AF1-123 Final System Impact Study (Retool 1) Report
v1.00 released 2025-12-08 18:17
Harper 230 kV
253.2 MW Capacity / 833.0 MW Energy
Introduction
This Final System Impact Study (SIS) Report has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 314 for New Service Requests (projects) in Transition Cycle 1 (TC1). 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 Final 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 Final 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 5, Final Agreement Negotiation Phase, the purpose of the Final Agreement Negotiation Phase is to:
- Negotiate, execute and enter into the applicable final interconnection related service agreement found in Tariff, Part IX;
- Conduct any remaining analyses or updated analyses based on New Service Requests withdrawn during Decision Point III (DP3); and
- Adjust the security obligation based on New Service Requests withdrawn during Decision Point III and/or during the Final Agreement Negotiation Phase.
Retool 1:
In accordance with PJM Tariff Part VII.D 314 B(1)(a), Final Agreement Negotiation Phase:
- PJM will perform a retool (Retool 1) after the conclusion of DP3 considering only the TC1 projects moving on in the Final Agreement Negotiation Phase (Removes DP3 withdrawals).
- The Final System Impact Study reflecting results from the retooled analysis (Retool 1) will be publicly available on PJM’s website; Project Developers and Eligible Customers must obtain the results from the website.
- PJM will provide updated final electronic agreements to Project Developers and Eligible Customers in the Cycle reflecting updates from the Final System Impact Study after Retool 1 including the adjusted Security requirements.
Retool 2 (if needed):
If particular New Service Requests do not sign their final agreements after receiving the updated information after Retool 1, there may be the need to run a second retool (Retool 2) to identify if any network upgrades are no longer necessary:
- PJM will perform Retool 2 (if necessary) considering only the removal of TC1 projects from the model which chose not to execute their agreements after Retool 1.
- The updated Final System Impact Study reflecting results from Retool 2 will be publicly available on PJM’s website; Project Developers and Eligible Customers must obtain the results from the website.
- If there are any adjustments to the agreements required after Retool 2, the necessary network upgrade or Security changes will be handled via the scope change process post-GIA.
General
The Project Developer has proposed a Offshore Wind generating facility located in the Virginia Electric and Power Company (d/b/a Dominion Energy Virginia) zone — City of Chesapeake County, Virginia. The installed facilities will have a total capability of 833.0 MW with 253.2 MW of this output being recognized by PJM as Capacity.Project Information
Physical Interconnection Facility Study
The transmission owner has completed the Physical Interconnection Facilities Study. This report is available for download.
Point of Interconnection
AF1-123, AF1-124 and AF1-125 will interconnect on the Dominion transmission system at the Harpers 230 kV Substation.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. The Facilities Studies for the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades were performed by the Transmission Owner in Phase II. Facilities Studies are available for download on PJM.com (see General Section for document links). The Interconnected Transmission Owner has performed a Facilities Study for the required System Reliability Network Upgrades in Phase III (see System Reinforcement Section for document links).
Based on the Final SIS results, the AF1-123 project has the following allocation of costs for interconnection. The Security amount required after the Final SIS and revised agreements is also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AF1-123 | Cost Subject to Security* | |
| Transmission Owner Interconnection Facilities (TOIF) | $7,308,561 | $7,308,561 | |
| Other Scope | $0 | $0 | |
| Option To Build Oversight | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $98,140,632 | $98,140,632 | |
| Network Upgrades | $151,928,890 | $151,928,890 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $234,799,638 | $234,799,638 | |
| Transient Stability | $28,851,095 | $28,851,095 | |
| 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 | $521,028,816 | $521,028,816 | |
* Contributes to calculation for Security. See Security Section of this 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, 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.
Security Requirement
Per Tariff Part VII, Subpart D, section 314 (Final Agreement Negotiation Phase) A.1 and PJM Manual 14H, Section 5, if a Transition Cycle 1 New Service Request is withdrawn during Decision Point III and/or the Final Agreement Negotiation Phase, PJM shall remove the New Service Request from the Cycle and adjust the Security obligations of other New Service Requests based on the withdrawal. The Final System Impact Study results will reflect the updated Security amount for this project. Security may be in the form of cash, letter of credit, or other form of Security acceptable to PJM (see PJM M14H, Section 6.4).
