AG2-149 Phase I Study Report
v1.00 released 2025-10-29 21:43
Galion-South Berwick 345 kV
52.0 MW Capacity / 314.0 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 Wombat Solar LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is American Electric Power.
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 Storage facility located in the American Electric Power zone — Crawford County, Ohio. This project is an increase to the developer’s AG2-148 project(s), which will share the same Point of Interconnection. The AG2-149 project is a 314.0 MW uprate (52.0 MW Capacity uprate) to the previous project(s). The total installed facilities will have a capability of 400.0 MW with 52.0 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
AG2-149 will interconnect on the American Electric Power transmission system by tapping the South Berwick-Galion 345 kV Line.
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 AG2-149 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 AG2-149 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $0 | $0 | |
| Other Scope | $0 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $10,908,000 | $10,908,000 | |
| Network Upgrades | $6,931,000 | $6,931,000 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $79,781,179 | $79,781,179 | |
| 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 | $97,620,179 | $97,620,179 | |
* 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 AG2-149
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 AG2-149 Project due at DP1 |
| A | B | A - B | |
| AG2-149 | $9,762,018 | $1,600,000 | $8,162,018 |
Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
| Stand-Alone Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | AEP will construct a new breaker and a half station, initially populated with 3 breakers and operated as a ring bus | $32,724,000 | $10,908,000 (See Note 1) |
| Network Upgrades | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | AEP will construct a new circuit breaker and line exit for the new generator | $6,931,000 | $6,931,000 |
Based on the scope of work for the Interconnection Facilities, it is expected to take a range of 30 to 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.
Note 1: A Common Use Upgrade is a Network Upgrade that is needed for the interconnection of Generating Facilities or Merchant Transmission Facilities of more than one Project Developer or Eligible Customer and which is the shared responsibility of each Project Developer or Eligible Customer. If multiple Project Developers request to connect to the same interconnection substation, the Transmission Owner will determine the cost to accommodate all the requests at the substation. The cost for the interconnection will be allocated in proportion to the number of required terminations into the substation.
Remote end work required:
Please note that your project interconnects directly to an AEP facility which shares a tie line with ATSI. The Transmission Owner Scope of Work above outlines the interconnection facilities required on the AEP facilities. Your project will also require upgrades at the remote end ATSI facility. The scope, cost and schedule of work required on the ATSI facilities will be provided in the PJM Phase II SIS report.
Transmission Owner Analysis
No Transmission Owner impacts identified.
Developer Requirements
The developer is responsible for all design and construction related activities on the developer’s side of the Point of Change in Ownership. AEP interconnection requirements can be found here.
To the extent that these Applicable Technical Requirements and Standards may conflict with the terms and conditions of the Tariff, the Tariff shall control.
Revenue Metering and SCADA Requirements
PJM 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 AG2-149 was evaluated as a 314.0 MW (52.0 MW Capacity) injection in the AEP area.
AG2-149 was evaluated as part of a plant. The plant consists of AG2-149, AG2-148, AG2-329. The total Energy output of the plant was evaluated at its maximum seasonal capability of 400.0 MW (444.8 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 | 01KAMMER-01 502 J 500.0 kV Ckt 1 line | AP_P1-2_MP-500-007A_SRT-A | Single | AC | 130.62 % | 3729.0 | B | 4870.98 | 6.27 | |
| GD2 | AP | 01KAMMER-01 502 J 500.0 kV Ckt 1 line | AP_P2-3_MP-500-012_SRT-A | Breaker | AC | 130.23 % | 3729.0 | B | 4856.26 | 35.35 | |
| GD2 | AP | 01KAMMER-01 502 J 500.0 kV Ckt 1 line | AP_P1-2_MP-500-008A_SRT-SL | Single | AC | 124.1 % | 3729.0 | B | 4627.6 | 6.07 | |
| GD2 | ATSI | 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-008B_SRT-SL | Breaker | AC | 168.3 % | 1683.0 | B | 2832.52 | 24.16 | |
| GD2 | ATSI | 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-013_SRT-SL | Breaker | AC | 146.58 % | 1683.0 | B | 2466.99 | 24.89 | |
| GD2 | ATSI | 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-014_SRT-A | Breaker | AC | 146.58 % | 1683.0 | B | 2466.97 | 24.89 | |
| GD2 | ATSI | 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-009_SRT-A | Breaker | AC | 146.4 % | 1683.0 | B | 2463.99 | 24.84 | |
| GD2 | ATSI | 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P1-2_TE-345-602_SRT-A | Single | AC | 142.52 % | 1683.0 | B | 2398.59 | 4.69 | |
| 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 | 22.55 | |
| 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 | 19.93 | |
| 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 | 19.36 | |
| 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 | 19.99 | |
| 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 | 28.27 | |
| 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 | 20.04 | |
| 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 | 20.09 | |
| GD2 | ATSI | 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-005_SRT-A | Breaker | AC | 149.08 % | 1892.0 | B | 2820.59 | 22.39 | |
| GD2 | ATSI | 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-006_SRT-SL | Breaker | AC | 146.41 % | 1892.0 | B | 2770.12 | 22.6 | |
| GD2 | ATSI | 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-010A_SRT-SL | Breaker | AC | 144.5 % | 1892.0 | B | 2733.88 | 22.53 | |
| GD2 | ATSI | 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-825_SRT-A | Single | AC | 136.86 % | 1892.0 | B | 2589.31 | 4.25 | |
| GD2 | ATSI | 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-824_SRT-A | Single | AC | 136.39 % | 1892.0 | B | 2580.58 | 4.26 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-F1_SRT-A | Breaker | AC | 155.03 % | 1646.0 | B | 2551.84 | 22.2 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-12_SRT-A | Breaker | AC | 155.03 % | 1646.0 | B | 2551.84 | 22.2 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-010B2_SRT-SL | Breaker | AC | 153.46 % | 1646.0 | B | 2525.94 | 21.87 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-010B1_SRT-SL | Breaker | AC | 153.46 % | 1646.0 | B | 2525.94 | 21.87 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-3_SRT-A | Breaker | AC | 151.55 % | 1646.0 | B | 2494.57 | 22.42 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-810_SRT-A | Single | AC | 136.64 % | 1646.0 | B | 2249.01 | 4.13 | |
| GD2 | ATSI | 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-809_SRT-A | Single | AC | 128.94 % | 1646.0 | B | 2122.34 | 4.19 | |
| GD2 | ATSI | 02DUALR+-02ROBERT 138.0 kV Ckt 1 line | AEP_P4_#8396_05OHIOCT 345_M_SRT-A | Breaker | AC | 108.55 % | 209.0 | B | 226.88 | 17.55 | |
| GD2 | ATSI | 02DUALR+-02ROBERT 138.0 kV Ckt 1 line | AEP_P4_#16815_05OHIOCT 345_M2_SRT-A | Breaker | AC | 108.52 % | 209.0 | B | 226.81 | 17.55 | |
| GD2 | ATSI | 02DUALR+-02ROBERT 138.0 kV Ckt 1 line | ATSI_P2-3_OES-138-020_SRT-SL | Breaker | AC | 105.07 % | 209.0 | B | 219.59 | 15.88 | |
| GD2 | ATSI | 02GALION-02GALION 345.0/138.0 kV Ckt 3 transformer | ATSI_P2-3_OES-138-021_SRT-SL | Breaker | AC | 103.25 % | 417.0 | B | 430.54 | 46.11 | |
| GD2 | ATSI | 02GALION-02GALION 345.0/138.0 kV Ckt 4 transformer | ATSI_P2-3_OES-138-018_SRT-SL | Breaker | AC | 104.79 % | 411.0 | B | 430.69 | 46.12 | |
| GD2 | ATSI | 02HAYES-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-005_SRT-A | Breaker | AC | 146.75 % | 1878.0 | B | 2755.89 | 24.03 | |
| GD2 | ATSI | 02HAYES-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-006_SRT-SL | Breaker | AC | 144.08 % | 1878.0 | B | 2705.74 | 24.54 | |
| GD2 | ATSI | 02HAYES-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-010A_SRT-SL | Breaker | AC | 142.21 % | 1878.0 | B | 2670.76 | 24.18 | |
| GD2 | ATSI | 02HAYES-02BEAVER 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-825_SRT-A | Single | AC | 136.05 % | 1878.0 | B | 2554.95 | 4.56 | |
| GD2 | ATSI | 02HAYES-02BEAVER 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-824_SRT-A | Single | AC | 135.68 % | 1878.0 | B | 2548.09 | 4.57 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-007_SRT-SL | Breaker | AC | 137.87 % | 1878.0 | B | 2589.19 | 26.04 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-004_SRT-A | Breaker | AC | 118.2 % | 1878.0 | B | 2219.8 | 26.74 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-005_SRT-SL | Breaker | AC | 118.2 % | 1878.0 | B | 2219.73 | 26.74 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-006_SRT-SL | Breaker | AC | 118.2 % | 1878.0 | B | 2219.73 | 26.74 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P1-2_TE-345-601_SRT-A | Single | AC | 113.99 % | 1878.0 | B | 2140.73 | 5.05 | |
| GD2 | ATSI | 02LEMOYN-02DAV-BE 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-021_SRT-A-1 | Tower | AC | 109.02 % | 1878.0 | B | 2047.43 | 24.66 | |
| GD2 | AEP | 05E LIMA-05SW LIM 345.0 kV Ckt 1 line | AEP_P4_#6497_05MARYSV 345_J2_SRT-A | Breaker | AC | 112.9 % | 971.0 | B | 1096.25 | 17.43 | |
| GD2 | AEP | 05E LIMA-05SW LIM 345.0 kV Ckt 1 line | AEP_P4_#17564_05BOKESCRK 345_CB2_SRT-A | Breaker | AC | 105.18 % | 971.0 | B | 1021.28 | 17.52 | |
| GD2 | AEP | 05E LIMA-05SW LIM 345.0 kV Ckt 1 line | AEP_P4_#16659_05GUNN RD SW 345_M2_SRT-A | Breaker | AC | 104.18 % | 971.0 | B | 1011.61 | 17.54 | |
| GD2 | AEP | 05E LIMA-05SW LIM 345.0 kV Ckt 1 line | AEP_P2-2_#16655_05GUNN RD SW 345_2_SRT-A | Bus | AC | 104.17 % | 971.0 | B | 1011.54 | 17.54 | |
| GD2 | AEP/AP | 05KAMMER-01KAMMER 765.0/500.0 kV Ckt 1 transformer | AP_P1-2_MP-500-007A_SRT-A | Single | AC | 131.92 % | 3792.0 | B | 5002.28 | 6.27 | |
| GD2 | AEP/AP | 05KAMMER-01KAMMER 765.0/500.0 kV Ckt 1 transformer | AP_P2-3_MP-500-012_SRT-A | Breaker | AC | 131.49 % | 3792.0 | B | 4985.98 | 35.35 | |
| GD2 | AEP/AP | 05KAMMER-01KAMMER 765.0/500.0 kV Ckt 1 transformer | AP_P1-2_MP-500-008A_SRT-SL | Single | AC | 125.38 % | 3792.0 | B | 4754.33 | 6.07 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-009_SRT-SL | Breaker | AC | 165.39 % | 1499.0 | B | 2479.15 | 22.46 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-F1_SRT-A | Breaker | AC | 145.45 % | 1798.0 | B | 2615.26 | 22.13 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-12_SRT-A | Breaker | AC | 145.45 % | 1798.0 | B | 2615.26 | 22.13 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_OEC-345-1152-3_SRT-A | Breaker | AC | 142.16 % | 1798.0 | B | 2556.01 | 22.36 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P2-3_TE-345-010B1_SRT-SL | Breaker | AC | 141.11 % | 1798.0 | B | 2537.18 | 21.81 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-810_SRT-A | Single | AC | 123.08 % | 1798.0 | B | 2212.91 | 4.12 | |
| GD2 | ATSI | AC2-103 TAP-02BEAVER 345.0 kV Ckt 1 line | ATSI_P1-2_OEC-345-809_SRT-A | Single | AC | 117.76 % | 1798.0 | B | 2117.36 | 4.18 | |
| GD2 | AEP/ATSI | AG2-148 TP-02GALION 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-027A_SRT-A | Tower | AC | 106.19 % | 1308.0 | B | 1388.99 | 144.61 | |
| GD2 | AEP/ATSI | AG2-148 TP-02GALION 345.0 kV Ckt 1 line | ATSI_P7-1_TE-345-030_SRT-A | Tower | AC | 105.3 % | 1308.0 | B | 1377.33 | 144.5 | |
| GD2 | ATSI | AH1-690 TP-02BAY SH 345.0 kV Ckt 2 line | ATSI_P1-2_TE-345-606_SRT-A-1 | Single | AC | 102.39 % | 1774.0 | B | 1816.36 | 2.97 | |
| GD2 | ATSI | AH1-690 TP-02BAY SH 345.0 kV Ckt 2 line | ATSI_P2-3_TE-345-002_SRT-SL | Breaker | AC | 101.27 % | 1720.0 | B | 1741.77 | 15.37 |
Winter Peak Analysis
The New Service Request AG2-149 was evaluated as a 314.0 MW (52.0 MW Capacity) injection in the AEP area.
