AG2-109 Phase I Study Report
v1.00 released 2025-10-29 21:52
Fitchville-New London 69 kV
28.1 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 Rosemary Solar, LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is American Transmission Systems, Incorporated.
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 generating facility located in the American Transmission Systems, Incorporated zone — Huron County, Ohio. The installed facilities will have a total capability of 40.0 MW with 28.1 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
AG2-109 will interconnect on the American Transmission Systems, Incorporated transmission system by tapping the Hanville to Wellington 69 kV line between Fitchville and New London.
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 AG2-109 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 AG2-109 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $1,787,012 | $0 | |
| Other Scope | $58,400 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $11,847,599 | $11,847,599 | |
| Network Upgrades | $204,400 | $204,400 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $0 | $0 | |
| Transient Stability | $0 | $0 | |
| Short Circuit | $0 | $0 | |
| Transmission Owner Analysis | |||
| SubRegional | $361,264 | $361,264 | |
| Distribution | $0 | $0 | |
| Affected System Reinforcements | |||
| AFS - PJM Violatons | $0 | $0 | |
| AFS - Non-PJM Violations | $0 | $0 | |
| Total | $14,258,675 | $12,413,263 | |
* 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 AG2-109
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 AG2-109 Project due at DP1 |
| A | B | A - B | |
| AG2-109 | $1,241,326 | $160,000 | $1,081,326 |
Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
| Transmission Owner Interconnection Facilities | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Integrate Interconnection Facilities protection and controls to the Transmission Owner system. | $61,320 | $61,320 |
| (Pending) | Cut the existing 69 kV line and Loop in the new Interconnection substation. | $979,968 | $979,968 |
| (Pending) | Construction of (1) span of conductor between the new Interconnection substation takeoff structure and Developer owned dead end structure. | $745,724 | $745,724 |
| Stand-Alone Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Construct a new 69 kV 3-breaker ring bus Interconnection substation. | $11,847,599 | $11,847,599 |
| Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Revise relay settings at FEC New London substation as required. | $51,100 | $51,100 |
| (Pending) | Revise relay settings at FEC Fitchville substation as required. | $51,100 | $51,100 |
| (Pending) | Revise relay settings at Wellington substation as required. | $51,100 | $51,100 |
| (Pending) | Revise relay settings at Hanville substation as required. | $51,100 | $51,100 |
| Physical Interconnection | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | Install 69 kV revenue metering within new Interconnection substation. | $58,400 | $58,400 |
Based on the scope of work for the Interconnection Facilities, it is expected to take 36 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.
The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.
Transmission Owner Analysis
There were no network impacts to Distribution facilities identified by the Transmission Owner.
The Transmission Owner identified network impacts to Sub-Regional facilities as follows:
| Overloaded Element | Contingency | Rating [MVA] | Final Cycle Loading % | Contribution [MW] |
|---|---|---|---|---|
| 239713 02NOVA 69.0 - 239167 02WELLNG 69.0 CKT 1 | ATSI_P1-2_OEC-345-809_SRT-A | 33.0 | 159.11 % | 18.09 |
| TO | RTEP ID / TO ID | Category | Title | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|---|---|---|
| ATSI | (Pending) / TC2-ATSI-L02 | SubRegional | Upgrade (1) 4A overcurrent relay for breaker B41 at Wellington | 18.1 MW | 70.9% | $361,264 |
| Grand Total: | $361,264 | |||||
System Reinforcement
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-L02
- Category
- SubRegional
- Title
- Upgrade (1) 4A overcurrent relay for breaker B41 at Wellington
- Description
- Upgrade (1) 4A overcurrent relay for breaker B41 at Wellington New ratings to be 55/69/80 MVA
- Total Cost
- $509,895
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AG2-109 | 18.1 MW | 70.9% | $361,264 |
| AH1-690 | 7.4 MW | 29.1% | $148,631 |
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 AG2-109 was evaluated as a 40.0 MW (28.1 MW Capacity) injection in the ATSI area.
