/2029)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.4
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.4
- Title
- Construct a new 765 kV switchyard - Welton Spring (Projected ISD 6/1/2029)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.5
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.5
- Title
- Install four 250 MVAR shunt capacitors, and a +/-500 MVAR STATCOM at Welton Spring 765 kV substation
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.6
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.6
- Title
- Construct a new 86 miles Welton Spring to Rocky Point 765 kV line (Welton Spring to DVP local area, roughly 21 miles) (VA Portion)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.7
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.7
- Title
- Construct a new 86 miles Welton Spring to Rocky Point 765 kV line - in DVP local area/Millville to Lovettsville section, roughly 10.5 miles (Projected ISD 6/1/2029)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.8
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.8
- Title
- Construct a new 86 miles Welton Spring to Rocky Point 765 kV line (DVP local area to Rocky Point, roughly 4.8 miles)
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.9
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.9
- Title
- Construct a new substation called Rocky Point with a 765 kV and a 500 kV yard (Projected ISD 6/1/2029)
- Description
- Construct a new substation called Rocky Point with a 765 kV and a 500 kV yard. Loop in the Doubs-Goose Creek 500 kV line, the Doubs-Aspen 500 kV line, and the Woodside-Goose Creek 500 kV line. Install two 765/500 kV transformer at Rocky Point substation. 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.10
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- b4000.10
- Title
- Install four 250 MVAR cap banks (two on 765 and two on 500 kV side) and a +/-500 MVAR STATCOM on the 765 kV Rocky Point yard
- Description
- 765kV Solution: 2024 W1 Solution - Regional Cluster Ties Doubs 500kV area to John Amos 765kV via a new 765kV line
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 01BELMNT-05BELMON 500.0/765.0 kV Ckt 5 transformer | (Any) | No new ratings for this Flowgate. | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MOUNTN-05BELMON 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | No new ratings for this Flowgate. | |
| 01BELMNT-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 01HARRSN-01FLINTRUN 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05KAMMER-05KAMMER_RG 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. | |
| 05HYATT-05VASSEL 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4068.1
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b4068.1 / AEP-TC2-18693
- Title
- b4068: Greentown 765 kV - Teddy 765kV - Marysville 765 kV - Greenfield Line - AEP Proposal 570
- Description
- b4068.1 through b4068.49: Affected Transmission Owners: AEP / Dayton / ATSI The objective of this project is to construct multiple transmission lines to address Ohio area violations. The total distance covered by the lines is approximately 359.54 miles. The first transmission line ranges from the existing Greentown Substation in Howard County, Indiana to the new Teddy Substation in Clark County, Ohio, the line then branches north towards the existing Marysville Substation in Union County, Ohio, and east to the existing Beatty Substation in Franklin County, Ohio, and then extends to the existing Cole Substation in Franklin County, Ohio. The second transmission line extends from the existing Adkins Substation in Pickaway County, Ohio, to the new West Millersport Substation in Fairfield County, Ohio, then continues to the existing Conesville Substation in Coshocton County, Ohio before finally extending to the existing Guernsey Substation in Guernsey County, Ohio. There is a total of five transmission lines that extend between unnamed substations (Hayden - Cole 345 kV, Hyatt - Maliszewski 345 kV [double circuit], Roberts - Kenny 138 kV, Wilson - 5th Avenue 138 kV, West Millersport-Kirk 345 kV). This project will traverse 4 counties (Howard, Grant, Blackford, Jay) in Indiana, and 13 counties (Darke, Shelby, Champaign, Clark, Madison, Franklin, Delaware, Pickaway, Fairfield, Licking, Muskingum, Coshocton, Guernsey) in Ohio. This proposal has a total of 38 components, including 16 substation upgrade components, two greenfield substation components, eight greenfield transmission line components covering approximately 336.2 miles, and 12 transmission line upgrade components covering approximately 23.34 miles. b4068.28/b4068.49 is dependent on b3919.1 Baseline completion.
- Cost Information
- Time Estimate
- Jun 01 2030
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 05MARYSV-05MARYSV 765.0/345.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 05MARYSV-05BOKESCRK 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05GUNN RD SW-05BOKESCRK 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MALIS-05VASSEL 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MALIS-05MARYSVL_RM 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3919.1
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b3919.1
- Title
- Reconfigure Maliszewski 765 kV station and establish 345 kV breaker yard
- Description
- Reconfigure Maliszewski 765 kV station from 2 breakers to a 6 breaker ring bus. Install a new 765/345 kV transformer. Establish new 345 kV breaker yard with 3 string breaker and a half to include a line exit to Hyatt and a line exit to Corridor. Loop the existing Hyatt - West Millersport 345 kV line into the new established 345 kV yard at the Maliszewski station.
- Cost Information
- Time Estimate
- Jun 01 2029
ContingentTopology Changing Note 1: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| 05MARYSV-05MARYSV 765.0/345.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 05MARYSV-05BOKESCRK 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05GUNN RD SW-05BOKESCRK 345.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MALIS-05VASSEL 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MALIS-05MARYSVL_RM 765.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 05MARYSV-05MARYSVL_RM 765.0 kV Ckt Z1 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b4000.251
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b4000.251
- Title
- Replace the wave trap and upgrade the relay at Cloverdale 765kV substation
- Description
- Replace the wave trap and upgrade the relay at Cloverdale 765kV substation
- Cost Information
- Time Estimate
- Jun 01 2029
Contingent Note: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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 | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05JOSHUA-05CLOVRD_RJO 765.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b4000.252
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b4000.252
- Title
- Replace the wave trap and upgrade the relay at Joshua Falls 765kV substation
- Description
- Replace the wave trap and upgrade the relay at Joshua Falls 765kV substation
- Cost Information
- Time Estimate
- Jun 01 2029
Contingent Note: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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 | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05JOSHUA-05CLOVRD_RJO 765.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3919.5
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- b3919.5 / (Pending)
- Title
- Reconductor 4.75-miles of the existing Bokes Creek-Marysville 345 kV circuit.
- Description
- Reconductor 4.75-miles of the existing Bokes Creek-Marysville 345 kV circuit. Update the associated relay settings.
- Cost Information
- Time Estimate
- Jun 01 2029
Contingent Note: Although AG2-106 may not presently have cost responsibility for this upgrade, AG2-106 may need this upgrade in-service to be deliverable to the PJM system. If AG2-106 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 | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 05MARYSV-05BOKESCRK 345.0 kV Ckt 1 line | (Any) |
|
Attachments
AG2-106 One Line Diagram
