AH1-713 Phase I Study Report
v1.00 released 2025-10-29 21:26
Mt. Storm 500kV
14.0 MW Capacity / 0.0 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 Virginia Electric and Power Company (d/b/a) Dominion Energy Virginia, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Virginia Electric and Power Company (d/b/a Dominion Energy Virginia).
Preface
The Phase I System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase I System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.3, PJM takes the following actions during the Phase I System Impact Study:
- PJM studies each New Service Request on a summer peak, winter peak and light load RTEP base case study. The case year is dependent on the new services cycle under study. PJM will identify the base case year to be used in the study of a specific cycle on its website.
- PJM will only perform load flow analysis during the Phase I System Impact Study.
- In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with Affected System impacts and provides each Affected System Operator with a list of New Service Request in the Cycle with potential impacts to their respective system.
- PJM will create both the short circuit and stability base cases to be used in the Phase II System Impact Study.
- The Phase I System Impact Study results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase I System Impact Study:
- Identify required Interconnection Facilities to accommodate the New Service Request.
- Identify required Network Upgrades to mitigate system violations from the Phase I System Impact Study.
- Provide planning-level preliminary estimates of Interconnection Facilities and Network Upgrades including scope, cost and elapsed time to complete the work.
Decision Point I Requirements
At the close of Phase I System Impact Study, PJM will initiate Decision Point I (DP1). During DP1, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.A.1. Additional information on these elements is available in PJM Manual 14H sections 4.4, 6, and 7.
Allowable project modifications at Decision Point I are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
General
The Project Developer has proposed a Coal generating facility located in the Virginia Electric and Power Company (d/b/a Dominion Energy Virginia) zone — Grant County, West Virginia. The installed facilities will have a total capability of 538.0 MW with 14.0 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
AH1-713 will interconnect on the Virginia Electric and Power Company (d/b/a Dominion Energy Virginia) transmission system at the Mt. Storm 500 kV Substation.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. In the Phase I SIS, the costs shown are subject to change as a result of a facility study performed by the TO during the Phase II or Phase III System Impact Study.
Based on the Phase I SIS results, the AH1-713 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AH1-713 | 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 | $0 | $0 | |
| Network Upgrades | $0 | $0 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $0 | $0 | |
| 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 | $0 | $0 | |
* Contributes to calculation for Readiness Deposit #2 (RD2). See Readiness Deposit section of report for additional detail.
Definitions
Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.
Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.
Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.
Notes
Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.
Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.
Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim deliverability study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 309 (Decision Point I) A.1.a.i and PJM Manual 14H, section 6.2, Readiness Deposit #2 (RD2) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point I (DP1), the Project Developer or Eligible Customer is required to submit Readiness Deposit #2, which is calculated as 10% of cost allocation for required Phase I Network Upgrades minus Readiness Deposit #1.
Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.
Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (RD2) = 10% of cost allocation for required Network Upgrades minus RD1. Readiness Deposit #2 (RD2) can be zero, but may not be a negative number.
Readiness Deposit #2 Due for Project AH1-713
Readiness Deposit #2 has been calculated for the project based on the Phase I System Impact Study results and is shown in the table below. This Readiness Deposit #2 must be provided at Decision Point I through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
| Readiness Deposit | |||
|---|---|---|---|
| Project ID | 10% of cost allocation for Phase I Network Upgrades | Readiness Deposit #1 Received (RD1) | Readiness Deposit #2 (RD2) for AH1-713 Project due at DP1 |
| A | B | A - B | |
| AH1-713 | $0 | $56,000 | $0 |
Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
| Transmission Owner Interconnection Facilities | |||
|---|---|---|---|
| RTEP ID | Description | Total Cost ($USD) | Allocated Cost ($USD) |
| (Pending) | AH1-713 is sharing a POI and the TOIF with Mt.Storm Unit 3, so there are no associated interconnection costs for this project. | $0 | $0 |
Based on the scope of work for the Interconnection Facilities, it is expected to take a range of 50 to 54 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.
The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.
Transmission Owner Analysis
PJM performed a power flow analysis of the transmission system using a 2028 load flow model and the results were verified by Dominion.
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. Dominion interconnection requirements can be found here.
To the extent that these Applicable Technical Requirements and Standards may conflict with the terms and conditions of the Tariff, the Tariff shall control.
