AH1-552 Phase II System Impact Study Report
v1.00 released 2026-06-03 18:28
Chalk Point 230 kV
670.2 MW Capacity / 670.2 MW Energy
Introduction
This Phase II System Impact Study (SIS) Report has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 310 for New Service Requests (projects) in Transition Cycle 2 (TC2). The Project Developer/Eligible Customer (developer) is Chalk Point Reliability Storage LLC, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Potomac Electric Power Company.
Preface
The Phase II System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle summary format and (ii) an individual project-level basis. The Phase II System Impact Study Results (for both the summary and individual reports) will be publicly available on PJM’s website. Project Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.5, PJM takes the following actions during the Phase II System Impact Study:
- PJM will retool load flow results from the Phase I System Impact Study (summer peak, winter peak and light load) based on decisions made by Project Developers or Eligible Customers during Decision Point I.
- PJM will conduct any required voltage analyses.
- PJM will perform short circuit and stability analyses as required.
- PJM will coordinate with the Affected System to confirm which projects in the PJM Cycle will require Affected System studies. If the Affected System Operator indicates that an Affected System study is required, PJM will:
- Notify the Project Developer or Eligible Customer of the need for an Affected System study and the requirement to execute an Affected System study agreement with the impacted Affected System Operator, and;
- Include the results of the Affected System Operator’s Affected System Study in the Phase II System Impact Study results, if applicable and available.
- The Phase II System Impact Study Results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase II System Impact Study:
- Verify Interconnection Facilities and Network Upgrades required to accommodate the New Service Request.
- Perform a Facilities Study. The Facilities Study in Phase II System Impact Study phase will be for the physical Interconnection Facilities. The Facilities Study requirements are outlined in Attachment C of this manual. The study will be conducted pursuant to Tariff, Part VII, Subpart D, section 307(A)(7) and Tariff, Part VIII, Subpart C, section 404(A)(7).
Decision Point II Requirements
At the close of Phase II System Impact Study, PJM will initiate Decision Point II (DP2). During DP2, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.A. Additional information on these elements is available in PJM Manual 14H sections 4.6, 6, and 7.
Allowable project modifications at Decision Point II are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
Adverse Test Eligibility
This New Service Request meets the Adverse Study Impact Criteria and has the option to either move forward in the Cycle process or withdraw at DP2 with Readiness Deposits refunded. See Readiness Deposit calculation below.
This section details whether a Project Developer or Eligible Customer qualifies for the Adverse Study Impact clause outlined in the PJM OATT, Part VII, Subpart D, section 311.B and Manual 14H, section 6.2.2. In order to qualify for an Adverse Study Impact at Decision Point II, the Network Upgrade cost from Phase I to Phase II must:
- Increase overall by 25% or more
- Increases by more than $10,000 per MW (Includes Costs identified in Affected System studies)
If a New Service Request meets the criteria above and chooses to withdraw the request, PJM will refund the cumulative Readiness Deposit amounts paid at the Application Phase and at Decision Point I (RD1 and RD2, respectively).
The below calculations show the computation of this New Service Request's Adverse Study Impact
General
The Project Developer has proposed a Solar/Storage generating facility located in the Potomac Electric Power Company zone — Prince George's County, Maryland. The installed facilities will have a total capability of 670.2 MW with 670.2 MW of this output being recognized by PJM as Capacity.Project Information
Capacity Interconnection Rights (CIR) Transfer Details
This project intends to claim and transfer CIRs from the following Deactivation capacity generation resources. PJM performed a reliability analysis of the impacts to the system capability for the proposed transfer of CIRs from the Deactivation generation resources.
| Unit Name | Status | CIR Claimed | POI Transfer |
|---|---|---|---|
| Chalk Point Unit 1 | Deactivated Generator | 333.0 | No |
| Chalk Point Unit 2 | Deactivated Generator | 337.2 | No |
Physical Interconnection Facility Study
The transmission owner has completed the Physical Interconnection Facilities Study. This report is available for download.
Point of Interconnection
AH1-552 will interconnect with the Potomac Electric Power Company transmission system at the Chalk Point 230 kV Substation.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. In Phase II SIS, the interconnected Transmission Owner has performed a facilities study for both the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades. The System Reliability Network Upgrade shown in the table are planning level cost estimates which are subject to change as a result of a facility study performed by the TO during Phase III System Impact Study.
