AG2-418 Phase I Study Report
v1.00 released 2025-10-29 20:37
Blain 115 kV
20.0 MW Capacity / 40.0 MW Energy
Introduction
This Phase I System Impact Study Report (PH1) has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, sections 307 and 308 for New Service Requests (projects) in Transition Cycle 2. The Project Developer/Eligible Customer (developer) is Wills Creek Solar LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Mid-Atlantic Interstate Transmission, LLC.
Preface
The Phase I System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase I System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.3, PJM takes the following actions during the Phase I System Impact Study:
- PJM studies each New Service Request on a summer peak, winter peak and light load RTEP base case study. The case year is dependent on the new services cycle under study. PJM will identify the base case year to be used in the study of a specific cycle on its website.
- PJM will only perform load flow analysis during the Phase I System Impact Study.
- In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with Affected System impacts and provides each Affected System Operator with a list of New Service Request in the Cycle with potential impacts to their respective system.
- PJM will create both the short circuit and stability base cases to be used in the Phase II System Impact Study.
- The Phase I System Impact Study results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase I System Impact Study:
- Identify required Interconnection Facilities to accommodate the New Service Request.
- Identify required Network Upgrades to mitigate system violations from the Phase I System Impact Study.
- Provide planning-level preliminary estimates of Interconnection Facilities and Network Upgrades including scope, cost and elapsed time to complete the work.
Decision Point I Requirements
At the close of Phase I System Impact Study, PJM will initiate Decision Point I (DP1). During DP1, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.A.1. Additional information on these elements is available in PJM Manual 14H sections 4.4, 6, and 7.
Allowable project modifications at Decision Point I are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
General
The Project Developer has proposed a Solar/Storage generating facility located in the Mid-Atlantic Interstate Transmission, LLC zone — Perry County, Pennsylvania. The installed facilities will have a total capability of 40.0 MW with 20.0 MW of this output being recognized by PJM as Capacity.Project Information
Physical Interconnection Facility Study
Physical Interconnection Facilities Study is not performed as part of the Phase I System Impact Study. Physical Interconnection Facilities Study will commence in the Phase II System Impact Study.
Point of Interconnection
AG2-418 will interconnect on the Mid-Atlantic Interstate Transmission, LLC transmission system as a direct connect at the Blain 115 kV substation.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. In the Phase I SIS, the costs shown are subject to change as a result of a facility study performed by the TO during the Phase II or Phase III System Impact Study.
Based on the Phase I SIS results, the AG2-418 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AG2-418 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $823,627 | $0 | |
| Other Scope | $59,600 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $1,490,000 | $1,490,000 | |
| Network Upgrades | $11,484,686 | $11,484,686 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $66,928,102 | $66,928,102 | |
| Transient Stability | $0 | $0 | |
| Short Circuit | $0 | $0 | |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | |
| Distribution | $0 | $0 | |
| Affected System Reinforcements | |||
| AFS - PJM Violatons | $0 | $0 | |
| AFS - Non-PJM Violations | $0 | $0 | |
| Total | $80,786,015 | $79,902,788 | |
* Contributes to calculation for Readiness Deposit #2 (RD2). See Readiness Deposit section of report for additional detail.
Definitions
Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.
Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.
Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.
Notes
Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.
Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.
Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim deliverability study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 309 (Decision Point I) A.1.a.i and PJM Manual 14H, section 6.2, Readiness Deposit #2 (RD2) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point I (DP1), the Project Developer or Eligible Customer is required to submit Readiness Deposit #2, which is calculated as 10% of cost allocation for required Phase I Network Upgrades minus Readiness Deposit #1.
Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.
Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (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.
Readiness Deposit #2 Due for Project AG2-418
Readiness Deposit #2 has been calculated for the project based on the Phase I System Impact Study results and is shown in the table below. This Readiness Deposit #2 must be provided at Decision Point I through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
| Readiness Deposit | |||
|---|---|---|---|
| Project ID | 10% of cost allocation for Phase I Network Upgrades | Readiness Deposit #1 Received (RD1) | Readiness Deposit #2 (RD2) for AG2-418 Project due at DP1 |
| A | B | A - B | |
| AG2-418 | $7,990,279 | $160,000 | $7,830,279 |
Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
| Transmission Owner Interconnection Facilities | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Integrate interconnection facilities protection and controls to the Transmission Owner system. | $62,580 | $62,580 |
| (Pending) | Construction of one (1) span of conductor from the existing/reconfigured substation to the developer owned dead end structure at the Point of Change in Ownership. | $761,047 | $761,047 |
| Stand-Alone Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Extend fiber to new interconnection substation. | $1,490,000 | $1,490,000 |
| Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Expand/reconfigure the existing Blain 115 kV substation into a 3-breaker ring bus. | $9,753,111 | $9,753,111 |
| (Pending) | Revise relay settings at Lewistown substation as required. | $52,150 | $52,150 |
| (Pending) | Loop the existing line into the reconfigured substation. | $1,627,275 | $1,627,275 |
| (Pending) | Revise relay settings at Shade Gap substation as required. | $52,150 | $52,150 |
| Physical Interconnection | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Install 115 kV revenue metering within existing/reconfigured substation. | $59,600 | $59,600 |
Based on the scope of work for the Interconnection Facilities, it is expected to take 41 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.
The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.
Transmission Owner Analysis
FE performed an analysis of its underlying transmission system <100 kV. New Service Request Project AG2-418 did not contribute to any overloads on the FE transmission <100 kV system.
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. FirstEnergy 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.Meteorological Data Reporting Requirement
The solar generation facility shall provide the Transmission Provider with site-specific meteorological data including:Transmission Owner Requirements
- Temperature (degrees Fahrenheit)
- Atmospheric Pressure (hectopascals)
- Irradiance
- Forced outage data
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 AG2-418 was evaluated as a 40.0 MW (20.0 MW Capacity) injection in the PENELEC area.
AG2-418 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 40.0 MW (40.0 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.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | AP/DVP | 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | AP_P7-1_PE-500-235105-004T_SRT-A | Tower | AC | 100.81 % | 4357.0 | B | 4392.29 | 3.04 | |
| GD2 | AP/DVP | 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | DVP_P7-1: LN 203-9404_SRT-S | Tower | AC | 100.81 % | 4357.0 | B | 4392.29 | 3.04 | |
| GD2 | PENELEC/PJM | 26CONEMAGH-CONEM-GH 230.0/500.0 kV Ckt 3 transformer | PN_P2-3_PN-230-0252-C_SRT-A | Breaker | AC | 106.31 % | 1001.0 | B | 1064.17 | 1.97 | |
| GD2 | PENELEC/PJM | 26CONEMAGH-CONEM-GH 230.0/500.0 kV Ckt 3 transformer | PN_P2-3_PN-230-0252-B_SRT-A | Breaker | AC | 106.31 % | 1001.0 | B | 1064.17 | 1.97 | |
| GD2 | PENELEC/PJM | 26CONEMAGH-CONEM-GH 230.0/500.0 kV Ckt 3 transformer | PN_P2-3_PN-230-0252-A_SRT-A | Breaker | AC | 106.31 % | 1001.0 | B | 1064.16 | 1.97 | |
| GD2 | PENELEC/PJM | 26CONEMAGH-CONEM-GH 230.0/500.0 kV Ckt 3 transformer | PN_P2-3_PN-230-0201A-20_SRT-A | Breaker | AC | 104.94 % | 1001.0 | B | 1050.42 | 1.95 | |