Security is calculated for a New Service Request based on the Network Upgrade costs allocated pursuant to the Final System Impact Study results.
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.
Security Due for AF1-123
Security has been calculated for the AF1-123 project(s) based on the Final System Impact Study results and is shown in the table below. This Security must be provided at Final SIS through either a wire transfer or letter of credit or other form of Security deemed acceptable by PJM per Manual 14H, Section 6.4.
Security Due for AF1-123
In accordance with Tariff, Part VII, Subpart D, section 314(B)(4)(a) (Final Agreement Negotiation Phase) failure to provide any required adjustments to Security within the 15 Business Day period will result in the New Service Request project being terminated and withdrawn.
Please see the cover letter for more details on Letter of Credit/Wire details to satisfy the additional Security requirement.
If no additional Security is required, please coordinate with your assigned Project Manager to initiate any refunds of Security reductions.
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 Scope
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| n8317.1 | Expand Fentress 500 kV and 230 kV substations to terminate three new 230 kV lines from Harpers Road substation and connect them to Fentress 500 kV | $32,089,434 | $188,729,124 | $3,121,660 | $2,604,178 | $226,544,396 | $75,514,799 (See Note 1) |
| n8317.2 | Construct three (3) overhead 230kV transmission lines that will start at the existing Fentress Substation and terminate at the new Harpers Road Substation, located approximately 14.3 miles away | $87,809,759 | $122,418,217 | $7,002,882 | $12,011,417 | $229,242,275 | $76,414,092 (See Note 1) |
| Stand-Alone Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| n8317.3 | Build new 230 kV Harpers Road switching station to terminate nine offshore wind export cables for AF1-123/124/125 and consolidate to three overhead 230 kV transmission lines to go to Fentress Substation | $54,931,535 | $211,895,213 | $9,823,673 | $17,771,475 | $294,421,896 | $98,140,632 (See Note 1) |
| Transmission Owner Interconnection Facilities | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) | Install 230 kV backbone structures and foundations within the fence of the Interconnection Substation, to terminate the Project Developer’s generator lead lines. Line conductor from the backbone structure to the bus position in the switchyard of the interconnection substation. | $497,960 | $6,185,453 | $105,765 | $519,383 | $7,308,561 | $7,308,561 |
Based on the scope of work for the Interconnection Facilities, it is expected to take 10 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.
Note 1: A Common Use Upgrade is a Network Upgrade that is needed for the interconnection of Generating Facilities or Merchant Transmission Facilities of more than one Project Developer or Eligible Customer and which is the shared responsibility of each Project Developer or Eligible Customer. If multiple Project Developers request to connect to the same interconnection substation, the Transmission Owner will determine the cost to accommodate all the requests at the substation. The cost for the interconnection will be allocated in proportion to the number of required terminations into the substation.
Transmission Owner Analysis
PJM performed a power flow analysis of the transmission system using a 2027 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.Meteorological Data Reporting Requirement
The wind generation facility shall provide the Transmission Provider with site-specific meteorological data including:Transmission Owner Requirements
- Wind speed (meters/second) - (Required)
- Wind direction (decimal degrees from true north) - (Required)
- Ambient air temperature (Fahrenheit) - (Required)
- Air Pressure (Hectopascals) - (Required)
- Humidity (Percent) - (Accepted, not required)
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 AF1-123 was evaluated as a 833.0 MW (253.2 MW Capacity) injection in the Dominion area.
