AH1-734 Phase I Study Report
v1.00 released 2025-10-29 21:52
South Bend 500 kV
268.6 MW Capacity / 270.3 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 Armstrong Power, LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Keystone Appalachian Transmission Company.
Preface
The Phase I System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase I System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.3, PJM takes the following actions during the Phase I System Impact Study:
- 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 an uprate to a planned/existing Natural Gas facility located in the Keystone Appalachian Transmission Company zone — Indiana County, Pennsylvania. This project is an increase to the developer’s AD1-099/AD2-113 project(s), which will share the same Point of Interconnection. The AH1-734 project is a 270.3 MW uprate (268.6 MW Capacity uprate) to the previous project(s). The total installed facilities will have a capability of 1058.4 MW with 399.2 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
AH1-734 will interconnect on the Keystone Appalachian Transmission Company transmission system at South Bend 500 kV substation as an uprate to AD2-113.
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 AH1-734 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 AH1-734 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $800,083 | $0 | |
| Other Scope | $7,300 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $0 | $0 | |
| Network Upgrades | $51,100 | $51,100 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $129,735 | $129,735 | |
| 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 | $988,218 | $180,835 | |
* 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 AH1-734
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 AH1-734 Project due at DP1 |
| A | B | A - B | |
| AH1-734 | $18,083 | $1,115,200 | $0 |
Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
| Transmission Owner Interconnection Facilities | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Integrate Interconnection Facilities protection and controls to the Transmission Owner system. | $61,320 | $61,320 |
| (Pending) | Install SCADA Controlled Disconnect Switches at South Bend. | $738,763 | $738,763 |
| Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Revise relay settings at South Bend substation as required. | $51,100 | $51,100 |
| Physical Interconnection | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Support for existing revenue metering coordination. | $7,300 | $7,300 |
Based on the scope of work for the Interconnection Facilities, it is expected to take 35 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 AH1-734 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.Transmission Owner Requirements
The Project Developer will be required to comply with all interconnected Transmission Owner’s revenue metering requirements located at the following link: PJM - Transmission Owner Engineering & Construction Standards.
Summer Peak Analysis
The New Service Request AH1-734 was evaluated as a 270.3 MW (268.6 MW Capacity) injection in the APS area.
AH1-734 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 1058.4 MW (270.3 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/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 | 109.98 |
Winter Peak Analysis
The New Service Request AH1-734 was evaluated as a 270.3 MW (268.6 MW Capacity) injection in the APS area.
AH1-734 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 1058.4 MW (270.3 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 AH1-734 was evaluated as a 270.3 MW injection
AH1-734 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 1058.4 MW (270.3 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 |
| AA1-076 | Hunterstown-Conemaugh 500kV | In Service |
| AA2-184 | Atlantic-Red Bank 34kV | In Service |
| AB1-001 | Absecon 12 kV | 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 |
| AB2-032 | Church-Wye Mills 138 kV | In Service |
| AB2-036 | Church - Oil City 138kV | Suspended |
| AB2-037 | Keeney-Steele 230kV | Under Construction |
| AB2-049 | Gloucester Township 12kV | In Service |
| AB2-057 | Brunswick 26kV | In Service |
| AB2-133 | Chestertown 69kV | Under Construction |
| AB2-135 | Church-Kent 69kV | In Service |
| AB2-136 | Cambridge-West Cambridge 69kV | Under Construction |
| AB2-153 | Church-Wye Mills 138 kV | In Service |
| AB2-172 | Todd 69kV | In Service |
| AB2-179 | Townsend 138kV | In Service |
| AC1-010 | Gloucester 26kV | Under Construction |
| AC1-017 | Levittown 13 kV | In Service |
| AC1-030 | Cinnaminson 13kV | 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 |
| AC1-167 | Mark Center 69kV | Under Construction |
| AC1-190 | East New Market 69kV | Suspended |
| AC2-009 | Pennington 13 kV | In Service |
| AC2-023 | Hebron 69kV | Engineering & Procurement |
| AC2-103 | Beaver-Davis Besse 345 kV I | Engineering & Procurement |
| 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 |
| AD1-020 | Hunterstown-Lincoln 115 kV | In Service |
| AD1-130 | Hardin Switch 345 kV | In Service |
| AD2-027 | Camden Switch 26 kV | In Service |
| AD2-042 | Camden Switch 26 kV II | In Service |
| AD2-065 | Atco 12 kV | In Service |
| AD2-070 | Gilbert-Morris Park 34.5kV | In Service |
| AD2-076 | Carville 138 kV | Suspended |
| 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 |
| AD2-163 | Broadview-Tangy 138 kV | In Service |