AG2-109 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 | ATSI | 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | ATSI_P7-1_OEC-345-002_SRT-A | Tower | AC | 109.31 % | 1745.0 | B | 1907.45 | 3.42 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-901_SRT-SL | Breaker | AC | 113.76 % | 1720.0 | B | 1956.7 | 2.55 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-007A_SRT-SL | Breaker | AC | 104.78 % | 1878.0 | B | 1967.82 | 1.83 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-031_SRT-A | Breaker | AC | 100.84 % | 1878.0 | B | 1893.72 | 2.87 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | ATSI_P2-3_OEC-345-002_SRT-A | Breaker | AC | 174.17 % | 1878.0 | B | 3270.93 | 3.92 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | ATSI_P2-3_OEC-345-003_SRT-SL | Breaker | AC | 104.76 % | 1878.0 | B | 1967.48 | 2.57 | |
| GD2 | ATSI | 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | ATSI_P2-3_OEC-345-028_SRT-A | Breaker | AC | 101.37 % | 1878.0 | B | 1903.65 | 2.88 |
Winter Peak Analysis
The New Service Request AG2-109 was evaluated as a 40.0 MW (28.1 MW Capacity) injection in the ATSI area.
AG2-109 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 AG2-109 was evaluated as a 40.0 MW injection
AG2-109 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 |
| AB2-170 | East Lima-Marysville 345kV | In Service |
| AC1-111 | Aurora 138kV | In Service |
| AC1-167 | Mark Center 69kV | Under Construction |
| AC2-015 | Chatfield-Howard 138kV | Partially in Service - Under Construction |
| AC2-044 | Maddox Creek 345kV | Suspended |
| AC2-103 | Beaver-Davis Besse 345 kV I | Engineering & Procurement |
| AC2-154 | Davis Creek 138kV | Engineering & Procurement |
| AC2-168 | Clinton 23kV | In Service |
| AC2-195 | Galion-Roberts South 138 kV | Under Construction |
| AD1-100 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Under Construction |
| AD1-101 | Continental 69 kV | In Service |
| AD1-106 | North Waldo-Wild Creek 138 kV | Suspended |
| AD1-119 | Payne 69 kV | In Service |
| AD1-130 | Hardin Switch 345 kV | In Service |
| AD2-020 | Valley 138 kV | Engineering & Procurement |
| AD2-047 | Davis Creek 138 kV | Suspended |
| AD2-060 | Davis Creek 138kV | Engineering & Procurement |
| AD2-079 | Capitol Ave 34.5kV | In Service |
| AD2-086 | Hardin Switch 345 kV | In Service |
| AD2-133 | Eagle Valley 115kV | In Service |
| AE1-079 | Maysville-Sharon 69 kV | Under Construction |
| AE1-090 | Hardin Switch 345 kV | In Service |
| AE1-091 | West Newton-Lynn 138 kV | Suspended |
| AE1-102 | Maddox Creek 345 kV | Suspended |
| AE1-146 | Ebersole #2-Fostoria Central 138 kV | Under Construction |
| AE1-166 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE1-170 | Kenzie Creek-Colby 138 kV | Suspended |
| AE1-183 | Maysville-McDowell 69 kV | Engineering & Procurement |
| AE1-237 | Andover (Maysville) 69kV I | Under Construction |
| AE1-245 | Haviland 138 kV | Under Construction |
| AE2-045 | Olive-Reynolds 345 kV | Engineering & Procurement |
| AE2-072 | East Leipsic-Richland 138 kV | In Service |
| AE2-089 | Pennville-Adams 138 kV | Engineering & Procurement |
| 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 |
| AE2-126 | Dubois-Curwensville 34.5 kV | In Service |
| AE2-129 | Philipsburg-Clarence 34.5 kV | In Service |
| AE2-131 | Philipsburg-Karthaus 34.5 | Under Construction |
| AE2-139 | East Towanda-Grover 230 kV | Engineering & Procurement |
| AE2-152 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE2-176 | Groton 138 kV Solar | In Service |