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The full energy output of Generation Interconnection Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6CHESTF B-6BASIN 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S | Breaker | AC | 142.63 % | 812.0 | C | 1158.14 | 45.5 | |
| GD1 | DVP | 6CHESTF B-6BASIN 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | Single | AC | 133.85 % | 663.64 | B | 888.27 | 15.42 | |
| GD1 | DVP | 6CHESTF B-6BASIN 230.0 kV Ckt 1 line | DVP_P1-2: LN 217_SRT-A | Single | AC | 109.77 % | 663.64 | B | 728.5 | 13.02 | |
| GD1 | DVP | 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | DVP_P4-2: H2T557_SRT-S | Breaker | AC | 132.14 % | 1065.0 | C | 1407.28 | 118.15 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P4-2: 224022-1_SRT-S | Breaker | AC | 145.91 % | 830.0 | C | 1211.04 | 225.28 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P4-2: 224022-2_SRT-S | Breaker | AC | 145.75 % | 830.0 | C | 1209.69 | 225.07 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 271_SRT-A | Single | AC | 107.49 % | 678.68 | B | 729.5 | 64.01 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 2240_SRT-A | Single | AC | 104.51 % | 678.68 | B | 709.27 | 64.04 | |
| GD1 | DVP | 6LADYSMITH-8LADYSMITH 230.0/500.0 kV Ckt 1 transformer | DVP_P4-2: H2T574_SRT-S_SENS | Breaker | AC | 134.99 % | 1031.0 | C | 1391.73 | 70.29 | |
| GD1 | DVP | 6POCATY-6LANDSTN 230.0 kV Ckt 1 line | DVP_P4-2: 2110T2128_SRT-A | Breaker | AC | 122.86 % | 830.0 | C | 1019.7 | 129.09 | |
| GD1 | DVP | 6POCATY-6LANDSTN 230.0 kV Ckt 1 line | DVP_P4-2: 212822_SRT-S | Breaker | AC | 120.29 % | 830.0 | C | 998.4 | 159.65 | |
| GD1 | DVP | 6POCATY-6LANDSTN 230.0 kV Ckt 1 line | DVP_P4-2: 269T2128_SRT-S | Breaker | AC | 116.98 % | 830.0 | C | 970.97 | 150.24 | |
| GD1 | DVP | 8CARSON-6CARSON 500.0/230.0 kV Ckt 2 transformer | DVP_P4-2: 56372_SRT-S | Breaker | AC | 113.54 % | 1056.8 | C | 1199.86 | 56.25 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | DVP_P4-2: 557T574_SRT-S | Breaker | AC | 106.16 % | 3940.0 | C | 4182.74 | 232.3 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | DVP_P7-1: ELMONT-LADYSMITH_500_230_SRT-A | Tower | AC | 104.22 % | 3940.0 | C | 4106.12 | 210.95 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | DVP_P4-2: H1T567_SRT-A | Breaker | AC | 103.44 % | 3940.0 | C | 4075.55 | 236.44 | |
| GD1 | DVP | 8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A | Single | AC | 100.39 % | 1058.16 | B | 1062.25 | 19.12 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P7-1: ELMONT-LADYSMITH_500_230_SRT-A | Tower | AC | 108.98 % | 3940.0 | C | 4293.98 | 238.65 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P4-2: 557T574_SRT-S | Breaker | AC | 104.85 % | 3940.0 | C | 4130.98 | 241.02 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P4-2: H2T574_SRT-S_SENS | Breaker | AC | 102.96 % | 3940.0 | C | 4056.76 | 224.3 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S_SENS | Single | AC | 102.07 % | 3220.44 | B | 3287.01 | 66.22 | |
| GD1 | DVP | 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line | DVP_P4-2: 56372_SRT-S | Breaker | AC | 102.59 % | 3144.0 | C | 3225.32 | 249.63 | |
| GD1 | DVP | 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line | DVP_P4-2: H6T576_SRT-A | Breaker | AC | 102.48 % | 3144.0 | C | 3221.97 | 251.24 | |
| GD1 | DVP | 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line | DVP_P4-2: H6T563_SRT-S | Breaker | AC | 102.48 % | 3144.0 | C | 3221.97 | 251.24 | |
| GD1 | DVP | 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line | DVP_P4-2: 563T576_SRT-S | Breaker | AC | 102.48 % | 3144.0 | C | 3221.81 | 251.24 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6FOUR RIVERS-6STJOHN 230.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | Single | AC | 107.9 % | 1123.3 | B | 1212.05 | 20.7 | |