AG2-149 was evaluated as part of a plant. The plant consists of AG2-149, AG2-148, AG2-329. The total Energy output of the plant was evaluated at its maximum seasonal capability of 400.0 MW (556.0 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 AG2-149 was evaluated as a 314.0 MW injection
AG2-149 was evaluated as part of a plant. The plant consists of AG2-149, AG2-148, AG2-329. The total Energy output of the plant was evaluated at its maximum seasonal capability of 400.0 MW (542.29 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 |
| AA1-018 | Powerton-Goodings Grove | In Service |
| AA1-095 | Halfway-Marlowe 34.5kV | In Service |
| AA2-184 | Atlantic-Red Bank 34kV | In Service |
| AB1-001 | Absecon 12 kV | In Service |
| AB1-006 | Meadow Lake 345kV | 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 |
| AB1-138 | 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 |
| AB2-029 | Remington 34.5kV | In Service |
| AB2-032 | Church-Wye Mills 138 kV | In Service |
| AB2-037 | Keeney-Steele 230kV | Under Construction |
| AB2-049 | Gloucester Township 12kV | In Service |
| AB2-067 | Kammer-Vassell 765kV | In Service |
| AB2-070 | Mt. Pulaski-Brokaw | In Service |
| AB2-093 | Ormet 138kV | 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 |
| AB2-157 | Prince George's County 12kV | In Service |
| AB2-158 | Louisa-South Anna 230kV | In Service |
| AB2-170 | East Lima-Marysville 345kV | In Service |
| AB2-179 | Townsend 138kV | In Service |
| AC1-001 | Delano 138kV | In Service |
| AC1-010 | Gloucester 26kV | Under Construction |
| AC1-017 | Levittown 13 kV | In Service |
| AC1-030 | Cinnaminson 13kV | In Service |
| AC1-033 | Kewanee 138 kV | In Service |
| AC1-044 | Kammer-Vassell 765kV | In Service |
| AC1-053 | Lanesville-Brokaw | Partially in Service - Under Construction |
| AC1-068 | Atlanta 69kV I | In Service |
| AC1-069 | Atlanta 69kV II | In Service |
| AC1-076 | Locust Grove-Paytes 115kV | In Service |
| AC1-078 | Beatty-London 138kV | In Service |
| AC1-082 | Ravenswood-Hemlock 69kV | Under Construction |
| AC1-085 | Stuart-Clinton 345kV | In Service |
| AC1-089 | Hillsboro-Wildcat 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 |
| AC1-111 | Aurora 138kV | In Service |
| AC1-120 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-121 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-158 | Spotsylvania 500kV | In Service |
| AC1-165 | Atlanta 69kV III | In Service |
| AC1-166 | Atlanta 69kV IV | In Service |
| AC1-167 | Mark Center 69kV | Under Construction |
| AC1-168 | Kewanee-Streator | Suspended |
| AC1-174 | Losantville 345kV | In Service |
| AC1-175 | Losantville 345kV | In Service |
| AC1-188 | Rio-Lick 138kV | Engineering & Procurement |
| AC1-194 | Elk 138kV | Active |
| AC1-214 | Crescent Ridge | In Service |
| AC2-015 | Chatfield-Howard 138kV | Partially in Service - Under Construction |
| AC2-023 | Hebron 69kV | Engineering & Procurement |
| AC2-029 | Circleville 138kV | Suspended |
| AC2-044 | Maddox Creek 345kV | Suspended |
| AC2-059 | Biers Run-Circleville 138kV | In Service |
| AC2-060 | Buckskin 69kV | In Service |
| AC2-061 | Hillsboro-Clinton 138kV | In Service |
| AC2-067 | Camden-Crystal I 69kV | Engineering & Procurement |
| AC2-068 | Camden-Crystal II 69kV | Engineering & Procurement |
| AC2-088 | S. Bethel-Brown 69kV | In Service |
| AC2-090 | Losantville 345kV | In Service |
| AC2-103 | Beaver-Davis Besse 345 kV I | Engineering & Procurement |
| AC2-111 | College Corner 138kV | Engineering & Procurement |
| AC2-120 | Ripley 69kV | In Service |
| AC2-136 | East Hagerstown 12kV | Under Construction |
| AC2-154 | Davis Creek 138kV | Engineering & Procurement |
| AC2-168 | Clinton 23kV | In Service |
| AC2-176 | Jay 138 kV | In Service |
| 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 |
| AD1-013 | Twombly Road 138kV | Engineering & Procurement |
| AD1-020 | Hunterstown-Lincoln 115 kV | In Service |
| AD1-060 | Mercersburg-Milnor 34.5 kV | In Service |
| AD1-061 | McConnelsburg-Mercersburg 34 kV | In Service |
| 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 |
| AD1-115 | Mountain Run-Mitchell 115 kV | Engineering & Procurement |
| AD1-119 | Payne 69 kV | In Service |
| AD1-128 | Modoc-Delaware 138 kV | Partially in Service - Under Construction |
| AD1-130 | Hardin Switch 345 kV | In Service |
| AD1-136 | South Bethel-Brown 69 kV | In Service |
| AD1-140 | Greene-Clark 138 kV | Engineering & Procurement |
| AD1-155 | Meadow Brook-Strasburg 138 kV | In Service |
| AD2-009 | McConnellsburg 138 kV | In Service |
| AD2-016 | Biers Run-Circleville 138 kV | In Service |
| AD2-020 | Valley 138 kV | Engineering & Procurement |
| AD2-027 | Camden Switch 26 kV | In Service |
| AD2-031 | Martinsville-Wilmington 69 kV | In Service |
| AD2-038 | Powerton-Nevada 345 kV | Under Construction |
| AD2-042 | Camden Switch 26 kV II | In Service |
| AD2-047 | Davis Creek 138 kV | Suspended |
| AD2-058 | St. Barnabas 13 kV | In Service |
| AD2-060 | Davis Creek 138kV | Engineering & Procurement |
| AD2-065 | Atco 12 kV | In Service |
| AD2-066 | Mazon-Crescent Ridge 138 kV | Engineering & Procurement |
| AD2-067 | Centerburg 138kV | Engineering & Procurement |
| AD2-070 | Gilbert-Morris Park 34.5kV | In Service |
| AD2-071 | Strawton-Deer Creek 138 kV | Suspended |
| AD2-079 | Capitol Ave 34.5kV | In Service |
| AD2-086 | Hardin Switch 345 kV | In Service |
| AD2-091 | Hardin Tap 345kV | Suspended |
| AD2-092 | Marysville 345kV | Under Construction |
| AD2-093 | Marysville 345kV | Under Construction |
| AD2-096 | Marysville 345kV | Suspended |
| AD2-115 | Lyons-Moselem 69kV | In Service |
| AD2-116 | Hokes-Grantley 69 kV | In Service |
| AD2-133 | Eagle Valley 115kV | In Service |
| AD2-134 | Shady Oaks | Partially in Service - Under Construction |
| AD2-135 | Williamstown 12kV | Partially in Service - Under Construction |
| AD2-163 | Broadview-Tangy 138 kV | In Service |
| AD2-172 | Lena 138kV | In Service |
| AD2-180 | Elk Garden-Parr Run 138kV | In Service |
| AE1-040 | Greenfield 69 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 |
| AE1-091 | West Newton-Lynn 138 kV | Suspended |
| AE1-092 | Blue Jacket-Kirby 138 kV | Active |
| AE1-101 | McConnellsburg-Texas Eastern 138 kV | In Service |
| AE1-102 | Maddox Creek 345 kV | Suspended |
| AE1-109 | Frenchs Mill 34 kV | In Service |
| AE1-113 | Mole Creek 345 kV | Engineering & Procurement |
| AE1-114 | Maryland-Lancaster 138 kV | Active |
| 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 |
| AE1-163 | Powerton-Nevada 345 kV | Engineering & Procurement |
| AE1-166 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE1-170 | Kenzie Creek-Colby 138 kV | Suspended |
| AE1-172 | Loretto-Wilton Center | Active |
| 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 |
| AE1-205 | McLean 345 kV | Engineering & Procurement |
| AE1-207 | Mississinewa-Gaston 138 kV | Suspended |
| AE1-208 | Delaware-Van Buren 138 kV | Suspended |
| AE1-209 | Desoto 345 kV | Suspended |
| AE1-210 | Desoto 345 kV | Suspended |
| AE1-227 | South Cumberland 69 kV | Suspended |
| AE1-229 | Deepwater-Upper Pittsgrove 138 kV | Suspended |
| AE1-237 | Andover (Maysville) 69kV I | Under Construction |
| AE1-245 | Haviland 138 kV | Under Construction |
| AE2-035 | Lena 138 kV | In Service |
| AE2-045 | Olive-Reynolds 345 kV | Engineering & Procurement |
| AE2-048 | Muskingum-W. Millersport 345 kV | Engineering & Procurement |
| AE2-054 | Warfordsburg 34 kV | In Service |
| 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 |
| AE2-136 | Muskingum River-W. Millersport 345 kV | Engineering & Procurement |
| AE2-139 | East Towanda-Grover 230 kV | Engineering & Procurement |
| AE2-148 | Beatty-Greene 345 kV | In Service |
| AE2-152 | Loretto-Wilton 345 kV & Braidwood-Davis Creek 345 kV | Engineering & Procurement |
| AE2-169 | Delaware-Van Buren 138 kV | Suspended |
| AE2-172 | Mississinewa-Gaston 138 kV | Suspended |
| AE2-173 | McLean 345 kV | Active |
| 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 |
| AE2-214 | Cole 345 kV | Engineering & Procurement |
| AE2-216 | Hardin Switch 345 kV | Engineering & Procurement |
| AE2-217 | East Springfield-London 138 kV | Engineering & Procurement |
| AE2-219 | Bluff Point-Randolph 138 kV | Suspended |
| AE2-220 | Losantville 345 kV | Engineering & Procurement |
| AE2-221 | Clinton-Stuart 345 kV | Under Construction |
| AE2-223 | McLean 345 kV | Active |
| AE2-224 | Bear Rock-Johnstown 230 kV | In Service |
| AE2-226 | Millville-Old Chapel 138 kV | Engineering & Procurement |
| AE2-230 | Bartonsville-Meadow Brook 138 kV | In Service |
| AE2-234 | Liberty Center-Buckeye Tap 69 kV | Engineering & Procurement |
| AE2-236 | Columbia-Northeast 138 kV | Suspended |
| AE2-255 | Molecreek 345 kV | Engineering & Procurement |
| AE2-262 | Moshannon-Milesburg 230 kV | Engineering & Procurement |
| AE2-263 | Moshannon-Milesburg 230 kV II | Engineering & Procurement |
| AE2-267 | Woodsdale 345 kV | Engineering & Procurement |
| AE2-281 | Powerton-Nevada 345 kV | Engineering & Procurement |
| AE2-282 | East Fayette 138 kV | In Service |
| AE2-285 | Maysville 69 kV | Engineering & Procurement |
| AE2-297 | Madison-Tanners Creek 138 kV | In Service |
| AE2-298 | Cavett Switch - West Van Wert 69 kV | Engineering & Procurement |
| AE2-305 | Givens-Mechanicsburg 138 kV | Engineering & Procurement |
| AE2-306 | Gunn Road 345 kV | Under Construction |
| AE2-309 | Carlos Junction-Lonaconing 34.5 kV | In Service |
| AE2-315 | Yankee Tap 69 kV | In Service |
| AE2-318 | Ford-Cedarville 138 kV | Suspended |
| AE2-321 | Belvidere-Marengo 138 kV | Active |
| AE2-322 | Mark Center 69 kV | Under Construction |
| AE2-323 | Twin Branch-Guardian 138 kV | Under Construction |
| AE2-325 | Valley 138 kV | Active |
| AE2-341 | Sandwich-Plano 138 kV | Active |
| AE2-342 | Woodstock 69 kV | Engineering & Procurement |
| AE2-343 | Andover (Maysville) 69 kV II | Under Construction |
| AF1-006 | Fairview East 34.5 kV | In Service |
| AF1-007 | Indian River 230 kV I | Suspended |
| AF1-022 | Lake Lynn-Uniontown 25 kV | In Service |
| AF1-030 | Sandwich-Plano 138 kV | Active |
| AF1-045 | Cedarville-Ford 138 kV | Suspended |
| AF1-053 | Givens-Mechanicsburg 138 kV | Engineering & Procurement |
| AF1-054 | Givens-Mechanicsburg 138 kV | Engineering & Procurement |
| AF1-062 | Jug Street 138 kV | Engineering & Procurement |
| AF1-064 | Weston 69 kV | Under Construction |
| AF1-078 | East Sidney-Quincy 138 kV | In Service |
| AF1-084 | Hartford-Almena 69 kV | Engineering & Procurement |
| AF1-086 | Madera-Westover South 115 kV | Under Construction |
| AF1-088 | Sullivan 345 kV | Active |
| 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 |
| AF1-118 | Sorenson-Desoto 345 kV | Engineering & Procurement |
| AF1-119 | Keystone-Desoto 345 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 |
| AF1-136 | Warfordsburg-Purcell Junction 34.5 kV | Engineering & Procurement |
| AF1-140 | Claysburg 23 kV | Engineering & Procurement |
| AF1-147 | Poland Rd-Runway DP 230kV | Under Construction |
| AF1-153 | Motion-Ridgeway 46 kV | Suspended |
| AF1-158 | Edison-Gravel Pit 138 kV | In Service |
| AF1-176 | Corey 138 kV | Active |
| AF1-202 | Keystone-Desoto 345 kV | Under Construction |
| AF1-205 | Napoleon Muni 138 kV | Suspended |
| AF1-206 | East Fayette 138 kV | Engineering & Procurement |
| AF1-207 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF1-215 | Olive-Reynolds 345 kV | In Service |
| AF1-223 | Keystone-Desoto 345 kV | Under Construction |
| AF1-227 | Marysville – Gunn Road 345 kV | In Service |
| AF1-228 | Beatty-Greene 345 kV | Engineering & Procurement |
| AF1-229 | Galion-South Berwick 345 kV | Engineering & Procurement |
| AF1-233 | Flemingsburg – Spurlock 138kV | Active |
| AF1-249 | Nickel 12.47 kV | In Service |
| AF1-254 | Milnor-Huyetts 34.5 kV | Under Construction |
| AF1-262 | Upper Pittsgrove 12 kV | In Service |
| AF1-264 | Runnemede 13 kV | In Service |
| AF1-268 | Desoto-Jay 138 kV | Engineering & Procurement |
| AF1-272 | Lucerne 115 kV | Engineering & Procurement |
| AF1-275 | Cole 345 kV | Engineering & Procurement |
| AF1-282 | Stuart-Clinton 345 kV | Engineering & Procurement |
| AF1-283 | Stuart-Clinton 345 kV | Engineering & Procurement |
| AF1-285 | Gunn Road 345 kV | Under Construction |
| AF1-290 | Feagans Mill-Millville 138 kV | In Service |
| AF1-291A | Bartonsville-Meadow Brook 138 kV | In Service |
| AF1-296 | Garden Plain 138 kV | Active |
| 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 |
| AF1-322 | Meadow Lake 345 kV | Engineering & Procurement |
| AF1-331 | Twombley Road | 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 |
| AF2-041 | Nelson-Electric Junction 345 kV | Active |
| AF2-048 | Rio-Lick 138 kV | Engineering & Procurement |
| AF2-068 | Jay 138 kV | Active |
| AF2-069 | Crescent Ridge 138 kV | Active |
| AF2-075 | Bartonsville-Meadow Brook 138 kV III | In Service |
| AF2-078 | Reynolds-Olive #1 345 kV | Engineering & Procurement |
| AF2-083 | Kenzie Creek-Stone Lake 69 kV | Under Construction |
| AF2-088 | Shawville-Clearfield 34.5 kV II | Engineering & Procurement |
| AF2-095 | Davis Creek 138 kV | Active |
| AF2-103 | Haviland 138 kV | In Service |
| AF2-111 | North Clark-Spurlock 345 kV | Active |
| AF2-122 | Kirk 138 kV | Under Construction |
| 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 |
| AF2-138 | Flanders-West Wharton 34.5 kV | In Service |
| AF2-139 | Gilbert-Warren Glen 34.5 kV | In Service |
| AF2-142 | Nevada 345 kV | Active |
| AF2-143 | Powerton-Nevada 345 kV | Active |
| AF2-149 | Sharp Road 69 kV | Engineering & Procurement |
| AF2-150 | Galion 138 kV | Under Construction |
| AF2-162 | Keystone-Desoto 345 kV | Engineering & Procurement |
| AF2-173 | Desoto 345 kV | Active |
| AF2-177 | Sorenson-DeSoto #2 345 kV | Active |
| AF2-187 | Brookside-Cloverdale 138 kV | Engineering & Procurement |
| AF2-192 | Frenchtown Solar-West Flemington 34.5 kV | Suspended |
| AF2-199 | Nelson-Electric Junction 345 kV | Active |
| AF2-200 | Nelson-Electric Junction 345 kV | Active |
| AF2-205 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AF2-224 | Allen 345 kV | Engineering & Procurement |
| AF2-225 | McLean 345 kV | Active |
| AF2-229 | Roxbury 23 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 |
| AF2-252 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-291 | Sporn South-Leon 138 kV | Engineering & Procurement |
| AF2-298 | Crown-New Lebanon 69 kV | Engineering & Procurement |
| AF2-325 | Jacktown 12 kV | Engineering & Procurement |
| AF2-335 | Delaware-Royerton 138 kV | Active |
| AF2-350 | Kensington 138 kV | Active |
| AF2-352 | Blue Mound 345 kV | Engineering & Procurement |
| AF2-354 | Washington 34.5 kV II | Engineering & Procurement |
| AF2-356 | Albright-Mt. Zion 138 kV | Under Construction |
| AF2-359 | Olive-University Park 345 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 |
| AF2-388 | Keystone-Desoto 345 kV | Active |
| AF2-389 | Kenzie Creek-Stone Lake 69 kV | Withdrawn |
| AF2-392 | Nelson-Dixon 138 kV | Active |
| AF2-396 | Stinger 138 kV | Active |
| AG1-017 | Jay 138 kV | Under Construction |
| AG1-024 | Centerburg 138 kV | Engineering & Procurement |