| GD2 | PENELEC/PJM | 26CONEMAGH-CONEM-GH 230.0/500.0 kV Ckt 3 transformer | PN_P2-3_PN-230-0183-208_SRT-A | Breaker | AC | 103.22 % | 1001.0 | B | 1033.26 | 1.86 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P2-3_PN-230-0347-2_SRT-A | Breaker | AC | 132.2 % | 980.0 | B | 1295.55 | 2.18 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P2-3_PN-500-003JT_SRT-A | Breaker | AC | 131.02 % | 980.0 | B | 1284.02 | 2.17 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P2-2_PN-500-001T_SRT-A | Bus | AC | 131.02 % | 980.0 | B | 1284.02 | 2.17 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P2-3_PN-230-0347-A_SRT-A | Breaker | AC | 131.01 % | 980.0 | B | 1283.85 | 1.97 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | ATSI_P2-3_CEI-345-041D_SRT-A | Breaker | AC | 121.6 % | 980.0 | B | 1191.64 | 1.94 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | ATSI_P2-3_CEI-345-041E_SRT-A | Breaker | AC | 121.6 % | 980.0 | B | 1191.64 | 1.94 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | AP_P2-2_WP-138-059_SRT-A | Bus | AC | 112.4 % | 980.0 | B | 1101.51 | 1.67 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P2-2_PN-115-016A_SRT-A | Bus | AC | 109.01 % | 980.0 | B | 1068.29 | 1.75 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | AP_P7-1_WPP-138-053A_SRT-A | Tower | AC | 108.9 % | 980.0 | B | 1067.2 | 1.72 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | AP_P2-2_MP-138-100_SRT-A | Bus | AC | 108.04 % | 980.0 | B | 1058.75 | 1.67 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | AP_P2-2_WP-500-DRT18_SRT-A | Bus | AC | 106.12 % | 980.0 | B | 1040.01 | 1.59 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P1-2_PN-230-025_SRT-A | Single | AC | 105.44 % | 980.0 | B | 1033.27 | 1.72 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | PN_P1-3_PN-500-003_SRT-A | Single | AC | 105.43 % | 980.0 | B | 1033.25 | 1.72 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | AP_P7-1_WPP-138-051A_SRT-A | Tower | AC | 104.72 % | 980.0 | B | 1026.22 | 1.64 | |
| GD2 | PENELEC | 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | Base Case | Single | AC | 100.25 % | 809.0 | A | 811.02 | 1.27 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-3_PN-115-0331-A_SRT-A | Breaker | AC | 156.72 % | 618.0 | B | 968.54 | 13.99 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-3_PN-115-0331-B_SRT-A | Breaker | AC | 156.7 % | 618.0 | B | 968.43 | 14.0 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-3_PN-500-DRT31_SRT-SL | Breaker | AC | 155.32 % | 618.0 | B | 959.88 | 9.7 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-3_PN-500-004-DRT-008_SRT-SL | Breaker | AC | 155.32 % | 618.0 | B | 959.88 | 9.7 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-3_PN-115-0331-D_SRT-A | Breaker | AC | 154.64 % | 618.0 | B | 955.66 | 13.99 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-2_PN-115-030_SRT-A | Bus | AC | 149.64 % | 618.0 | B | 924.75 | 14.02 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-2_PN-115-031_SRT-A | Bus | AC | 144.8 % | 618.0 | B | 894.87 | 1.28 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P2-2_PN-500-001T_SRT-A | Bus | AC | 142.79 % | 618.0 | B | 882.46 | 9.94 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | AP_P2-2_WP-138-074_SRT-A | Bus | AC | 136.41 % | 618.0 | B | 843.02 | 10.56 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PL_08_P22_102799_SRT-A | Bus | AC | 136.19 % | 618.0 | B | 841.64 | 9.78 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PL_48_P71_102649_SRT-A | Tower | AC | 135.55 % | 618.0 | B | 837.69 | 9.78 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PECO_P7-1_220-9091_SRT-A/* $ BUCKS $ PECO_P7-1_220-9091 $ DCT | Tower | AC | 135.09 % | 618.0 | B | 834.83 | 9.78 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | Base Case | Single | AC | 131.72 % | 493.0 | A | 649.4 | 7.77 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PN_P1-2_PN-115-094_A_SRT-A | Single | AC | 127.45 % | 618.0 | B | 787.65 | 11.11 | |
| GD2 | PENELEC/PL | 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | PL_10_P12_000085_SRT-A | Single | AC | 127.27 % | 618.0 | B | 786.5 | 7.67 | |
| GD2 | PENELEC | 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | PN_P2-3_PN-230-0014-14_SRT-A | Breaker | AC | 124.93 % | 225.0 | B | 281.08 | 9.62 | |
| GD2 | PENELEC | 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | PL_10_P42_001131_SRT-A | Breaker | AC | 124.71 % | 225.0 | B | 280.59 | 9.62 | |
| GD2 | PENELEC | 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | PN_P2-3_PN-230-0014-13_SRT-A | Breaker | AC | 124.71 % | 225.0 | B | 280.59 | 9.62 | |
| GD2 | PENELEC | 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | PN_P1-2_PN-230-0014-01_SRT-A | Single | AC | 113.69 % | 225.0 | B | 255.8 | 7.63 | |
| GD2 | PENELEC | 26ROXBURY-26CARLISLE 115.0 kV Ckt 1 line | AP_P2-3_WP-138-272T_SRT-A | Breaker | AC | 112.34 % | 160.0 | B | 179.75 | 4.93 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P2-3_PN-230-0347-2_SRT-A | Breaker | AC | 133.95 % | 980.0 | B | 1312.71 | 2.3 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P2-3_PN-500-003JT_SRT-A | Breaker | AC | 133.46 % | 980.0 | B | 1307.88 | 2.3 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P2-2_PN-500-001T_SRT-A | Bus | AC | 133.46 % | 980.0 | B | 1307.88 | 2.3 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P2-3_PN-230-0347-A_SRT-A | Breaker | AC | 133.4 % | 980.0 | B | 1307.34 | 2.18 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | ATSI_P2-3_CEI-345-041E_SRT-A | Breaker | AC | 122.69 % | 980.0 | B | 1202.4 | 2.06 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | ATSI_P2-3_CEI-345-041D_SRT-A | Breaker | AC | 122.69 % | 980.0 | B | 1202.4 | 2.06 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P2-2_WP-138-033T_SRT-A | Bus | AC | 110.79 % | 980.0 | B | 1085.77 | 1.89 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P2-2_WP-138-059_SRT-A | Bus | AC | 110.5 % | 980.0 | B | 1082.93 | 1.76 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P2-2_MP-138-100_SRT-A | Bus | AC | 108.43 % | 980.0 | B | 1062.61 | 1.78 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P2-2_WP-138-036_SRT-A | Bus | AC | 108.01 % | 980.0 | B | 1058.48 | 1.78 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P7-1_WPP-138-053A_SRT-A | Tower | AC | 107.82 % | 980.0 | B | 1056.6 | 1.8 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | AP_P7-1_WPP-138-083_SRT-A | Tower | AC | 105.56 % | 980.0 | B | 1034.46 | 1.78 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P1-2_PN-230-025_SRT-A | Single | AC | 104.25 % | 980.0 | B | 1021.65 | 1.82 | |
| GD2 | PENELEC | 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | PN_P1-3_PN-500-003_SRT-A | Single | AC | 104.25 % | 980.0 | B | 1021.63 | 1.82 | |
| GD2 | PENELEC | AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line | PL_10_P42_001131_SRT-A | Breaker | AC | 103.87 % | 333.0 | B | 345.9 | 9.21 | |
| GD2 | PENELEC | AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line | PN_P2-3_PN-230-0014-13_SRT-A | Breaker | AC | 103.87 % | 333.0 | B | 345.9 | 9.21 | |
| GD2 | PENELEC | AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line | PN_P2-3_PN-230-0014-14_SRT-A | Breaker | AC | 103.18 % | 333.0 | B | 343.58 | 9.21 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | PL_10_P42_103068_SRT-A | Breaker | AC | 106.27 % | 618.0 | B | 656.76 | 1.76 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | PL_10_P42_103067_SRT-A | Breaker | AC | 106.27 % | 618.0 | B | 656.75 | 1.76 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | PL_10_P42_103151_SRT-A | Breaker | AC | 106.27 % | 618.0 | B | 656.75 | 1.76 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | PL_10_P42_103152_SRT-A | Breaker | AC | 106.27 % | 618.0 | B | 656.75 | 1.76 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | ME_P2-3_ME-500-DTR001_SRT-SL | Breaker | AC | 105.34 % | 618.0 | B | 651.0 | 1.56 | |
| GD2 | PL | JUNI-DAUP TR2 230.0 kV Ckt 1 line | PL_10_P12_000195_SRT-A | Single | AC | 104.81 % | 618.0 | B | 647.73 | 1.39 | |
| GD2 | AP/PJM | KEYSTONE-01CABOT 500.0 kV Ckt 1 line | AP_P2-3_WP-500-DRT45_SRT-SL | Breaker | AC | 108.06 % | 2844.0 | B | 3073.32 | 3.51 | |
| GD2 | AP/PJM | KEYSTONE-01SOBEND 500.0 kV Ckt 1 line | PN_P2-3_PN-500-DRT32_SRT-A | Breaker | AC | 107.79 % | 2078.0 | B | 2239.81 | 3.46 | |
| GD2 | AP/PJM | KEYSTONE-01SOBEND 500.0 kV Ckt 1 line | PN_P2-3_PN-500-004-DRT-002_SRT-SL | Breaker | AC | 107.79 % | 2078.0 | B | 2239.81 | 3.46 |
Winter Peak Analysis
The New Service Request AG2-418 was evaluated as a 40.0 MW (20.0 MW Capacity) injection in the PENELEC area.
AG2-418 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 40.0 MW (40.0 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.
(No impacts were found for this analysis)
Light Load Analysis
The New Service Request AG2-418 was evaluated as a 40.0 MW injection and 20.0 MW withdrawal in the PENELEC area.
AG2-418 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 40.0 MW (40.0 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.
(No impacts were found for this analysis)
Short Circuit Analysis
Short Circuit analysis is not performed as part of the Phase I System Impact Study. Short Circuit analysis will commence in the Phase II System Impact Study.
Stability Analysis
Stability analysis is not performed as part of the Phase I System Impact Study. Stability analysis will commence in the Phase II System Impact Study.
Reactive Power Analysis
Reactive Power analysis is not performed as part of the Phase I System Impact Study. Reactive Power analysis will commence in the Phase II System Impact Study.
Steady-State Voltage Analysis
Steady State Voltage Analysis is Not Required.
New Service Request Dependencies
The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.