Based on the Phase II SIS results, the AH1-552 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit #3 are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AH1-552 | Cost Subject to Readiness* | Cost Subject to Adverse |
| Transmission Owner Interconnection Facilities (TOIF) | $134,199 | $0 | $0 |
| Other Scope | $0 | $0 | $0 |
| Option To Build Oversight | $0 | $0 | $0 |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $0 | $0 | $0 |
| Network Upgrades | $4,728,462 | $4,728,462 | $4,728,462 |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage | $10,000,000 | $10,000,000 | $10,000,000 |
| Transient Stability | $0 | $0 | $0 |
| Short Circuit | $0 | $0 | $0 |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | $0 |
| Distribution | $0 | $0 | $0 |
| Affected System Reinforcements | |||
| AFS - PJM Violations | $0 | $0 | $0 |
| AFS - Non-PJM Violations | $0 | $0 | $0 |
| Total | $14,862,661 | $14,728,462 | $14,728,462 |
* Contributes to calculation for Readiness Deposit #3 (RD3). See Readiness Deposit section of report for additional detail.
Definitions
Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.
Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.
Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.
Notes
Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.
Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.
Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.
Note 4: Please see the ‘Affected Systems Studies’ section of this Phase II SIS report for details on your project’s need for an Affected Systems Study. If your project requires an Affected Systems Study, the Affected Systems impacts may not be available from the Affected System Operator at the time of the PJM Phase II SIS. Therefore, the cost in this section would not reflect any required upgrades by the Affected System until the study is completed. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 311 (Decision Point II) A.1.b and PJM Manual 14H, section 6.2, Readiness Deposit #3 (RD3) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point II (DP2), the Project Developer or Eligible Customer is required to submit Readiness Deposit #3, which is calculated as 20% of cost allocation for required Phase II Network Upgrades minus Readiness Deposit #1 & Readiness Deposit #2.
Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.
Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (RD2) = 10% of cost allocation for required Network Upgrades minus RD1. Readiness Deposit #2 (RD2) can be zero, but may not be a negative number.
Note 4: Readiness Deposit #3 can be zero, but may not be a negative number.
Readiness Deposit #3 Due for Project AH1-552
Readiness Deposit #3 has been calculated for the project based on the Phase II System Impact Study results and is shown in the table below. This Readiness Deposit #3 must be provided at Decision Point II through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
Readiness Deposit #3 Due for AH1-552
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
Transmission Owner Build Option
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | Chalk Point 230kV Substation Upgrade | $2,368,996 | $1,576,618 | $374,887 | $407,961 | $4,728,462 | $4,728,462 |
| Transmission Owner Interconnection Facilities | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | PEPCO interconnection facilities for Chalk Point 230kV | $29,746 | $79,632 | $7,734 | $17,087 | $134,199 | $134,199 |
Developer Build Option
(No Developer Build Option for this project.)
| Build Option Price Comparison | |||||||
|---|---|---|---|---|---|---|---|
| Build Option | Total Cost | Allocated Cost | |||||
| Transmission Owner Build Option | $4,862,661 | $4,862,661 | |||||
| Developer Build Option | (No Developer Build Option) | ||||||
Based on the scope of work for the Interconnection Facilities, it is expected to take a range of 38 to 41 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.
Note that the TO findings were made from a conceptual review of this project. A more detailed review of the connection facilities and their cost will be identified in a future study phase. Further note that the cost estimate data provided should be considered high level estimates since it was produced without a detailed engineering review. The Project Developer will be responsible for the actual cost of construction. TO herein reserves the right to return to any issues in this document and, upon appropriate justification, request additional monies to complete any reinforcements to the transmission systems.
Remote Terminal Work: During Phase II of the PJM interconnection process, TO’s System Protection Engineering Department will review transmission line protection as well as anti-islanding required to accommodate the new generation and interconnection substation. System Protection Engineering will determine the minimal acceptable protection requirements to reliably interconnect the proposed generating facility with the transmission system. The review is based on maintaining system reliability by reviewing TO’s protection requirements with the known transmission system configuration which includes generating facilities in the area. This review may determine that transmission line protection and communication upgrades are required at remote substations.
Transmission Owner Analysis
No impacts identified by Transmission Owner.
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. PEPCO interconnection requirements can be found here.
To the extent that these Applicable Technical Requirements and Standards may conflict with the terms and conditions of the Tariff, the Tariff shall control.
Revenue Metering and SCADA Requirements
The developer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for their generating Resource. See PJM Manual 01, PJM Manual 14D, and PJM Tariff Part IX, Subpart B, Appendix 2, section 8.Meteorological Data Reporting Requirement
The solar generation facility shall provide the Transmission Provider with site-specific meteorological data including:Transmission Owner Requirements
- Temperature (degrees Fahrenheit)
- Atmospheric Pressure (hectopascals)
- Irradiance
- Forced outage data
The Project Developer will be required to comply with all interconnected Transmission Owner’s revenue metering requirements located at the following link: PJM - Transmission Owner Engineering & Construction Standards.