| AG1-034 | Centerburg 138 kV | Engineering & Procurement |
| AG1-039 | Galion 138 kV II | Under Construction |
| AG1-040 | Morgan Street-Mount Hope 34.5 kV | Engineering & Procurement |
| AG1-047 | Jay 138 kV | Engineering & Procurement |
| AG1-054 | Potter-Harlan 69 kV | Engineering & Procurement |
| AG1-100 | Venango-Saegertown 34.5 kV | Engineering & Procurement |
| AG1-107 | Hillsboro-Middleboro 138 kV | Engineering & Procurement |
| AG1-118 | Sugar Grove-Waterman 138kV | Active |
| AG1-125 | Marysville-Flatlick 765 kV | Engineering & Procurement |
| AG1-126 | Marysville-Flatlick 765 kV | Engineering & Procurement |
| AG1-127 | Crego Rd 138 kV | Active |
| 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 |
| AG1-226 | Dequine-Eugene 345 kV | Active |
| AG1-232 | Magley 138 kV | Engineering & Procurement |
| AG1-236 | Lanesville-Brokaw 345 kV | Active |
| AG1-237 | Dequine-Eugene 345 kV | Engineering & Procurement |
| AG1-254 | Salem-Woodstown 69 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 |
| AG1-323 | Blue Jacket 138 kV | Active |
| AG1-324 | Jay-Desoto 138 kV | Engineering & Procurement |
| AG1-348 | Pequest River-Washington 34.5 kV | In Service |
| AG1-349 | Olive-Reynolds #2 345 kV | Engineering & Procurement |
| AG1-351 | Harrison-Good Hope 138 kV | Engineering & Procurement |
| AG1-363 | Black Oak-Hatfield 500 kV | Engineering & Procurement |
| AG1-365 | Allen 345 kV | Engineering & Procurement |
| AG1-366 | Allen 345 kV | Engineering & Procurement |
| AG1-367 | DeSoto 345 kV | Active |
| AG1-368 | Tillman 138 kV | Engineering & Procurement |
| AG1-369 | Logtown 138 kV | Engineering & Procurement |
| AG1-374 | Blue Mound 345 kV | Active |
| AG1-375 | Sorenson-Desoto 345 kV | Active |
| AG1-386 | Smith-Francis Junction 25 kV | In Service |
| AG1-397 | Walston 12 kV | Withdrawn |
| AG1-410 | Maddox Creek-RP Mone 345 kV | Active |
| AG1-411 | Maddox Creek-RP Mone 345 kV | Active |
| AG1-433 | Keystone-DeSoto 345 kV | Active |
| AG1-436 | Olive-University Park 345 kV | Active |
| AG1-447 | Olive-University Park 345 kV | Active |
| AG1-462 | Cordova 345 kV | Active |
| AG1-469 | Gordonsville 34.5 kV | Engineering & Procurement |
| AG1-478 | Wilmington 34.5 kV | Engineering & Procurement |
| AG1-480 | Shawnee 34.5 kV | Engineering & Procurement |
| AG1-482 | Hamilton 115 kV | Withdrawn |
| AG1-495 | Gilbert-Rocktown 34.5 kV | Engineering & Procurement |
| AG1-499 | Lambs 12.47 kV | Under Construction |
| AG1-500 | Beaver 345 kV | Engineering & Procurement |
| AG1-501 | Beaver 138 kV | Engineering & Procurement |
| AG1-554 | South Kenton 138 kV | Engineering & Procurement |
| AG1-555 | Dequine 345 kV | Engineering & Procurement |
| AG1-559 | Caroline Pines 22 kV | Engineering & Procurement |
| AG2-029 | Forest G. Hipple-Collingwood 345 kV | Active |
| AG2-057 | Cardington-Liberty 69 kV II | Active |
| AG2-063 | North Hampton 69 kV | Active |
| AG2-072 | Rockport 765 kV | Active |
| AG2-085 | Delaware-Royerton 138 kV | Active |
| AG2-104 | Marysville-Flatlick 765 kV | Active |
| AG2-106 | Marysville-Flatlick 765 kV | Active |
| AG2-107 | Marysville-Flatlick 765 kV | Active |
| AG2-109 | Fitchville-New London 69 kV | Active |
| AG2-114 | Dresden-Pontiac Midpoint 345 kV | Active |
| AG2-119 | Galion-Roberts South 138 kV II | Active |
| AG2-125 | Camden-Crystal 69 kV | Active |
| AG2-162 | Jefferson-Greentown 765 kV | Active |
| AG2-163 | Dequine-Eugene 345 kV | Active |
| AG2-164 | Jefferson-Greentown 765 kV | Active |
| AG2-165 | Dumont-Greentown 765 kV | Active |
| AG2-191 | Mississinewa 138 kV | Active |
| AG2-192 | Mississinewa 138 kV | Active |
| AG2-212 | Dumont-Greentown 765 kV | Active |
| AG2-216 | East Sidney-Quincy 138 kV | Active |
| AG2-219 | Jefferson-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 |
| AG2-331 | Jefferson-Greentown 765 kV | Active |
| AG2-363 | Powerton 345 kV | Active |
| AG2-364 | Powerton 345 kV | Active |
| AG2-378 | North Hampton – Medway 69 kV | Active |
| AG2-385 | North Hampton 69 kV | Active |
| AG2-400 | Allen 345 kV | Active |
| AG2-401 | Losantville 345 kV | Active |
| AG2-405 | Continental 69 kV | Active |
| AG2-406 | Payne 69 kV | Active |
| AG2-408 | Allen 345 kV | Active |
| AG2-444 | Bixby - Biers Run 345 kV | Active |
| AG2-449 | Jefferson-Greentown 765 kV | Active |
| AG2-453 | Lasalle - Plano 345 kV | Active |
| AG2-487 | Madison - Tanners Creek 138 kV | Active |
| AG2-491 | Meadow Lake 345 kV | Active |
| AG2-515 | Midway 345 kV III | Active |
| AG2-516 | Pecatonica 138kV | Active |
| AG2-519 | Royerton - Desoto 138 kV | Active |
| AG2-524 | LaSalle Station - Mazon 138 kV | Active |
| AG2-548 | Corwin - Elk 138 kV | Active |
| AG2-550 | Bluff Point - Randolph 138 kV | Active |
| AG2-551 | Bluff Point - Randolph 138 kV | Active |
| AG2-564 | Sulphur Springs 138 kV | Active |
| AG2-575 | Crego Rd. 138 kV | Active |
| AG2-582 | Flint Run 500 kV | Active |
| AG2-585 | Kensington 138kV | Active |
| AG2-589 | Ravenswood - Hemlock 69 kV | Active |
| AG2-637 | Randolph - Hodgin 138 kV | Active |
| AG2-660 | Nelson-Electric Junction 345 kV | Active |
| AG2-665 | Corwin - Elk 138 kV | Active |
| AH1-044 | Nelson - Electric Junction 345 kV | Active |
| AH1-047 | Marengo - Belvidere 138 kV | Active |
| AH1-055 | Kyger Creek - Don Marquis 345 kV | Active |
| AH1-059 | Sharp Road 69 kV | 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 |
| AH1-146 | White Rock - Wayne 345 kV | Active |
| AH1-147 | White Rock - Wayne 345 kV | Active |
| AH1-150 | Nelson-Electric Junction 345 kV | Active |
| AH1-151 | Nelson-Electric Junction 345 kV | Active |
| AH1-153 | Dumont 345 kV | Active |
| AH1-196 | Prairie 345 kV | Active |
| AH1-234 | Wempletown - Paddock 345 kV | Active |
| AH1-272 | Argenta - Twin Branch 345 kV | Active |
| AH1-282 | Galion - Ohio Central 345 kV | Active |
| AH1-285 | Sandwich 138 kV | Active |
| AH1-302 | Olive - Reynolds 345 kV | Active |
| AH1-304 | Delaware-Van Buren 138 kV | Active |
| AH1-305 | Olive - Reynolds 345 kV | Active |
| AH1-306 | Mississinewa-Gaston 138 kV | Active |
| AH1-308 | Pennville - Adams 138 kV | Active |
| AH1-309 | Kenzie Creek-Colby 138 kV | Active |
| AH1-327 | Hardin Switch 345 kV | Active |
| AH1-328 | Blue Jacket - Kirby 138 kV | Active |
| AH1-337 | Randolph - Hodgin 138 kV | Active |
| AH1-338 | McGirr Rd - Ritchie Road 138kV | Active |
| AH1-339 | West Crawford 69 kV | Active |
| AH1-341 | Stillman - Dixon 138KV | Active |
| AH1-391 | Olive 138 kV | Active |
| AH1-392 | Gravel Pit-Kankakee 138 kV | Active |
| AH1-482 | Olive - Reynolds #2 345 kV | Active |
| AH1-537 | Pierce - Kyger Creek 345 kV | Active |
| AH1-539 | South Kenton 138 kV | Active |
| AH1-541 | Chestnut 345 kV | Active |
| AH1-542 | Crissinger-Kirby 138kV | Active |
| AH1-543 | Mulberry – Tazewell 345 kV | Active |
| AH1-567 | University Park 138 kV | Active |
| AH1-661 | Cannelville 12.47 kV | Active |
| AH1-664 | Goddard-Plumville 138 kV | Active |
| AH1-665 | Goddard-Plumsville 138 kV II | Active |
| AH1-666 | Flemingsburg - Spurlock 138 kV | Active |
| AH1-669 | Circleville-Biers Run 138 kV | Active |
| AH1-670 | Blue Mound-Chestnut 345 kV | Active |
| AH1-686 | Hanging Rock 765 kV | Active |
| AH1-690 | Bay Shore - Lallendorf 345 kV | Active |
| AH1-698 | Braidwood 345 kV | Active |
| AH1-702 | Byron 345 kV | Active |
| AH1-704 | Hannibal 138 kV | Active |
| AH1-711 | Lemoyne 345 kV | Active |
| AH1-714 | Lasalle 345 kV | Active |
| AH1-718 | Nelson 345 kV | Active |
| AH1-719 | Beverly 345 kV | Active |
| AH1-735 | Richland 138 kV | Active |
| U2-030 | Four Mile Ridge Wind 138kV | In Service |
| U2-072 | East Lima-Marysville 345kV | In Service |
| U2-073 | Frostburg 138kV II | In Service |
| V1-011 | Haviland 138kV | In Service |
| V3-007 | Desoto-Tanners Creek #1 345kV | In Service |
| V4-067 | Cates Road Egg Harbor Township 12kV | Deactivated |
| V4-073 | Yankee 12.5kV | In Service |
| 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 |
| W1-130 | Vine Road 12kV | In Service |
| W2-030 | Egg Harbor Township | In Service |
| W2-048 | Brokaw-Lanesville | In Service |
| W3-077 | Broadway-Stewartsville 34.5kV | In Service |
| W4-005 | Blue Mound-Latham | In Service |
| X1-042 | Watervliet | In Service |
| X2-022 | Brokaw-Lanesville | In Service |
| X3-005 | Wildwood 12kV | In Service |
| X3-066 | Church Hill 69kV | In Service |
| Y1-079 | Wye Mills 69kV | In Service |
| Y1-080 | Dorchester 12kV | In Service |
| Y3-023 | Country Side 12kV | In Service |
| Y3-024 | Bluff Point 12kV | In Service |
| Y3-058 | Rockawalkin 69kV | In Service |
| Z2-076 | Worcester South 25kV | In Service |
| Z2-077 | Worcester North 25kV | In Service |
| Z2-087 | Pontiac MidPoint-Brokaw 345kV | In Service |
| Z2-115 | Deer Creek 12.47kV | In Service |
| Z2-116 | Twin Branch 12.47kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, 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.
Midcontinent Independent System Operator, Inc. (MISO)No Impact
New York Independent System Operator (NYISO)No Impact
Tennessee Valley Authority (TVA)No Impact
Louisville Gas & Electric (LG&E)No Impact
Duke Energy Carolinas (DUKE)No Impact
Duke Energy Progress – East (CPLE)No Impact
Duke Energy Progress – West (CPLW)No Impact
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:
Midcontinent Independent System Operator, Inc. (MISO)Study Pending
New York Independent System Operator (NYISO)Not required
Tennessee Valley Authority (TVA)Not required
Louisville Gas & Electric (LG&E)Not required
Duke Energy Carolinas (DUKE)Not required
Duke Energy Progress – East (CPLE)Not required
Duke Energy Progress – West (CPLW)Not required
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) |
|---|---|---|---|
| ATSI | (Pending) / TC2-ATSI-014.a | Reconductor (possible rebuild) 29.61 miles of transmission line and line drops ( line drops at Hayes) on the Beaver - Hayes Ckt 1 345 kV line | $10,237,972 |
| ATSI | (Pending) / TC2-ATSI-006.a | Reconductor (possible rebuild) 30.25 miles of 954 ACSR 48/7 transmission line and line drops (line drops at Davis Besse) on the Davis Besse-Hayes 345 kV line | $9,354,606 |
| ATSI | (Pending) / TC2-ATSI-020.d | Reconductor (possible rebuild) 29.61 miles of transmission line and (4) line drops beginning at Beaver towards Davis Besse on the Beaver - Davis Besse Ckt 1 345 kV line | $8,125,408 |
| ATSI | (Pending) / TC2-ATSI-004.c | 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 | $8,091,541 |
| ATSI | (Pending) / TC2-ATSI-015.a | Reconductor (possible rebuild) 21.68 miles of transmission line and (1) line drop (line drop at Lemoyne) on the Davis Besse - Lemoyne 345 kV | $7,692,075 |
| ATSI | (Pending) / TC2-ATSI-008.f | Reconductor (possible rebuild) 18.7 miles of 954 ACSR 48/7 on the Davis Besse - AC2-103 TAP 345kV | $6,337,596 |
| AEP | (Pending) / AEP-TC2-18681 | 05E LIMA 345.0 kV to 05SW LIM 345.0 kV ckt 1 - Rebuild | $6,072,657 |
| ATSI | (Pending) / TC2-ATSI-008.c | Reconductor (possible rebuild) 15.6 miles of 954 ACSR 45/7 on the Davis Besse - AC2-103 Tap 345 kV line | $5,201,428 |
| ATSI | (Pending) / TC2-ATSI-002.d | Reconductor (possible rebuild) 345kV 20.75 miles of transmission line and line drops at both remote ends | $4,914,548 |
| ATSI | (Pending) / TC2-ATSI-005.d | Reconductor (possible rebuild) 8.37 miles of 954 ACSR 48/7 transmission line on the Beaver - Lake Avenue Ckt 1 345 kV | $3,585,590 |
| ATSI | n9227.0 / TC1-ATSI-001.b | Upgrade T-line drops, overhead substation conductor and TL reconductor | $3,393,878 |
| ATSI | (Pending) / TC2-ATSI-021.a | Upgrade (4) circuit breakers at Beaver and Lake Ave (B:3,4,216,219) | $540,728 |
| ATSI | (Pending) / TC2-ATSI-014.d | Upgrade (4) circuit breakers at Beaver and Hayes (B88, B115, B3, B6) | $461,984 |
| ATSI | (Pending) / TC2-ATSI-015.c | Upgrade (2) 3000A CBs at Davis Besse and (1) 3000A CB at Lemoyne | $384,270 |
| ATSI | (Pending) / TC2-ATSI-002.g | Upgrade (2) 345kV circuit breakers at Bayshore and (2) at Davis Besse | $314,723 |
| ATSI | (Pending) / TC2-ATSI-021.h | Upgrade (9) disconnect switches at Beaver and Lake Ave (D: 19,20,21,22, 212,215,217,218,220) | $267,405 |
| ATSI | (Pending) / TC2-ATSI-015.i | Upgrade (10) 3000A bus and line side disconnect switches at Davis Besse and Lemoyne (34624, A34604, D345:63A,63B,64D,64C,01N,01S,02W,02E) | $254,753 |
| ATSI | (Pending) / TC2-ATSI-006.j | Upgrade (6) disconnect switches at Davis Besse (D27,28,29,30,34625,37) and (5) disconnect switches at Hayes (D20,19,16,13,14) | $235,316 |
| ATSI | (Pending) / TC2-ATSI-014.k | Upgrade (9) 3000A disconnect switches at Beaver and Hayes (D:74,92,93,116,4,5,7,8,11) | $230,820 |
| ATSI | (Pending) / TC2-ATSI-020.a | Upgrade B185 and B182 circuit breakers at Beaver | $223,755 |
| ATSI | (Pending) / TC2-ATSI-006.d | Upgrade (2) B18 & B12 345 kV Ciruit Breakers at Hayes | $202,435 |
| ATSI | (Pending) / TC2-ATSI-006.g | Upgrade B66 and B67 circuit breakers at Davis Besse substation | $202,435 |
| ATSI | (Pending) / TC2-ATSI-021.k | Upgrade the (15) B216, B219, B3 and B4 2000 CTs at Beaver and Lake Ave | $187,576 |
| ATSI | (Pending) / TC2-ATSI-019 | Upgrade phase 2 wave trap at Galion | $184,641 |
| ATSI | (Pending) / TC2-ATSI-002.m | Upgrade (7) 3000A disconnect switches (D34545:N,S, D3454:W,E, A34673, D34561C, and 34623)and (2) B34545 impedance relays at Bayshore and Davis Besse | $153,617 |
| ATSI | (Pending) / TC2-ATSI-015.g | Upgrade (2) B34501 and B34502 relay thermals at Lemoyne and (3) 34563 relay and meter thermals at Davis Besse | $137,758 |
| ATSI | (Pending) / TC2-ATSI-015.d | Upgrade (12) dual 1590 ACSR SCCIR at Davis Besse and Lemoyne | $133,476 |
| ATSI | (Pending) / TC2-ATSI-015.f | Upgrade the B34502 CB at Lemoyne | $133,338 |
| ATSI | (Pending) / TC2-ATSI-008.h | Upgrade Circuit Breaker 34564 at Davis Besse | $117,254 |
| ATSI | (Pending) / TC2-ATSI-008.l | Upgrade Circuit Breaker B65 at Davis Besse | $117,254 |
| ATSI | (Pending) / TC2-ATSI-005.a | Upgrade (3) disconnect switches at Beaver (D:120,166,165) | $100,649 |
| ATSI | (Pending) / TC2-ATSI-020.b | Upgrade (4) disconnect switches at Beaver (D186,184,181,183) | $92,436 |
| ATSI | (Pending) / TC2-ATSI-014.h | Upgrade the B88 and B115 CTs at Beaver | $73,253 |
| ATSI | (Pending) / TC2-ATSI-015.b | Upgrade (4) L300 wavetraps at Davis Besse and Lemoyne | $69,075 |
| ATSI | (Pending) / TC2-ATSI-004.a | Upgrade D120 and D125 disconnect switches at Beaver substation | $68,868 |
| ATSI | (Pending) / TC2-ATSI-020.g | Upgrade (2) B185 and B182 revenue meter CTs at Beaver | $68,450 |
| AEP | n9675.0 / AEPO0035a | Sag Study will be required on ACSR ~ 954 ~ 45/7, 18.3 miles line between South Berwick and Galion . | $68,228 |
| ATSI | (Pending) / TC2-ATSI-015.e | Upgrade (2) 8.6 Ohm impedance relays at Davis Besse and (2) 7.8 Ohm impedance relays at Lemoyne | $65,726 |
| ATSI | (Pending) / TC2-ATSI-006.e | Upgrade (2) B12 and B18 CTs at Hayes | $65,440 |
| ATSI | (Pending) / TC2-ATSI-006.c | Upgrade (2) Wave Traps at Davis Besse and (2) Wave Traps at Hayes | $63,209 |
| ATSI | (Pending) / TC2-ATSI-015.h | Upgrade (12) 4.00 SPS.AL PIPE at Lemoyne | $61,956 |
| ATSI | (Pending) / TC2-ATSI-014.j | Upgrade the B88 and B3 impedance relays at Beaver and Hayes | $59,354 |