| New Service Requests Dependencies | ||
|---|---|---|
| Project ID | Project Name | Status |
| AA1-038 | Lexington-Low Moor 230kV | Under Construction |
| AA1-050 | Tarboro-Everetts 230kV | In Service |
| AA1-063A | Carolina–Seaboard 115kV | In Service |
| AA1-067 | Everetts 34.5kV | In Service |
| AA1-076 | Hunterstown-Conemaugh 500kV | In Service |
| AA1-095 | Halfway-Marlowe 34.5kV | In Service |
| AA1-139 | Hickory-Shawboro 230kV | In Service |
| AA2-053 | Carolina-Jackson 115kV | In Service |
| AA2-057 | Hornertown-Whitakers 115kV | In Service |
| AA2-133 | Wyalusing 34.5kV | In Service |
| AA2-174 | Carolina-Jackson 115kV | In Service |
| AA2-178 | Mackeys 230kV | In Service |
| AA2-184 | Atlantic-Red Bank 34kV | In Service |
| AB1-001 | Absecon 12 kV | In Service |
| AB1-027 | Old Church 34.5 KV | In Service |
| AB1-081 | Anaconda-Mayo Dunbar 115kV | In Service |
| AB1-096 | Carroll-Mt. Airy 34.5kV | In Service |
| AB1-124 | Carroll-Monocacy 34.5kV | Partially in Service - Under Construction |
| AB1-125 | Carroll-Monocacy 34.5kV | In Service |
| AB1-127 | St. Thomas-Guilford 34.5kV | In Service |
| AB1-128 | St. Thomas-Mercersburg 34.5kV | In Service |
| AB1-132 | Thelma 230kV | In Service |
| AB1-138 | Navy 34.5kV | In Service |
| AB1-139 | Metuchen 26kV | In Service |
| AB1-141 | Church-Wye Mills 138 kV I | In Service |
| AB1-142 | Church-Wye Mills 138 kV II | In Service |
| AB1-176 | Price 25kV II | Engineering & Procurement |
| AB2-022 | Elizabeth City 34.5kV | In Service |
| AB2-025 | Sapony 34.5kV | In Service |
| AB2-026 | Powhatan 34.5kV | In Service |
| AB2-029 | Remington 34.5kV | In Service |
| AB2-031 | Brink-Trego 115kV | In Service |
| AB2-032 | Church-Wye Mills 138 kV | In Service |
| AB2-036 | Church - Oil City 138kV | Suspended |
| AB2-037 | Keeney-Steele 230kV | Under Construction |
| AB2-040 | Brink 115kV | In Service |
| AB2-045 | Buckingham 34.5kV | In Service |
| AB2-049 | Gloucester Township 12kV | In Service |
| AB2-057 | Brunswick 26kV | In Service |
| AB2-059 | Benson-Dunbar 115kV | In Service |
| AB2-060 | Chase City-Lunenburg 115kV | In Service |
| AB2-077 | Buggs Island-Chase City 115kV | In Service |
| AB2-078 | Buggs Island-Chase City 115kV | In Service |
| AB2-079 | Buggs Island-Chase City 115kV | In Service |
| AB2-099 | Ahoskie 34.5kV | In Service |
| AB2-133 | Chestertown 69kV | Under Construction |
| AB2-134 | Hopewell-Surry 230kV | In Service |
| AB2-135 | Church-Kent 69kV | In Service |
| AB2-136 | Cambridge-West Cambridge 69kV | Under Construction |
| AB2-153 | Church-Wye Mills 138 kV | In Service |
| AB2-158 | Louisa-South Anna 230kV | In Service |
| AB2-169 | Pantago-Five Points 115kV | In Service |
| AB2-172 | Todd 69kV | In Service |
| AB2-174 | Emporia-Trego 115kV | In Service |
| AB2-179 | Townsend 138kV | In Service |
| AB2-190 | Hopewell-Surry 230kV | In Service |
| AC1-010 | Gloucester 26kV | Under Construction |
| AC1-017 | Levittown 13 kV | In Service |
| AC1-027 | Pendleton 34.5kV | In Service |
| AC1-030 | Cinnaminson 13kV | In Service |
| AC1-036 | Twittys Creek 34.5kV | In Service |
| AC1-042 | Altavista-Mt. Airy 69kV | In Service |
| AC1-054 | Kerr Dam–Eatons Ferry 115 kV | In Service |
| AC1-075 | Perth-Hickory Grove 115kV | In Service |
| AC1-076 | Locust Grove-Paytes 115kV | In Service |
| AC1-078 | Beatty-London 138kV | In Service |
| AC1-091 | Cedar Creek 138kV I | Engineering & Procurement |
| AC1-092 | Cedar Creek 138kV II | Engineering & Procurement |
| AC1-093 | Cedar Creek 138kV III | Engineering & Procurement |
| AC1-094 | Cedar Creek 138kV IV | Engineering & Procurement |
| AC1-098 | Dawson-South Justice 115kV | Partially in Service - Under Construction |
| AC1-099 | Dawson-South Justice 115kV | Partially in Service - Under Construction |
| AC1-105 | Halifax-Mt. Laurel 115kV | In Service |
| AC1-118 | Westmoreland 34.5kV | In Service |
| AC1-120 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-121 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-122 | Smith Mountain-Candler's Mountain 138kV | In Service |
| AC1-147 | Grassfield 34.5kV | In Service |
| AC1-158 | Spotsylvania 500kV | In Service |
| AC1-161 | Septa 500kV | In Service |
| AC1-167 | Mark Center 69kV | Under Construction |
| AC1-189 | Chinquapin-Everetts 230kV | Under Construction |
| AC1-190 | East New Market 69kV | Suspended |
| AC1-191 | Elmont 115kV | Engineering & Procurement |
| AC1-208 | Cox-Whitakers 115kV | Under Construction |
| AC1-221 | Halifax-Person 230kV | In Service |
| AC1-222 | Crystal Hill-Halifax 115kV | In Service |
| AC2-009 | Pennington 13 kV | In Service |
| AC2-012 | Grassfield-Great Bridge 115kV | In Service |
| AC2-023 | Hebron 69kV | Engineering & Procurement |
| AC2-100 | Halifax-Person 230kV | In Service |
| AC2-103 | Beaver-Davis Besse 345 kV I | Engineering & Procurement |
| AC2-136 | East Hagerstown 12kV | Under Construction |
| AC2-137 | Elko 34.5kV | In Service |
| AC2-138 | Northern Neck 34.5kV | In Service |
| AC2-141 | Septa 500kV | Engineering & Procurement |
| AC2-165 | Bremo-Powhatan 230kV | Suspended |
| AC2-168 | Clinton 23kV | In Service |
| AC2-185 | Cedar Creek 138kV II | Engineering & Procurement |
| AC2-186 | Harrington 25kV | Under Construction |
| AC2-187 | Harrington 69kV | Under Construction |
| AC2-188 | Harrington 69 kV | Under Construction |
| AC2-195 | Galion-Roberts South 138 kV | Under Construction |
| AD1-017 | Smith Mountain-Bearskin 138 kV | In Service |
| AD1-020 | Hunterstown-Lincoln 115 kV | In Service |
| AD1-025 | Hopewell-Surry 230 kV | Under Construction |
| AD1-033 | Fentress-Landstown 230 kV | In Service |
| AD1-041 | Harmony Village-Shackleford 115 kV | In Service |
| AD1-056 | Hornertown-Hathaway 230 kV | Suspended |
| AD1-057 | Hornertown-Hathaway 230 kV | Suspended |
| AD1-060 | Mercersburg-Milnor 34.5 kV | In Service |
| AD1-061 | McConnelsburg-Mercersburg 34 kV | In Service |
| AD1-063 | Harmony Village 34.5 kV | In Service |
| AD1-074 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-075 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-076 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-082 | Bakers Pond-Ivor 115kV | In Service |
| AD1-087 | Clover-Sedge Hill 230 kV | In Service |
| AD1-105 | Kings Dominion DP 115 kV | Under Construction |
| AD1-115 | Mountain Run-Mitchell 115 kV | Engineering & Procurement |
| AD1-130 | Hardin Switch 345 kV | In Service |
| AD1-144 | Kings Fork 34.5 kV | In Service |
| AD1-152 | Clover-Sedge Hill 230 kV | In Service |
| AD1-155 | Meadow Brook-Strasburg 138 kV | In Service |
| AD2-009 | McConnellsburg 138 kV | In Service |
| AD2-022 | East Danville - Roxborough 230 kV | Engineering & Procurement |
| AD2-023 | East Danville - Roxborough 230 kV | Engineering & Procurement |
| AD2-027 | Camden Switch 26 kV | In Service |
| AD2-030 | Wan 34.5 kV | In Service |
| AD2-033 | Chase City-Lunenburg 115 kV | Under Construction |
| AD2-042 | Camden Switch 26 kV II | In Service |
| AD2-062 | Roxbury-Greene 138 kV | Suspended |
| AD2-065 | Atco 12 kV | In Service |
| AD2-070 | Gilbert-Morris Park 34.5kV | In Service |
| AD2-073 | Sanders DP 230 kV | In Service |
| AD2-074 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AD2-076 | Carville 138 kV | Suspended |
| AD2-085 | Myrtle-Windsor DP 115kV | Engineering & Procurement |
| AD2-086 | Hardin Switch 345 kV | In Service |
| AD2-092 | Marysville 345kV | Under Construction |
| AD2-093 | Marysville 345kV | Under Construction |
| AD2-113 | South Bend 500kV | In Service |
| AD2-115 | Lyons-Moselem 69kV | In Service |
| AD2-116 | Hokes-Grantley 69 kV | In Service |
| AD2-133 | Eagle Valley 115kV | In Service |
| AD2-135 | Williamstown 12kV | Partially in Service - Under Construction |
| AD2-160 | Hickory-Moyock 230kV | In Service |
| AD2-163 | Broadview-Tangy 138 kV | In Service |
| AD2-202 | Clover-Sedge Hill 230kV | In Service |
| AE1-041 | Edison 4kV | In Service |
| AE1-071 | Shade Gap-Roxbury 115 kV | In Service |
| AE1-072 | Shawboro-Sligo 230 kV | Under Construction |
| AE1-074 | Winterpock 34.5 kV | Under Construction |
| AE1-075 | Powhatan 34.5 kV | In Service |
| AE1-079 | Maysville-Sharon 69 kV | Under Construction |
| AE1-081 | Landing 12.47 kV | In Service |
| AE1-090 | Hardin Switch 345 kV | In Service |
| AE1-101 | McConnellsburg-Texas Eastern 138 kV | In Service |
| AE1-103 | Holland-Union Camp 115 kV | Under Construction |
| AE1-104 | BL England 138 kV | Suspended |
| AE1-108 | Bremo-Scottsville 138 kV | Engineering & Procurement |
| AE1-123 | Emlenton 34.5 kV | In Service |
| AE1-129 | Zion View - Middletown 115 kV | Suspended |
| AE1-142 | Manitou-Pleasant Plains 34.5 kV | In Service |
| AE1-146 | Ebersole #2-Fostoria Central 138 kV | Under Construction |
| AE1-155 | Garner-Northern Neck 115 kV | In Service |
| AE1-156 | Quakertown Solar II 34.5 kV | Partially in Service - Under Construction |
| AE1-162 | Smithfield 34.5 kV | In Service |
| AE1-175 | Light Foot 34.5 kV | In Service |
| AE1-183 | Maysville-McDowell 69 kV | Engineering & Procurement |
| AE1-185 | Hokes-Jackson 69 kV | In Service |