Revenue Metering and SCADA Requirements
The developer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for their generating Resource. See PJM Manual 01, PJM Manual 14D, and PJM Tariff Part IX, Subpart B, Appendix 2, section 8.Transmission Owner Requirements
The Project Developer will be required to comply with all interconnected Transmission Owner’s revenue metering requirements located at the following link: PJM - Transmission Owner Engineering & Construction Standards.
Summer Peak Analysis
The New Service Request AH1-713 was evaluated as a 0.0 MW (14.0 MW Capacity) injection in the Dominion area.
AH1-713 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 538.0 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.
| Study | Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD2 | DVP/PEPCO | 6EDFERRY-DICKH230 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019B_SRT-A | Breaker | AC | 131.46 % | 1417.0 | B | 1862.72 | 0.7 | |
| GD2 | DVP | 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019B_SRT-A | Breaker | AC | 105.55 % | 1809.0 | C | 1909.41 | 0.7 | |
| GD2 | DVP | 8FRONT ROYAL-8MORRSVL 500.0 kV Ckt 1 line | AP_P1-2_PE-500-404T_SRT-A | Single | AC | 103.1 % | 3220.44 | B | 3320.14 | 2.04 |
Winter Peak Analysis
The New Service Request AH1-713 was evaluated as a 0.0 MW (14.0 MW Capacity) injection in the Dominion area.
AH1-713 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 538.0 MW (0.0 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 AH1-713 was evaluated as a 0.0 MW injection
AH1-713 was evaluated as part of a plant. The total Energy output of the plant was evaluated at its maximum seasonal capability of 538.0 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.
(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 Required.
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 |
| AA1-139 | Hickory-Shawboro 230kV | In Service |
| AA2-178 | Mackeys 230kV | In Service |
| AA2-184 | Atlantic-Red Bank 34kV | In Service |
| AB1-001 | Absecon 12 kV | In Service |
| AB1-027 | Old Church 34.5 KV | In Service |
| AB1-096 | 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 |
| AB2-022 | Elizabeth City 34.5kV | In Service |
| AB2-024 | Correctional 34.5kV | In Service |
| AB2-025 | Sapony 34.5kV | In Service |
| AB2-026 | Powhatan 34.5kV | In Service |
| AB2-029 | Remington 34.5kV | In Service |
| AB2-032 | Church-Wye Mills 138 kV | In Service |
| AB2-037 | Keeney-Steele 230kV | Under Construction |
| AB2-045 | Buckingham 34.5kV | In Service |
| AB2-049 | Gloucester Township 12kV | In Service |
| AB2-133 | Chestertown 69kV | Under Construction |
| AB2-134 | Hopewell-Surry 230kV | In Service |
| AB2-135 | Church-Kent 69kV | In Service |
| AB2-136 | Cambridge-West Cambridge 69kV | Under Construction |
| AB2-153 | Church-Wye Mills 138 kV | In Service |
| AB2-157 | Prince George's County 12kV | In Service |
| AB2-158 | Louisa-South Anna 230kV | In Service |
| AB2-161 | Waverly #2 DP 115kV | In Service |
| AB2-179 | Townsend 138kV | In Service |
| AB2-190 | Hopewell-Surry 230kV | In Service |
| AC1-010 | Gloucester 26kV | Under Construction |
| AC1-017 | Levittown 13 kV | In Service |
| AC1-027 | Pendleton 34.5kV | In Service |
| AC1-030 | Cinnaminson 13kV | In Service |
| AC1-076 | Locust Grove-Paytes 115kV | 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 |
| AC1-118 | Westmoreland 34.5kV | In Service |
| AC1-120 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-121 | Mitchell-Mountain Run 115kV | Engineering & Procurement |
| AC1-147 | Grassfield 34.5kV | In Service |