| ATSI | (Pending) / TC2-ATSI-021.c | Upgrade the (3) B216, B219 and B4 1500 CTs | $59,293 |
| ATSI | (Pending) / TC2-ATSI-005.b | Upgrade (4) 954 ACSR 45/7 overhead line and line drops at Beaver Substation | $57,986 |
| ATSI | (Pending) / TC2-ATSI-008.a | Upgrade D41 and D42 disconnect switches at Davis Besse | $54,846 |
| ATSI | (Pending) / TC2-ATSI-002.b | Upgrade (3) 345kV bus and line side disconnect switches at Davis Besse substation at Davis Besse | $53,518 |
| ATSI | (Pending) / TC2-ATSI-006.i | Upgrade (2) 9.6 Ohms impedance relays at Hayes and (2) 12.9 Ohms impedance relays at Davis Besse | $53,023 |
| ATSI | (Pending) / TC2-ATSI-002.f | Upgrade (2) 345kV Wave Traps at Bayshore and (2) at Davis Besse | $49,135 |
| ATSI | (Pending) / TC2-ATSI-021.d | Upgrade (3) 1590 line drops at Beaver and Lake Ave | $47,962 |
| ATSI | (Pending) / TC2-ATSI-006.k | Upgrade (1) 1590 AACSR Phase A/C line drop at Davis Besse substation and (3) Phase 3 "B-B", Phase 1&2 "C-C", and shared node to wave trap line drops at Hayes | $46,558 |
| ATSI | (Pending) / TC2-ATSI-002.a | Upgrade (4) 1024.5 ACAR 24/13 sub conductors at Davis Besse | $44,435 |
| ATSI | (Pending) / TC2-ATSI-006.h | Upgrade B66 (1) meter and (1) relay thermals and B67 (1) meter thermal at Davis Besse substation | $44,323 |
| ATSI | (Pending) / TC2-ATSI-008.i | Upgrade (4) 1590 ACSR 45/7 sub conductors at Davis Besse | $42,859 |
| ATSI | (Pending) / TC2-ATSI-014.c | Upgrade (2) L3000 wavetraps at Beaver and Hayes | $42,437 |
| ATSI | (Pending) / TC2-ATSI-014.f | Upgrade the B6 CT at Hayes | $42,331 |
| ATSI | (Pending) / TC2-ATSI-002.k | Upgrade the B34545 and 34562 (4) Meter and (2) Relay Thermals at Bayshore and Davis Besse | $40,370 |
| ATSI | (Pending) / TC2-ATSI-020.e | Upgrade (2) L3000 wavetraps at Beaver | $35,666 |
| ATSI | (Pending) / TC2-ATSI-021.i | Upgrade the (2) B3 SEL411L impedance relays at Lake Ave | $35,408 |
| ATSI | (Pending) / TC2-ATSI-021.f | Upgrade the (1) B216 relay thermal at Beaver | $35,408 |
| ATSI | (Pending) / TC2-ATSI-021.l | Upgrade the (2) B216 SEL411L impedance relays at Lake Ave | $35,408 |
| ATSI | (Pending) / TC2-ATSI-008.g | Upgrade (2) Wave Traps at Davis Besse | $35,173 |
| ATSI | (Pending) / TC2-ATSI-014.g | Upgrade (3) 1590 AAC line drops at Beaver (line drop to WT, Phase 1&3 "B-B", and SHARED NODE TO: WT, PH 2 / 5" AL, PH 1&3) | $34,448 |
| ATSI | (Pending) / TC2-ATSI-014.i | Upgrade the 10A B115 relay and B88 meter thermal at Beaver | $29,677 |
| ATSI | (Pending) / TC2-ATSI-008.j | Upgrade (2) 13.03 Ohm B65 Impedance Relays at Davis Besse | $28,899 |
| ATSI | (Pending) / TC2-ATSI-008.k | Upgrade (2) 6.65 Ohm B65 Impedance Relays at Davis Besse | $28,899 |
| ATSI | (Pending) / TC2-ATSI-008.m | Upgrade (2) B65 Meter Thermals at Davis Besse | $28,899 |
| ATSI | (Pending) / TC2-ATSI-002.i | Upgrade B34544 CT at BAYSHORE | $28,792 |
| ATSI | (Pending) / TC2-ATSI-020.f | Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z2-BU & Z2-PR) | $27,731 |
| ATSI | (Pending) / TC2-ATSI-020.i | Upgrade B182 relay thermal at Beaver | $27,731 |
| ATSI | (Pending) / TC2-ATSI-020.j | Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z4-BU & Z4-PR) | $27,731 |
| ATSI | (Pending) / TC2-ATSI-021.e | Upgrade the (1) B219 1200 CT to PVD at Beaver | $24,301 |
| ATSI | (Pending) / TC2-ATSI-021.b | Upgrade 1590 AAC B3, B4, B216 and B219 breaker leads at Beaver and Lake Ave | $21,217 |
| ATSI | (Pending) / TC2-ATSI-004.d | Upgrade (1) 3500 SAC 127 D120-to-B121 breaker lead at Beaver | $19,649 |
| ATSI | (Pending) / TC2-ATSI-004.b | Upgrade (1) 3000 SAC 169 line drop at Beaver | $19,498 |
| ATSI | (Pending) / TC2-ATSI-020.h | Upgrade the B185 CT to PVD at Beaver | $19,032 |
| ATSI | (Pending) / TC2-ATSI-021.m | Upgrade (8) 5.00 SPS.AL PIPE SCCIR at Beaver | $17,363 |
| ATSI | (Pending) / TC2-ATSI-002.j | Upgrade (1) 1590 ACSR 45/7 sub conductor at Davis Besse | $15,919 |
| ATSI | (Pending) / TC2-ATSI-006.f | Upgrade (10) 1590 ACSR sub conductor (B66 and B67 breaker leads, wave trap subconductor, Overheadline-34625) at Davis Besse and B12 breaker leads at Hayes | $15,866 |
| ATSI | (Pending) / TC2-ATSI-008.b | Upgrade (1) 1024 ACAR 6E550-52-1 "A" line drop at Davis Besse | $14,915 |
| ATSI | (Pending) / TC2-ATSI-008.d | Upgrade (2) 3500 SAC 127 line drops at Davis Besse | $14,915 |
| ATSI | (Pending) / TC2-ATSI-006.b | Upgrade 3500 SAC 127 OVERHEAD PIPE to disc sw. 34625 at Davis Besse and B18 breaker leads at Hayes | $14,770 |
| ATSI | (Pending) / TC2-ATSI-005c | Upgrade 3500 SAC 127 B161 (2) breaker leads and (1) B121-to-D120 breaker lead at Beaver | $13,690 |
| ATSI | (Pending) / TC2-ATSI-021.g | Upgrade (1) 4.00 SPS.AL PIPE at Beaver | $12,367 |
| ATSI | (Pending) / TC2-ATSI-021.j | Upgrade (2) 2.50 SPS.AL PIPE SCCIR at Beaver | $12,041 |
| ATSI | (Pending) / TC2-ATSI-008.e | Upgrade 3500 SAC B65 breaker leads and subconductor (D42 to wave trap) at Davis Besse | $11,199 |
| ATSI | (Pending) / TC2-ATSI-002.l | Upgrade (5) 4.00 SPS AL PIPE 61 sub conductors at BAYSHORE on the Bayshore - Davis Besse 345kV line | $10,686 |
| ATSI | (Pending) / TC2-ATSI-002.c | Upgrade 345kV 1033.5 AAC 61 sub conductors at Davis Besse substation at Davis Besse | $10,418 |
| ATSI | (Pending) / TC2-ATSI-002.e | Upgrade 345kV 3500 SAC 127 sub conductor at Davis Besse | $10,418 |
| ATSI | (Pending) / TC2-ATSI-020.c | Upgrade 3000 AAC B185 and B185 breaker leads at Beaver | $10,195 |
| ATSI | (Pending) / TC2-ATSI-014.b | Upgrade 3500 SAC (2) B3 and (2) B6 breaker leads at Hayes | $8,880 |
| ATSI | (Pending) / TC2-ATSI-014.e | Upgrade the 1590 AAC (2) B88 and (2) B15 breaker leads at Beaver | $8,880 |
| ATSI | (Pending) / TC2-ATSI-002.h | Upgrade (8) 1590 AAC 61 sub conductor at BAYSHORE | $8,533 |
| Grand Total: | $79,781,179 | ||
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.a
- Title
- Reconductor (possible rebuild) 29.61 miles of transmission line and line drops ( line drops at Hayes) on the Beaver - Hayes Ckt 1 345 kV line
- Description
- Reconductor (possible rebuild) 29.61 miles of transmission line and line drops ( line drops at Hayes) on the Beaver - Hayes Ckt 1 345 kV line using dual (2) 954 54/7 "Cardinal" ACSS
- Total Cost ($USD)
- $175,902,477
- Allocated Cost ($USD)
- $10,237,972
- Time Estimate
- 90 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $10,237,972 |
AG2-165 | 8.3 MW | 2.0% | $3,519,183 |
AG2-212 | 8.3 MW | 2.0% | $3,519,183 |
AG2-328 | 8.3 MW | 2.0% | $3,519,183 |
AG2-660 | 1.0 MW | 0.3% | $446,130 |
AH1-044 | 6.3 MW | 1.5% | $2,675,499 |
AH1-150 | 6.3 MW | 1.5% | $2,675,499 |
AH1-151 | 6.3 MW | 1.5% | $2,675,499 |
AH1-690 | 288.2 MW | 69.8% | $122,797,286 |
AH1-711 | 55.9 MW | 13.6% | $23,837,042 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.a
- Title
- Reconductor (possible rebuild) 30.25 miles of 954 ACSR 48/7 transmission line and line drops (line drops at Davis Besse) on the Davis Besse-Hayes 345 kV line
- Description
- Reconductor (possible rebuild) 30.25 miles of 954 ACSR 48/7 transmission line and line drops (line drops at Davis Besse) on the Davis Besse-Hayes 345 kV line using dual (2) 1590 54/19 "Falcon" ACSS
- Total Cost ($USD)
- $179,916,169
- Allocated Cost ($USD)
- $9,354,606
- Time Estimate
- 90 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $9,354,606 |
AG2-165 | 8.1 MW | 1.9% | $3,373,039 |
AG2-212 | 8.1 MW | 1.9% | $3,373,039 |
AG2-328 | 8.1 MW | 1.9% | $3,373,039 |
AG2-660 | 1.0 MW | 0.2% | $427,374 |
AH1-044 | 6.1 MW | 1.4% | $2,563,827 |
AH1-150 | 6.1 MW | 1.4% | $2,563,827 |
AH1-151 | 6.1 MW | 1.4% | $2,563,827 |
AH1-690 | 306.6 MW | 71.2% | $128,073,552 |
AH1-711 | 58.0 MW | 13.5% | $24,250,037 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.d
- Title
- Reconductor (possible rebuild) 29.61 miles of transmission line and (4) line drops beginning at Beaver towards Davis Besse on the Beaver - Davis Besse Ckt 1 345 kV line
- Description
- Reconductor (possible rebuild) 29.61 miles of transmission line and (4) line drops beginning at Beaver towards Davis Besse on the Beaver - Davis Besse Ckt 1 345 kV line using dual (2) 1590 54/19 "Falcon" ACSS
- Total Cost ($USD)
- $149,403,319
- Allocated Cost ($USD)
- $8,125,408
- Time Estimate
- 82 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $5,835,961 |
AG2-149 | 22.1 MW | 5.4% | $8,125,408 |
AG2-165 | 7.9 MW | 1.9% | $2,891,547 |
AG2-212 | 7.9 MW | 1.9% | $2,891,547 |
AG2-328 | 7.9 MW | 1.9% | $2,891,547 |
AH1-690 | 290.0 MW | 71.3% | $106,455,624 |
AH1-711 | 55.3 MW | 13.6% | $20,311,685 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.c
- Title
- Reconductor (possible rebuild) 18.22 miles of 954 ACSR 48/7 transmission line and (3) line drops at Beaver on the Beaver - Carlisle Ckt 1 345 kV
- Description
- Reconductor (possible rebuild) 18.22 miles of 954 ACSR 48/7 transmission line and (3) line drops at Beaver on the Beaver - Carlisle Ckt 1 345 kV using dual (2) 795 26/7 "Drake ACSS
- Total Cost ($USD)
- $109,211,408
- Allocated Cost ($USD)
- $8,091,541
- Time Estimate
- 63 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.6 MW | 7.4% | $8,091,541 |
AH1-690 | 238.1 MW | 78.2% | $85,440,891 |
AH1-711 | 43.7 MW | 14.4% | $15,678,976 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.a
- Title
- Reconductor (possible rebuild) 21.68 miles of transmission line and (1) line drop (line drop at Lemoyne) on the Davis Besse - Lemoyne 345 kV
- Description
- Reconductor (possible rebuild) 21.68 miles of transmission line and (1) line drop (line drop at Lemoyne) on the Davis Besse - Lemoyne 345 kV using dual (2) 1272 54/19 "Pheasant" ACSS
- Total Cost ($USD)
- $126,131,949
- Allocated Cost ($USD)
- $7,692,075
- Time Estimate
- 73 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.5% | $5,726,959 |
AG2-149 | 26.0 MW | 6.1% | $7,692,075 |
AG2-165 | 9.2 MW | 2.2% | $2,716,066 |
AG2-212 | 9.2 MW | 2.2% | $2,716,066 |
AG2-328 | 9.2 MW | 2.2% | $2,716,066 |
AG2-515 | 20.4 MW | 4.8% | $6,022,672 |
AG2-660 | 1.2 MW | 0.3% | $356,864 |
AH1-044 | 7.3 MW | 1.7% | $2,142,071 |
AH1-150 | 7.3 MW | 1.7% | $2,142,071 |
AH1-151 | 7.3 MW | 1.7% | $2,142,071 |
AH1-690 | 230.6 MW | 54.0% | $68,126,768 |
AH1-711 | 80.0 MW | 18.7% | $23,632,200 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.f
- Title
- Reconductor (possible rebuild) 18.7 miles of 954 ACSR 48/7 on the Davis Besse - AC2-103 TAP 345kV
- Description
- Reconductor (possible rebuild) 18.7 miles of 954 ACSR 48/7 on the Davis Besse - AC2-103 TAP 345kV using dual (2) 1272 54/19 "Pheasant" ACSS
- Total Cost ($USD)
- $111,822,087
- Allocated Cost ($USD)
- $6,337,596
- Time Estimate
- 64 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $6,337,596 |
AG2-165 | 7.9 MW | 2.0% | $2,258,920 |
AG2-212 | 7.9 MW | 2.0% | $2,258,920 |
AG2-328 | 7.9 MW | 2.0% | $2,258,920 |
AH1-690 | 290.3 MW | 74.1% | $82,891,012 |
AH1-711 | 55.4 MW | 14.1% | $15,816,720 |
System Reinforcement
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- (Pending) / AEP-TC2-18681
- Title
- 05E LIMA 345.0 kV to 05SW LIM 345.0 kV ckt 1 - Rebuild
- Description
- AEP owned line, ~14.66 miles (total 21.97 miles) of 345kV single circuit needs to be rebuilt. Existing conductor is 1-1414 ACSR/PE 62/19 & 1-1708.8 ACSR/AE 66/19
- Total Cost ($USD)
- $58,640,000
- Allocated Cost ($USD)
- $6,072,657
- Time Estimate
- 24 to 36 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 05E LIMA-05SW LIM 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 17.4 MW | 10.4% | $6,072,657 |
AH1-539 | 10.5 MW | 6.2% | $3,662,823 |
AH1-690 | 115.6 MW | 68.6% | $40,254,475 |
AH1-711 | 24.8 MW | 14.8% | $8,650,044 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.c
- Title
- Reconductor (possible rebuild) 15.6 miles of 954 ACSR 45/7 on the Davis Besse - AC2-103 Tap 345 kV line
- Description
- Reconductor (possible rebuild) 15.6 miles of 954 ACSR 45/7 on the Davis Besse - AC2-103 Tap 345 kV line using dual (2) 1272 54/19 "Pheasant" ACSS
- Total Cost ($USD)
- $91,775,258
- Allocated Cost ($USD)
- $5,201,428
- Time Estimate
- 57 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $5,201,428 |
AG2-165 | 7.9 MW | 2.0% | $1,853,953 |
AG2-212 | 7.9 MW | 2.0% | $1,853,953 |
AG2-328 | 7.9 MW | 2.0% | $1,853,953 |
AH1-690 | 290.3 MW | 74.1% | $68,030,782 |
AH1-711 | 55.4 MW | 14.1% | $12,981,188 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.d
- Title
- Reconductor (possible rebuild) 345kV 20.75 miles of transmission line and line drops at both remote ends
- Description
- Reconductor (possible rebuild) 345kV 20.75 miles of transmission line and line drops at both remote ends using dual (2) 1590 54/19 "Falcon" ACSS
- Total Cost ($USD)
- $121,594,776
- Allocated Cost ($USD)
- $4,914,548
- Time Estimate
- 71 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $3,726,804 |
AG2-149 | 24.2 MW | 4.0% | $4,914,548 |
AG2-165 | 9.0 MW | 1.5% | $1,840,616 |
AG2-212 | 9.0 MW | 1.5% | $1,840,616 |
AG2-328 | 9.0 MW | 1.5% | $1,840,616 |
AG2-363 | 10.7 MW | 1.8% | $2,168,781 |
AG2-364 | 7.1 MW | 1.2% | $1,445,922 |
AG2-660 | 1.2 MW | 0.2% | $241,903 |
AH1-044 | 7.1 MW | 1.2% | $1,451,212 |
AH1-150 | 7.1 MW | 1.2% | $1,451,212 |
AH1-151 | 7.1 MW | 1.2% | $1,451,212 |
AH1-690 | 441.8 MW | 73.9% | $89,885,811 |
AH1-711 | 45.9 MW | 7.7% | $9,335,525 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.d
- Title
- Reconductor (possible rebuild) 8.37 miles of 954 ACSR 48/7 transmission line on the Beaver - Lake Avenue Ckt 1 345 kV
- Description
- Reconductor (possible rebuild) 8.37 miles of 954 ACSR 48/7 transmission line on the Beaver - Lake Avenue Ckt 1 345 kV using dual (2) 954 54/7 "Cardinal" ACSS
- Total Cost ($USD)
- $50,053,445
- Allocated Cost ($USD)
- $3,585,590
- Time Estimate
- 38 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 19.4 MW | 7.2% | $3,585,590 |
AH1-690 | 212.1 MW | 78.5% | $39,274,455 |
AH1-711 | 38.8 MW | 14.4% | $7,193,400 |
System Reinforcement: n9227.0
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- n9227.0 / TC1-ATSI-001.b
- Title
- Upgrade T-line drops, overhead substation conductor and TL reconductor
- Description
- Reconductor (possible rebuild) of 8.12 miles of dual transmission line and (2) single conductor line drops at Beaver on the Beaver-Lake Ave Ckt 2 345 kV line using triple (3) 1113 54/19 ""Finch"" ACSS"
- Total Cost ($USD)
- $48,873,856
- Allocated Cost ($USD)
- $3,393,878
- Time Estimate
- 37 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $3,393,878 |
AG2-165 | 8.9 MW | 2.2% | $1,069,072 |
AG2-212 | 8.9 MW | 2.2% | $1,069,072 |
AG2-328 | 8.9 MW | 2.2% | $1,069,072 |
AH1-690 | 297.6 MW | 73.1% | $35,718,003 |
AH1-711 | 54.6 MW | 13.4% | $6,554,759 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.a
- Title
- Upgrade (4) circuit breakers at Beaver and Lake Ave (B:3,4,216,219)
- Description
- Upgrade (4) circuit breakers at Beaver and Lake Ave (B:3,4,216,219)
- Total Cost ($USD)
- $7,786,809
- Allocated Cost ($USD)
- $540,728
- Time Estimate
- 56 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $540,728 |
AG2-165 | 8.9 MW | 2.2% | $170,330 |
AG2-212 | 8.9 MW | 2.2% | $170,330 |
AG2-328 | 8.9 MW | 2.2% | $170,330 |
AH1-690 | 297.6 MW | 73.1% | $5,690,758 |
AH1-711 | 54.6 MW | 13.4% | $1,044,335 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.d