| GD1 | DVP | 6STJOHN-AE1-157 TP 230.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | Single | AC | 101.4 % | 1123.3 | B | 1139.01 | 20.7 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | DVP_P4-2: H2T574_SRT-S | Breaker | AC | 113.38 % | 3940.0 | C | 4467.2 | 205.21 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | Single | AC | 103.8 % | 3220.44 | B | 3342.68 | 61.96 | |
| GD1 | DVP | 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line | DVP_P4-2: 563T576_SRT-S | Breaker | AC | 104.31 % | 3637.0 | C | 3793.69 | 275.47 | |
| GD1 | DVP | 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | Single | AC | 111.92 % | 4070.2 | B | 4555.56 | 80.21 | |
| GD1 | DVP | 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S | Breaker | AC | 111.48 % | 5011.0 | C | 5586.28 | 263.8 | |
| GD1 | DVP | 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | Single | AC | 101.04 % | 4070.2 | B | 4112.5 | 69.29 | |
| GD1 | DVP | 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | DVP_P4-2: 545T552_SRT-S | Breaker | AC | 107.93 % | 3940.0 | C | 4252.57 | 136.37 | |
| GD1 | DVP | 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | DVP_P1-2: LN 581_SRT-S | Single | AC | 100.32 % | 3220.44 | B | 3230.79 | 39.81 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | Single | AC | 119.82 % | 3220.44 | B | 3858.59 | 68.98 | |
| GD1 | DVP | 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | DVP_P4-2: H2T574_SRT-S | Breaker | AC | 117.79 % | 3940.0 | C | 4641.11 | 229.4 | |
| GD1 | DVP | 8MORRSVL-8LOUDOUN 500.0 kV Ckt 1 line | DVP_P4-2: H3T539_SRT-A | Breaker | AC | 105.76 % | 3532.0 | C | 3735.42 | 96.96 | |
| GD1 | DVP | 8MORRSVL-8LOUDOUN 500.0 kV Ckt 1 line | DVP_P4-2: H1T539_SRT-S | Breaker | AC | 105.47 % | 3532.0 | C | 3725.16 | 96.78 | |
| GD1 | DVP | 8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 594_SRT-S | Single | AC | 111.38 % | 3220.44 | B | 3586.78 | 32.05 | |
| GD1 | DVP | 8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 573_SRT-A | Single | AC | 111.09 % | 3220.44 | B | 3577.61 | 34.1 | |
| GD1 | DVP | 8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: SPOTS H1T594_SRT-S | Breaker | AC | 110.41 % | 3940.0 | C | 4350.17 | 111.42 | |
| GD1 | DVP | 8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: H1T594_SRT-S | Breaker | AC | 106.75 % | 3940.0 | C | 4205.81 | 105.71 | |
| GD1 | DVP | 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | DVP_P1-2: LN 575_SRT-S | Single | AC | 116.97 % | 3220.44 | B | 3767.03 | 40.9 | |
| GD1 | DVP | 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | DVP_P1-2: LN 581_SRT-S | Single | AC | 114.22 % | 3220.44 | B | 3678.49 | 51.28 | |
| GD1 | DVP | 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | DVP_P4-2: 568T575_SRT-A | Breaker | AC | 111.99 % | 3940.0 | C | 4412.36 | 141.64 | |
| GD1 | DVP | 8OX-8CLIFTON 500.0 kV Ckt 1 line | DVP_P7-1: LN 2101-569_SRT-S | Tower | AC | 105.43 % | 3144.0 | C | 3314.57 | 97.5 | |
| GD1 | DVP | 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line | DVP_P1-2: LN 575_SRT-S | Single | AC | 121.18 % | 3220.44 | B | 3902.62 | 39.91 | |
| GD1 | DVP | 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line | DVP_P1-2: LN 552_SRT-S | Single | AC | 120.07 % | 3220.44 | B | 3866.79 | 50.22 | |
| GD1 | DVP | 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line | DVP_P4-2: 568T575_SRT-A | Breaker | AC | 117.55 % | 3940.0 | C | 4631.32 | 139.41 |
Summer Potential Congestion due to Local Energy Deliverability
PJM also studied the delivery of the energy portion of this interconnection request. Any problems identified below are likely to result in operational restrictions to the project under study. The developer can proceed with network upgrades to eliminate the operational restriction at their discretion by submitting an Upgrade Request into the New Service Request process.