| AC1-158 | Spotsylvania 500kV | In Service |
| AC1-161 | Septa 500kV | In Service |
| AC1-164 | Chickahominy 230kV | Partially in Service - Under Construction |
| AC1-191 | Elmont 115kV | Engineering & Procurement |
| AC2-012 | Grassfield-Great Bridge 115kV | In Service |
| AC2-023 | Hebron 69kV | Engineering & Procurement |
| AC2-079 | Ivor-Oak Ridge 115kV | Suspended |
| AC2-120 | Ripley 69kV | In Service |
| AC2-136 | East Hagerstown 12kV | Under Construction |
| AC2-137 | Elko 34.5kV | In Service |
| AC2-138 | Northern Neck 34.5kV | In Service |
| AC2-141 | Septa 500kV | Engineering & Procurement |
| AC2-165 | Bremo-Powhatan 230kV | Suspended |
| AC2-186 | Harrington 25kV | Under Construction |
| AC2-187 | Harrington 69kV | Under Construction |
| AC2-188 | Harrington 69 kV | Under Construction |
| AD1-020 | Hunterstown-Lincoln 115 kV | In Service |
| AD1-022 | Cashie-Trowbridge 230 kV | Engineering & Procurement |
| AD1-025 | Hopewell-Surry 230 kV | Under Construction |
| AD1-033 | Fentress-Landstown 230 kV | In Service |
| AD1-041 | Harmony Village-Shackleford 115 kV | In Service |
| AD1-060 | Mercersburg-Milnor 34.5 kV | In Service |
| AD1-061 | McConnelsburg-Mercersburg 34 kV | In Service |
| AD1-063 | Harmony Village 34.5 kV | In Service |
| AD1-074 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-075 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-076 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-082 | Bakers Pond-Ivor 115kV | In Service |
| AD1-105 | Kings Dominion DP 115 kV | Under Construction |
| AD1-115 | Mountain Run-Mitchell 115 kV | Engineering & Procurement |
| AD1-144 | Kings Fork 34.5 kV | In Service |
| AD1-151 | Hopewell-Surry 230 kV | Suspended |
| AD1-155 | Meadow Brook-Strasburg 138 kV | In Service |
| AD2-027 | Camden Switch 26 kV | In Service |
| AD2-030 | Wan 34.5 kV | In Service |
| AD2-042 | Camden Switch 26 kV II | In Service |
| AD2-058 | St. Barnabas 13 kV | In Service |
| AD2-065 | Atco 12 kV | In Service |
| AD2-070 | Gilbert-Morris Park 34.5kV | In Service |
| AD2-073 | Sanders DP 230 kV | In Service |
| AD2-074 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AD2-085 | Myrtle-Windsor DP 115kV | Engineering & Procurement |
| AD2-115 | Lyons-Moselem 69kV | In Service |
| AD2-116 | Hokes-Grantley 69 kV | In Service |
| AD2-135 | Williamstown 12kV | Partially in Service - Under Construction |
| AD2-160 | Hickory-Moyock 230kV | In Service |
| AE1-041 | Edison 4kV | In Service |
| AE1-071 | Shade Gap-Roxbury 115 kV | In Service |
| AE1-072 | Shawboro-Sligo 230 kV | Under Construction |
| AE1-074 | Winterpock 34.5 kV | Under Construction |
| AE1-075 | Powhatan 34.5 kV | In Service |
| AE1-081 | Landing 12.47 kV | In Service |
| AE1-101 | McConnellsburg-Texas Eastern 138 kV | In Service |
| AE1-103 | Holland-Union Camp 115 kV | Under Construction |
| AE1-142 | Manitou-Pleasant Plains 34.5 kV | In Service |
| AE1-149 | Disputanta-Poe 115 kV | Suspended |
| AE1-153 | Remington-Gordonsville 230 kV | Suspended |
| AE1-155 | Garner-Northern Neck 115 kV | In Service |
| AE1-156 | Quakertown Solar II 34.5 kV | Partially in Service - Under Construction |
| AE1-157 | Ladysmith CT-St. Johns 230 kV | Suspended |
| AE1-162 | Smithfield 34.5 kV | In Service |
| AE1-173 | Carson-Suffolk 500 kV | Under Construction |
| AE1-175 | Light Foot 34.5 kV | In Service |
| AE1-185 | Hokes-Jackson 69 kV | In Service |
| AE1-190 | Harmony Village-Shackleford 115 kV | Partially in Service - Under Construction |
| AE1-191 | Harmony Village-Shackleford 115 kV | Partially in Service - Under Construction |