Summer Peak Analysis
The New Service Request AH1-552 was evaluated as a 670.2 MW (670.2 MW Capacity) injection in the PEPCO area.
AH1-552 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 670.2 MW (670.2 MW under study).
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
(No flowgates were eliminated after considering the topology reinforcements required by the cycle.)
Winter Peak Analysis
The New Service Request AH1-552 was evaluated as a 670.2 MW (670.2 MW Capacity) injection in the PEPCO area.
AH1-552 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 670.2 MW (670.2 MW under study).
Note: The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for single or N-1 contingencies and multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
(No flowgates were eliminated after considering the topology reinforcements required by the cycle.)
Light Load Analysis
The New Service Request AH1-552 was evaluated as a 670.2 MW injection and 670.2 MW withdrawal in the PEPCO area.
AH1-552 was evaluated as part of a plant. The plant consists of AH1-552. The total Energy output of the plant was evaluated at its maximum seasonal capability of 670.2 MW (0.0 MW under study).
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The energy portion, ramped up to a percentage of its full energy output based on season and fuel-specific ramping limits, of Generation Interconnection Requests are evaluated for multiple facility (common mode) contingencies (double circuit tower line, fault with a stuck breaker, and bus fault). For additional details regarding Generator Deliverability, reference PJM Manual 14B, Attachment C, Section C.3.
The following flowgates remain after considering the topology reinforcements required by the cycle.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | PEPCO | DICKH230-DICK 230 230.0 kV Ckt 1 line | PEPCO_P1_5070_SRT-A | Single | AC | 111.92 % | 680.0 | B | 761.05 | 37.99 |
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | PEPCO | DICKH230-DICK 230 230.0 kV Ckt 1 line | PEPCO_P1_PP2_SRT-A | Single | AC | 121.85 % | 680.0 | B | 828.55 | 41.94 | |
| GD2 | PEPCO | DICKH230-DICK 230 230.0 kV Ckt 2 line | PEPCO_P1_PP1_SRT-A | Single | AC | 121.85 % | 680.0 | B | 828.55 | 41.94 |
Short Circuit Analysis
Analysis Complete - No Issues
Based on PJM’s TC2 Phase II Short Circuit Analysis, this project did not contribute >1% fault duty to any previously identified overdutied breakers, nor did it cause any new overdutied breakers.
Please note that in TC2 Phase III, PJM will perform additional analysis including the evaluation of impacts from topology upgrades which may have potential effects on breaker duties not seen in the Phase II analysis.
Stability Analysis
Analysis Complete - No Issues
Executive Summary SP Analysis:
New Service Requests (projects) in PJM Transition Cycle 2, Cluster 91 are listed in Table 1 below. This report will cover the dynamic analysis of Cluster 91 projects.
This analysis is effectively a screening study to determine whether the addition of the Cluster 91 projects will meet the dynamics requirements of the NERC, PEPCO, and PJM reliability standards.
The load flow scenario for the analysis was based on the RTEP 2028 summer peak load case, modified to include applicable projects. Cluster 91 projects have been dispatched online at maximum power output, with 1.0 pu voltage at the terminal bus.
Cluster 91 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. A steady-state condition and 224 contingencies were studied, each with a 20 second simulation time period. Studied faults included:
- Steady-state operation (20 second run); (and with unsuccessful high-speed reclosing),
- Three-phase faults with normal clearing time;
- Single-phase bus faults with normal clearing time;
- Single-phase faults with stuck breaker;
- Three-phase faults with loss of multiple-circuit tower line; (and with unsuccessful high-speed reclosing).
There are no delayed (Zone 2) clearing faults due to dual primary relays being employed in the PEPCO 500/230 kV transmission system.
For all simulations, the queue project under study along with the rest of the PJM system were required to maintain synchronism, with all states returning to an acceptable new condition following the disturbance.
For all of the fault contingencies tested on the 2028 summer peak load case:
- Cluster 91 projects were able to ride through the faults (except for faults where protective action trips a generator(s)),
- The system with Cluster 91 projects included is transiently stable and post-contingency oscillations were positively damped with a damping margin of at least 3 % for interarea modes and 4 % for local modes.
- Following fault clearing, all bus voltages recovered to a minimum of 0.7 pu after 2.5 seconds (except where protective action isolates that bus).
- No transmission element tripped, other than those either directly connected or designed to trip as a consequence of that fault.
AG2-618 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer with the addition of a 5 MVAR customer planned capacitor bank.
AH1-552 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
AH1-744 meets the 0.9 lagging and 1.0 leading reactive power requirements with the addition of a customer planned 30 MVAR STATCOM device.