- Title
- Upgrade (4) circuit breakers at Beaver and Hayes (B88, B115, B3, B6)
- Description
- Upgrade (4) circuit breakers at Beaver and Hayes (B88, B115, B3, B6)
- Total Cost ($USD)
- $7,937,520
- Allocated Cost ($USD)
- $461,984
- Time Estimate
- 60 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $461,984 |
AG2-165 | 8.3 MW | 2.0% | $158,802 |
AG2-212 | 8.3 MW | 2.0% | $158,802 |
AG2-328 | 8.3 MW | 2.0% | $158,802 |
AG2-660 | 1.0 MW | 0.3% | $20,131 |
AH1-044 | 6.3 MW | 1.5% | $120,731 |
AH1-150 | 6.3 MW | 1.5% | $120,731 |
AH1-151 | 6.3 MW | 1.5% | $120,731 |
AH1-690 | 288.2 MW | 69.8% | $5,541,172 |
AH1-711 | 55.9 MW | 13.6% | $1,075,636 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.c
- Title
- Upgrade (2) 3000A CBs at Davis Besse and (1) 3000A CB at Lemoyne
- Description
- Upgrade (2) 3000A CBs at Davis Besse and (1) 3000A CB at Lemoyne
- Total Cost ($USD)
- $5,962,261
- Allocated Cost ($USD)
- $384,270
- Time Estimate
- 56 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $286,099 |
AG2-149 | 26.0 MW | 6.4% | $384,270 |
AG2-165 | 9.2 MW | 2.3% | $135,685 |
AG2-212 | 9.2 MW | 2.3% | $135,685 |
AG2-328 | 9.2 MW | 2.3% | $135,685 |
AG2-515 | 20.4 MW | 5.0% | $300,872 |
AH1-690 | 230.6 MW | 57.1% | $3,403,380 |
AH1-711 | 80.0 MW | 19.8% | $1,180,584 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.g
- Title
- Upgrade (2) 345kV circuit breakers at Bayshore and (2) at Davis Besse
- Description
- Upgrade (2) 345kV circuit breakers at Bayshore and (2) at Davis Besse
- Total Cost ($USD)
- $7,786,806
- Allocated Cost ($USD)
- $314,723
- Time Estimate
- 60 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $238,661 |
AG2-149 | 24.2 MW | 4.0% | $314,723 |
AG2-165 | 9.0 MW | 1.5% | $117,871 |
AG2-212 | 9.0 MW | 1.5% | $117,871 |
AG2-328 | 9.0 MW | 1.5% | $117,871 |
AG2-363 | 10.7 MW | 1.8% | $138,887 |
AG2-364 | 7.1 MW | 1.2% | $92,595 |
AG2-660 | 1.2 MW | 0.2% | $15,491 |
AH1-044 | 7.1 MW | 1.2% | $92,934 |
AH1-150 | 7.1 MW | 1.2% | $92,934 |
AH1-151 | 7.1 MW | 1.2% | $92,934 |
AH1-690 | 441.8 MW | 73.9% | $5,756,196 |
AH1-711 | 45.9 MW | 7.7% | $597,838 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.h
- Title
- Upgrade (9) disconnect switches at Beaver and Lake Ave (D: 19,20,21,22, 212,215,217,218,220)
- Description
- Upgrade (9) disconnect switches at Beaver and Lake Ave (D: 19,20,21,22, 212,215,217,218,220)
- Total Cost ($USD)
- $3,850,794
- Allocated Cost ($USD)
- $267,405
- Time Estimate
- 39 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $267,405 |
AG2-165 | 8.9 MW | 2.2% | $84,233 |
AG2-212 | 8.9 MW | 2.2% | $84,233 |
AG2-328 | 8.9 MW | 2.2% | $84,233 |
AH1-690 | 297.6 MW | 73.1% | $2,814,238 |
AH1-711 | 54.6 MW | 13.4% | $516,453 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.i
- Title
- Upgrade (10) 3000A bus and line side disconnect switches at Davis Besse and Lemoyne (34624, A34604, D345:63A,63B,64D,64C,01N,01S,02W,02E)
- Description
- Upgrade (10) 3000A bus and line side disconnect switches at Davis Besse and Lemoyne (34624, A34604, D345:63A,63B,64D,64C,01N,01S,02W,02E)
- Total Cost ($USD)
- $3,952,709
- Allocated Cost ($USD)
- $254,753
- Time Estimate
- 29 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $189,671 |
AG2-149 | 26.0 MW | 6.4% | $254,753 |
AG2-165 | 9.2 MW | 2.3% | $89,953 |
AG2-212 | 9.2 MW | 2.3% | $89,953 |
AG2-328 | 9.2 MW | 2.3% | $89,953 |
AG2-515 | 20.4 MW | 5.0% | $199,465 |
AH1-690 | 230.6 MW | 57.1% | $2,256,287 |
AH1-711 | 80.0 MW | 19.8% | $782,674 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.j
- Title
- Upgrade (6) disconnect switches at Davis Besse (D27,28,29,30,34625,37) and (5) disconnect switches at Hayes (D20,19,16,13,14)
- Description
- Upgrade (6) disconnect switches at Davis Besse (D27,28,29,30,34625,37) and (5) disconnect switches at Hayes (D20,19,16,13,14)
- Total Cost ($USD)
- $4,525,814
- Allocated Cost ($USD)
- $235,316
- Time Estimate
- 31 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $235,316 |
AG2-165 | 8.1 MW | 1.9% | $84,849 |
AG2-212 | 8.1 MW | 1.9% | $84,849 |
AG2-328 | 8.1 MW | 1.9% | $84,849 |
AG2-660 | 1.0 MW | 0.2% | $10,751 |
AH1-044 | 6.1 MW | 1.4% | $64,493 |
AH1-150 | 6.1 MW | 1.4% | $64,493 |
AH1-151 | 6.1 MW | 1.4% | $64,493 |
AH1-690 | 306.6 MW | 71.2% | $3,221,706 |
AH1-711 | 58.0 MW | 13.5% | $610,013 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.k
- Title
- Upgrade (9) 3000A disconnect switches at Beaver and Hayes (D:74,92,93,116,4,5,7,8,11)
- Description
- Upgrade (9) 3000A disconnect switches at Beaver and Hayes (D:74,92,93,116,4,5,7,8,11)
- Total Cost ($USD)
- $3,774,791
- Allocated Cost ($USD)
- $230,820
- Time Estimate
- 29 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 6.1% | $230,820 |
AG2-165 | 8.3 MW | 2.1% | $79,342 |
AG2-212 | 8.3 MW | 2.1% | $79,342 |
AG2-328 | 8.3 MW | 2.1% | $79,342 |
AH1-690 | 288.2 MW | 73.3% | $2,768,527 |
AH1-711 | 55.9 MW | 14.2% | $537,418 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.a
- Title
- Upgrade B185 and B182 circuit breakers at Beaver
- Description
- Upgrade B185 and B182 circuit breakers at Beaver
- Total Cost ($USD)
- $3,893,404
- Allocated Cost ($USD)
- $223,755
- Time Estimate
- 56 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 4.1% | $158,348 |
AG2-149 | 22.5 MW | 5.7% | $223,755 |
AG2-165 | 7.8 MW | 2.0% | $77,540 |
AG2-212 | 7.8 MW | 2.0% | $77,540 |
AG2-328 | 7.8 MW | 2.0% | $77,540 |
AH1-690 | 275.9 MW | 70.6% | $2,748,721 |
AH1-711 | 53.2 MW | 13.6% | $529,961 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.d
- Title
- Upgrade (2) B18 & B12 345 kV Ciruit Breakers at Hayes
- Description
- Upgrade (2) B18 & B12 345 kV Ciruit Breakers at Hayes
- Total Cost ($USD)
- $3,893,404
- Allocated Cost ($USD)
- $202,435
- Time Estimate
- 56 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $202,435 |
AG2-165 | 8.1 MW | 1.9% | $72,993 |
AG2-212 | 8.1 MW | 1.9% | $72,993 |
AG2-328 | 8.1 MW | 1.9% | $72,993 |
AG2-660 | 1.0 MW | 0.2% | $9,248 |
AH1-044 | 6.1 MW | 1.4% | $55,481 |
AH1-150 | 6.1 MW | 1.4% | $55,481 |
AH1-151 | 6.1 MW | 1.4% | $55,481 |
AH1-690 | 306.6 MW | 71.2% | $2,771,525 |
AH1-711 | 58.0 MW | 13.5% | $524,773 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.g
- Title
- Upgrade B66 and B67 circuit breakers at Davis Besse substation
- Description
- Upgrade B66 and B67 circuit breakers at Davis Besse substation
- Total Cost ($USD)
- $3,893,404
- Allocated Cost ($USD)
- $202,435
- Time Estimate
- 56 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $202,435 |
AG2-165 | 8.1 MW | 1.9% | $72,993 |
AG2-212 | 8.1 MW | 1.9% | $72,993 |
AG2-328 | 8.1 MW | 1.9% | $72,993 |
AG2-660 | 1.0 MW | 0.2% | $9,248 |
AH1-044 | 6.1 MW | 1.4% | $55,481 |
AH1-150 | 6.1 MW | 1.4% | $55,481 |
AH1-151 | 6.1 MW | 1.4% | $55,481 |
AH1-690 | 306.6 MW | 71.2% | $2,771,525 |
AH1-711 | 58.0 MW | 13.5% | $524,773 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.k
- Title
- Upgrade the (15) B216, B219, B3 and B4 2000 CTs at Beaver and Lake Ave
- Description
- Upgrade the (15) B216, B219, B3 and B4 2000 CTs at Beaver and Lake Ave
- Total Cost ($USD)
- $2,701,212
- Allocated Cost ($USD)
- $187,576
- Time Estimate
- 17 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $187,576 |
AG2-165 | 8.9 MW | 2.2% | $59,087 |
AG2-212 | 8.9 MW | 2.2% | $59,087 |
AG2-328 | 8.9 MW | 2.2% | $59,087 |
AH1-690 | 297.6 MW | 73.1% | $1,974,100 |
AH1-711 | 54.6 MW | 13.4% | $362,275 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-019
- Title
- Upgrade phase 2 wave trap at Galion
- Description
- Upgrade phase 2 wave trap at Galion
- Total Cost ($USD)
- $620,599
- Allocated Cost ($USD)
- $184,641
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02GALION-AG2-148 TP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 144.6 MW | 29.8% | $184,641 |
AG2-329 | 65.6 MW | 13.5% | $83,732 |
AH1-690 | 228.6 MW | 47.0% | $291,889 |
AH1-711 | 47.3 MW | 9.7% | $60,337 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.m
- Title
- Upgrade (7) 3000A disconnect switches (D34545:N,S, D3454:W,E, A34673, D34561C, and 34623)and (2) B34545 impedance relays at Bayshore and Davis Besse
- Description
- Upgrade (7) 3000A disconnect switches (D34545:N,S, D3454:W,E, A34673, D34561C, and 34623)and (2) B34545 impedance relays at Bayshore and Davis Besse
- Total Cost ($USD)
- $3,544,138
- Allocated Cost ($USD)
- $153,617
- Time Estimate
- 42 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.3% | $116,491 |
AG2-149 | 24.2 MW | 4.3% | $153,617 |
AG2-165 | 9.0 MW | 1.6% | $57,533 |
AG2-212 | 9.0 MW | 1.6% | $57,533 |
AG2-328 | 9.0 MW | 1.6% | $57,533 |
AH1-690 | 441.8 MW | 79.3% | $2,809,622 |
AH1-711 | 45.9 MW | 8.2% | $291,807 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.g
- Title
- Upgrade (2) B34501 and B34502 relay thermals at Lemoyne and (3) 34563 relay and meter thermals at Davis Besse
- Description
- Upgrade (2) B34501 and B34502 relay thermals at Lemoyne and (3) 34563 relay and meter thermals at Davis Besse
- Total Cost ($USD)
- $2,137,421
- Allocated Cost ($USD)
- $137,758
- Time Estimate
- 20 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $102,564 |
AG2-149 | 26.0 MW | 6.4% | $137,758 |
AG2-165 | 9.2 MW | 2.3% | $48,642 |
AG2-212 | 9.2 MW | 2.3% | $48,642 |
AG2-328 | 9.2 MW | 2.3% | $48,642 |
AG2-515 | 20.4 MW | 5.0% | $107,860 |
AH1-690 | 230.6 MW | 57.1% | $1,220,083 |
AH1-711 | 80.0 MW | 19.8% | $423,229 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.d
- Title
- Upgrade (12) dual 1590 ACSR SCCIR at Davis Besse and Lemoyne
- Description
- Upgrade (12) dual 1590 ACSR SCCIR at Davis Besse and Lemoyne
- Total Cost ($USD)
- $2,070,983
- Allocated Cost ($USD)
- $133,476
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $99,376 |
AG2-149 | 26.0 MW | 6.4% | $133,476 |
AG2-165 | 9.2 MW | 2.3% | $47,130 |
AG2-212 | 9.2 MW | 2.3% | $47,130 |
AG2-328 | 9.2 MW | 2.3% | $47,130 |
AG2-515 | 20.4 MW | 5.0% | $104,507 |
AH1-690 | 230.6 MW | 57.1% | $1,182,159 |
AH1-711 | 80.0 MW | 19.8% | $410,074 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.f
- Title
- Upgrade the B34502 CB at Lemoyne
- Description
- Upgrade the B34502 CB at Lemoyne
- Total Cost ($USD)
- $2,068,856
- Allocated Cost ($USD)
- $133,338
- Time Estimate
- 54 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $99,274 |
AG2-149 | 26.0 MW | 6.4% | $133,338 |
AG2-165 | 9.2 MW | 2.3% | $47,082 |
AG2-212 | 9.2 MW | 2.3% | $47,082 |
AG2-328 | 9.2 MW | 2.3% | $47,082 |
AG2-515 | 20.4 MW | 5.0% | $104,400 |
AH1-690 | 230.6 MW | 57.1% | $1,180,945 |
AH1-711 | 80.0 MW | 19.8% | $409,653 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.h
- Title
- Upgrade Circuit Breaker 34564 at Davis Besse
- Description
- Upgrade Circuit Breaker 34564 at Davis Besse
- Total Cost ($USD)
- $2,068,856
- Allocated Cost ($USD)
- $117,254
- Time Estimate
- 54 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $117,254 |
AG2-165 | 7.9 MW | 2.0% | $41,793 |
AG2-212 | 7.9 MW | 2.0% | $41,793 |
AG2-328 | 7.9 MW | 2.0% | $41,793 |
AH1-690 | 290.3 MW | 74.1% | $1,533,593 |
AH1-711 | 55.4 MW | 14.1% | $292,630 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.l
- Title
- Upgrade Circuit Breaker B65 at Davis Besse
- Description
- Upgrade Circuit Breaker B65 at Davis Besse
- Total Cost ($USD)
- $2,068,856
- Allocated Cost ($USD)
- $117,254
- Time Estimate
- 54 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $117,254 |
AG2-165 | 7.9 MW | 2.0% | $41,793 |
AG2-212 | 7.9 MW | 2.0% | $41,793 |
AG2-328 | 7.9 MW | 2.0% | $41,793 |
AH1-690 | 290.3 MW | 74.1% | $1,533,593 |
AH1-711 | 55.4 MW | 14.1% | $292,630 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.a
- Title
- Upgrade (3) disconnect switches at Beaver (D:120,166,165)
- Description
- Upgrade (3) disconnect switches at Beaver (D:120,166,165)
- Total Cost ($USD)
- $1,350,788
- Allocated Cost ($USD)
- $100,649
- Time Estimate
- 37 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 19.9 MW | 7.5% | $100,649 |
AH1-690 | 209.2 MW | 78.2% | $1,056,291 |
AH1-711 | 38.4 MW | 14.4% | $193,848 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.b
- Title
- Upgrade (4) disconnect switches at Beaver (D186,184,181,183)
- Description
- Upgrade (4) disconnect switches at Beaver (D186,184,181,183)
- Total Cost ($USD)
- $1,699,640
- Allocated Cost ($USD)
- $92,436
- Time Estimate
- 25 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $66,391 |
AG2-149 | 22.1 MW | 5.4% | $92,436 |
AG2-165 | 7.9 MW | 1.9% | $32,895 |
AG2-212 | 7.9 MW | 1.9% | $32,895 |
AG2-328 | 7.9 MW | 1.9% | $32,895 |
AH1-690 | 290.0 MW | 71.3% | $1,211,059 |
AH1-711 | 55.3 MW | 13.6% | $231,070 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.h
- Title
- Upgrade the B88 and B115 CTs at Beaver
- Description
- Upgrade the B88 and B115 CTs at Beaver
- Total Cost ($USD)
- $1,258,596
- Allocated Cost ($USD)
- $73,253
- Time Estimate
- 21 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $73,253 |
AG2-165 | 8.3 MW | 2.0% | $25,180 |
AG2-212 | 8.3 MW | 2.0% | $25,180 |
AG2-328 | 8.3 MW | 2.0% | $25,180 |
AG2-660 | 1.0 MW | 0.3% | $3,192 |
AH1-044 | 6.3 MW | 1.5% | $19,143 |
AH1-150 | 6.3 MW | 1.5% | $19,143 |
AH1-151 | 6.3 MW | 1.5% | $19,143 |
AH1-690 | 288.2 MW | 69.8% | $878,624 |
AH1-711 | 55.9 MW | 13.6% | $170,556 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.b
- Title
- Upgrade (4) L300 wavetraps at Davis Besse and Lemoyne
- Description
- Upgrade (4) L300 wavetraps at Davis Besse and Lemoyne
- Total Cost ($USD)
- $1,132,675
- Allocated Cost ($USD)
- $69,075
- Time Estimate
- 22 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.5% | $51,429 |
AG2-149 | 26.0 MW | 6.1% | $69,075 |
AG2-165 | 9.2 MW | 2.2% | $24,390 |
AG2-212 | 9.2 MW | 2.2% | $24,390 |
AG2-328 | 9.2 MW | 2.2% | $24,390 |
AG2-515 | 20.4 MW | 4.8% | $54,084 |
AG2-660 | 1.2 MW | 0.3% | $3,205 |
AH1-044 | 7.3 MW | 1.7% | $19,236 |
AH1-150 | 7.3 MW | 1.7% | $19,236 |
AH1-151 | 7.3 MW | 1.7% | $19,236 |
AH1-690 | 230.6 MW | 54.0% | $611,784 |
AH1-711 | 80.0 MW | 18.7% | $212,219 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.a
- Title
- Upgrade D120 and D125 disconnect switches at Beaver substation
- Description
- Upgrade D120 and D125 disconnect switches at Beaver substation
- Total Cost ($USD)
- $929,516
- Allocated Cost ($USD)
- $68,868
- Time Estimate
- 22 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.6 MW | 7.4% | $68,868 |
AH1-690 | 238.1 MW | 78.2% | $727,201 |
AH1-711 | 43.7 MW | 14.4% | $133,446 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.g
- Title
- Upgrade (2) B185 and B182 revenue meter CTs at Beaver
- Description
- Upgrade (2) B185 and B182 revenue meter CTs at Beaver
- Total Cost ($USD)
- $1,258,596
- Allocated Cost ($USD)
- $68,450
- Time Estimate
- 21 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $49,163 |
AG2-149 | 22.1 MW | 5.4% | $68,450 |
AG2-165 | 7.9 MW | 1.9% | $24,359 |
AG2-212 | 7.9 MW | 1.9% | $24,359 |
AG2-328 | 7.9 MW | 1.9% | $24,359 |
AH1-690 | 290.0 MW | 71.3% | $896,798 |
AH1-711 | 55.3 MW | 13.6% | $171,109 |
System Reinforcement: n9675.0
- Type
- Load Flow
- TO
- AEP
- RTEP ID / TO ID
- n9675.0 / AEPO0035a
- Title
- Sag Study will be required on ACSR ~ 954 ~ 45/7, 18.3 miles line between South Berwick and Galion .