| AE1-196 | Hokes-Jackson 69 kV II | In Service |
| AE1-229 | Deepwater-Upper Pittsgrove 138 kV | Suspended |
| AE2-005 | Harmony Village-Shackleford 115 kV | Under Construction |
| AE2-019 | New Road 230 kV | Under Construction |
| AE2-027 | Harrowgate-Locks 115kV | Under Construction |
| AE2-033 | Clubhouse-Sapony 230 kV | Suspended |
| AE2-034 | Mackeys 230 kV | Partially in Service - Under Construction |
| AE2-042 | Milton 69 kV | In Service |
| AE2-051 | Carson-Septa 500 kV | Engineering & Procurement |
| AE2-054 | Warfordsburg 34 kV | In Service |
| AE2-059 | Derry Tap-Derry Bus 69 kV | In Service |
| AE2-060 | Mifflintown Bus-Mifflintown Tap 69 kV | In Service |
| AE2-094 | Carson-Rogers Road 500 kV | Engineering & Procurement |
| AE2-104 | Suffolk 115 kV | Suspended |
| AE2-133 | Penns Tap-Richfield Tie 69 kV | In Service |
| AE2-175 | Jackson-Long Pond 69 kV | Partially in Service - Under Construction |
| AE2-212 | Harrowgate 34 kV | Engineering & Procurement |
| AE2-230 | Bartonsville-Meadow Brook 138 kV | In Service |
| AE2-253 | Hickory-Moyock 230 kV | In Service |
| AF1-007 | Indian River 230 kV I | Suspended |
| AF1-014 | Harmony Village-Shackleford 115 kV | Under Construction |
| AF1-017 | Myrtle-Windsor 115 kV | Engineering & Procurement |
| AF1-032 | Suffolk 34.5 kV | In Service |
| AF1-042 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AF1-069 | Carson-Rogers Rd 500 kV | Engineering & Procurement |
| AF1-114 | Oak Grove-Dahlgren 230 kV | Engineering & Procurement |
| AF1-123 | Harper 230 kV | Active |
| AF1-124 | Harper 230 kV | Active |
| AF1-125 | Harper 230 kV | Active |
| AF1-128 | Chesterfield 230 kV | Active |
| AF1-129 | Chesterfield 230 kV | Engineering & Procurement |
| AF1-147 | Poland Rd-Runway DP 230kV | Under Construction |
| AF1-254 | Milnor-Huyetts 34.5 kV | Under Construction |
| AF1-262 | Upper Pittsgrove 12 kV | In Service |
| AF1-264 | Runnemede 13 kV | In Service |
| AF1-291 | Tyler 34.5 kV | Engineering & Procurement |
| AF1-291A | Bartonsville-Meadow Brook 138 kV | In Service |
| AF1-299 | Otter Point 34.5 kV I | In Service |
| AF1-300 | Otter Point 34.5 kV II | In Service |
| AF1-320 | Merrill Creek 115 kV | Engineering & Procurement |
| AF1-333 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-337 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-338 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF1-339 | Laurelton-Mifflinburg 69 kV | Engineering & Procurement |
| AF2-035 | St. Johns 115 kV | Active |
| AF2-042 | Clover-Rawlings 500 kV | Active |
| AF2-043 | Suffolk 34.5 kV | In Service |
| AF2-046 | Tunis-Mapleton 115 kV | Active |
| AF2-054 | Wan 34.5 kV | In Service |
| AF2-075 | Bartonsville-Meadow Brook 138 kV III | In Service |
| AF2-077 | White Marsh 34.5 kV | In Service |
| AF2-081 | Moyock 230 kV | Active |
| AF2-086 | Scott Tap-Bowmans Mill Tap 69 kV | Engineering & Procurement |
| AF2-091 | Oak Grove-Dahlgren 230 kV | Engineering & Procurement |
| AF2-110 | Suffolk 115 kV | Suspended |
| AF2-120 | Garner-Northern Neck 115 kV | Active |
| AF2-138 | Flanders-West Wharton 34.5 kV | In Service |
| AF2-139 | Gilbert-Warren Glen 34.5 kV | In Service |
| AF2-144 | Powhatan 34.5 kV | In Service |
| AF2-192 | Frenchtown Solar-West Flemington 34.5 kV | Suspended |
| AF2-229 | Roxbury 23 kV | Engineering & Procurement |
| AF2-233 | Penns-Richfield Tie #1 69 kV | Engineering & Procurement |
| AF2-234 | Sunbury Yard #1-Richfield Tie #2 69 kV | Engineering & Procurement |
| AF2-247 | Bustleton 13.2 kV | In Service |
| AF2-250 | Edgewood 12 kV III | In Service |