AG2-618 exhibited slow reactive power recovery for several contingencies. This issue did not result in system instability. The model was tuned to improve the reactive power settling time by updating the Kc parameter to 0.05 and setting the VCFlag to 0 in the REPCA1 module .
High voltage spikes occurred in the simulations immediately after fault clearing for some of the contingencies studied (i.e., fault where spike is observed). The voltage spike is a known artifact of the WECC generic renewable models as stated in the WECC Solar Plant Dynamic Model Guidelines : “It should be noted that generic dynamic models for inverter-based generator tend to produce a short-duration (a cycle or shorter) voltage spike at fault inception and clearing. These spikes should be ignored in most cases, as they do not represent the performance of actual hardware. They are simply a consequence of the model’s limited bandwidth, integration time step, and the way current injection models interface with the network solution.”
The IPCMD and IQCMD states in the REGCAU model of AG2-618 and AH1-552 showed erratic behavior for some contingencies in which these generators have been disconnected as part of the contingency event. Since the machine is disconnected and no active or reactive power is injected into the system, this behavior is likely fictitious and a limitation of the software. This does not cause instability in the system.
No mitigations were found to be required.
Table 1: Transition Cycle 2 Cluster 91 Queues
Cluster | Project | Fuel Type | Transmission Owner | MFO | MWE | MWC | Point of Interconnection |
91 | AG2-618 | Solar | PEPCO | 110.0 | 110 | 71.5 | Morgantown 230 kV Substation |
AH1-744 | Gas | PEPCO | 853.5 | 53.5 | 48.285 | Cheltenham 500 kV Line | |
AH1-552 | Hybrid | PEPCO | 670.2 | 670.2 | 670.2 | Chalk Point 230 kV Line |
Executive Summary LL Analysis:
New Service Requests (projects) in PJM Transition Cycle 2, Cluster 91 are listed in Table 1 below. This report will cover the dynamic analysis of Cluster 91 projects.
This analysis is effectively a screening study to determine whether the addition of the Cluster 91 projects will meet the dynamics requirements of the NERC, PEPCO, and PJM reliability standards.
The load flow scenario for the analysis was based on the RTEP 2028 light load case, modified to include applicable projects. Cluster 91 projects have been dispatched online at maximum power output, with 1.0 pu voltage at the terminal bus.
Cluster 91 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. A steady-state condition and 224 contingencies were studied, each with a 20 second simulation time period. Studied faults included:
- Steady-state operation (20 second run); (and with unsuccessful high-speed reclosing),
- Three-phase faults with normal clearing time;
- Single-phase bus faults with normal clearing time;
- Single-phase faults with stuck breaker;
- Three-phase faults with loss of multiple-circuit tower line; (and with unsuccessful high-speed reclosing).
There are no delayed (Zone 2) clearing faults due to dual primary relays being employed in the PEPCO 500/230 kV transmission system.
For all simulations, the queue project under study along with the rest of the PJM system were required to maintain synchronism, with all states returning to an acceptable new condition following the disturbance.
For all of the fault contingencies tested on the 2028 light load case:
- Cluster 91 projects were able to ride through the faults (except for faults where protective action trips a generator(s)),
- The system with Cluster 91 projects included is transiently stable and post-contingency oscillations were positively damped with a damping margin of at least 3 % for interarea modes and 4 % for local modes.
- Following fault clearing, all bus voltages recovered to a minimum of 0.7 pu after 2.5 seconds (except where protective action isolates that bus).
- No transmission element tripped, other than those either directly connected or designed to trip as a consequence of that fault.
AG2-618 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer with the addition of a 5 MVAR customer planned capacitor bank.
AH1-552 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
AH1-744 meets the 0.9 lagging and 1.0 leading reactive power requirements with the addition of a customer planned 30 MVAR STATCOM device.
AG2-618 exhibited slow reactive power recovery for several contingencies. This issue did not result in system instability. The model was tuned to improve the reactive power settling time by updating the Kc parameter to 0.05 and setting the VCFlag to 0 in the REPCA1 module .
High voltage spikes occurred in the simulations immediately after fault clearing for some of the contingencies studied (i.e., fault where spike is observed). The voltage spike is a known artifact of the WECC generic renewable models as stated in the WECC Solar Plant Dynamic Model Guidelines : “It should be noted that generic dynamic models for inverter-based generator tend to produce a short-duration (a cycle or shorter) voltage spike at fault inception and clearing. These spikes should be ignored in most cases, as they do not represent the performance of actual hardware. They are simply a consequence of the model’s limited bandwidth, integration time step, and the way current injection models interface with the network solution.”
The IPCMD and IQCMD states in the REGCAU model of AG2-618 and AH1-552 showed erratic behavior for some contingencies in which these generators have been disconnected as part of the contingency event. Since the machine is disconnected and no active or reactive power is injected into the system, this behavior is likely fictitious and a limitation of the software. This does not cause instability in the system.