| AE1-190 | Harmony Village-Shackleford 115 kV | Partially in Service - Under Construction |
| AE1-191 | Harmony Village-Shackleford 115 kV | Partially in Service - Under Construction |
| AE1-196 | Hokes-Jackson 69 kV II | In Service |
| AE1-226 | Face Rock-Kinzer #13 69 kV | Withdrawn |
| AE1-229 | Deepwater-Upper Pittsgrove 138 kV | Suspended |
| AE1-237 | Andover (Maysville) 69kV I | Under Construction |
| AE1-245 | Haviland 138 kV | Under Construction |
| AE1-250 | Smith Mountain-E. Danville 138 kV | Engineering & Procurement |
| AE2-001 | Nittany-Zion 46 kV | Suspended |
| AE2-029 | Grottoes-Merck 115kV | Under Construction |
| AE2-034 | Mackeys 230 kV | Partially in Service - Under Construction |
| AE2-042 | Milton 69 kV | In Service |
| AE2-047 | Ridgeway-Solite 69 kV | Engineering & Procurement |
| AE2-054 | Warfordsburg 34 kV | In Service |
| AE2-059 | Derry Tap-Derry Bus 69 kV | In Service |
| AE2-060 | Mifflintown Bus-Mifflintown Tap 69 kV | In Service |
| AE2-072 | East Leipsic-Richland 138 kV | In Service |
| AE2-074 | Potter 46 kV | Under Construction |
| AE2-084 | Derry Tap-Derry Bus 69 kV | Engineering & Procurement |
| AE2-092 | Kidds Store-Sherwood 115 kV | Engineering & Procurement |
| AE2-110 | Columbia-West Bloomsburg 69 kV | Suspended |
| AE2-112 | Carville 138 kV II | 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 |
| AE2-117 | ABW Tap-Alexandria 46 kV | Suspended |
| AE2-118 | ABW Tap-Williamsburg 46 kV | Suspended |
| 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 |
| AE2-133 | Penns Tap-Richfield Tie 69 kV | In Service |
| AE2-139 | East Towanda-Grover 230 kV | Engineering & Procurement |
| AE2-148 | Beatty-Greene 345 kV | In Service |
| AE2-175 | Jackson-Long Pond 69 kV | Partially in Service - Under Construction |
| AE2-176 | Groton 138 kV Solar | In Service |
| AE2-181 | Snyder 69kV | Under Construction |
| AE2-206 | East Sidney-Quincy 138 kV | In Service |
| AE2-211 | Jackson-Three Mile Island 230 kV | Suspended |
| AE2-212 | Harrowgate 34 kV | Engineering & Procurement |
| AE2-214 | Cole 345 kV | Engineering & Procurement |
| AE2-224 | Bear Rock-Johnstown 230 kV | In Service |
| AE2-230 | Bartonsville-Meadow Brook 138 kV | In Service |
| AE2-241 | Bloomsburg-Columbia 69 kV | Suspended |
| AE2-248 | Fillmore-Thompson Farm 46 kV | Suspended |
| AE2-253 | Hickory-Moyock 230 kV | In Service |
| AE2-259 | Curdsville-Willis Mtn 115 kV | Engineering & Procurement |
| AE2-262 | Moshannon-Milesburg 230 kV | Engineering & Procurement |
| AE2-263 | Moshannon-Milesburg 230 kV II | Engineering & Procurement |
| AE2-271 | Montour 230 kV | Withdrawn |
| AE2-282 | East Fayette 138 kV | In Service |
| AE2-285 | Maysville 69 kV | Engineering & Procurement |
| AE2-298 | Cavett Switch - West Van Wert 69 kV | Engineering & Procurement |
| AE2-306 | Gunn Road 345 kV | Under Construction |
| AE2-316 | Brookville-Squab Hollow 138 kV | Under Construction |
| AE2-322 | Mark Center 69 kV | Under Construction |
| AE2-333 | Bedington 138 kV | Suspended |
| AE2-342 | Woodstock 69 kV | Engineering & Procurement |
| AE2-343 | Andover (Maysville) 69 kV II | Under Construction |
| AE2-344 | Edinboro South-Venango Junction 115 kV | Suspended |
| AE2-345 | Hunterstown-Texas Eastern Tap 115 kV | Suspended |
| AE2-346 | Ahoskie 34.5 kV | In Service |
| AF1-006 | Fairview East 34.5 kV | In Service |
| AF1-007 | Indian River 230 kV I | Suspended |
| AF1-021 | Bethelboro-Connellsville #1 25 kV | In Service |
| AF1-022 | Lake Lynn-Uniontown 25 kV | In Service |
| AF1-032 | Suffolk 34.5 kV | In Service |
| AF1-036 | Carville 138 kV III | Suspended |
| AF1-039 | Listonburg-Highpoint 24.9 kV | In Service |
| AF1-042 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AF1-058 | Welco 34.5 kV | In Service |
| AF1-064 | Weston 69 kV | Under Construction |
| AF1-078 | East Sidney-Quincy 138 kV | In Service |
| AF1-086 | Madera-Westover South 115 kV | Under Construction |
| AF1-091 | Varner - Sowers 138 kV | Engineering & Procurement |
| AF1-093 | Henderson-Stoneboro 69 kV | Engineering & Procurement |
| AF1-094 | Union City-Cambridge Springs 34.5 kV | Engineering & Procurement |
| AF1-098 | Four Mile Jct-Corry East 115 kV | Engineering & Procurement |
| AF1-106 | East Sayre 34.5 kV | Withdrawn |
| AF1-120 | East Fayette 2 138 kV | In Service |
| AF1-134 | Philipsburg-Madera 34.5 kV | Engineering & Procurement |
| AF1-136 | Warfordsburg-Purcell Junction 34.5 kV | Engineering & Procurement |
| AF1-140 | Claysburg 23 kV | Engineering & Procurement |
| AF1-143 | Lick Run 115 kV | Engineering & Procurement |
| AF1-147 | Poland Rd-Runway DP 230kV | Under Construction |
| AF1-153 | Motion-Ridgeway 46 kV | Suspended |
| AF1-167 | West Freedom-C&K Coal 25 kV | Suspended |
| AF1-206 | East Fayette 138 kV | Engineering & Procurement |
| AF1-208 | Laurel-Roadstown 69 kV | Withdrawn |
| AF1-226 | Bowmans Mill-Scott 69 kV | Suspended |
| AF1-227 | Marysville – Gunn Road 345 kV | In Service |
| AF1-228 | Beatty-Greene 345 kV | Engineering & Procurement |
| AF1-229 | Galion-South Berwick 345 kV | Engineering & Procurement |
| AF1-240 | Timblin 34.5 kV | Active |
| AF1-254 | Milnor-Huyetts 34.5 kV | Under Construction |
| AF1-262 | Upper Pittsgrove 12 kV | In Service |
| AF1-264 | Runnemede 13 kV | In Service |
| AF1-271A | Gratz 69 kV | Suspended |
| AF1-272 | Lucerne 115 kV | Engineering & Procurement |
| AF1-275 | Cole 345 kV | Engineering & Procurement |
| AF1-285 | Gunn Road 345 kV | Under Construction |
| AF1-287 | Edinboro South 34.5 kV II | Suspended |
| AF1-291 | Tyler 34.5 kV | Engineering & Procurement |
| AF1-291A | Bartonsville-Meadow Brook 138 kV | In Service |
| AF1-292 | Fields 34.5kV | Engineering & Procurement |
| AF1-299 | Otter Point 34.5 kV I | In Service |
| AF1-300 | Otter Point 34.5 kV II | In Service |
| AF1-302 | Brookville-Squab Hollow 138 kV | Engineering & Procurement |
| AF1-320 | Merrill Creek 115 kV | Engineering & Procurement |
| AF1-321 | Hooversville 115 kV I | Suspended |
| AF1-333 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-337 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-338 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-339 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF2-001 | Hooversville 115 kV II | Suspended |
| AF2-002 | Hooversville 115 kV III | Suspended |
| AF2-010 | Union City-Titusville 115 kV | Active |
| AF2-014 | Maddox Creek 345 kV | Engineering & Procurement |
| AF2-039 | Shawville-Clearfield 34.5 kV | Engineering & Procurement |
| AF2-043 | Suffolk 34.5 kV | In Service |
| AF2-050 | Bear Rock-Johnstown 230 kV | Active |
| AF2-054 | Wan 34.5 kV | In Service |
| AF2-075 | Bartonsville-Meadow Brook 138 kV III | In Service |
| AF2-077 | White Marsh 34.5 kV | In Service |
| AF2-086 | Scott Tap-Bowmans Mill Tap 69 kV | Engineering & Procurement |
| AF2-088 | Shawville-Clearfield 34.5 kV II | Engineering & Procurement |
| AF2-092 | Snake Spring-Bedford Area 23 kV | Suspended |
| AF2-122 | Kirk 138 kV | Under Construction |
| AF2-130 | Cobalt Corners 34.5 kV | In Service |
| AF2-138 | Flanders-West Wharton 34.5 kV | In Service |
| AF2-139 | Gilbert-Warren Glen 34.5 kV | In Service |
| AF2-144 | Powhatan 34.5 kV | In Service |
| AF2-165 | Clark Summit-Emlenton 34.5 kV | In Service |
| AF2-166 | Emlenton 34.5 kV | Withdrawn |
| AF2-187 | Brookside-Cloverdale 138 kV | Engineering & Procurement |
| AF2-192 | Frenchtown Solar-West Flemington 34.5 kV | Suspended |
| AF2-221 | Scalp Level 22.9 kV | Suspended |
| AF2-229 | Roxbury 23 kV | Engineering & Procurement |
| AF2-233 | Penns-Richfield Tie #1 69 kV | Engineering & Procurement |
| AF2-234 | Sunbury Yard #1-Richfield Tie #2 69 kV | Engineering & Procurement |
| AF2-235 | Titusville-Oil Creek 34.5 kV | Withdrawn |
| AF2-238 | Mansfield-South Troy 34.5 kV | Engineering & Procurement |
| AF2-247 | Bustleton 13.2 kV | In Service |
| AF2-250 | Edgewood 12 kV III | In Service |
| AF2-254 | Cookstown-New Lisbon 34.5 kV | Suspended |
| AF2-294 | Thompson 34.5 kV | Suspended |
| AF2-296 | Madera 34.5 kV | Active |
| AF2-325 | Jacktown 12 kV | Engineering & Procurement |
| AF2-354 | Washington 34.5 kV II | Engineering & Procurement |
| AF2-358 | Airey-Vienna 69 kV | Active |
| AF2-361 | Mifflintown Tap 69 kV | Engineering & Procurement |
| AF2-371 | Harrison-Good Hope 138 kV | Engineering & Procurement |
| AF2-375 | Ebersole-Fostoria 138 kV | Engineering & Procurement |
| AF2-378 | Cambridge 12 kV | Engineering & Procurement |
| AF2-379 | Princess Anne 25 kV | Under Construction |
| AF2-383 | Tolna 115 kV | Withdrawn |
| AF2-417 | West Damascus Tap-West Damascus 69 kV | Engineering & Procurement |
| AF2-421 | East Hazelton-Weatherly Tap 69 | Engineering & Procurement |
| AF2-424 | Reed-Reed Tap #1 69 kV | Engineering & Procurement |
| AF2-425 | Reed-Reed Tap#1 69 kV | Engineering & Procurement |
| AF2-433 | Columbia-Geisinger Tap #1 69 kV | Engineering & Procurement |
| AF2-434 | Columbia-Geisinger Tap #1 69 kV | Engineering & Procurement |
| AF2-445A | Fishbach-Port Carbon 69 kV | Suspended |
| AG1-007 | Tar River 12.5 kV | Engineering & Procurement |