| AF2-325 | Jacktown 12 kV | Engineering & Procurement |
| AF2-354 | Washington 34.5 kV II | Engineering & Procurement |
| AF2-361 | Mifflintown Tap 69 kV | Engineering & Procurement |
| AF2-378 | Cambridge 12 kV | Engineering & Procurement |
| AF2-379 | Princess Anne 25 kV | Under Construction |
| AF2-383 | Tolna 115 kV | Withdrawn |
| AF2-417 | West Damascus Tap-West Damascus 69 kV | Engineering & Procurement |
| AF2-421 | East Hazelton-Weatherly Tap 69 | Engineering & Procurement |
| AF2-424 | Reed-Reed Tap #1 69 kV | Engineering & Procurement |
| AF2-425 | Reed-Reed Tap#1 69 kV | Engineering & Procurement |
| AF2-433 | Columbia-Geisinger Tap #1 69 kV | Engineering & Procurement |
| AF2-434 | Columbia-Geisinger Tap #1 69 kV | Engineering & Procurement |
| AG1-008 | Tunis-Mapleton 115 kV | Active |
| AG1-038 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AG1-045 | Redbud-Gaylord 34.5 kV | Suspended |
| AG1-135 | Garner-Lancaster 115 kV | Active |
| AG1-145 | Lightfoot 34.5 kV | In Service |
| AG1-146 | Garner DP-Lancaster 115 kV | Active |
| AG1-147 | Garner DP-Lancaster 115 kV | Active |
| AG1-156 | Jack Frost-Lake Harmony 69 kV | Engineering & Procurement |
| AG1-164 | East Hazelton-Weatherly Tap 69 kV | Engineering & Procurement |
| AG1-165 | East Hazelton-Weatherly Tap 69 kV | Engineering & Procurement |
| AG1-188 | Manitou-Oyster Creek 34.5 kV | Engineering & Procurement |
| AG1-189 | Oyster Creek-Bamber Lake 34.5 | Engineering & Procurement |
| AG1-191 | Chester-Pohatcong Mountain 34.5 kV | Partially in Service - Under Construction |
| AG1-221 | Poland Rd-Runway DP 230 kV | Under Construction |
| AG1-223 | Larrabee-Allaire 34.5 kV | Under Construction |
| AG1-254 | Salem-Woodstown 69 kV | Engineering & Procurement |
| AG1-259 | Sunbury-Dalmatia 69 kV | Engineering & Procurement |
| AG1-260 | Sunbury-Dalmatia 69 kV | Engineering & Procurement |
| AG1-282 | Dunnsville 34.5 kV | Engineering & Procurement |
| AG1-307 | Old Chapel-Millville 138 kV | Engineering & Procurement |
| AG1-348 | Pequest River-Washington 34.5 kV | In Service |
| AG1-393 | Sapony 34.5 kV | Active |
| AG1-394 | Boykins 34.5 kV | Active |
| AG1-397 | Walston 12 kV | Withdrawn |
| AG1-415 | Double Toll Gate-Old Chapel 138 kV | Engineering & Procurement |
| AG1-469 | Gordonsville 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 |
| AG1-558 | Buckner 34.5 kV | Engineering & Procurement |
| AG1-559 | Caroline Pines 22 kV | Engineering & Procurement |
| AG2-005 | Garner DP-Lancaster 115 kV | Active |
| AG2-049 | Van Dorn 34.5 kV | Active |
| AG2-068 | Heritage - Wake 500 kV | Active |
| AG2-069 | Heritage - Wake 500 kV | Active |
| AG2-077 | Clover-Rawlings 500 kV | Active |
| AG2-086 | Mt. Jackson DP-Mt. Jackson 115 kV | Active |
| AG2-093 | Colonial Trail-Hopewell 230 kV | Active |
| AG2-095 | Hopewell 34.5 kV (Circuit 313) | Active |
| AG2-188 | Farmville - Buckingham 230 kV | Active |
| AG2-193 | Turner 34.5 kV | Active |
| AG2-198 | Briery - Finneywood 230 kV | Active |
| AG2-208 | Greenwood DP - St. Johns DP 115 kV | Active |
| AG2-300 | Meadow Brook 138 kV | Active |
| AG2-304 | Liberty 230 kV | Active |
| AG2-369 | Heritage - Wake 500 kV | Active |
| AG2-382 | Cashie 230 kV | Active |
| AG2-403 | Meadow Brook - Mt. Storm 500 kV | Active |
| AG2-404 | Meadow Brook - Mt. Storm 500 kV II | Active |
| AG2-426 | Wakefield - Waverly 115 kV | Active |
| AG2-427 | Waverly 115 kV | Active |
| AG2-428 | Wakefield 115 kV | Active |
| AG2-436 | Carson - Rogers Road 500 kV | Active |
| AG2-469 | Westmoreland – Oak Grove 230 kV | Active |