No mitigations were found to be required.
Table 1: Transition Cycle 2 Cluster 91 Queues
Cluster | Project | Fuel Type | Transmission Owner | MFO | MWE | MWC | Point of Interconnection |
91 | AG2-618 | Solar | PEPCO | 110.0 | 110 | 71.5 | Morgantown 230 kV Substation |
AH1-744 | Gas | PEPCO | 853.5 | 53.5 | 48.285 | Cheltenham 500 kV Line | |
AH1-552 | Hybrid | PEPCO | 670.2 | 670.2 | 670.2 | Chalk Point 230 kV Line |
Reactive Power Analysis
Analysis Complete - No Issues
The reactive power capability of AH1-552 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
Steady-State Voltage Analysis
Analysis Complete - No Issues
Steady State Voltage Analysis complete, no voltage issues identified.
New Service Request Dependencies
The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.
| New Service Requests Dependencies | ||
|---|---|---|
| Project ID | Project Name | Status |
| AG1-063 | Fairhaven 13,8 kV | In Service |
| AG1-483 | Dickerson 230 kV | Engineering & Procurement |
| AG2-050 | Randle Cliff 13.8 kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, per Tariff Part VII.G.336 & Manual 14H, Section 13, PJM evaluated the potential impacts on tie line facilities between PJM and an affected system entity, which were identified per PJM planning analysis criteria. This upgrade may be required on the affected system portion of the tie line along with cost allocation of such upgrade if applicable, in coordination with the affected system. Depending on the affected system, this project may not be contingent on upgrade based on PJM planning analysis criteria, but may be contingent on this upgrade based on the Affected System Operator's planning criteria, provided in the Affected Systems Study Section, herein.
Affected System - Non-PJM Identified Violations
In accordance with PJM Tariff Part VII, Subpart D, section 310.A and as outlined in PJM Manual 14H, Sections 4.5 and 13, in Phase II of the Cycle, PJM provides the Affected System Operator any updates on the PJM projects that require an Affected Systems Study based on their response at DP1. New Service Requests that require an Affected Systems Study are required to enter into an Affected Systems Study Agreement with the Affected System Operator, as applicable, prior to the close of DP2 or they will be withdrawn from the Cycle.
If the Project Developer already entered into the necessary agreement and the results are available, PJM will supply them in the Phase II SIS report. See below for the status of any required Affected Systems Study. A status of “Pending” means that the study is not yet completed by the Affected System Operator. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
System Reinforcements
Based on the Phase II System Impact Study analysis results, this project is contingent on and may have cost responsibility for the following System Reinforcements:
| TO | RTEP ID | Title | Category | Allocated Cost ($USD) | Facilities Study |
|---|---|---|---|---|---|
| PEPCO | n9760.0 | Relocate Dickerson D to Quince Orchard 23033 to terminate at Dickerson H | Cost Allocated | $10,000,000 | N/A |
| BGE | b3780.5 | Build Solley Road substation + Statcom (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| PEPCO | b3780.11 | Brighton Statcom and Capacitor (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3780.6 | Build Granite substation + Statcom (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3800.37 | Replace terminal equipment limitations at Conastone 500 kV - on the (existing Peach Bottom-Conastone) or (new Graceton-Conastone) 500 kV line (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| PECO | b3800.49 | North Delta 500 kV termination for the Calpine generator (Calpine/Transource work). | Contingent | $0 | N/A |
| PECO | b3800.42 | Peach Bottom 500kV North bus upgrade (Projected ISD 12/1/2030) | Contingent | $0 | N/A |
| PECO | b3800.47 | Build new Peach Bottom South-North Delta 500 kV line (Projected ISD 12/1/2030) | Contingent | $0 | N/A |
| BGE | b3800.30 | High Ridge - Install two 500/230 kV transformers (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| BGE | b3800.28 | High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) -Brighton side (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| BGE | b3800.27 | High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) - Waugh Chapel side (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| BGE | b3800.26 | Build High Ridge 500 kV substation - Three bay breaker and half configuration (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| BGE | b3800.32 | Build new North Delta-High Ridge 500 kV line - BGE Portion (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| BGE | b3800.29 | High Ridge termination for the North Delta-High Ridge 500 kV line (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| PECO | b3737.47 | Build New North Delta 500 kV substation (Four bay breaker and half configuration) | Contingent | $0 | N/A |
| PECO | b3800.48 | North Delta termination for the North Delta-High Ridge 500 line (Transource work). | Contingent | $0 | N/A |