| AG1-037 | Ahoskie 34.5 kV | Engineering & Procurement |
| AG1-040 | Morgan Street-Mount Hope 34.5 kV | Engineering & Procurement |
| AG1-041 | Osterburg-Bedford North 23 kV | Withdrawn |
| AG1-054 | Potter-Harlan 69 kV | Engineering & Procurement |
| AG1-090 | Philipsburg 115 kV | Active |
| AG1-100 | Venango-Saegertown 34.5 kV | Engineering & Procurement |
| AG1-140 | Union City 34.5 kV | Suspended |
| AG1-145 | Lightfoot 34.5 kV | In Service |
| AG1-156 | Jack Frost-Lake Harmony 69 kV | Engineering & Procurement |
| AG1-164 | East Hazelton-Weatherly Tap 69 kV | Engineering & Procurement |
| AG1-165 | East Hazelton-Weatherly Tap 69 kV | Engineering & Procurement |
| AG1-188 | Manitou-Oyster Creek 34.5 kV | Engineering & Procurement |
| AG1-189 | Oyster Creek-Bamber Lake 34.5 | Engineering & Procurement |
| AG1-191 | Chester-Pohatcong Mountain 34.5 kV | Partially in Service - Under Construction |
| AG1-193 | Utica Junction 34.5 kV | Suspended |
| AG1-197 | Morgan Street-Cochranton 34.5 kV | Suspended |
| AG1-198 | Union City 34.5 kV | Under Construction |
| AG1-223 | Larrabee-Allaire 34.5 kV | Under Construction |
| AG1-253 | Erie East-Union City 34.5 kV | Suspended |
| AG1-254 | Salem-Woodstown 69 kV | Engineering & Procurement |
| AG1-259 | Sunbury-Dalmatia 69 kV | Engineering & Procurement |
| AG1-260 | Sunbury-Dalmatia 69 kV | Engineering & Procurement |
| AG1-281 | Claysburg-HCR Tap 46 kV | Engineering & Procurement |
| AG1-282 | Dunnsville 34.5 kV | Engineering & Procurement |
| AG1-301 | Miller REC-Warrior Ridge 46 kV | Engineering & Procurement |
| AG1-348 | Pequest River-Washington 34.5 kV | In Service |
| AG1-351 | Harrison-Good Hope 138 kV | Engineering & Procurement |
| AG1-362 | Wernersville 12.47 kV | Suspended |
| AG1-363 | Black Oak-Hatfield 500 kV | Engineering & Procurement |
| AG1-377 | Philipsburg 115 kV | Active |
| AG1-378 | Philipsburg 115 kV | Active |
| AG1-386 | Smith-Francis Junction 25 kV | In Service |
| AG1-397 | Walston 12 kV | Withdrawn |
| AG1-450 | Airey-Vienna 69 kV II | Active |
| AG1-469 | Gordonsville 34.5 kV | Engineering & Procurement |
| AG1-480 | Shawnee 34.5 kV | Engineering & Procurement |
| AG1-482 | Hamilton 115 kV | Withdrawn |
| AG1-483 | Dickerson 230 kV | Engineering & Procurement |
| AG1-487 | Gilbert 230 kV | Withdrawn |
| AG1-495 | Gilbert-Rocktown 34.5 kV | Engineering & Procurement |
| AG1-499 | Lambs 12.47 kV | Under Construction |
| AG1-511 | Kittatinny 230 kV | Engineering & Procurement |
| AG1-515 | Guilford 138 kV | Withdrawn |
| AG1-532 | Fields 34.5 kV | Engineering & Procurement |
| AG1-548 | Erie South-Union City 115 kV | Active |
| AG1-554 | South Kenton 138 kV | Engineering & Procurement |
| AG1-558 | Buckner 34.5 kV | Engineering & Procurement |
| AG1-559 | Caroline Pines 22 kV | Engineering & Procurement |
| AG2-016 | Oyster Creek-Whitings 34.5 kV | Active |
| AG2-055 | Deans 500 kV | Withdrawn |
| AG2-074 | Meckesville Tap 69kV | Active |
| AG2-090 | Scalp Level 23 kV IV | Active |
| AG2-091 | Scalp Level 23 kV V | Active |
| AG2-161 | Wheelabrator Frackville-Gilberton 69 kV | Active |
| AG2-176 | Geneva 115 kV | Active |
| AG2-181 | Airey - Golden Hill 69 kV | Active |
| AG2-200 | North Warren–Russell 34.5 kV | Active |
| AG2-206 | Tennessee Gas-East Towanda 115 kV | Active |
| AG2-220 | East Towanda-South Troy 115 kV | Active |
| AG2-221 | South Troy - North Towanda 34.5 kV | Active |
| AG2-279 | Hagerstown-Conservit 34.5 kV | Active |
| AG2-297 | Cumberland 230 kV | Active |
| AG2-327 | Tennessee Gas-East Towanda 115 kV | Active |
| AG2-347 | Indian River 230 kV II | Active |
| AG2-356 | South Troy - Canton 34.5 kV | Active |
| AG2-380 | Carville 138 kV IV | Active |
| AG2-411 | Statler Hill 115 kV | Active |
| AG2-420 | Eclipse #2 34.5 kV | Active |
| AG2-423 | Cherry Run–Harmony 138 kV | Active |
| AG2-429 | Burma - Armstrong 138 kV | Active |
| AG2-430 | Sunbury-Dalmatia 69 kV II | Active |
| AG2-438 | Union City 34.5 kV | Active |
| AG2-439 | Oxbow 34.5 kV | Active |
| AG2-447 | Cedar Creek 138 kV VII | Active |
| AG2-456 | Pierce Brook-Lewis Run 230 kV | Active |
| AG2-457 | Pierce Brook - Lewis Run 230 kV | Active |
| AG2-484 | Mifflintown Bus-Mifflintown Tap 69 kV II | Active |
| AG2-561 | Glory - Glen Campbell 34.5 kV | Active |
| AG2-616 | Churchtown - Upper Pittsgrove 138 kV | Active |
| AG2-617 | Waugh Chapel 115 kV | Active |
| AG2-625 | Pequest River-Furnace Brook Tap 34.5 kV II | Active |
| AG2-626 | Pequest River-Furnace Brook Tap 34.5 kV III | Active |
| AG2-627 | Woodstown-High Street 69 kV | Active |
| AG2-654 | Craigsville - Leards Crossing 12 kV | Active |
| AH1-005 | East Towanda-South Troy 115 kV II | Active |
| AH1-027 | Cartanza 230 kV | Active |
| AH1-050 | Eclipse-Piney 115 kV | Active |
| AH1-051 | Eclipse-Piney 115 kV II | Active |
| AH1-054 | Upton-Whitings 34.5 kV | Active |
| AH1-057 | Edgewood 12.47 kV | Active |
| AH1-102 | Seward-Glory 115 kV | Active |
| AH1-140 | Vasco 138 kV | Active |
| AH1-158 | Eclipse-Piney 115 kV III | Active |
| AH1-201 | Allegheny-New Baltimore 115kV | Active |
| AH1-203 | Allegheny-Somerset 115 kV | Active |
| AH1-205 | Allegheny-New Baltimore 115kV | Active |
| AH1-212 | Bethlehem - Lilly 46 kV | Active |
| AH1-257 | Broadway - Washington 34.5 kV | Active |
| AH1-258 | Belford - Keansburg 34.5 kV | Active |
| AH1-265 | Winslow - Monroe 69kV | Active |
| AH1-268 | Seward-Glory 115 kV II | Active |
| AH1-274 | Butler 69 kV | Active |
| AH1-313 | Moshannon-Milesburg 230 kV VII | Active |
| AH1-334 | Lakehurst - Whitings 34.5 kV | Active |
| AH1-357 | Pierce Brook-Lewis Run 230kV | Active |
| AH1-358 | Pierce Brook-Lewis Run 230kV | Active |
| AH1-359 | Pierce Brook - Lewis Run 230 kV | Active |
| AH1-360 | Pierce Brook - Lewis Run 230 kV | Active |
| AH1-380 | Mt Olive - Kenny 69kV | Active |
| AH1-452 | Clementine-Clementine Jct. 25 kV | Active |
| AH1-460 | Hooversville - Scalp Level 115 kV | Active |
| AH1-490 | Venango Junction 34.5 kV | Active |
| AH1-491 | Union City 34.5 kV | Active |
| AH1-536 | Church-Oil City 138kV | Active |
| AH1-584 | Nelson-Indian River 138kV | Active |
| AH1-585 | Nelson-Indian River 138kV | Active |
| AH1-586 | Nelson-Indian River 138kV | Active |
| AH1-587 | Farmers Valley – Ridgeway 115 kV | Active |
| AH1-588 | Lewis Run - Pierce Brook 230 kV | Active |
| AH1-589 | Lewis Run - Pierce Brook 230 kV | Active |
| AH1-634 | Indian River 230kV I | Active |
| AH1-641 | Churchtown - Upper Pittsgrove 138kV | Active |
| AH1-667 | Philipsburg-Shawville 34.5 kV | Active |
| AH1-672 | Farmview 138 kV | Active |
| AH1-695 | Three Mile Island 230 kV | Active |
| AH1-701 | Valero 69 kV | Active |
| AH1-703 | Bergen 230kV | Active |
| AH1-705 | Sunbury #1 500kV | Active |
| AH1-707 | Saegers 230 kV | Active |
| AH1-710 | Salem 500kV | Active |
| AH1-715 | Linden 230kV | Active |
| AH1-720 | East Towanda 230 kV | Active |
| AH1-722 | Linden 230kV | Active |
| AH1-734 | South Bend 500 kV | Active |
| AH1-746 | Madera - Westover South 115 kV | Active |
| U2-072 | East Lima-Marysville 345kV | In Service |
| V1-011 | Haviland 138kV | In Service |
| V1-021 | Cape May County 12kV | In Service |
| V2-041 | Clayville 12kV | In Service |
| V2-046 | Pilesgrove Township 12kV | In Service |
| V3-037 | Naval Academy Junction 13kV | In Service |
| V4-054 | Fairfield Township 12kV | In Service |
| V4-067 | Cates Road Egg Harbor Township 12kV | Deactivated |
| W1-003 | Oak Hall | In Service |
| W1-004 | Oak Hall | In Service |
| W1-005 | Oak Hall | In Service |
| W1-006 | Oak Hall | In Service |
| W1-056 | Ada-Dunkirk 69kV | In Service |
| W1-062 | Clayton 138kV | In Service |
| W1-130 | Vine Road 12kV | In Service |
| W2-030 | Egg Harbor Township | In Service |
| W3-077 | Broadway-Stewartsville 34.5kV | In Service |
| W3-106 | Sussex-Wykertown 34.5kV | In Service |
| X2-083 | Newark 12kV | In Service |
| X3-008 | Todd 69kV | In Service |
| X3-066 | Church Hill 69kV | In Service |
| Y1-033 | Penn Mar-Rock Wood 115kV | In Service |
| Y1-065 | Rock Springs 500kV | In Service |
| Y1-079 | Wye Mills 69kV | In Service |
| Y1-080 | Dorchester 12kV | In Service |
| Y1-086 | Morgans Corner | In Service |
| Y3-058 | Rockawalkin 69kV | In Service |
| Z1-036 | WinFall-Chowan 230kV | In Service |
| Z2-027 | Pasquotank 34.5kV | In Service |
| Z2-076 | Worcester South 25kV | In Service |
| Z2-077 | Worcester North 25kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, PJM evaluated the potential impacts on tie line facilities between PJM and an affected system entity, which were identified per PJM planning analysis criteria. This upgrade may be required on the affected system portion of the tie line along with cost allocation of such upgrade if applicable, in coordination with the affected system. Depending on the affected system, this project may not be contingent on upgrade based on PJM planning analysis criteria, but may be contingent on this upgrade based on the Affected System Operator's planning criteria, provided in the Affected Systems Study Section, herein.