| AG2-566 | Briery - Finneywood 230 kV | Active |
| AG2-570 | Heritage - Wake 500 kV | Active |
| AG2-571 | Heritage - Wake 500 kV | Active |
| AG2-581 | Rawlings-Clover 500 kV | Active |
| AG2-583 | Bremo - Cartersville 230 kV | Active |
| AG2-661 | Hopewell - Colonial Trail 230 kV | Active |
| AH1-033 | Sligo 34.5 kV | Active |
| AH1-035 | Plymouth 34.5 kV | Active |
| AH1-040 | Mackeys - Creswell 115 kV | Active |
| AH1-042 | Providence Forge-Turner 115kV | Active |
| AH1-071 | Midlothian 34.5 kV | Active |
| AH1-106 | Winterpock 34.5kV | Active |
| AH1-107 | Winterpock 34.5kV | Active |
| AH1-108 | Spruance NUG 230 kV | Active |
| AH1-138 | Penniman 34.5 kV | Active |
| AH1-216 | Smithfield-Surry 230 kV | Active |
| AH1-223 | Poland Rd-Runway DP 230 kV | Active |
| AH1-254 | Greenland Gap 500 kV II | Active |
| AH1-271 | Cashie 230 kV | Active |
| AH1-283 | Mount Storm-Pruntytown 500kV | Active |
| AH1-324 | Colonial Trail – Surry 230 kV | Active |
| AH1-345 | Remington 324 34.5 kV | Active |
| AH1-377 | Clover- Farmville 230kV | Active |
| AH1-387 | Meadowbrook-Greenland Gap 500kV | Active |
| AH1-397 | Shacklesford 34.5 kV | Active |
| AH1-399 | North Doswell 12.5 kV | Active |
| AH1-439 | Buckingham- Farmville 230kV | Active |
| AH1-528 | Rawlings - Unity 500 kV | Active |
| AH1-546 | Bremo - Buckingham 230 kV | Active |
| AH1-637 | Oak Grove 34.5 kV | Active |
| AH1-676 | Gordonsville 230 kV | Active |
| AH1-677 | Rogers Road 500 kV | Active |
| AH1-678 | Heritage 500 kV | Active |
| AH1-679 | Four Rivers 230 kV | Active |
| AH1-681 | Cunningham 500 kV | Active |
| AH1-682 | Ladysmith CT 230 kV | Active |
| AH1-683 | Ladysmith CT 230 kV | Active |
| AH1-684 | Remington CT 230 kV | Active |
| AH1-685 | Remington CT 230 kV | Active |
| AH1-687 | Bear Garden 230kV | Active |
| AH1-691 | Ladysmith CT 230 kV | Active |
| AH1-692 | Ladysmith CT 230 kV | Active |
| AH1-693 | Remington CT 230 kV | Active |
| AH1-694 | Ladysmith CT 230 kV | Active |
| AH1-696 | Possum Point 230kV | Active |
| AH1-712 | Cunningham 500 kV | Active |
| AH1-717 | Surry 230kV | Active |
| AH1-723 | Cunningham 500 kV | Active |
| AH1-729 | Ocean Court 230 kV | Active |
| V4-067 | Cates Road Egg Harbor Township 12kV | Deactivated |
| V4-068 | Murphy's 34.5kV | 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 |
| W1-130 | Vine Road 12kV | In Service |
| W2-030 | Egg Harbor Township | In Service |
| W3-077 | Broadway-Stewartsville 34.5kV | In Service |
| X3-066 | Church Hill 69kV | In Service |
| Y1-079 | Wye Mills 69kV | In Service |
| Y1-080 | Dorchester 12kV | In Service |
| Y1-086 | Morgans Corner | In Service |
| Y3-058 | Rockawalkin 69kV | In Service |
| Z1-036 | WinFall-Chowan 230kV | In Service |
| Z2-027 | Pasquotank 34.5kV | In Service |
| Z2-076 | Worcester South 25kV | In Service |
| Z2-077 | Worcester North 25kV | In Service |
Affected System - PJM Identified Violations
As part of PJM's analysis, PJM evaluated the potential impacts on tie line facilities between PJM and an affected system entity, which were identified per PJM planning analysis criteria. This upgrade may be required on the affected system portion of the tie line along with cost allocation of such upgrade if applicable, in coordination with the affected system. Depending on the affected system, this project may not be contingent on upgrade based on PJM planning analysis criteria, but may be contingent on this upgrade based on the Affected System Operator's planning criteria, provided in the Affected Systems Study Section, herein.