| AE2-181 | Snyder 69kV | Under Construction |
| AE2-224 | Bear Rock-Johnstown 230 kV | In Service |
| AE2-234 | Liberty Center-Buckeye Tap 69 kV | Engineering & Procurement |
| AE2-236 | Columbia-Northeast 138 kV | Suspended |
| AE2-262 | Moshannon-Milesburg 230 kV | Engineering & Procurement |
| AE2-263 | Moshannon-Milesburg 230 kV II | Engineering & Procurement |
| 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 |
| AE2-323 | Twin Branch-Guardian 138 kV | Under Construction |
| AE2-325 | Valley 138 kV | Active |
| AE2-343 | Andover (Maysville) 69 kV II | Under Construction |
| AF1-006 | Fairview East 34.5 kV | In Service |
| AF1-064 | Weston 69 kV | Under Construction |
| AF1-084 | Hartford-Almena 69 kV | Engineering & Procurement |
| AF1-086 | Madera-Westover South 115 kV | Under Construction |
| AF1-091 | Varner - Sowers 138 kV | Engineering & Procurement |
| AF1-092 | Huntington Jct. 138 kV | Suspended |
| 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 |
| AF1-120 | East Fayette 2 138 kV | In Service |
| AF1-122 | Cardington-Liberty 69 kV | Suspended |
| AF1-134 | Philipsburg-Madera 34.5 kV | Engineering & Procurement |
| AF1-140 | Claysburg 23 kV | Engineering & Procurement |
| AF1-153 | Motion-Ridgeway 46 kV | Suspended |
| AF1-158 | Edison-Gravel Pit 138 kV | In Service |
| AF1-176 | Corey 138 kV | Active |
| AF1-205 | Napoleon Muni 138 kV | Suspended |
| AF1-206 | East Fayette 138 kV | Engineering & Procurement |
| AF1-215 | Olive-Reynolds 345 kV | In Service |
| AF1-229 | Galion-South Berwick 345 kV | Engineering & Procurement |
| AF1-272 | Lucerne 115 kV | Engineering & Procurement |
| AF1-285 | Gunn Road 345 kV | Under Construction |
| AF1-302 | Brookville-Squab Hollow 138 kV | Engineering & Procurement |
| AF2-004 | Beaver 345 kV | Engineering & Procurement |
| AF2-005 | Beaver 138 kV | Engineering & Procurement |
| AF2-014 | Maddox Creek 345 kV | Engineering & Procurement |
| AF2-039 | Shawville-Clearfield 34.5 kV | Engineering & Procurement |
| AF2-083 | Kenzie Creek-Stone Lake 69 kV | Under Construction |
| AF2-088 | Shawville-Clearfield 34.5 kV II | Engineering & Procurement |
| AF2-095 | Davis Creek 138 kV | Active |
| AF2-103 | Haviland 138 kV | In Service |
| AF2-126 | Weston 69 kV II | Active |
| AF2-130 | Cobalt Corners 34.5 kV | In Service |
| AF2-132 | Reynolds-Olive #1 345 kV | Under Construction |
| AF2-133 | Reynolds-Olive #2 345 kV | Under Construction |
| AF2-134 | Olive-Reynolds #2 345 kV | In Service |
| AF2-150 | Galion 138 kV | Under Construction |
| AF2-205 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AF2-224 | Allen 345 kV | Engineering & Procurement |
| AF2-235 | Titusville-Oil Creek 34.5 kV | Withdrawn |
| AF2-238 | Mansfield-South Troy 34.5 kV | Engineering & Procurement |
| AF2-350 | Kensington 138 kV | Active |
| AF2-359 | Olive-University Park 345 kV | Engineering & Procurement |
| AF2-375 | Ebersole-Fostoria 138 kV | Engineering & Procurement |
| AF2-389 | Kenzie Creek-Stone Lake 69 kV | Withdrawn |
| AF2-396 | Stinger 138 kV | Active |
| AG1-039 | Galion 138 kV II | Under Construction |
| AG1-040 | Morgan Street-Mount Hope 34.5 kV | Engineering & Procurement |
| AG1-054 | Potter-Harlan 69 kV | Engineering & Procurement |
| AG1-100 | Venango-Saegertown 34.5 kV | Engineering & Procurement |
| 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 |
| AG1-232 | Magley 138 kV | Engineering & Procurement |
| AG1-281 | Claysburg-HCR Tap 46 kV | Engineering & Procurement |
| AG1-301 | Miller REC-Warrior Ridge 46 kV | Engineering & Procurement |