Affected System - Non-PJM Identified Violations
In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with potential Affected System impacts. PJM initiates coordination with each Affected System Operator by providing a list of New Service Requests in the Cycle with potential impacts to their respective system. If the Affected System Operator indicates an Affected System Study is required, PJM will notify the Project Developer or Eligible Customer of the need for an Affected System Study. See below if any Affected System Operator requires a study for this project:
System Reinforcements
Based on the Phase I analysis results, this project may have a cost responsibility for the following System Reinforcements:
| TO | RTEP ID | Title | Allocated Cost ($USD) |
|---|---|---|---|
| PENELEC | n7641 | Reconductor 9.41 miles of transmission line. Replace line drops at Carlisle Pike substation. | $33,874,732 |
| PENELEC | n6820.1 | Rebuild 22.36 miles of the Shade Gap to Reeds Gap Switching Station 115kV line | $21,692,313 |
| PENELEC | n6817.1 | Rebuild 24.59 miles of the Lewistown-Juniata 230kV transmission line | $10,085,515 |
| PENELEC | n6820.2 | Rebuild 0.3 miles of line and replace line drop at Reed Gap Switching Station | $699,800 |
| PPL | n6818 | Rebuild PPL's ~0.9 miles LEWI-JUNI 230kV Line with a summer normal rating of at least 3000 Amps. | $296,013 |
| PENELEC | n6820.4 | Replace substation conductor at Shade Gap on the Shade Gap - Reeds Gap Switching Station 115 kV Line. | $140,304 |
| PENELEC | (Pending) / TC2-PN-006 | Replace Wave Trap at Shade Gap | $112,898 |
| PENELEC | n7763.2 | Adjust relay settings at Roxbury 115kV Substation | $26,528 |
| Grand Total: | $66,928,103 | ||
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement: n7641
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n7641
- Title
- Reconductor 9.41 miles of transmission line. Replace line drops at Carlisle Pike substation.
- Description
- Reconductor 9.41 miles of the Carlisle Pike - Roxbury 115 kV Line. Replace line drops at Carlisle Pike substation.
- Total Cost ($USD)
- $33,874,732
- Allocated Cost ($USD)
- $33,874,732
- Time Estimate
- 25 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26CARLISLE-26ROXBURY 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 4.9 MW | 100.0% | $33,874,732 |
System Reinforcement: n6820.1
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n6820.1
- Title
- Rebuild 22.36 miles of the Shade Gap to Reeds Gap Switching Station 115kV line
- Description
- Total Cost ($USD)
- $70,047,107
- Allocated Cost ($USD)
- $21,692,313
- Time Estimate
- 36 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 9.6 MW | 31.0% | $21,692,313 |
AH1-313 | 7.9 MW | 25.3% | $17,721,593 |
AH1-588 | 7.4 MW | 24.0% | $16,798,852 |
AH1-589 | 6.1 MW | 19.8% | $13,834,349 |
System Reinforcement: n6817.1
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n6817.1
- Title
- Rebuild 24.59 miles of the Lewistown-Juniata 230kV transmission line
- Description
- Total Cost ($USD)
- $122,656,404
- Allocated Cost ($USD)
- $10,085,515
- Time Estimate
- 81 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-176 | 8.7 MW | 5.1% | $6,270,835 |
AG2-418 | 14.0 MW | 8.2% | $10,085,515 |
AG2-456 | 8.0 MW | 4.7% | $5,741,839 |
AG2-457 | 8.0 MW | 4.7% | $5,741,839 |
AH1-050 | 2.8 MW | 1.6% | $2,002,833 |
AH1-051 | 1.7 MW | 1.0% | $1,202,132 |
AH1-102 | 6.9 MW | 4.0% | $4,938,255 |
AH1-158 | 1.9 MW | 1.1% | $1,397,443 |
AH1-203 | 6.5 MW | 3.8% | $4,704,748 |
AH1-268 | 2.9 MW | 1.7% | $2,101,569 |
AH1-313 | 26.0 MW | 15.3% | $18,769,262 |
AH1-357 | 2.0 MW | 1.2% | $1,435,640 |
AH1-358 | 2.3 MW | 1.4% | $1,669,148 |
AH1-359 | 2.0 MW | 1.2% | $1,435,640 |
AH1-360 | 2.3 MW | 1.4% | $1,669,148 |
AH1-460 | 6.4 MW | 3.8% | $4,608,894 |
AH1-587 | 24.2 MW | 14.2% | $17,466,952 |
AH1-588 | 23.9 MW | 14.0% | $17,226,238 |
AH1-589 | 19.7 MW | 11.6% | $14,188,475 |
System Reinforcement: n6820.2
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n6820.2
- Title
- Rebuild 0.3 miles of line and replace line drop at Reed Gap Switching Station
- Description
- Total Cost ($USD)
- $2,259,738
- Allocated Cost ($USD)
- $699,800
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 9.6 MW | 31.0% | $699,800 |
AH1-313 | 7.9 MW | 25.3% | $571,703 |
AH1-588 | 7.4 MW | 24.0% | $541,935 |
AH1-589 | 6.1 MW | 19.8% | $446,300 |
System Reinforcement: n6818
- Type
- Load Flow
- TO
- PPL
- RTEP ID / TO ID
- n6818
- Title
- Rebuild PPL's ~0.9 miles LEWI-JUNI 230kV Line with a summer normal rating of at least 3000 Amps.
- Description
- The FE portion of the line is rated at 546/666 MVA SN/SE. The PPL portion is limiting, which requires n6818. Reinforcement scope no longer includes any substation scope as Juniata 230kV substation is being rebuilt under S0945.1. Actual PPL facility ratings after upgrade: 1245/1431 MVA SN/SE (FE facilities are more limiting)
- Total Cost ($USD)
- $3,600,000
- Allocated Cost ($USD)
- $296,013
- Time Estimate
- 24 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-176 | 8.7 MW | 5.1% | $184,051 |
AG2-418 | 14.0 MW | 8.2% | $296,013 |
AG2-456 | 8.0 MW | 4.7% | $168,525 |
AG2-457 | 8.0 MW | 4.7% | $168,525 |
AH1-050 | 2.8 MW | 1.6% | $58,784 |
AH1-051 | 1.7 MW | 1.0% | $35,283 |
AH1-102 | 6.9 MW | 4.0% | $144,939 |
AH1-158 | 1.9 MW | 1.1% | $41,015 |
AH1-203 | 6.5 MW | 3.8% | $138,086 |
AH1-268 | 2.9 MW | 1.7% | $61,682 |
AH1-313 | 26.0 MW | 15.3% | $550,883 |
AH1-357 | 2.0 MW | 1.2% | $42,136 |
AH1-358 | 2.3 MW | 1.4% | $48,990 |
AH1-359 | 2.0 MW | 1.2% | $42,136 |
AH1-360 | 2.3 MW | 1.4% | $48,990 |
AH1-460 | 6.4 MW | 3.8% | $135,272 |
AH1-587 | 24.2 MW | 14.2% | $512,660 |
AH1-588 | 23.9 MW | 14.0% | $505,595 |
AH1-589 | 19.7 MW | 11.6% | $416,436 |
System Reinforcement: n6820.4
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n6820.4
- Title
- Replace substation conductor at Shade Gap on the Shade Gap - Reeds Gap Switching Station 115 kV Line.