Affected System - Non-PJM Identified Violations
In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with potential Affected System impacts. PJM initiates coordination with each Affected System Operator by providing a list of New Service Requests in the Cycle with potential impacts to their respective system. If the Affected System Operator indicates an Affected System Study is required, PJM will notify the Project Developer or Eligible Customer of the need for an Affected System Study. See below if any Affected System Operator requires a study for this project:
System Reinforcements
No cost allocated system reinforcements were identified for this project in the Phase I System Impact Study load flow analysis.
Shown below are the details of the cost allocated, contingent, eliminated, topology and potential aggregate contributor reinforcements for this project. Please refer to the System Reinforcement table above and the information below for more detail.
System Reinforcement: b4000.327
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.327
- Title
- Upgrade/install equipment at Ladysmith Substation to 4000A. Expansion will be required to accommodate a total of three (3) new 230 kV strings of breaker and a half scheme.
- Description
- Upgrade/install equipment at Ladysmith substation to 4000A. Expansion will be required to accommodate a total of three (3) new 230kV strings of breaker and a half scheme.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.348
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.348
- Title
- Build a new 500/230kV substation called Kraken. The 500kV, 5000A ring bus will be set up for a redundant breaker configuration. Install (2) 1400MVA 500/230 kV transformers.
- Description
- Build a new 500/230kV substation called Kraken. The 500kV, 5000A ring bus will be set up for a redundant breaker configuration. Install (2) 1400MVA 500/230 kV transformers. A new redundant breaker ring will be added at Kraken to accommodate the new 500kV line from North Anna to Kraken.
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.341
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.341
- Title
- Remove the 500 kV conductor previously planned to terminate into the Vint Hill 500 kV Substation and extend approximately 0.2 miles of conductor to fly-over the site.
- Description
- Remove the 500 kV conductor previously planned to terminate into the Vint Hill 500 kV substation and extend approximately 0.2 miles of conductor to fly-over the site.
- Cost Information
- Time Estimate
- Jul 13 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.357
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.357
- Title
- Build a new 765/500/230 kV substation called Yeat. Install (2) 765/500 kV transformers. Cut in 500 kV line Bristers-Ox and 500 kV line Meadowbrook-Vint Hill into Yeat.
- Description
- Build a new 765/500/230 kV substation called Yeat. Install (2) 765/500 kV transformers. Cut in 500 kV line Bristers-Ox and 500 kV line Meadowbrook-Vint Hill into Yeat.
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.349
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.349
- Title
- Update relay settings at Ladysmith to change the destination of 500kV line #568 from Possum Point to Kraken.
- Description
- Update relay settings at Ladysmith to change the destination of 500kV line #568 from Possum Point to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.352
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.352
- Title
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating new Line #568 Kraken to Possum Point.
- Description
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating new Line #568 Kraken to Possum Point.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.344
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.344
- Title
- Build a 500kV line from North Anna substation (bypassing Ladysmith Substation) to a new substation called Kraken. New conductor to have a minimum summer normal rating of 4357MVA.
- Description
- Build a 500kV line from North Anna substation (bypassing Ladysmith Substation) to a new substation called Kraken. New conductor to have a minimum summer normal rating of 4357MVA.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.325
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.325
- Title
- Build a new 26.38mi 230kV Line from Elmont – Ladysmith on the existing 5-2 structures between the two stations. New conductor has a summer rating of 1573 MVA.
- Description
- Build a new 26.38mi 230kV Line from Elmont – Ladysmith on the existing 5-2 structures between the two stations. New conductor has a summer rating of 1573 MVA.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.346
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.346
- Title
- Cut-in 500kV line from Kraken substation into Yeat substation
- Description
- Cut-in 500kV line from Kraken substation into Yeat substation
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.356
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.356
- Title
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 86.7 miles in Dominion section).
- Description
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 86.7 miles in Dominion section).
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.345
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.345
- Title
- Build a 500kV line from a new substation called Kraken to a new substation called Yeat. New conductor to have a minimum summer normal rating of 4357MVA.