Note: Only the most severely overloaded conditions are listed below. There is no guarantee of full delivery of energy for this project by fixing only the conditions listed in this section. With an Upgrade Request, a subsequent analysis will be performed which shall study all overload conditions associated with the overloaded element(s) identified.
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6CHARCTY-6LAKESIDE 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 100.11 % | 984.18 | B | 985.29 | 49.46 | |
| GD1 | DVP | 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 567_SRT-A | OP | AC | 117.72 % | 934.92 | B | 1100.62 | 89.38 | |
| GD1 | DVP | 6CHESTF A-6IRON208 230.0 kV Ckt 1 line | DVP_P1-2: LN 557_SRT-S | OP | AC | 119.65 % | 663.64 | B | 794.05 | 48.08 | |
| GD1 | DVP | 6CHESTF B-6VARINA 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 103.74 % | 984.18 | B | 1020.96 | 49.46 | |
| GD1 | DVP | 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | DVP_P1-2: LN 557_SRT-S | OP | AC | 108.08 % | 879.84 | B | 950.94 | 79.9 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | Base Case | OP | AC | 120.66 % | 678.68 | A | 818.89 | 163.87 | |
| GD1 | DVP | 6IRON208-6SOUWEST 230.0 kV Ckt 1 line | DVP_P1-2: LN 557_SRT-S | OP | AC | 110.61 % | 663.64 | B | 734.04 | 48.02 | |
| GD1 | DVP | 6LADYSMITH-8LADYSMITH 230.0/500.0 kV Ckt 2 transformer | DVP_P1-2: LN 574_SRT-S_SENS | OP | AC | 103.88 % | 889.43 | B | 923.97 | 46.62 | |
| GD1 | DVP | 6NRTHEST-6ELMONT 230.0 kV Ckt 1 line | DVP_P1-2: LN 557_SRT-S | OP | AC | 117.46 % | 678.68 | B | 797.16 | 64.39 | |
| GD1 | DVP | 6VARINA-6CHARCTY 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 103.68 % | 984.18 | B | 1020.42 | 49.46 | |
| GD1 | DVP | 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | Base Case | OP | AC | 104.12 % | 3220.44 | A | 3352.99 | 169.01 | |
| GD1 | DVP | 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 136.21 % | 2442.12 | B | 3326.4 | 261.5 | |
| GD1 | DVP | 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | OP | AC | 115.81 % | 4070.2 | B | 4713.59 | 251.43 | |
| GD1 | DVP | 8LADYSMITH-8KRAKEN 500.0 kV Ckt 1 line | DVP_P1-2: LN 581_SRT-S | OP | AC | 113.6 % | 3220.44 | B | 3658.56 | 160.72 | |
| GD1 | DVP | 8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A | OP | AC | 126.88 % | 1058.16 | B | 1342.55 | 62.9 | |
| GD1 | DVP | 8SEPTA-8SURRY 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 106.42 % | 2442.12 | B | 2598.93 | 150.16 | |