| PECO | b3800.44 | North Delta termination for the North Delta-High Ridge 500 line (PECO work). | Contingent | $0 | N/A |
| PECO | b3800.31 | Build new North Delta-High Ridge 500 kV line - PECO Portion (Projected ISD 12/1/2030) | Contingent | $0 | N/A |
| PECO | b3800.51 | North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (Transource work). | Contingent | $0 | N/A |
| PEPCO | b3800.46 | North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (PECO work). | Contingent | $0 | N/A |
| PECO | b3800.50 | North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (Transource work). | Contingent | $0 | N/A |
| PECO | b3800.45 | North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (PECO work). | Contingent | $0 | N/A |
| PECO | b3780.16 | Terminate new Cooper-North Delta 230 kV line (Transource Scope) at North Delta 230 kV | Contingent | $0 | N/A |
| PECO | b3780.14 | Reconfigure Cooper transmission feeds by establishing new Cooper-North Delta 230 kV line and rerouting existing transmissions lines by Cooper. | Contingent | $0 | N/A |
| PECO | b3800.52 | Reconfigure Peach Bottom North and South 500 kV yards (Projected ISD 12/1/2030) | Contingent | $0 | N/A |
| PECO | b3780.1 | Peach Bottom North upgrades – substation work (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3800.36 | Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton BGE) 500 kV (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| PECO | b3800.35 | Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton PECO) 500 kV (Projected ISD 12/1/2030) | Contingent | $0 | N/A |
| BGE | b3800.34 | Rebuild 5012 (existing Peach Bottom-Conastone) (new Graceton-Conastone) 500 kV and cut into North Delta 500kV (Projected ISD 12/31/2030) | Contingent | $0 | N/A |
| PECO | b3780.17 | Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub (Transource) | Contingent | $0 | N/A |
| PECO | b3780.15 | Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub | Contingent | $0 | N/A |
| BGE | b3780.13 | Batavia Road to Riverside 230 kV reconductor | Contingent | $0 | N/A |
| BGE | b3780.9 | Graceton to Batavia Road 230 kV double circuit pole line (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3780.8 | Graceton 500 kV substation expansion (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3780.7 | Build new Batavia Road substation (Projected ISD 12/31/2028) | Contingent | $0 | N/A |
| BGE | b3800.33 | Replace terminal equipment limitations at Brighton 500 kV - on the existing Brighton-Waugh Chapel 500 kV (5053) or new Brighton-High Ridge 500 kV. | Contingent | $0 | N/A |
| BGE | b3780.4 | Peach Bottom to Graceton (BGE Portion) – New 500kV Line | Contingent | $0 | N/A |
| PECO | b3780.2 | Peach Bottom to Graceton (PECO Portion) – New 500kV Line | Contingent | $0 | N/A |
| PEPCO | b3800.243 | Rebuild 7.26 miles of existing 500 kV circuit from Dickerson Station H to Ed's Ferry | Contingent | $0 | N/A |
| PEPCO | b3800.244 | Rebuild 7.26 miles of existing 230 kV circuit from Dickerson Station H to Ed's Ferry | Contingent | $0 | N/A |
| PEPCO | b3800.245 | Reconfigure Dickerson H 230 kV Substation and upgrade terminal equipment. | Contingent | $0 | N/A |
| Grand Total: | $10,000,000 | ||||
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement: n9760.0
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- n9760.0 / PECO_TC2_PH2
- Title
- Relocate Dickerson D to Quince Orchard 23033 to terminate at Dickerson H
- Description
- Relocate Dickerson D to Quince Orchard 23033 to terminate at Dickerson H
- Total Cost ($USD)
- $10,000,000
- Discounted Total Cost ($USD)
- $10,000,000
- Allocated Cost ($USD)
- $10,000,000
- Time Estimate
- 60 Months
Contributor
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AH1-552 | 41.9 MW | 100.0% | $10,000,000 |
System Reinforcement: b3780.5
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.5
- Title
- Build Solley Road substation + Statcom (Projected ISD 12/31/2028)
- Description
- Build Solley Road substation + Statcom. New STATCOM rating: 350 MVAR Add 4x 230 kV breakers bays.
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.11
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3780.11
- Title
- Brighton Statcom and Capacitor (Projected ISD 12/31/2028)
- Description
- Brighton Statcom and capacitor New STATCOM rating: 350 MVAR New capacitor rating: 350 MVAR
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.6
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.6
- Title
- Build Granite substation + Statcom (Projected ISD 12/31/2028)
- Description
- Build Granite substation + Statcom. New STATCOM rating: 350 MVAR. Add 4x 230 kV breaker bays.
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.37
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.37
- Title
- Replace terminal equipment limitations at Conastone 500 kV - on the (existing Peach Bottom-Conastone) or (new Graceton-Conastone) 500 kV line (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.49
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.49
- Title
- North Delta 500 kV termination for the Calpine generator (Calpine/Transource work).