- Description
- Build a 500kV line from a new substation called Kraken to a new substation called Yeat. New conductor to have a minimum summer normal rating of 4357MVA.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.351
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.351
- Title
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating Line #9517 Ladysmith to Kraken.
- Description
- Cut in Line #568 Ladysmith - Possum Point into Kraken, creating Line #9517 Ladysmith to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.326
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.326
- Title
- At Elmont substation, install/upgrade associated equipment to accommodate a 4000A line rating for the new 230kV line between Elmont - Ladysmith.
- Description
- At Elmont substation, install/upgrade associated equipment to accommodate a 4000A line rating for the new 230kV line between Elmont - Ladysmith.
- Cost Information
- Time Estimate
- Feb 24 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.342
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.342
- Title
- Remove the terminal equipment and substation work required for the termination of the Morrisville-Wishing Star 500 kV line into Vint Hill.
- Description
- Remove the terminal equipment and substation work required for the termination of the Morrisville-Wishing Star 500 kV line into Vint Hill.
- Cost Information
- Time Estimate
- Jul 13 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.355
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.355
- Title
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 69.3 miles in AEP section).
- Description
- Build a new 156 mile 765kV line from Joshua Falls – Yeat. (Roughly 69.3 miles in AEP section).
- Cost Information
- Time Estimate
- Jun 01 2029
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement: b4000.350
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b4000.350
- Title
- Update relay settings at Possum Point to change the destination of 500kV line #568 from Ladysmith to Kraken.
- Description
- Update relay settings at Possum Point to change the destination of 500kV line #568 from Ladysmith to Kraken.
- Cost Information
- Time Estimate
- Sep 16 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| 8MORRSVL-8FRONT ROYAL 500.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC2-PH1-DOM-2097
- Title
- Build a new 11.95 mile line from Aspen 230 kV to Dickerson 230 kV with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C.
- Description
- Build a new 11.95 mile line from Aspen 230 kV to Dickerson 230 kV with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C.
- Total Cost ($USD)
- $33,230,000
- Allocated Cost ($USD)
- $0
- Time Estimate
- 48 to 60 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AH1-713 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) AH1-713 could receive cost allocation. Although AH1-713 may not presently have cost responsibility for this upgrade, AH1-713 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | (Any) | |
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | PEPCO_P1_5070_SRT-A | |
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019B_SRT-A | |
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019F_SRT-SL | |
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | AP_P1-2_PE-500-406T_SRT-A | |
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019F_SRT-SL | |
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | AP_P2-3_PE-500-019B_SRT-A | |
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | PEPCO_P1_5070_SRT-A | |
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | (Any) |
System Reinforcement: b3800.242
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.242
- Title
- Upgrading switches 20366M and 20369M and line leads to 4000A continuous current rating of 230kV Line #203 at Edwards Ferry substation
- Description
- Upgrading switches 20366M and 20369M and line leads to 4000A continuous current rating of 230kV Line #203 at Edwards Ferry substation
- Cost Information
- Time Estimate
- Sep 13 2030
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | (Any) |
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 area to accommodate the new 500 kV circuit between Doubs and Aspen. (The 230kV portion of the project)
- 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
Not Contingent Note: AH1-713 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AH1-713 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.
| Facility | Contingency | |
|---|---|---|
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | (Any) |
System Reinforcement
- Type
- Load Flow
- TO
- PEPCO
- RTEP ID / TO ID
- (Pending) / (Pending)
- Title
- Additional Aspen to Dickerson H 230 kV line
- Description
- PEPCO’s substation cost to accommodate an additional circuit at Dickerson H to be approximately $7.86 million. The cost for the remaining 7.25 miles of 230 kV transmission line is estimated at $78.62 million.
- Total Cost ($USD)
- $86,480,000
- Allocated Cost ($USD)
- $0
- Time Estimate
- 24 to 48 Months
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AH1-713 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) AH1-713 could receive cost allocation. Although AH1-713 may not presently have cost responsibility for this upgrade, AH1-713 is a potential Aggregate Pool Contributor.
| Facility | Contingency | |
|---|---|---|
| DICKH230-6EDFERRY 230.0 kV Ckt 1 line | (Any) | |
| 6TWINCREEK-6EDFERRY 230.0 kV Ckt 1 line | (Any) |
Attachments
AH1-713 One Line Diagram