| GD1 | DVP | 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line | DVP_P1-2: LN 552_SRT-S | OP | AC | 105.3 % | 3220.44 | B | 3390.97 | 140.11 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6FENT1-8FENTRES 230.0/500.0 kV Ckt 1 transformer | DVP P1-3: 8FENTRESS 500 - 6FENT1 230 XFMR 3_SRT-A | OP | AC | 112.51 % | 1130.82 | B | 1272.23 | 416.5 | |
| GD1 | DVP | 6FENT1-8FENTRES 230.0/500.0 kV Ckt 2 transformer | DVP P1-3: 8FENTRESS 500 - 6FENT1 230 XFMR 1_SRT-A | OP | AC | 112.51 % | 1130.82 | B | 1272.23 | 416.5 | |
| GD1 | DVP | 6FENT1-8FENTRES 230.0/500.0 kV Ckt 3 transformer | DVP P1-3: 8FENTRESS 500 - 6FENT1 230 XFMR 1_SRT-A | OP | AC | 112.51 % | 1130.82 | B | 1272.23 | 416.5 | |
| GD1 | DVP | 6FOUR RIVERS-6STJOHN 230.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | OP | AC | 128.71 % | 1123.3 | B | 1445.82 | 68.09 | |
| GD1 | DVP | 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 563_SRT-S-1 | OP | AC | 111.78 % | 1058.16 | B | 1182.78 | 64.16 | |
| GD1 | DVP | 6POCATY-6LANDSTN 230.0 kV Ckt 1 line | DVP_P1-2: LN 588_SRT-A | OP | AC | 160.69 % | 678.68 | B | 1090.58 | 239.99 | |
| GD1 | DVP | 6STJOHN-AE1-157 TP 230.0 kV Ckt 1 line | DVP_P1-2: LN 574_SRT-S | OP | AC | 121.31 % | 1123.3 | B | 1362.65 | 68.09 | |
| GD1 | DVP | 8CHANCE-8BRISTER 500.0 kV Ckt 1 line | DVP_P1-2: LN 594_SRT-S | OP | AC | 103.49 % | 4070.2 | B | 4212.31 | 160.96 | |
| GD1 | DVP | 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line | Base Case | OP | AC | 104.11 % | 2442.12 | A | 2542.46 | 215.85 | |
| GD1 | DVP | 8FENTRES-6FENTRES 500.0/230.0 kV Ckt 1 transformer | DVP_P1-2: LN 588_SRT-A | OP | AC | 117.03 % | 1115.59 | B | 1305.6 | 419.08 | |
| GD1 | DVP | 8FENTRES-6FENTRES 500.0/230.0 kV Ckt 2 transformer | DVP_P1-2: LN 588_SRT-A | OP | AC | 116.88 % | 1103.28 | B | 1289.51 | 413.92 | |
| GD1 | DVP | 8LADYSMITH-8CHANCE 500.0 kV Ckt 1 line | DVP_P1-2: LN 573_SRT-A | OP | AC | 103.53 % | 4070.2 | B | 4213.9 | 164.08 | |
| GD1 | DVP | 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line | Base Case | OP | AC | 104.94 % | 3220.44 | A | 3379.54 | 120.36 |
Winter Peak Analysis
PJM will start performing Winter Peak analysis in Transition Cycle 2.
Winter Potential Congestion due to Local Energy Deliverability
PJM will start performing Winter Peak analysis in Transition Cycle 2.
Light Load Analysis
The New Service Request AF1-123 was evaluated as a 833.0 MW injection in the Dominion area.