| AG1-302 | Olive-Reynolds #1 345 kV | Under Construction |
| AG1-349 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AG1-365 | Allen 345 kV | Engineering & Procurement |
| AG1-366 | Allen 345 kV | Engineering & Procurement |
| AG1-368 | Tillman 138 kV | Engineering & Procurement |
| AG1-369 | Logtown 138 kV | Engineering & Procurement |
| AG1-386 | Smith-Francis Junction 25 kV | In Service |
| AG1-410 | Maddox Creek-RP Mone 345 kV | Active |
| AG1-436 | Olive-University Park 345 kV | Active |
| AG1-447 | Olive-University Park 345 kV | Active |
| AG1-478 | Wilmington 34.5 kV | Engineering & Procurement |
| AG1-500 | Beaver 345 kV | Engineering & Procurement |
| AG1-501 | Beaver 138 kV | Engineering & Procurement |
| AG1-554 | South Kenton 138 kV | Engineering & Procurement |
| AG2-029 | Forest G. Hipple-Collingwood 345 kV | Active |
| AG2-057 | Cardington-Liberty 69 kV II | Active |
| AG2-119 | Galion-Roberts South 138 kV II | Active |
| AG2-149 | Galion-South Berwick 345 kV | Active |
| AG2-165 | Dumont-Greentown 765 kV | Active |
| AG2-212 | Dumont-Greentown 765 kV | Active |
| AG2-230 | Dumont 345 kV | Active |
| AG2-245 | Olive - Reynolds #1 345 kV | Active |
| AG2-328 | Dumont - Greentown 765 kV | Active |
| AG2-329 | S Berwick - Galion 345 kV | Active |
| AG2-330 | Dumont - Greentown 765 kV | Active |
| AG2-400 | Allen 345 kV | Active |
| AG2-453 | Lasalle - Plano 345 kV | Active |
| AG2-515 | Midway 345 kV III | Active |
| AG2-524 | LaSalle Station - Mazon 138 kV | Active |
| AG2-564 | Sulphur Springs 138 kV | Active |
| AG2-585 | Kensington 138kV | Active |
| AH1-060 | Cardington-Liberty 69 kV III | Active |
| AH1-069 | Jerome – Mohicanville 69 kV | Active |
| AH1-070 | Jerome – Mohicanville 69 kV | Active |
| AH1-075 | North Waldo - Wild Creek 138 kV | Active |
| AH1-153 | Dumont 345 kV | Active |
| AH1-272 | Argenta - Twin Branch 345 kV | Active |
| AH1-282 | Galion - Ohio Central 345 kV | Active |
| AH1-302 | Olive - Reynolds 345 kV | Active |
| AH1-308 | Pennville - Adams 138 kV | Active |
| AH1-339 | West Crawford 69 kV | Active |
| AH1-391 | Olive 138 kV | Active |
| AH1-392 | Gravel Pit-Kankakee 138 kV | Active |
| AH1-482 | Olive - Reynolds #2 345 kV | Active |
| AH1-539 | South Kenton 138 kV | Active |
| AH1-567 | University Park 138 kV | Active |
| AH1-690 | Bay Shore - Lallendorf 345 kV | Active |
| AH1-698 | Braidwood 345 kV | Active |
| AH1-702 | Byron 345 kV | Active |
| AH1-711 | Lemoyne 345 kV | Active |
| AH1-714 | Lasalle 345 kV | Active |
| AH1-735 | Richland 138 kV | Active |
| U2-072 | East Lima-Marysville 345kV | In Service |
| V1-011 | Haviland 138kV | In Service |
| W1-056 | Ada-Dunkirk 69kV | In Service |
| X1-042 | Watervliet | In Service |
| X3-005 | Wildwood 12kV | In Service |
| Y3-023 | Country Side 12kV | In Service |
| Z2-116 | Twin Branch 12.47kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, PJM evaluated the potential impacts on tie line facilities between PJM and an affected system entity, which were identified per PJM planning analysis criteria. This upgrade may be required on the affected system portion of the tie line along with cost allocation of such upgrade if applicable, in coordination with the affected system. Depending on the affected system, this project may not be contingent on upgrade based on PJM planning analysis criteria, but may be contingent on this upgrade based on the Affected System Operator's planning criteria, provided in the Affected Systems Study Section, herein.