- Description
- Replace substation conductor at Shade Gap on the Shade Gap - Reeds Gap Switching Station 115 kV Line.
- Total Cost ($USD)
- $453,060
- Allocated Cost ($USD)
- $140,304
- Time Estimate
- 14 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 9.6 MW | 31.0% | $140,304 |
AH1-313 | 7.9 MW | 25.3% | $114,622 |
AH1-588 | 7.4 MW | 24.0% | $108,654 |
AH1-589 | 6.1 MW | 19.8% | $89,480 |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-006
- Title
- Replace Wave Trap at Shade Gap
- Description
- Total Cost ($USD)
- $364,562
- Allocated Cost ($USD)
- $112,898
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26REED TAP-26SHADE GP 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 9.6 MW | 31.0% | $112,898 |
AH1-313 | 7.9 MW | 25.3% | $92,232 |
AH1-588 | 7.4 MW | 24.0% | $87,430 |
AH1-589 | 6.1 MW | 19.8% | $72,001 |
System Reinforcement: n7763.2
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n7763.2
- Title
- Adjust relay settings at Roxbury 115kV Substation
- Description
- Total Cost ($USD)
- $51,762
- Allocated Cost ($USD)
- $26,528
- Time Estimate
- 11 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 26ROXBURY-AE1-071-POI 115.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-418 | 9.2 MW | 51.2% | $26,528 |
AH1-313 | 8.8 MW | 48.8% | $25,234 |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3737.50
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3737.50
- Title
- Bring the Peach Bottom-Delta Power Plant 500 kV line “in and out” of North Delta
- Description
- Bring the Peach Bottom-Delta Power Plant 500 kV line “in and out” of North Delta by constructing a new Peach Bottom-North Delta 500 kV (0.3 miles) cut-in and cut-out lines.
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.31
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.31
- Title
- Build new North Delta-High Ridge 500 kV line - PECO Portion (Projected ISD 12/1/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.44
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.44
- Title
- North Delta termination for the North Delta-High Ridge 500 line (PECO work).
- Description
- None
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.48
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.48
- Title
- North Delta termination for the North Delta-High Ridge 500 line (Transource work).
- Description
- None
- Cost Information
- Time Estimate
- Dec 15 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.29
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.29
- Title
- High Ridge termination for the North Delta-High Ridge 500 kV line (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.32
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.32
- Title
- Build new North Delta-High Ridge 500 kV line - BGE Portion (Projected ISD 12/31/2030)
- Description
- Build new North Delta-High Ridge 500 kV line. (~59 miles)
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.26
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.26
- Title
- Build High Ridge 500 kV substation - Three bay breaker and half configuration (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.27
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.27
- Title
- High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) - Waugh Chapel side (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.30
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.30
- Title
- High Ridge - Install two 500/230 kV transformers (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.5
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.5
- Title
- Build Solley Road substation + Statcom (Projected ISD 12/31/2028)
- Description
- Build Solley Road substation + Statcom. New STATCOM rating: 350 MVAR Add 4x 230 kV breakers bays.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.11
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3780.11
- Title
- Brighton Statcom and Capacitor (Projected ISD 12/31/2028)
- Description
- Brighton Statcom and capacitor New STATCOM rating: 350 MVAR New capacitor rating: 350 MVAR
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.49
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.49
- Title
- North Delta 500 kV termination for the Calpine generator (Calpine/Transource work).
- Description
- None
- Cost Information
- Time Estimate
- Oct 06 2027
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
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
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9116.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9116.0 / TC1-PN-001.d
- Title
- Rebuild approximately 11 miles of the Homer City-Shelocta 230 kV line with double bundled 795 kcmil 26/7 ACSS conductor
- Description
- Rebuild the Homer City – Shelocta 230 kV Line, approximately 11 miles, with double bunded 795 kcmil 26/7 ACSS conductor. Terminate new conductor at Homer City substation. Terminate new conductor at Shelocta substation.
- Total Cost ($USD)
- $39,312,233
- Allocated Cost ($USD)
- $0
- Time Estimate
- 31 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9117.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9117.0 / TC1-PN-001.f
- Title
- Replace disconnect switches at Homer City Substation (Homer City-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $1,254,760
- Allocated Cost ($USD)
- $0
- Time Estimate
- 24 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9225.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9225.0 / TC1-PN-001.e
- Title
- Replace 230 kV substation conductor and line drops at Shelocta substation for the Homer City-Shelocta 230 kV line terminal
- Description
- Replace 230 kV substation conductor and line drops at Shelocta substation for the Homer City-Shelocta 230 kV line terminal
- Total Cost ($USD)
- $107,569
- Allocated Cost ($USD)
- $0
- Time Estimate
- 13 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9118.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9118.0 / TC1-PN-001.g
- Title
- Replace disconnect switches and leads at Shelocta Substation (Homer City-Shelocta 230kV line terminal)
- Description
- Note: Due to shared breaker arrangements, this cost is split 50/50 with TC1-PN-003.g (Keystone-Shelocta 230kV line terminal)
- Total Cost ($USD)
- $1,783,345
- Allocated Cost ($USD)
- $0
- Time Estimate
- 26 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-005.a
- Title
- Replace Sub conductor at Shelocta Substation (Homer City-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $869,783
- Allocated Cost ($USD)
- $0
- Time Estimate
- 13 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-005.b
- Title
- Adjust Relays at Shelocta Substation (Homer City-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $52,848
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26HOMER CT-26SHELOCTA 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: s0945.1
- Type
- Load Flow
- TO
- PPL
- RTEP ID / TO ID
- s0945.1
- Title
- Rebuild the Juniata 230/69 kV Substation
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2025
Contingent Note: Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 may need this upgrade in-service to be deliverable to the PJM system. If AG2-418 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.
| Facility | Contingency | |
|---|---|---|
| 26LEWISTWN-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9120.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9120.0 / TC1-PN-003.c
- Title
- Replace substation conductor at Keystone substation (Keystone-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $187,749
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9121.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9121.0 / TC1-PN-003.d
- Title
- Replace line drops at Keystone Substation (Keystone-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $257,762
- Allocated Cost ($USD)
- $0
- Time Estimate
- 11 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9124.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9124.0 / TC1-PN-003.e
- Title
- Replace bus conductor at Keystone Substation (Keystone-Shelocta 230kV line terminal)
- Description
- None
- Total Cost ($USD)
- $1,104,686
- Allocated Cost ($USD)
- $0
- Time Estimate
- 13 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9125.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9125.0 / TC1-PN-003.f
- Title
- Replace disconnect switches at Keystone Substation (Keystone-Shelocta 230kV line terminal)
- Description
- None
- Total Cost ($USD)
- $1,254,762
- Allocated Cost ($USD)
- $0
- Time Estimate
- 24 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9127.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9127.0 / TC1-PN-003.g
- Title
- Replace disconnect switches and leads at Shelocta Substation (Keystone-Shelocta 230kV line terminal)
- Description
- Note: Due to shared breaker arrangements, this cost is split 50/50 with TC1-PN-001.g (Homer City-Shelocta 230kV line) terminal)
- Total Cost ($USD)
- $1,783,345
- Allocated Cost ($USD)
- $0
- Time Estimate
- 26 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9126.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9126.0 / TC1-PN-003.h
- Title
- Replace breaker leads at Keystone Substation (Keystone-Shelocta 230kV line terminal)
- Description
- None
- Total Cost ($USD)
- $152,770
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: n9119.0
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- n9119.0 / TC1-PN-003.b
- Title
- Reconductor/Rebuild the Shelocta – Keystone 230 kV Line, approximately 2.5 miles, with 1272 kcmil 45/7 ACSR 2-conductor
- Description
- Reconductor/Rebuild the Shelocta – Keystone 230 kV Line, approximately 2.5 miles, with 1272 kcmil 45/7 ACSR 2-conductor. Terminate new conductor at Keystone substation. Terminate new conductor at Shelocta substation.
- Total Cost ($USD)
- $9,533,592
- Allocated Cost ($USD)
- $0
- Time Estimate
- 23 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-007.a
- Title
- Adjust relay settings at Keystone and Shelocta
- Description
- Total Cost ($USD)
- $103,523
- Allocated Cost ($USD)
- $0
- Time Estimate
- 11 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-007.b
- Title
- Replace line drops at Keystone Substation (Keystone-Shelocta 230kV line terminal)
- Description
- Total Cost ($USD)
- $263,169
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 26SHELOCTA-26KEYSTONE 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.13
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.13
- Title
- Batavia Road to Riverside 230 kV reconductor
- Description
- Batavia Road to Riverside 230 kV reconductor New rating: 1941 MVA SN / 2181 MVA SE
- Cost Information
- Time Estimate
- Dec 31 2027
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.36
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.36
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton BGE) 500 kV (Projected ISD 12/31/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton BGE) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.357
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.357
- Title
- Build a new 765/500/230 kV substation called Yeat. Install (2) 765/500 kV transformers. Cut in 500 kV line Bristers-Ox and 500 kV line Meadowbrook-Vint Hill into Yeat.
- Description
- Build a new 765/500/230 kV substation called Yeat. Install (2) 765/500 kV transformers. Cut in 500 kV line Bristers-Ox and 500 kV line Meadowbrook-Vint Hill into Yeat.
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.355
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.355
- Title
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 69.3 miles in AEP section).
- Description
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 69.3 miles in AEP section).
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.342
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.342
- Title
- Remove the terminal equipment and substation work required for the termination of the Morrisville-Wishing Star 500 kV line into Vint Hill.
- Description
- Remove the terminal equipment and substation work required for the termination of the Morrisville-Wishing Star 500 kV line into Vint Hill.
- Cost Information
- Time Estimate
- Jul 13 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.341
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.341
- Title
- Remove the 500 kV conductor previously planned to terminate into the Vint Hill 500 kV Substation and extend approximately 0.2 miles of conductor to fly-over the site.