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The full energy output of Generation Interconnection Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6BREMO-6BREMODIST 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | Single | AC | 113.52 % | 678.68 | B | 770.46 | 33.86 | |
| GD1 | DVP | 6BREMO-6BREMODIST 230.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | Single | AC | 106.87 % | 678.68 | B | 725.29 | 37.16 | |
| GD1 | DVP | 6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | Single | AC | 113.06 % | 678.68 | B | 767.3 | 33.86 | |
| GD1 | DVP | 6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | Single | AC | 106.41 % | 678.68 | B | 722.16 | 37.16 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 271_SRT-A | Single | AC | 111.0 % | 678.68 | B | 753.35 | 168.32 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 2240_SRT-A | Single | AC | 111.0 % | 678.68 | B | 753.33 | 168.32 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 3BREMO-3FORK UNION 115.0 kV Ckt 2 line | DVP_P1-2: LN 2193_SRT-A | Single | AC | 112.33 % | 134.42 | B | 151.0 | 7.0 | |
| GD1 | DVP | 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | Single | AC | 110.03 % | 661.76 | B | 728.15 | 34.74 | |
| GD1 | DVP | 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | Single | AC | 101.32 % | 661.76 | B | 670.5 | 36.25 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 588_SRT-A | Single | AC | 155.94 % | 678.68 | B | 1058.33 | 378.92 | |
| GD1 | DVP | 6FORK UNION-6CUNNING 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | Single | AC | 111.3 % | 661.76 | B | 736.51 | 34.74 | |
| GD1 | DVP | 6FORK UNION-6CUNNING 230.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A | Single | AC | 102.58 % | 661.76 | B | 678.83 | 36.25 | |
| GD1 | DVP | 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | Single | AC | 108.36 % | 661.76 | B | 717.07 | 34.74 |
Light Load Potential Congestion due to Local Energy Deliverability
PJM also studied the delivery of the energy portion of this interconnection request. Any problems identified below are likely to result in operational restrictions to the project under study. The developer can proceed with network upgrades to eliminate the operational restriction at their discretion by submitting an Upgrade Request into the New Service Request process.
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 6BREMO-6BREMODIST 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | OP | AC | 108.48 % | 678.68 | B | 736.22 | 33.86 | |
| GD1 | DVP | 6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | OP | AC | 108.04 % | 678.68 | B | 733.22 | 33.86 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 271_SRT-A | OP | AC | 109.46 % | 678.68 | B | 742.85 | 168.32 |
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 | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| GD1 | DVP | 3BREMO-3FORK UNION 115.0 kV Ckt 2 line | DVP_P1-2: LN 2193_SRT-A | OP | AC | 112.33 % | 134.42 | B | 151.0 | 7.0 | |
| GD1 | DVP | 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | OP | AC | 103.72 % | 661.76 | B | 686.41 | 34.74 | |
| GD1 | DVP | 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | DVP_P1-2: LN 588_SRT-A | OP | AC | 155.94 % | 678.68 | B | 1058.33 | 378.92 | |
| GD1 | DVP | 6FORK UNION-6CUNNING 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | OP | AC | 105.01 % | 661.76 | B | 694.91 | 34.74 | |
| GD1 | DVP | 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line | DVP_P1-2: LN 534_SRT-L | OP | AC | 102.08 % | 661.76 | B | 675.51 | 34.74 |
Short Circuit Analysis
Based on PJM’s Short Circuit Analysis, this project did not contribute >1% fault duty to previously identified overdutied breakers, nor did it cause any new overdutied breakers.
Stability Analysis
Analysis Complete - Issues Found
Executive Summary for Dynamic Stability Analysis using PSSE
New Service Requests (projects) in PJM Transition Cycle 1 Cluster 29 are listed in Table 1 below. This report will cover the dynamic analysis of Cluster 29 projects.
Table 1: Transition Cycle 1 Cluster 29 Projects |
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Cluster | Project | Fuel Type | Transmission Owner | MFO (MW) | MWE (MW) | MWC (MW) | Point of Interconnection |
29 | AF1-123 | Wind | Dominion | 833 | 833 | 253.2 | Harper 230 kV |
AF1-124 | Wind | Dominion | 836 | 836 | 254.1 | Harper 230 kV | |
AF1-125 | Wind | Dominion | 820 | 820 | 249.3 | Harper 230 kV |
This analysis is effectively a screening study to determine whether the addition of the Cluster 29 projects will meet the dynamics requirements of the NERC, Dominion Energy, and PJM reliability standards.
The load flow case finalized for Phase 2 was used as a starting point and was updated based on latest Cluster 29 data, Dominion Energy recommended transmission changes and withdrawn generation. Projects in vicinity of Cluster 29 have been dispatched online at maximum power output with near unity power factor measured at the high-side of the main substation transformer. The dynamic models for Cluster 29 projects were updated based on the latest DP2 data and include any tuning adjustments recommended during Phase 2.