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
No cost allocated system reinforcements were identified for this project in the Phase I System Impact Study load flow analysis.
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.c
- Title
- Reconductor (possible rebuild) 18.22 miles of 954 ACSR 48/7 transmission line and (3) line drops at Beaver on the Beaver - Carlisle Ckt 1 345 kV
- Description
- Reconductor (possible rebuild) 18.22 miles of 954 ACSR 48/7 transmission line and (3) line drops at Beaver on the Beaver - Carlisle Ckt 1 345 kV using dual (2) 795 26/7 "Drake ACSS
- Total Cost ($USD)
- $109,211,408
- Allocated Cost ($USD)
- $0
- Time Estimate
- 63 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.a
- Title
- Upgrade D120 and D125 disconnect switches at Beaver substation
- Description
- Upgrade D120 and D125 disconnect switches at Beaver substation
- Total Cost ($USD)
- $929,516
- Allocated Cost ($USD)
- $0
- Time Estimate
- 22 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.b
- Title
- Upgrade (1) 3000 SAC 169 line drop at Beaver
- Description
- Upgrade (1) 3000 SAC 169 line drop at Beaver
- Total Cost ($USD)
- $263,169
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.d
- Title
- Upgrade (1) 3500 SAC 127 D120-to-B121 breaker lead at Beaver
- Description
- Upgrade (1) 3500 SAC 127 D120-to-B121 breaker lead at Beaver
- Total Cost ($USD)
- $265,209
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.d
- Title
- Reconductor (possible rebuild) 8.37 miles of 954 ACSR 48/7 transmission line on the Beaver - Lake Avenue Ckt 1 345 kV
- Description
- Reconductor (possible rebuild) 8.37 miles of 954 ACSR 48/7 transmission line on the Beaver - Lake Avenue Ckt 1 345 kV using dual (2) 954 54/7 "Cardinal" ACSS
- Total Cost ($USD)
- $50,053,445
- Allocated Cost ($USD)
- $0
- Time Estimate
- 38 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.b
- Title
- Upgrade (4) 954 ACSR 45/7 overhead line and line drops at Beaver Substation
- Description
- Upgrade (4) 954 ACSR 45/7 overhead line and line drops at Beaver Substation
- Total Cost ($USD)
- $809,465
- Allocated Cost ($USD)
- $0
- Time Estimate
- 15 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005c
- Title
- Upgrade 3500 SAC 127 B161 (2) breaker leads and (1) B121-to-D120 breaker lead at Beaver
- Description
- Upgrade 3500 SAC 127 B161 (2) breaker leads and (1) B121-to-D120 breaker lead at Beaver
- Total Cost ($USD)
- $191,109
- Allocated Cost ($USD)
- $0
- Time Estimate
- 11 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.a
- Title
- Upgrade (3) disconnect switches at Beaver (D:120,166,165)
- Description
- Upgrade (3) disconnect switches at Beaver (D:120,166,165)
- Total Cost ($USD)
- $1,350,788
- Allocated Cost ($USD)
- $0
- Time Estimate
- 37 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.h
- Title
- Upgrade (9) disconnect switches at Beaver and Lake Ave (D: 19,20,21,22, 212,215,217,218,220)
- Description
- Upgrade (9) disconnect switches at Beaver and Lake Ave (D: 19,20,21,22, 212,215,217,218,220)
- Total Cost ($USD)
- $3,850,794
- Allocated Cost ($USD)
- $0
- Time Estimate
- 39 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.c
- Title
- Upgrade the (3) B216, B219 and B4 1500 CTs
- Description
- Upgrade the (3) B216, B219 and B4 1500 CTs
- Total Cost ($USD)
- $853,850
- Allocated Cost ($USD)
- $0
- Time Estimate
- 16 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement: n9227.0
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- n9227.0 / TC1-ATSI-001.b