- Description
- Sag Study will be required on ACSR ~ 954 ~ 45/7, 18.3 miles line between South Berwick and Galion .The cost is expected to be 73,200.New Ratings after sag study : S/N: 1409 MVA S/E: 1887 MVA.Rebuild/Reconductor, cost : $ 36.6 million
- Total Cost ($USD)
- $229,320
- Allocated Cost ($USD)
- $68,228
- Time Estimate
- 24 to 36 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02GALION-AG2-148 TP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 144.6 MW | 29.8% | $68,228 |
AG2-329 | 65.6 MW | 13.5% | $30,940 |
AH1-690 | 228.6 MW | 47.0% | $107,857 |
AH1-711 | 47.3 MW | 9.7% | $22,295 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.e
- Title
- Upgrade (2) 8.6 Ohm impedance relays at Davis Besse and (2) 7.8 Ohm impedance relays at Lemoyne
- Description
- Upgrade (2) 8.6 Ohm impedance relays at Davis Besse and (2) 7.8 Ohm impedance relays at Lemoyne
- Total Cost ($USD)
- $1,019,790
- Allocated Cost ($USD)
- $65,726
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $48,935 |
AG2-149 | 26.0 MW | 6.4% | $65,726 |
AG2-165 | 9.2 MW | 2.3% | $23,208 |
AG2-212 | 9.2 MW | 2.3% | $23,208 |
AG2-328 | 9.2 MW | 2.3% | $23,208 |
AG2-515 | 20.4 MW | 5.0% | $51,461 |
AH1-690 | 230.6 MW | 57.1% | $582,117 |
AH1-711 | 80.0 MW | 19.8% | $201,928 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.e
- Title
- Upgrade (2) B12 and B18 CTs at Hayes
- Description
- Upgrade (2) B12 and B18 CTs at Hayes
- Total Cost ($USD)
- $1,258,596
- Allocated Cost ($USD)
- $65,440
- Time Estimate
- 21 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $65,440 |
AG2-165 | 8.1 MW | 1.9% | $23,596 |
AG2-212 | 8.1 MW | 1.9% | $23,596 |
AG2-328 | 8.1 MW | 1.9% | $23,596 |
AG2-660 | 1.0 MW | 0.2% | $2,990 |
AH1-044 | 6.1 MW | 1.4% | $17,935 |
AH1-150 | 6.1 MW | 1.4% | $17,935 |
AH1-151 | 6.1 MW | 1.4% | $17,935 |
AH1-690 | 306.6 MW | 71.2% | $895,933 |
AH1-711 | 58.0 MW | 13.5% | $169,640 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.c
- Title
- Upgrade (2) Wave Traps at Davis Besse and (2) Wave Traps at Hayes
- Description
- Upgrade (2) Wave Traps at Davis Besse and (2) Wave Traps at Hayes
- Total Cost ($USD)
- $1,215,695
- Allocated Cost ($USD)
- $63,209
- Time Estimate
- 20 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $63,209 |
AG2-165 | 8.1 MW | 1.9% | $22,792 |
AG2-212 | 8.1 MW | 1.9% | $22,792 |
AG2-328 | 8.1 MW | 1.9% | $22,792 |
AG2-660 | 1.0 MW | 0.2% | $2,888 |
AH1-044 | 6.1 MW | 1.4% | $17,324 |
AH1-150 | 6.1 MW | 1.4% | $17,324 |
AH1-151 | 6.1 MW | 1.4% | $17,324 |
AH1-690 | 306.6 MW | 71.2% | $865,394 |
AH1-711 | 58.0 MW | 13.5% | $163,858 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-015.h
- Title
- Upgrade (12) 4.00 SPS.AL PIPE at Lemoyne
- Description
- Upgrade (12) 4.00 SPS.AL PIPE at Lemoyne
- Total Cost ($USD)
- $961,300
- Allocated Cost ($USD)
- $61,956
- Time Estimate
- 22 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02LEMOYN 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 19.4 MW | 4.8% | $46,128 |
AG2-149 | 26.0 MW | 6.4% | $61,956 |
AG2-165 | 9.2 MW | 2.3% | $21,877 |
AG2-212 | 9.2 MW | 2.3% | $21,877 |
AG2-328 | 9.2 MW | 2.3% | $21,877 |
AG2-515 | 20.4 MW | 5.0% | $48,510 |
AH1-690 | 230.6 MW | 57.1% | $548,730 |
AH1-711 | 80.0 MW | 19.8% | $190,346 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.j
- Title
- Upgrade the B88 and B3 impedance relays at Beaver and Hayes
- Description
- Upgrade the B88 and B3 impedance relays at Beaver and Hayes
- Total Cost ($USD)
- $1,019,790
- Allocated Cost ($USD)
- $59,354
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $59,354 |
AG2-165 | 8.3 MW | 2.0% | $20,402 |
AG2-212 | 8.3 MW | 2.0% | $20,402 |
AG2-328 | 8.3 MW | 2.0% | $20,402 |
AG2-660 | 1.0 MW | 0.3% | $2,586 |
AH1-044 | 6.3 MW | 1.5% | $15,511 |
AH1-150 | 6.3 MW | 1.5% | $15,511 |
AH1-151 | 6.3 MW | 1.5% | $15,511 |
AH1-690 | 288.2 MW | 69.8% | $711,914 |
AH1-711 | 55.9 MW | 13.6% | $138,195 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.c
- Title
- Upgrade the (3) B216, B219 and B4 1500 CTs
- Description
- Upgrade the (3) B216, B219 and B4 1500 CTs
- Total Cost ($USD)
- $853,850
- Allocated Cost ($USD)
- $59,293
- Time Estimate
- 16 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $59,293 |
AG2-165 | 8.9 MW | 2.2% | $18,677 |
AG2-212 | 8.9 MW | 2.2% | $18,677 |
AG2-328 | 8.9 MW | 2.2% | $18,677 |
AH1-690 | 297.6 MW | 73.1% | $624,011 |
AH1-711 | 54.6 MW | 13.4% | $114,515 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005.b
- Title
- Upgrade (4) 954 ACSR 45/7 overhead line and line drops at Beaver Substation
- Description
- Upgrade (4) 954 ACSR 45/7 overhead line and line drops at Beaver Substation
- Total Cost ($USD)
- $809,465
- Allocated Cost ($USD)
- $57,986
- Time Estimate
- 15 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 19.4 MW | 7.2% | $57,986 |
AH1-690 | 212.1 MW | 78.5% | $635,147 |
AH1-711 | 38.8 MW | 14.4% | $116,332 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.a
- Title
- Upgrade D41 and D42 disconnect switches at Davis Besse
- Description
- Upgrade D41 and D42 disconnect switches at Davis Besse
- Total Cost ($USD)
- $967,716
- Allocated Cost ($USD)
- $54,846
- Time Estimate
- 36 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $54,846 |
AG2-165 | 7.9 MW | 2.0% | $19,549 |
AG2-212 | 7.9 MW | 2.0% | $19,549 |
AG2-328 | 7.9 MW | 2.0% | $19,549 |
AH1-690 | 290.3 MW | 74.1% | $717,344 |
AH1-711 | 55.4 MW | 14.1% | $136,879 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.b
- Title
- Upgrade (3) 345kV bus and line side disconnect switches at Davis Besse substation at Davis Besse
- Description
- Upgrade (3) 345kV bus and line side disconnect switches at Davis Besse substation at Davis Besse
- Total Cost ($USD)
- $1,324,127
- Allocated Cost ($USD)
- $53,518
- Time Estimate
- 37 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $40,584 |
AG2-149 | 24.2 MW | 4.0% | $53,518 |
AG2-165 | 9.0 MW | 1.5% | $20,044 |
AG2-212 | 9.0 MW | 1.5% | $20,044 |
AG2-328 | 9.0 MW | 1.5% | $20,044 |
AG2-363 | 10.7 MW | 1.8% | $23,617 |
AG2-364 | 7.1 MW | 1.2% | $15,746 |
AG2-660 | 1.2 MW | 0.2% | $2,634 |
AH1-044 | 7.1 MW | 1.2% | $15,803 |
AH1-150 | 7.1 MW | 1.2% | $15,803 |
AH1-151 | 7.1 MW | 1.2% | $15,803 |
AH1-690 | 441.8 MW | 73.9% | $978,827 |
AH1-711 | 45.9 MW | 7.7% | $101,661 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.i
- Title
- Upgrade (2) 9.6 Ohms impedance relays at Hayes and (2) 12.9 Ohms impedance relays at Davis Besse
- Description
- Upgrade (2) 9.6 Ohms impedance relays at Hayes and (2) 12.9 Ohms impedance relays at Davis Besse
- Total Cost ($USD)
- $1,019,790
- Allocated Cost ($USD)
- $53,023
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $53,023 |
AG2-165 | 8.1 MW | 1.9% | $19,119 |
AG2-212 | 8.1 MW | 1.9% | $19,119 |
AG2-328 | 8.1 MW | 1.9% | $19,119 |
AG2-660 | 1.0 MW | 0.2% | $2,422 |
AH1-044 | 6.1 MW | 1.4% | $14,532 |
AH1-150 | 6.1 MW | 1.4% | $14,532 |
AH1-151 | 6.1 MW | 1.4% | $14,532 |
AH1-690 | 306.6 MW | 71.2% | $725,939 |
AH1-711 | 58.0 MW | 13.5% | $137,453 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.f
- Title
- Upgrade (2) 345kV Wave Traps at Bayshore and (2) at Davis Besse
- Description
- Upgrade (2) 345kV Wave Traps at Bayshore and (2) at Davis Besse
- Total Cost ($USD)
- $1,215,694
- Allocated Cost ($USD)
- $49,135
- Time Estimate
- 22 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $37,260 |
AG2-149 | 24.2 MW | 4.0% | $49,135 |
AG2-165 | 9.0 MW | 1.5% | $18,402 |
AG2-212 | 9.0 MW | 1.5% | $18,402 |
AG2-328 | 9.0 MW | 1.5% | $18,402 |
AG2-363 | 10.7 MW | 1.8% | $21,683 |
AG2-364 | 7.1 MW | 1.2% | $14,456 |
AG2-660 | 1.2 MW | 0.2% | $2,419 |
AH1-044 | 7.1 MW | 1.2% | $14,509 |
AH1-150 | 7.1 MW | 1.2% | $14,509 |
AH1-151 | 7.1 MW | 1.2% | $14,509 |
AH1-690 | 441.8 MW | 73.9% | $898,671 |
AH1-711 | 45.9 MW | 7.7% | $93,336 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.d
- Title
- Upgrade (3) 1590 line drops at Beaver and Lake Ave
- Description
- Upgrade (3) 1590 line drops at Beaver and Lake Ave
- Total Cost ($USD)
- $690,685
- Allocated Cost ($USD)
- $47,962
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $47,962 |
AG2-165 | 8.9 MW | 2.2% | $15,108 |
AG2-212 | 8.9 MW | 2.2% | $15,108 |
AG2-328 | 8.9 MW | 2.2% | $15,108 |
AH1-690 | 297.6 MW | 73.1% | $504,767 |
AH1-711 | 54.6 MW | 13.4% | $92,632 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.k
- Title
- Upgrade (1) 1590 AACSR Phase A/C line drop at Davis Besse substation and (3) Phase 3 "B-B", Phase 1&2 "C-C", and shared node to wave trap line drops at Hayes
- Description
- Upgrade (1) 1590 AACSR Phase A/C line drop at Davis Besse substation and (3) Phase 3 "B-B", Phase 1&2 "C-C", and shared node to wave trap line drops at Hayes
- Total Cost ($USD)
- $855,032
- Allocated Cost ($USD)
- $46,558
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.4% | $46,558 |
AG2-165 | 8.1 MW | 2.0% | $16,788 |
AG2-212 | 8.1 MW | 2.0% | $16,788 |
AG2-328 | 8.1 MW | 2.0% | $16,788 |
AH1-690 | 306.6 MW | 74.5% | $637,420 |
AH1-711 | 58.0 MW | 14.1% | $120,692 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.a
- Title
- Upgrade (4) 1024.5 ACAR 24/13 sub conductors at Davis Besse
- Description
- Upgrade (4) 1024.5 ACAR 24/13 sub conductors at Davis Besse
- Total Cost ($USD)
- $1,099,401
- Allocated Cost ($USD)
- $44,435
- Time Estimate
- 14 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $33,696 |
AG2-149 | 24.2 MW | 4.0% | $44,435 |
AG2-165 | 9.0 MW | 1.5% | $16,642 |
AG2-212 | 9.0 MW | 1.5% | $16,642 |
AG2-328 | 9.0 MW | 1.5% | $16,642 |
AG2-363 | 10.7 MW | 1.8% | $19,609 |
AG2-364 | 7.1 MW | 1.2% | $13,073 |
AG2-660 | 1.2 MW | 0.2% | $2,187 |
AH1-044 | 7.1 MW | 1.2% | $13,121 |
AH1-150 | 7.1 MW | 1.2% | $13,121 |
AH1-151 | 7.1 MW | 1.2% | $13,121 |
AH1-690 | 441.8 MW | 73.9% | $812,704 |
AH1-711 | 45.9 MW | 7.7% | $84,407 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.h
- Title
- Upgrade B66 (1) meter and (1) relay thermals and B67 (1) meter thermal at Davis Besse substation
- Description
- Upgrade B66 (1) meter and (1) relay thermals and B67 (1) meter thermal at Davis Besse substation
- Total Cost ($USD)
- $852,462
- Allocated Cost ($USD)
- $44,323
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $44,323 |
AG2-165 | 8.1 MW | 1.9% | $15,982 |
AG2-212 | 8.1 MW | 1.9% | $15,982 |
AG2-328 | 8.1 MW | 1.9% | $15,982 |
AG2-660 | 1.0 MW | 0.2% | $2,025 |
AH1-044 | 6.1 MW | 1.4% | $12,148 |
AH1-150 | 6.1 MW | 1.4% | $12,148 |
AH1-151 | 6.1 MW | 1.4% | $12,148 |
AH1-690 | 306.6 MW | 71.2% | $606,826 |
AH1-711 | 58.0 MW | 13.5% | $114,899 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.i
- Title
- Upgrade (4) 1590 ACSR 45/7 sub conductors at Davis Besse
- Description
- Upgrade (4) 1590 ACSR 45/7 sub conductors at Davis Besse
- Total Cost ($USD)
- $756,208
- Allocated Cost ($USD)
- $42,859
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $42,859 |
AG2-165 | 7.9 MW | 2.0% | $15,276 |
AG2-212 | 7.9 MW | 2.0% | $15,276 |
AG2-328 | 7.9 MW | 2.0% | $15,276 |
AH1-690 | 290.3 MW | 74.1% | $560,559 |
AH1-711 | 55.4 MW | 14.1% | $106,962 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.c
- Title
- Upgrade (2) L3000 wavetraps at Beaver and Hayes
- Description
- Upgrade (2) L3000 wavetraps at Beaver and Hayes
- Total Cost ($USD)
- $729,124
- Allocated Cost ($USD)
- $42,437
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $42,437 |
AG2-165 | 8.3 MW | 2.0% | $14,587 |
AG2-212 | 8.3 MW | 2.0% | $14,587 |
AG2-328 | 8.3 MW | 2.0% | $14,587 |
AG2-660 | 1.0 MW | 0.3% | $1,849 |
AH1-044 | 6.3 MW | 1.5% | $11,090 |
AH1-150 | 6.3 MW | 1.5% | $11,090 |
AH1-151 | 6.3 MW | 1.5% | $11,090 |
AH1-690 | 288.2 MW | 69.8% | $509,000 |
AH1-711 | 55.9 MW | 13.6% | $98,806 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.f
- Title
- Upgrade the B6 CT at Hayes
- Description
- Upgrade the B6 CT at Hayes
- Total Cost ($USD)
- $727,300
- Allocated Cost ($USD)
- $42,331
- Time Estimate
- 20 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $42,331 |
AG2-165 | 8.3 MW | 2.0% | $14,551 |
AG2-212 | 8.3 MW | 2.0% | $14,551 |
AG2-328 | 8.3 MW | 2.0% | $14,551 |
AG2-660 | 1.0 MW | 0.3% | $1,845 |
AH1-044 | 6.3 MW | 1.5% | $11,062 |
AH1-150 | 6.3 MW | 1.5% | $11,062 |
AH1-151 | 6.3 MW | 1.5% | $11,062 |
AH1-690 | 288.2 MW | 69.8% | $507,727 |
AH1-711 | 55.9 MW | 13.6% | $98,558 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.k
- Title
- Upgrade the B34545 and 34562 (4) Meter and (2) Relay Thermals at Bayshore and Davis Besse