- Description
- None
- Cost Information
- Time Estimate
- Oct 06 2027
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.42
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.42
- Title
- Peach Bottom 500kV North bus upgrade (Projected ISD 12/1/2030)
- Description
- Peach Bottom 500kV North bus upgrade - Replace 11 – Instances of strain bus conductor used for breaker drops or CT drops, 7 – 500 kV disconnect switches, 7 – Free Standing CTs, 1 – 500 kV breaker, 2 – Breaker relays or meters.
- Cost Information
- Time Estimate
- Dec 01 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.47
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.47
- Title
- Build new Peach Bottom South-North Delta 500 kV line (Projected ISD 12/1/2030)
- Description
- Build new Peach Bottom South-North Delta 500 kV line – cut in to Peach Bottom tie No. 1 and extending line to North Delta (~1.25 miles new ROW).
- Cost Information
- Time Estimate
- Jan 14 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.30
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.30
- Title
- High Ridge - Install two 500/230 kV transformers (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.28
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.28
- Title
- High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) -Brighton side (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.27
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.27
- Title
- High Ridge 500 kV substation (cut into Brighton-Waugh Chapel 500 kV line) - Waugh Chapel side (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.26
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.26
- Title
- Build High Ridge 500 kV substation - Three bay breaker and half configuration (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.32
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.32
- Title
- Build new North Delta-High Ridge 500 kV line - BGE Portion (Projected ISD 12/31/2030)
- Description
- Build new North Delta-High Ridge 500 kV line. (~59 miles)
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.29
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.29
- Title
- High Ridge termination for the North Delta-High Ridge 500 kV line (Projected ISD 12/31/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3737.47
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3737.47
- Title
- Build New North Delta 500 kV substation (Four bay breaker and half configuration)
- Description
- Build New North Delta 500 kV substation (four bay breaker and half configuration) - the substation will include 12 - 500kV breakers and one 500/230 kV transformer, will allow the termination of six - 500 kV lines
- Cost Information
- Time Estimate
- Oct 06 2027
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.48
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.48
- Title
- North Delta termination for the North Delta-High Ridge 500 line (Transource work).
- Description
- None
- Cost Information
- Time Estimate
- Dec 15 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.44
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.44
- Title
- North Delta termination for the North Delta-High Ridge 500 line (PECO work).
- Description
- None
- Cost Information
- Time Estimate
- Dec 15 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.31
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.31
- Title
- Build new North Delta-High Ridge 500 kV line - PECO Portion (Projected ISD 12/1/2030)
- Description
- None
- Cost Information
- Time Estimate
- Dec 15 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.51
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.51
- Title
- North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (Transource work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- May 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.46
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3800.46
- Title
- North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line (PECO work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Dec 11 2029
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.50
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.50
- Title
- North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (Transource work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Jan 23 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.45
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.45
- Title
- North Delta 500 kV termination for the Rock Springs 500 kV line (5034/5014 line) (PECO work).
- Description
- Loops in the 500kV line from Peach Bottom to Rock Springs into the new North Delta (Bramah) sub
- Cost Information
- Time Estimate
- Jan 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.16
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.16
- Title
- Terminate new Cooper-North Delta 230 kV line (Transource Scope) at North Delta 230 kV
- Description
- None
- Cost Information
- Time Estimate
- Oct 15 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.14
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.14
- Title
- Reconfigure Cooper transmission feeds by establishing new Cooper-North Delta 230 kV line and rerouting existing transmissions lines by Cooper.
- Description
- None
- Cost Information
- Time Estimate
- Oct 23 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.52
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.52
- Title
- Reconfigure Peach Bottom North and South 500 kV yards (Projected ISD 12/1/2030)
- Description
- Reconfigure Peach Bottom North and South yards to allow for termination of 500 kV lines from Peach Bottom to North Delta. North Delta 500 kV termination for the new Peach Bottom-North Delta 500 kV line.
- Cost Information
- Time Estimate
- Dec 01 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.1
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.1
- Title
- Peach Bottom North upgrades – substation work (Projected ISD 12/31/2028)
- Description
- Add 3x 500 kV breakers to form a breaker-and-a-half bay.
- Cost Information
- Time Estimate
- Oct 15 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.36
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.36
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton BGE) 500 kV (Projected ISD 12/31/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton BGE) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.35
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3800.35
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton PECO) 500 kV (Projected ISD 12/1/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new North Delta-Graceton PECO) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Apr 10 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.34
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.34
- Title
- Rebuild 5012 (existing Peach Bottom-Conastone) (new Graceton-Conastone) 500 kV and cut into North Delta 500kV (Projected ISD 12/31/2030)
- Description
- Rebuild 5012 (existing Peach Bottom-Conastone) (new Graceton-Conastone) 500 kV line on single circuit structures within existing ROW and cut into North Delta 500 kV and Gracetone 500 kV stations.