| AE1-041 | Edison 4kV | In Service |
| AE1-071 | Shade Gap-Roxbury 115 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 |
| AE1-104 | BL England 138 kV | Suspended |
| 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 |
| AE1-156 | Quakertown Solar II 34.5 kV | Partially in Service - Under Construction |
| AE1-183 | Maysville-McDowell 69 kV | Engineering & Procurement |
| AE1-185 | Hokes-Jackson 69 kV | In Service |
| 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 |
| AE2-001 | Nittany-Zion 46 kV | Suspended |
| AE2-042 | Milton 69 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 |
| AE2-084 | Derry Tap-Derry Bus 69 kV | Engineering & Procurement |
| AE2-110 | Columbia-West Bloomsburg 69 kV | Suspended |
| AE2-112 | Carville 138 kV II | Suspended |
| 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 |
| AE2-129 | 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 |
| AE2-214 | Cole 345 kV | Engineering & Procurement |
| AE2-224 | Bear Rock-Johnstown 230 kV | In Service |
| AE2-241 | Bloomsburg-Columbia 69 kV | Suspended |
| AE2-248 | Fillmore-Thompson Farm 46 kV | Suspended |
| 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 |
| AE2-322 | Mark Center 69 kV | Under Construction |
| AE2-342 | Woodstock 69 kV | Engineering & Procurement |
| AE2-343 | Andover (Maysville) 69 kV II | Under Construction |
| AE2-345 | Hunterstown-Texas Eastern Tap 115 kV | Suspended |
| AF1-007 | Indian River 230 kV I | Suspended |
| AF1-036 | Carville 138 kV III | Suspended |
| 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 |
| AF1-106 | East Sayre 34.5 kV | Withdrawn |
| AF1-120 | East Fayette 2 138 kV | In Service |
| AF1-134 | Philipsburg-Madera 34.5 kV | Engineering & Procurement |
| AF1-140 | Claysburg 23 kV | Engineering & Procurement |
| AF1-143 | Lick Run 115 kV | Engineering & Procurement |
| 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 |
| AF1-262 | 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 |
| AF1-320 | 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 |
| AF2-014 | Maddox Creek 345 kV | Engineering & Procurement |
| AF2-039 | Shawville-Clearfield 34.5 kV | Engineering & Procurement |
| AF2-050 | Bear Rock-Johnstown 230 kV | Active |
| 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 |
| AF2-138 | Flanders-West Wharton 34.5 kV | In Service |
| AF2-139 | Gilbert-Warren Glen 34.5 kV | In Service |
| 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 |
| AF2-233 | Penns-Richfield Tie #1 69 kV | Engineering & Procurement |
| AF2-234 | Sunbury Yard #1-Richfield Tie #2 69 kV | Engineering & Procurement |
| 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 |
| AG1-041 | Osterburg-Bedford North 23 kV | Withdrawn |
| AG1-054 | Potter-Harlan 69 kV | Engineering & Procurement |
| AG1-090 | Philipsburg 115 kV | Active |
| 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 |
| AG1-223 | Larrabee-Allaire 34.5 kV | Under Construction |
| 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 |
| AG1-301 | 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 |
| AG1-377 | 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 |
| AG1-480 | Shawnee 34.5 kV | Engineering & Procurement |
| AG1-482 | Hamilton 115 kV | Withdrawn |
| 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 |
| AG1-554 | South Kenton 138 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 |
| AG2-181 | Airey - Golden Hill 69 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 |
| AG2-297 | 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 |
| AG2-418 | Blain 115 kV | Active |
| AG2-430 | Sunbury-Dalmatia 69 kV II | Active |
| AG2-439 | Oxbow 34.5 kV | Active |
| AG2-447 | Cedar Creek 138 kV VII | Active |
| AG2-561 | Glory - Glen Campbell 34.5 kV | Active |
| AG2-616 | Churchtown - Upper Pittsgrove 138 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 |
| AH1-005 | East Towanda-South Troy 115 kV II | Active |
| AH1-027 | Cartanza 230 kV | Active |
| AH1-054 | Upton-Whitings 34.5 kV | Active |
| AH1-057 | Edgewood 12.47 kV | Active |
| AH1-102 | Seward-Glory 115 kV | 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 |
| AH1-380 | Mt Olive - Kenny 69kV | Active |
| AH1-460 | Hooversville - Scalp Level 115 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 |
| AH1-634 | 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 |
| AH1-722 | Linden 230kV | 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 |
| 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 |
| Y1-079 | Wye Mills 69kV | In Service |
| Y1-080 | Dorchester 12kV | In Service |
| Y3-058 | Rockawalkin 69kV | 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) |
|---|---|---|---|
| APS | (Pending) / WP-AF1-F-0001 | Replace Wave Trap at Keystone | $129,735 |
| Grand Total: | $129,735 | ||
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement
- Type
- Load Flow
- TO
- APS
- RTEP ID / TO ID
- (Pending) / WP-AF1-F-0001
- Title
- Replace Wave Trap at Keystone
- Description
- Upgrade/Replace Wave Trap at Keystone on the Keystone-Cabot 500kV line.
- Total Cost ($USD)
- $364,562
- Allocated Cost ($USD)
- $129,735
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| KEYSTONE-01CABOT 500.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-347 | 44.8 MW | 14.5% | $52,856 |
AH1-634 | 6.8 MW | 2.2% | $8,009 |
AH1-695 | 116.2 MW | 37.6% | $137,130 |
AH1-710 | 31.2 MW | 10.1% | $36,833 |
AH1-734 | 110.0 MW | 35.6% | $129,735 |
Attachments
AH1-734 One Line Diagram