- Title
- Upgrade T-line drops, overhead substation conductor and TL reconductor
- Description
- Reconductor (possible rebuild) of 8.12 miles of dual transmission line and (2) single conductor line drops at Beaver on the Beaver-Lake Ave Ckt 2 345 kV line using triple (3) 1113 54/19 ""Finch"" ACSS"
- Total Cost ($USD)
- $48,873,856
- Allocated Cost ($USD)
- $0
- Time Estimate
- 37 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.b
- Title
- Upgrade 1590 AAC B3, B4, B216 and B219 breaker leads at Beaver and Lake Ave
- Description
- Upgrade 1590 AAC B3, B4, B216 and B219 breaker leads at Beaver and Lake Ave
- Total Cost ($USD)
- $305,540
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.f
- Title
- Upgrade the (1) B216 relay thermal at Beaver
- Description
- Upgrade the (1) B216 relay thermal at Beaver
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $0
- Time Estimate
- 18 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.l
- Title
- Upgrade the (2) B216 SEL411L impedance relays at Lake Ave
- Description
- Upgrade the (2) B216 SEL411L impedance relays at Lake Ave
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $0
- Time Estimate
- 18 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.a
- Title
- Upgrade (4) circuit breakers at Beaver and Lake Ave (B:3,4,216,219)
- Description
- Upgrade (4) circuit breakers at Beaver and Lake Ave (B:3,4,216,219)
- Total Cost ($USD)
- $7,786,809
- Allocated Cost ($USD)
- $0
- Time Estimate
- 56 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.m
- Title
- Upgrade (8) 5.00 SPS.AL PIPE SCCIR at Beaver
- Description
- Upgrade (8) 5.00 SPS.AL PIPE SCCIR at Beaver
- Total Cost ($USD)
- $250,039
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.d
- Title
- Upgrade (3) 1590 line drops at Beaver and Lake Ave
- Description
- Upgrade (3) 1590 line drops at Beaver and Lake Ave
- Total Cost ($USD)
- $690,685
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.j
- Title
- Upgrade (2) 2.50 SPS.AL PIPE SCCIR at Beaver
- Description
- Upgrade (2) 2.50 SPS.AL PIPE SCCIR at Beaver
- Total Cost ($USD)
- $173,391
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.g
- Title
- Upgrade (1) 4.00 SPS.AL PIPE at Beaver
- Description
- Upgrade (1) 4.00 SPS.AL PIPE at Beaver
- Total Cost ($USD)
- $178,089
- Allocated Cost ($USD)
- $0
- Time Estimate
- 12 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.k
- Title
- Upgrade the (15) B216, B219, B3 and B4 2000 CTs at Beaver and Lake Ave
- Description
- Upgrade the (15) B216, B219, B3 and B4 2000 CTs at Beaver and Lake Ave
- Total Cost ($USD)
- $2,701,212
- Allocated Cost ($USD)
- $0
- Time Estimate
- 17 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.i
- Title
- Upgrade the (2) B3 SEL411L impedance relays at Lake Ave
- Description
- Upgrade the (2) B3 SEL411L impedance relays at Lake Ave
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $0
- Time Estimate
- 18 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.e
- Title
- Upgrade the (1) B219 1200 CT to PVD at Beaver
- Description
- Upgrade the (1) B219 1200 CT to PVD at Beaver
- Total Cost ($USD)
- $349,952
- Allocated Cost ($USD)
- $0
- Time Estimate
- 16 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-109 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) AG2-109 could receive cost allocation. Although AG2-109 may not presently have cost responsibility for this upgrade, AG2-109 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
Attachments
AG2-109 One Line Diagram