- Description
- Remove the 500 kV conductor previously planned to terminate into the Vint Hill 500 kV substation and extend approximately 0.2 miles of conductor to fly-over the site.
- Cost Information
- Time Estimate
- Jul 13 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.325
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.325
- Title
- Build a new 26.38mi 230kV Line from Elmont – Ladysmith on the existing 5-2 structures between the two stations. New conductor has a summer rating of 1573 MVA.
- Description
- Build a new 26.38mi 230kV Line from Elmont – Ladysmith on the existing 5-2 structures between the two stations. New conductor has a summer rating of 1573 MVA.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.327
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.327
- Title
- Upgrade/install equipment at Ladysmith Substation to 4000A. Expansion will be required to accommodate a total of three (3) new 230 kV strings of breaker and a half scheme.
- Description
- Upgrade/install equipment at Ladysmith substation to 4000A. Expansion will be required to accommodate a total of three (3) new 230kV strings of breaker and a half scheme.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.326
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.326
- Title
- At Elmont substation, install/upgrade associated equipment to accommodate a 4000A line rating for the new 230kV line between Elmont - Ladysmith.
- Description
- At Elmont substation, install/upgrade associated equipment to accommodate a 4000A line rating for the new 230kV line between Elmont - Ladysmith.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.344
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.344
- Title
- Build a 500kV line from North Anna substation (bypassing Ladysmith Substation) to a new substation called Kraken. New conductor to have a minimum summer normal rating of 4357MVA.
- Description
- Build a 500kV line from North Anna substation (bypassing Ladysmith Substation) to a new substation called Kraken. New conductor to have a minimum summer normal rating of 4357MVA.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.352
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.352
- Title
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating new Line #568 Kraken to Possum Point.
- Description
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating new Line #568 Kraken to Possum Point.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.351
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.351
- Title
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating Line #9517 Ladysmith to Kraken.
- Description
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating Line #9517 Ladysmith to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.349
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.349
- Title
- Update relay settings at Ladysmith to change the destination of 500kV line #568 from Possum Point to Kraken.
- Description
- Update relay settings at Ladysmith to change the destination of 500kV line #568 from Possum Point to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.348
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.348
- Title
- Build a new 500/230kV substation called Kraken. The 500kV, 5000A ring bus will be set up for a redundant breaker configuration. Install (2) 1400MVA 500/230 kV transformers.
- Description
- Build a new 500/230kV substation called Kraken. The 500kV, 5000A ring bus will be set up for a redundant breaker configuration. Install (2) 1400MVA 500/230 kV transformers. A new redundant breaker ring will be added at Kraken to accommodate the new 500kV line from North Anna to Kraken.
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.346
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.346
- Title
- Cut-in 500kV line from Kraken substation into Yeat substation
- Description
- Cut-in 500kV line from Kraken substation into Yeat substation
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.345
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.345
- Title
- Build a 500kV line from a new substation called Kraken to a new substation called Yeat. New conductor to have a minimum summer normal rating of 4357MVA.
- Description
- Build a 500kV line from a new substation called Kraken to a new substation called Yeat. New conductor to have a minimum summer normal rating of 4357MVA.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.350
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.350
- Title
- Update relay settings at Possum Point to change the destination of 500kV line #568 from Ladysmith to Kraken.
- Description
- Update relay settings at Possum Point to change the destination of 500kV line #568 from Ladysmith to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.356
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.356
- Title
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 86.7 miles in Dominion section).
- Description
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 86.7 miles in Dominion section).
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 01DOUBS-8GOOSE CREEK 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.33
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.33
- Title
- Replace terminal equipment limitations at Brighton 500 kV - on the existing Brighton-Waugh Chapel 500 kV (5053) or new Brighton-High Ridge 500 kV.
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.8
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.8
- Title
- Graceton 500 kV substation expansion (Projected ISD 12/31/2028)
- Description
- Add 3x 500 kV breaker bays, 2x 500/230 kV auto transformer, 1x 500 kV caps
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.15
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.15
- Title
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub
- Description
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV substation by rebuilding 5012 between new terminal at Peach Bottom South and North Delta on single circuit structures and terminating at North Delta.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.17
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.17
- Title
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub (Transource)
- Description
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV substation by rebuilding 5012 between new terminal at Peach Bottom South and North Delta on single circuit structures and terminating at North Delta (Transource Scope).
- Cost Information
- Time Estimate
- May 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.34
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.34
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new Graceton-Conastone) 500 kV and cut into North Delta 500kV (Projected ISD 12/31/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new Graceton-Conastone) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.35
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.35
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton PECO) 500 kV (Projected ISD 12/1/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton PECO) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.1
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.1
- Title
- Peach Bottom North upgrades – substation work (Projected ISD 12/31/2028)
- Description
- Add 3x 500 kV breakers to form a breaker-and-a-half bay.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.37
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.37
- Title
- Replace terminal equipment limitations at Conastone 500 kV - on the (existing Peach Bottom-Conastone) or (new Graceton-Conastone) 500 kV line (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending) / TC2-PN-011
- Title
- Replace 500/230 kV Conemaugh #3 Transformer
- Description
- Replace 500/230 kV Conemaugh #3 Transformer
- Total Cost ($USD)
- $28,558,871
- Allocated Cost ($USD)
- $0
- Time Estimate
- 66 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| CONEM-GH-26CONEMAGH 500.0/230.0 kV Ckt 3 transformer | (Any) |
System Reinforcement: b3780.14
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.14
- Title
- Reconfigure Cooper transmission feeds by establishing new Cooper-North Delta 230 kV line and rerouting existing transmissions lines by Cooper.
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.7
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.7
- Title
- Build new Batavia Road substation (Projected ISD 12/31/2028)
- Description
- Build Batavia Road substation. Add 4 x 230kV breaker bays
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.9
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.9
- Title
- Graceton to Batavia Road 230 kV double circuit pole line (Projected ISD 12/31/2028)
- Description
- Graceton to Batavia Road 230 kV double circuit pole line New rating: 1331 MVA SN/ 1594 MVA SE
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.16
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.16
- Title
- Terminate new Cooper-North Delta 230 kV line (Transource Scope) at North Delta 230 kV
- Description
- None
- Cost Information
- Time Estimate
- Oct 15 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.28
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.28
- Title
- High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) -Brighton side (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.6
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.6
- Title
- Build Granite substation + Statcom (Projected ISD 12/31/2028)
- Description
- Build Granite substation + Statcom. New STATCOM rating: 350 MVAR. Add 4x 230 kV breaker bays.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.50
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.50
- Title
- North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (Transource work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Jan 23 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3737.47
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3737.47
- Title
- Build New North Delta 500 kV substation (Four bay breaker and half configuration)
- Description
- Build New North Delta 500 kV substation (four bay breaker and half configuration) - the substation will include 12 - 500kV breakers and one 500/230 kV transformer, will allow the termination of six - 500 kV lines
- Cost Information
- Time Estimate
- Oct 15 2027
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- (Pending) / WP-AF1-F-0001
- Title
- Replace Wave Trap at Keystone
- Description
- Upgrade/Replace Wave Trap at Keystone on the Keystone-Cabot 500kV line.
- Total Cost ($USD)
- $364,562
- Allocated Cost ($USD)
- $0
- Time Estimate
- 19 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-418 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-418 could receive cost allocation. Although AG2-418 may not presently have cost responsibility for this upgrade, AG2-418 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| KEYSTONE-01CABOT 500.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PENELEC
- RTEP ID / TO ID
- (Pending)
- Title
- Single Element Derate - Eliminated by end of 2025
- Description
- FirstEnergy has an active internal project that will address the single element derate on the Keystone-South Bend 500kV line. This impacts the following contignencies: PN_P2-3_PN-500-DRT32_SRT-A [Breaker] and PN_P2-3_PN-500-004-DRT-002_SRT-SL [Breaker]
- Total Cost ($USD)
- $0
- Allocated Cost ($USD)
- $0
- Time Estimate
- TBD
Note: This reinforcement is fictitious and will not be cost allocated to projects. It is listed for information purposes only.
| Facility | Contingency | |
|---|---|---|
| KEYSTONE-01SOBEND 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.42
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.42
- Title
- Peach Bottom 500kV North bus upgrade (Projected ISD 12/1/2030)
- Description
- Peach Bottom 500kV North bus upgrade - Replace 11 – Instances of strain bus conductor used for breaker drops or CT drops, 7 – 500 kV disconnect switches, 7 – Free Standing CTs, 1 – 500 kV breaker, 2 – Breaker relays or meters.
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.52
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.52
- Title
- Reconfigure Peach Bottom North and South 500 kV yards (Projected ISD 12/1/2030)
- Description
- Reconfigure Peach Bottom North and South yards to allow for termination of 500 kV lines from Peach Bottom to North Delta. North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line.
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.2
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.2
- Title
- Peach Bottom to Graceton (PECO Portion) – New 500kV Line
- Description
- Peach Bottom to Graceton (PECO Portion) – New 500kV Line. New rating: 4503 MVA SN/ 5022 MVA SE. This is a baseline identified for the announced Brandon Shores deactivation.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3780.4
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.4
- Title
- Peach Bottom to Graceton (BGE Portion) – New 500kV Line
- Description
- New rating: 4503 MVA SN/ 5022 MVA SE. This is a baseline identified for the announced Brandon Shores deactivation.
- Cost Information
- Time Estimate
- Dec 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.45
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.45
- Title
- North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (PECO work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.46
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3800.46
- Title
- North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (PECO work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.51
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.51
- Title
- North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (Transource work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- May 31 2028
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.47
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.47
- Title
- Build new Peach Bottom South-North Delta 500 kV line (Projected ISD 12/1/2030)
- Description
- Build new Peach Bottom South-North Delta 500 kV line – cut in to Peach Bottom tie No. 1 and extending line to North Delta (~1.25 miles new ROW).
- Cost Information
- Time Estimate
- Dec 01 2030
Not Contingent Note: AG2-418 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG2-418 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DAUP TR2-JUNI 230.0 kV Ckt 1 line | (Any) |
Attachments
AG2-418 One Line Diagram