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.17
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.17
- Title
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub (Transource)
- Description
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV substation by rebuilding 5012 between new terminal at Peach Bottom South and North Delta on single circuit structures and terminating at North Delta (Transource Scope).
- Cost Information
- Time Estimate
- May 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.15
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.15
- Title
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV sub
- Description
- Cut in 5012 Peach Bottom-Conastone 500 kV line into North Delta 500/230 kV substation by rebuilding 5012 between new terminal at Peach Bottom South and North Delta on single circuit structures and terminating at North Delta.
- Cost Information
- Time Estimate
- Apr 10 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.13
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.13
- Title
- Batavia Road to Riverside 230 kV reconductor
- Description
- Batavia Road to Riverside 230 kV reconductor New rating: 1941 MVA SN / 2181 MVA SE
- Cost Information
- Time Estimate
- Dec 31 2027
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.9
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.9
- Title
- Graceton to Batavia Road 230 kV double circuit pole line (Projected ISD 12/31/2028)
- Description
- Graceton to Batavia Road 230 kV double circuit pole line New rating: 1331 MVA SN/ 1594 MVA SE
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.8
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.8
- Title
- Graceton 500 kV substation expansion (Projected ISD 12/31/2028)
- Description
- Add 3x 500 kV breaker bays, 2x 500/230 kV auto transformer, 1x 500 kV caps
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.7
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.7
- Title
- Build new Batavia Road substation (Projected ISD 12/31/2028)
- Description
- Build Batavia Road substation. Add 4 x 230kV breaker bays
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.33
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3800.33
- Title
- Replace terminal equipment limitations at Brighton 500 kV - on the existing Brighton-Waugh Chapel 500 kV (5053) or new Brighton-High Ridge 500 kV.
- Description
- None
- Cost Information
- Time Estimate
- Dec 31 2030
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.4
- Type
- Load Flow
- TO
- BGE
- RTEP ID / TO ID
- b3780.4
- Title
- Peach Bottom to Graceton (BGE Portion) – New 500kV Line
- Description
- New rating: 4503 MVA SN/ 5022 MVA SE. This is a baseline identified for the announced Brandon Shores deactivation.
- Cost Information
- Time Estimate
- Dec 31 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3780.2
- Type
- Load Flow
- TO
- PECO
- RTEP ID / TO ID
- b3780.2
- Title
- Peach Bottom to Graceton (PECO Portion) – New 500kV Line
- Description
- Peach Bottom to Graceton (PECO Portion) – New 500kV Line. New rating: 4503 MVA SN/ 5022 MVA SE. This is a baseline identified for the announced Brandon Shores deactivation.
- Cost Information
- Time Estimate
- Oct 23 2028
ContingentTopology Changing Note 1: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
| Facility | Contingency | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.243
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3800.243
- Title
- Rebuild 7.26 miles of existing 500 kV circuit from Dickerson Station H to Ed's Ferry
- Description
- Rebuild 7.26 miles of existing 500 kV circuit from Dickerson Station H to Ed's Ferry area to accommodate the new 500 kV circuit between Doubs and Aspen. (The 500 kV portion of the work)
- Cost Information
- Time Estimate
- Dec 31 2030
Contingent Note: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 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 | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.244
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3800.244
- Title
- Rebuild 7.26 miles of existing 230 kV circuit from Dickerson Station H to Ed's Ferry
- Description
- Rebuild 7.26 miles of existing 230 kV circuit from Dickerson Station H to Ed's Ferry area to accommodate the new 500 kV circuit between Doubs and Aspen. (The 230kV portion of the project)
- Cost Information
- Time Estimate
- Dec 31 2030
Contingent Note: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 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 | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
System Reinforcement: b3800.245
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- b3800.245
- Title
- Reconfigure Dickerson H 230 kV Substation and upgrade terminal equipment.
- Description
- Reconfigure Dickerson H 230 kV Substation and upgrade terminal equipment.
- Cost Information
- Time Estimate
- Dec 31 2030
Contingent Note: Although AH1-552 may not presently have cost responsibility for this upgrade, AH1-552 may need this upgrade in-service to be deliverable to the PJM system. If AH1-552 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 | ||
|---|---|---|---|
| DICK 230-DICKH230 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| DICK 230-DICKH230 230.0 kV Ckt 2 line | (Any) | No new ratings for this Flowgate. |
Attachments
AH1-552 One Line Diagram