- Description
- Upgrade the B34545 and 34562 (4) Meter and (2) Relay Thermals at Bayshore and Davis Besse
- Total Cost ($USD)
- $998,835
- Allocated Cost ($USD)
- $40,370
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $30,614 |
AG2-149 | 24.2 MW | 4.0% | $40,370 |
AG2-165 | 9.0 MW | 1.5% | $15,120 |
AG2-212 | 9.0 MW | 1.5% | $15,120 |
AG2-328 | 9.0 MW | 1.5% | $15,120 |
AG2-363 | 10.7 MW | 1.8% | $17,815 |
AG2-364 | 7.1 MW | 1.2% | $11,877 |
AG2-660 | 1.2 MW | 0.2% | $1,987 |
AH1-044 | 7.1 MW | 1.2% | $11,921 |
AH1-150 | 7.1 MW | 1.2% | $11,921 |
AH1-151 | 7.1 MW | 1.2% | $11,921 |
AH1-690 | 441.8 MW | 73.9% | $738,363 |
AH1-711 | 45.9 MW | 7.7% | $76,686 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.e
- Title
- Upgrade (2) L3000 wavetraps at Beaver
- Description
- Upgrade (2) L3000 wavetraps at Beaver
- Total Cost ($USD)
- $620,600
- Allocated Cost ($USD)
- $35,666
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 4.1% | $25,240 |
AG2-149 | 22.5 MW | 5.7% | $35,666 |
AG2-165 | 7.8 MW | 2.0% | $12,360 |
AG2-212 | 7.8 MW | 2.0% | $12,360 |
AG2-328 | 7.8 MW | 2.0% | $12,360 |
AH1-690 | 275.9 MW | 70.6% | $438,140 |
AH1-711 | 53.2 MW | 13.6% | $84,475 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.i
- Title
- Upgrade the (2) B3 SEL411L impedance relays at Lake Ave
- Description
- Upgrade the (2) B3 SEL411L impedance relays at Lake Ave
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $35,408
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $35,408 |
AG2-165 | 8.9 MW | 2.2% | $11,153 |
AG2-212 | 8.9 MW | 2.2% | $11,153 |
AG2-328 | 8.9 MW | 2.2% | $11,153 |
AH1-690 | 297.6 MW | 73.1% | $372,642 |
AH1-711 | 54.6 MW | 13.4% | $68,385 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.f
- Title
- Upgrade the (1) B216 relay thermal at Beaver
- Description
- Upgrade the (1) B216 relay thermal at Beaver
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $35,408
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $35,408 |
AG2-165 | 8.9 MW | 2.2% | $11,153 |
AG2-212 | 8.9 MW | 2.2% | $11,153 |
AG2-328 | 8.9 MW | 2.2% | $11,153 |
AH1-690 | 297.6 MW | 73.1% | $372,642 |
AH1-711 | 54.6 MW | 13.4% | $68,385 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.l
- Title
- Upgrade the (2) B216 SEL411L impedance relays at Lake Ave
- Description
- Upgrade the (2) B216 SEL411L impedance relays at Lake Ave
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $35,408
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $35,408 |
AG2-165 | 8.9 MW | 2.2% | $11,153 |
AG2-212 | 8.9 MW | 2.2% | $11,153 |
AG2-328 | 8.9 MW | 2.2% | $11,153 |
AH1-690 | 297.6 MW | 73.1% | $372,642 |
AH1-711 | 54.6 MW | 13.4% | $68,385 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.g
- Title
- Upgrade (2) Wave Traps at Davis Besse
- Description
- Upgrade (2) Wave Traps at Davis Besse
- Total Cost ($USD)
- $620,599
- Allocated Cost ($USD)
- $35,173
- Time Estimate
- 20 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $35,173 |
AG2-165 | 7.9 MW | 2.0% | $12,537 |
AG2-212 | 7.9 MW | 2.0% | $12,537 |
AG2-328 | 7.9 MW | 2.0% | $12,537 |
AH1-690 | 290.3 MW | 74.1% | $460,035 |
AH1-711 | 55.4 MW | 14.1% | $87,781 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.g
- Title
- Upgrade (3) 1590 AAC line drops at Beaver (line drop to WT, Phase 1&3 "B-B", and SHARED NODE TO: WT, PH 2 / 5" AL, PH 1&3)
- Description
- Upgrade (3) 1590 AAC line drops at Beaver (line drop to WT, Phase 1&3 "B-B", and SHARED NODE TO: WT, PH 2 / 5" AL, PH 1&3) using dual (2) 954 54/7 "Cardinal" ACSS
- Total Cost ($USD)
- $591,863
- Allocated Cost ($USD)
- $34,448
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $34,448 |
AG2-165 | 8.3 MW | 2.0% | $11,841 |
AG2-212 | 8.3 MW | 2.0% | $11,841 |
AG2-328 | 8.3 MW | 2.0% | $11,841 |
AG2-660 | 1.0 MW | 0.3% | $1,501 |
AH1-044 | 6.3 MW | 1.5% | $9,002 |
AH1-150 | 6.3 MW | 1.5% | $9,002 |
AH1-151 | 6.3 MW | 1.5% | $9,002 |
AH1-690 | 288.2 MW | 69.8% | $413,179 |
AH1-711 | 55.9 MW | 13.6% | $80,205 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.i
- Title
- Upgrade the 10A B115 relay and B88 meter thermal at Beaver
- Description
- Upgrade the 10A B115 relay and B88 meter thermal at Beaver
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $29,677
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $29,677 |
AG2-165 | 8.3 MW | 2.0% | $10,201 |
AG2-212 | 8.3 MW | 2.0% | $10,201 |
AG2-328 | 8.3 MW | 2.0% | $10,201 |
AG2-660 | 1.0 MW | 0.3% | $1,293 |
AH1-044 | 6.3 MW | 1.5% | $7,756 |
AH1-150 | 6.3 MW | 1.5% | $7,756 |
AH1-151 | 6.3 MW | 1.5% | $7,756 |
AH1-690 | 288.2 MW | 69.8% | $355,957 |
AH1-711 | 55.9 MW | 13.6% | $69,097 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.j
- Title
- Upgrade (2) 13.03 Ohm B65 Impedance Relays at Davis Besse
- Description
- Upgrade (2) 13.03 Ohm B65 Impedance Relays at Davis Besse
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $28,899
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $28,899 |
AG2-165 | 7.9 MW | 2.0% | $10,300 |
AG2-212 | 7.9 MW | 2.0% | $10,300 |
AG2-328 | 7.9 MW | 2.0% | $10,300 |
AH1-690 | 290.3 MW | 74.1% | $377,973 |
AH1-711 | 55.4 MW | 14.1% | $72,122 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.k
- Title
- Upgrade (2) 6.65 Ohm B65 Impedance Relays at Davis Besse
- Description
- Upgrade (2) 6.65 Ohm B65 Impedance Relays at Davis Besse
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $28,899
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $28,899 |
AG2-165 | 7.9 MW | 2.0% | $10,300 |
AG2-212 | 7.9 MW | 2.0% | $10,300 |
AG2-328 | 7.9 MW | 2.0% | $10,300 |
AH1-690 | 290.3 MW | 74.1% | $377,973 |
AH1-711 | 55.4 MW | 14.1% | $72,122 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.m
- Title
- Upgrade (2) B65 Meter Thermals at Davis Besse
- Description
- Upgrade (2) B65 Meter Thermals at Davis Besse
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $28,899
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $28,899 |
AG2-165 | 7.9 MW | 2.0% | $10,300 |
AG2-212 | 7.9 MW | 2.0% | $10,300 |
AG2-328 | 7.9 MW | 2.0% | $10,300 |
AH1-690 | 290.3 MW | 74.1% | $377,973 |
AH1-711 | 55.4 MW | 14.1% | $72,122 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.i
- Title
- Upgrade B34544 CT at BAYSHORE
- Description
- Upgrade B34544 CT at BAYSHORE
- Total Cost ($USD)
- $712,356
- Allocated Cost ($USD)
- $28,792
- Time Estimate
- 20 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $21,833 |
AG2-149 | 24.2 MW | 4.0% | $28,792 |
AG2-165 | 9.0 MW | 1.5% | $10,783 |
AG2-212 | 9.0 MW | 1.5% | $10,783 |
AG2-328 | 9.0 MW | 1.5% | $10,783 |
AG2-363 | 10.7 MW | 1.8% | $12,706 |
AG2-364 | 7.1 MW | 1.2% | $8,471 |
AG2-660 | 1.2 MW | 0.2% | $1,417 |
AH1-044 | 7.1 MW | 1.2% | $8,502 |
AH1-150 | 7.1 MW | 1.2% | $8,502 |
AH1-151 | 7.1 MW | 1.2% | $8,502 |
AH1-690 | 441.8 MW | 73.9% | $526,591 |
AH1-711 | 45.9 MW | 7.7% | $54,692 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.f
- Title
- Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z2-BU & Z2-PR)
- Description
- Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z2-BU & Z2-PR)
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $27,731
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $19,917 |
AG2-149 | 22.1 MW | 5.4% | $27,731 |
AG2-165 | 7.9 MW | 1.9% | $9,868 |
AG2-212 | 7.9 MW | 1.9% | $9,868 |
AG2-328 | 7.9 MW | 1.9% | $9,868 |
AH1-690 | 290.0 MW | 71.3% | $363,320 |
AH1-711 | 55.3 MW | 13.6% | $69,321 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.i
- Title
- Upgrade B182 relay thermal at Beaver
- Description
- Upgrade B182 relay thermal at Beaver
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $27,731
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $19,917 |
AG2-149 | 22.1 MW | 5.4% | $27,731 |
AG2-165 | 7.9 MW | 1.9% | $9,868 |
AG2-212 | 7.9 MW | 1.9% | $9,868 |
AG2-328 | 7.9 MW | 1.9% | $9,868 |
AH1-690 | 290.0 MW | 71.3% | $363,320 |
AH1-711 | 55.3 MW | 13.6% | $69,321 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.j
- Title
- Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z4-BU & Z4-PR)
- Description
- Upgrade (2) B182 impedance relays at Beaver (SEL-321: Z4-BU & Z4-PR)
- Total Cost ($USD)
- $509,895
- Allocated Cost ($USD)
- $27,731
- Time Estimate
- 19 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $19,917 |
AG2-149 | 22.1 MW | 5.4% | $27,731 |
AG2-165 | 7.9 MW | 1.9% | $9,868 |
AG2-212 | 7.9 MW | 1.9% | $9,868 |
AG2-328 | 7.9 MW | 1.9% | $9,868 |
AH1-690 | 290.0 MW | 71.3% | $363,320 |
AH1-711 | 55.3 MW | 13.6% | $69,321 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.e
- Title
- Upgrade the (1) B219 1200 CT to PVD at Beaver
- Description
- Upgrade the (1) B219 1200 CT to PVD at Beaver
- Total Cost ($USD)
- $349,952
- Allocated Cost ($USD)
- $24,301
- Time Estimate
- 16 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $24,301 |
AG2-165 | 8.9 MW | 2.2% | $7,655 |
AG2-212 | 8.9 MW | 2.2% | $7,655 |
AG2-328 | 8.9 MW | 2.2% | $7,655 |
AH1-690 | 297.6 MW | 73.1% | $255,752 |
AH1-711 | 54.6 MW | 13.4% | $46,934 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.b
- Title
- Upgrade 1590 AAC B3, B4, B216 and B219 breaker leads at Beaver and Lake Ave
- Description
- Upgrade 1590 AAC B3, B4, B216 and B219 breaker leads at Beaver and Lake Ave
- Total Cost ($USD)
- $305,540
- Allocated Cost ($USD)
- $21,217
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $21,217 |
AG2-165 | 8.9 MW | 2.2% | $6,683 |
AG2-212 | 8.9 MW | 2.2% | $6,683 |
AG2-328 | 8.9 MW | 2.2% | $6,683 |
AH1-690 | 297.6 MW | 73.1% | $223,295 |
AH1-711 | 54.6 MW | 13.4% | $40,978 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.d
- Title
- Upgrade (1) 3500 SAC 127 D120-to-B121 breaker lead at Beaver
- Description
- Upgrade (1) 3500 SAC 127 D120-to-B121 breaker lead at Beaver
- Total Cost ($USD)
- $265,209
- Allocated Cost ($USD)
- $19,649
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.6 MW | 7.4% | $19,649 |
AH1-690 | 238.1 MW | 78.2% | $207,485 |
AH1-711 | 43.7 MW | 14.4% | $38,075 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-004.b
- Title
- Upgrade (1) 3000 SAC 169 line drop at Beaver
- Description
- Upgrade (1) 3000 SAC 169 line drop at Beaver
- Total Cost ($USD)
- $263,169
- Allocated Cost ($USD)
- $19,498
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02CARLIL 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.6 MW | 7.4% | $19,498 |
AH1-690 | 238.1 MW | 78.2% | $205,889 |
AH1-711 | 43.7 MW | 14.4% | $37,782 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.h
- Title
- Upgrade the B185 CT to PVD at Beaver
- Description
- Upgrade the B185 CT to PVD at Beaver
- Total Cost ($USD)
- $349,952
- Allocated Cost ($USD)
- $19,032
- Time Estimate
- 17 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $13,670 |
AG2-149 | 22.1 MW | 5.4% | $19,032 |
AG2-165 | 7.9 MW | 1.9% | $6,773 |
AG2-212 | 7.9 MW | 1.9% | $6,773 |
AG2-328 | 7.9 MW | 1.9% | $6,773 |
AH1-690 | 290.0 MW | 71.3% | $249,354 |
AH1-711 | 55.3 MW | 13.6% | $47,577 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.m
- Title
- Upgrade (8) 5.00 SPS.AL PIPE SCCIR at Beaver
- Description
- Upgrade (8) 5.00 SPS.AL PIPE SCCIR at Beaver
- Total Cost ($USD)
- $250,039
- Allocated Cost ($USD)
- $17,363
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $17,363 |
AG2-165 | 8.9 MW | 2.2% | $5,469 |
AG2-212 | 8.9 MW | 2.2% | $5,469 |
AG2-328 | 8.9 MW | 2.2% | $5,469 |
AH1-690 | 297.6 MW | 73.1% | $182,734 |
AH1-711 | 54.6 MW | 13.4% | $33,534 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.j
- Title
- Upgrade (1) 1590 ACSR 45/7 sub conductor at Davis Besse
- Description
- Upgrade (1) 1590 ACSR 45/7 sub conductor at Davis Besse
- Total Cost ($USD)
- $393,871
- Allocated Cost ($USD)
- $15,919
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $12,072 |
AG2-149 | 24.2 MW | 4.0% | $15,919 |
AG2-165 | 9.0 MW | 1.5% | $5,962 |
AG2-212 | 9.0 MW | 1.5% | $5,962 |
AG2-328 | 9.0 MW | 1.5% | $5,962 |
AG2-363 | 10.7 MW | 1.8% | $7,025 |
AG2-364 | 7.1 MW | 1.2% | $4,684 |
AG2-660 | 1.2 MW | 0.2% | $784 |
AH1-044 | 7.1 MW | 1.2% | $4,701 |
AH1-150 | 7.1 MW | 1.2% | $4,701 |
AH1-151 | 7.1 MW | 1.2% | $4,701 |
AH1-690 | 441.8 MW | 73.9% | $291,159 |
AH1-711 | 45.9 MW | 7.7% | $30,240 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.f
- Title
- Upgrade (10) 1590 ACSR sub conductor (B66 and B67 breaker leads, wave trap subconductor, Overheadline-34625) at Davis Besse and B12 breaker leads at Hayes
- Description
- Upgrade (10) 1590 ACSR sub conductor (B66 and B67 breaker leads, wave trap subconductor, Overheadline-34625) at Davis Besse and B12 breaker leads at Hayes
- Total Cost ($USD)
- $305,149
- Allocated Cost ($USD)
- $15,866
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $15,866 |
AG2-165 | 8.1 MW | 1.9% | $5,721 |
AG2-212 | 8.1 MW | 1.9% | $5,721 |
AG2-328 | 8.1 MW | 1.9% | $5,721 |
AG2-660 | 1.0 MW | 0.2% | $725 |
AH1-044 | 6.1 MW | 1.4% | $4,348 |
AH1-150 | 6.1 MW | 1.4% | $4,348 |
AH1-151 | 6.1 MW | 1.4% | $4,348 |
AH1-690 | 306.6 MW | 71.2% | $217,221 |
AH1-711 | 58.0 MW | 13.5% | $41,130 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.b
- Title
- Upgrade (1) 1024 ACAR 6E550-52-1 "A" line drop at Davis Besse
- Description
- Upgrade (1) 1024 ACAR 6E550-52-1 "A" line drop at Davis Besse
- Total Cost ($USD)
- $263,169
- Allocated Cost ($USD)
- $14,915
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $14,915 |
AG2-165 | 7.9 MW | 2.0% | $5,316 |
AG2-212 | 7.9 MW | 2.0% | $5,316 |
AG2-328 | 7.9 MW | 2.0% | $5,316 |
AH1-690 | 290.3 MW | 74.1% | $195,081 |
AH1-711 | 55.4 MW | 14.1% | $37,224 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.d
- Title
- Upgrade (2) 3500 SAC 127 line drops at Davis Besse
- Description
- Upgrade (2) 3500 SAC 127 line drops at Davis Besse
- Total Cost ($USD)
- $263,169
- Allocated Cost ($USD)
- $14,915
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $14,915 |
AG2-165 | 7.9 MW | 2.0% | $5,316 |
AG2-212 | 7.9 MW | 2.0% | $5,316 |
AG2-328 | 7.9 MW | 2.0% | $5,316 |
AH1-690 | 290.3 MW | 74.1% | $195,081 |
AH1-711 | 55.4 MW | 14.1% | $37,224 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-006.b
- Title
- Upgrade 3500 SAC 127 OVERHEAD PIPE to disc sw. 34625 at Davis Besse and B18 breaker leads at Hayes
- Description
- Upgrade 3500 SAC 127 OVERHEAD PIPE to disc sw. 34625 at Davis Besse and B18 breaker leads at Hayes
- Total Cost ($USD)
- $284,061
- Allocated Cost ($USD)
- $14,770
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.4 MW | 5.2% | $14,770 |
AG2-165 | 8.1 MW | 1.9% | $5,326 |
AG2-212 | 8.1 MW | 1.9% | $5,326 |
AG2-328 | 8.1 MW | 1.9% | $5,326 |
AG2-660 | 1.0 MW | 0.2% | $675 |
AH1-044 | 6.1 MW | 1.4% | $4,048 |
AH1-150 | 6.1 MW | 1.4% | $4,048 |
AH1-151 | 6.1 MW | 1.4% | $4,048 |
AH1-690 | 306.6 MW | 71.2% | $202,209 |
AH1-711 | 58.0 MW | 13.5% | $38,287 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-005c
- Title
- Upgrade 3500 SAC 127 B161 (2) breaker leads and (1) B121-to-D120 breaker lead at Beaver
- Description
- Upgrade 3500 SAC 127 B161 (2) breaker leads and (1) B121-to-D120 breaker lead at Beaver
- Total Cost ($USD)
- $191,109
- Allocated Cost ($USD)
- $13,690
- Time Estimate
- 11 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 19.4 MW | 7.2% | $13,690 |
AH1-690 | 212.1 MW | 78.5% | $149,954 |
AH1-711 | 38.8 MW | 14.4% | $27,465 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.g
- Title
- Upgrade (1) 4.00 SPS.AL PIPE at Beaver
- Description
- Upgrade (1) 4.00 SPS.AL PIPE at Beaver
- Total Cost ($USD)
- $178,089
- Allocated Cost ($USD)
- $12,367
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $12,367 |
AG2-165 | 8.9 MW | 2.2% | $3,896 |
AG2-212 | 8.9 MW | 2.2% | $3,896 |
AG2-328 | 8.9 MW | 2.2% | $3,896 |
AH1-690 | 297.6 MW | 73.1% | $130,151 |
AH1-711 | 54.6 MW | 13.4% | $23,885 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-021.j
- Title
- Upgrade (2) 2.50 SPS.AL PIPE SCCIR at Beaver
- Description
- Upgrade (2) 2.50 SPS.AL PIPE SCCIR at Beaver
- Total Cost ($USD)
- $173,391
- Allocated Cost ($USD)
- $12,041
- Time Estimate
- 12 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02LAKEAVE 345.0 kV Ckt 2 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 28.3 MW | 6.9% | $12,041 |
AG2-165 | 8.9 MW | 2.2% | $3,793 |
AG2-212 | 8.9 MW | 2.2% | $3,793 |
AG2-328 | 8.9 MW | 2.2% | $3,793 |
AH1-690 | 297.6 MW | 73.1% | $126,718 |
AH1-711 | 54.6 MW | 13.4% | $23,254 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-008.e
- Title
- Upgrade 3500 SAC B65 breaker leads and subconductor (D42 to wave trap) at Davis Besse
- Description
- Upgrade 3500 SAC B65 breaker leads and subconductor (D42 to wave trap) at Davis Besse
- Total Cost ($USD)
- $197,592
- Allocated Cost ($USD)
- $11,199
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02DAV-BE-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 22.2 MW | 5.7% | $11,199 |
AG2-165 | 7.9 MW | 2.0% | $3,992 |
AG2-212 | 7.9 MW | 2.0% | $3,992 |
AG2-328 | 7.9 MW | 2.0% | $3,992 |
AH1-690 | 290.3 MW | 74.1% | $146,470 |
AH1-711 | 55.4 MW | 14.1% | $27,948 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.l
- Title
- Upgrade (5) 4.00 SPS AL PIPE 61 sub conductors at BAYSHORE on the Bayshore - Davis Besse 345kV line
- Description
- Upgrade (5) 4.00 SPS AL PIPE 61 sub conductors at BAYSHORE on the Bayshore - Davis Besse 345kV line
- Total Cost ($USD)
- $246,545
- Allocated Cost ($USD)
- $10,686
- Time Estimate
- 14 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.3% | $8,104 |
AG2-149 | 24.2 MW | 4.3% | $10,686 |
AG2-165 | 9.0 MW | 1.6% | $4,002 |
AG2-212 | 9.0 MW | 1.6% | $4,002 |
AG2-328 | 9.0 MW | 1.6% | $4,002 |
AH1-690 | 441.8 MW | 79.3% | $195,449 |
AH1-711 | 45.9 MW | 8.2% | $20,299 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.c
- Title
- Upgrade 345kV 1033.5 AAC 61 sub conductors at Davis Besse substation at Davis Besse
- Description
- Upgrade 345kV 1033.5 AAC 61 sub conductors at Davis Besse substation at Davis Besse
- Total Cost ($USD)
- $257,762
- Allocated Cost ($USD)
- $10,418
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $7,900 |
AG2-149 | 24.2 MW | 4.0% | $10,418 |
AG2-165 | 9.0 MW | 1.5% | $3,902 |
AG2-212 | 9.0 MW | 1.5% | $3,902 |
AG2-328 | 9.0 MW | 1.5% | $3,902 |
AG2-363 | 10.7 MW | 1.8% | $4,597 |
AG2-364 | 7.1 MW | 1.2% | $3,065 |
AG2-660 | 1.2 MW | 0.2% | $513 |
AH1-044 | 7.1 MW | 1.2% | $3,076 |
AH1-150 | 7.1 MW | 1.2% | $3,076 |
AH1-151 | 7.1 MW | 1.2% | $3,076 |
AH1-690 | 441.8 MW | 73.9% | $190,544 |
AH1-711 | 45.9 MW | 7.7% | $19,790 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.e
- Title
- Upgrade 345kV 3500 SAC 127 sub conductor at Davis Besse
- Description
- Upgrade 345kV 3500 SAC 127 sub conductor at Davis Besse
- Total Cost ($USD)
- $257,762
- Allocated Cost ($USD)
- $10,418
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $7,900 |
AG2-149 | 24.2 MW | 4.0% | $10,418 |
AG2-165 | 9.0 MW | 1.5% | $3,902 |
AG2-212 | 9.0 MW | 1.5% | $3,902 |
AG2-328 | 9.0 MW | 1.5% | $3,902 |
AG2-363 | 10.7 MW | 1.8% | $4,597 |
AG2-364 | 7.1 MW | 1.2% | $3,065 |
AG2-660 | 1.2 MW | 0.2% | $513 |
AH1-044 | 7.1 MW | 1.2% | $3,076 |
AH1-150 | 7.1 MW | 1.2% | $3,076 |
AH1-151 | 7.1 MW | 1.2% | $3,076 |
AH1-690 | 441.8 MW | 73.9% | $190,544 |
AH1-711 | 45.9 MW | 7.7% | $19,790 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-020.c
- Title
- Upgrade 3000 AAC B185 and B185 breaker leads at Beaver
- Description
- Upgrade 3000 AAC B185 and B185 breaker leads at Beaver
- Total Cost ($USD)
- $187,449
- Allocated Cost ($USD)
- $10,195
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-AC2-103 TAP 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 15.9 MW | 3.9% | $7,322 |
AG2-149 | 22.1 MW | 5.4% | $10,195 |
AG2-165 | 7.9 MW | 1.9% | $3,628 |
AG2-212 | 7.9 MW | 1.9% | $3,628 |
AG2-328 | 7.9 MW | 1.9% | $3,628 |
AH1-690 | 290.0 MW | 71.3% | $133,565 |
AH1-711 | 55.3 MW | 13.6% | $25,484 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.b
- Title
- Upgrade 3500 SAC (2) B3 and (2) B6 breaker leads at Hayes
- Description
- Upgrade 3500 SAC (2) B3 and (2) B6 breaker leads at Hayes
- Total Cost ($USD)
- $152,573
- Allocated Cost ($USD)
- $8,880
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $8,880 |
AG2-165 | 8.3 MW | 2.0% | $3,052 |
AG2-212 | 8.3 MW | 2.0% | $3,052 |
AG2-328 | 8.3 MW | 2.0% | $3,052 |
AG2-660 | 1.0 MW | 0.3% | $387 |
AH1-044 | 6.3 MW | 1.5% | $2,321 |
AH1-150 | 6.3 MW | 1.5% | $2,321 |
AH1-151 | 6.3 MW | 1.5% | $2,321 |
AH1-690 | 288.2 MW | 69.8% | $106,511 |
AH1-711 | 55.9 MW | 13.6% | $20,676 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-014.e
- Title
- Upgrade the 1590 AAC (2) B88 and (2) B15 breaker leads at Beaver
- Description
- Upgrade the 1590 AAC (2) B88 and (2) B15 breaker leads at Beaver
- Total Cost ($USD)
- $152,573
- Allocated Cost ($USD)
- $8,880
- Time Estimate
- 18 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BEAVER-02HAYES 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-149 | 24.0 MW | 5.8% | $8,880 |
AG2-165 | 8.3 MW | 2.0% | $3,052 |
AG2-212 | 8.3 MW | 2.0% | $3,052 |
AG2-328 | 8.3 MW | 2.0% | $3,052 |
AG2-660 | 1.0 MW | 0.3% | $387 |
AH1-044 | 6.3 MW | 1.5% | $2,321 |
AH1-150 | 6.3 MW | 1.5% | $2,321 |
AH1-151 | 6.3 MW | 1.5% | $2,321 |
AH1-690 | 288.2 MW | 69.8% | $106,511 |
AH1-711 | 55.9 MW | 13.6% | $20,676 |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-002.h
- Title
- Upgrade (8) 1590 AAC 61 sub conductor at BAYSHORE
- Description
- Upgrade (8) 1590 AAC 61 sub conductor at BAYSHORE
- Total Cost ($USD)
- $211,119
- Allocated Cost ($USD)
- $8,533
- Time Estimate
- 13 Months
Contributor
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-02DAV-BE 345.0 kV Ckt 1 line | (Any) |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
AG2-029 | 18.3 MW | 3.1% | $6,471 |
AG2-149 | 24.2 MW | 4.0% | $8,533 |
AG2-165 | 9.0 MW | 1.5% | $3,196 |
AG2-212 | 9.0 MW | 1.5% | $3,196 |
AG2-328 | 9.0 MW | 1.5% | $3,196 |
AG2-363 | 10.7 MW | 1.8% | $3,766 |
AG2-364 | 7.1 MW | 1.2% | $2,510 |
AG2-660 | 1.2 MW | 0.2% | $420 |
AH1-044 | 7.1 MW | 1.2% | $2,520 |
AH1-150 | 7.1 MW | 1.2% | $2,520 |
AH1-151 | 7.1 MW | 1.2% | $2,520 |
AH1-690 | 441.8 MW | 73.9% | $156,064 |
AH1-711 | 45.9 MW | 7.7% | $16,209 |
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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) |
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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) | |
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 500.0 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- (Pending) / TC2-ATSI-017
- Title
- Upgrade (2) 2000A bus and line side disconnect switches at Bayshore
- Description
- Upgrade (2) 2000A bus and line side disconnect switches at Bayshore
- Total Cost ($USD)
- $948,616
- Allocated Cost ($USD)
- $0
- Time Estimate
- 36 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG2-149 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) AG2-149 could receive cost allocation. Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 02BAY SH-AH1-690 TP 345.0 kV Ckt 2 line | (Any) |
System Reinforcement: s3360.1
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- s3360.1
- Title
- Galion 138kV Upgrades
- Description
- - Replace 138 kV breakers B-52, B-55, B-58, B-59 and B-60 as well as circuit switchers CS-136 and CS-137. - Replace and install associated disconnect switches and protective relaying. - Replace limiting substation conductor.
- Cost Information
- Time Estimate
- Jun 01 2027
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 02GALION-02GALION 345.0/138.0 kV Ckt 3 transformer | (Any) | |
| 02GALION-02GALION 345.0/138.0 kV Ckt 4 transformer | (Any) |
System Reinforcement: s3469.1
- Type
- Load Flow
- TO
- ATSI
- RTEP ID / TO ID
- s3469.1 / ATSI-2024-024
- Title
- Rebuild the double circuit Galion – Roberts North 138 kV Line and Galion – Roberts South 138 kV Line
- Description
- Rebuild the double circuit Galion – Roberts North 138 kV Line and Galion – Roberts South 138 kV Line on shared structures. - Galion: replace circuit breakers and associated disconnect switches. - Roberts: replace substation conductor https://pjm.com/-/media/committees-groups/committees/teac/2024/20241008/20241008-informational-only---atsi-local-plan-submission-of-supplemental-project-2024.ashx
- Cost Information
- Time Estimate
- Aug 27 2026
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 02DUALR+-02ROBERT 138.0 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 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
Contingent Note: Although AG2-149 may not presently have cost responsibility for this upgrade, AG2-149 may need this upgrade in-service to be deliverable to the PJM system. If AG2-149 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 | |
|---|---|---|
| 01KAMMER-05KAMMER 500.0/765.0 kV Ckt 1 transformer | (Any) | |
| 01 502 J-01KAMMER 500.0 kV Ckt 1 line | (Any) |
Attachments
AG2-149 One Line Diagram