This analysis currently was performed using the PSSE library models provided the developer. Dominion Energy Transmission provided the models for the FACT’s devices for the AF1-123, AF1-124, and AF1-125 queue projects.
Cluster 29 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. 133 contingencies were studied, each with a 20 second simulation time period. The studied contingencies included:
- Steady-state operation (30 seconds)
- Three-phase faults with normal clearing time
- Single-phase bus faults with normal clearing time
- Single-phase faults with stuck breaker
- Single-phase faults with delayed clearing at remote end
- Single-phase faults with loss of multiple-circuit tower line.
For all simulations, the projects under study along with the rest of the PJM system were required to maintain synchronism and with all states returning to an acceptable new condition following the disturbance.
The results of the analysis were evaluated against the following recovery criteria per PJM’s Regional Transmission Planning Process and Transmission Owner criteria:
- Cluster 29 projects were able to ride through the faults (except for faults where protective action trips a generator(s)).
- The system with Cluster 29 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 per unit after 2.5 seconds (except where protective action isolates that bus) and the final voltages are within the steady-state voltage ranges below per Dominion Energy’s transmission planning criteria.
- P1 Category Contingencies:
- 0.93 to 1.05 p.u. for 230, 115, 69 kV facilities
- 0.93 to 1.03 p.u. for 138 kV facilities due to legacy switches
- 1.01 to 1.096 p.u. for 500 kV facilities
- P2, P4, P5, and P7 Category Contingencies:
- 0.90 to 1.05 p.u. for 230, 115, 69 kV facilities
- 0.90 to 1.03 p.u. for 138 kV facilities due to legacy switches
- 1.00 to 1.096 p.u. for 500 kV facilities
- No transmission element tripped, other than those either directly connected or designed to trip as a consequence of that fault.
AF1-123, AF1-124 and AF1-125 met the 0.95 lagging and leading power factor requirements at the point of interconnect (POI) at Harpers 230 kV substation.
The results of the analysis identified that the addition of the AF1-123, AF1-124 and AF1-125 queue projects resulted in instability in a majority of contingencies. The following mitigation is required to maintain stability:
- Add a second 500 kV line from the Updated Fentress to the Yadkin substations
- Add two 230 kV gas-insulated lines (GILs) from the existing Fentress to the New Fentress substations
- All 230 kV breakers (212822, 269T2128, 26922, 224022-1, 224022-2, 208722, W22, L122, L322, H22, SC122, SC322, SC422, SV122, and the new breakers G1 and G2 for the gas insulated lines) at Fentress 230 kV Substation require a 14 cycle clearing time
- Dual pilot protection is required for the Fentress to AD1-033 POI 230 kV line circuit 2240
No voltage or frequency protection trips occurred for AF1-123, AF1-124 and AF1-125 queue projects using the settings provided.
The AF1-123, AF1-124 and AF1-125 queue projects exhibited slow active power recovery after the fault cleared and this is recovery was expected based on the model documentation provided for the OEMs’ wind turbine. The WGOWECC controller, clamps the active power at 95% for up to 5 seconds to ensure steady recovery of the system and then releases the active power to 100% to restore full operation.
An EMT analysis and stability analysis using a PSS/E user defined model is recommended for AF1-123, AF1-124 and AF1-125 due to the CSCR values being less than 3. A user defined model is under development by the IC and it will be evaluated as a sensitivity once the model initializes properly.
AE2-156 reactive power and terminal voltage recovery was not settling to a steady state value during the analysis. However, it was observed that reactive settling doesn’t violate PJM or Dominion’s criteria. The models were tuned to achieve a faster recovery in Cluster 46 Phase 2 Stability Analysis.
AE2-051 reactive power and terminal voltage recovery was not settling to a steady state value during the analysis. The models can be tuned to achieve a faster recovery upon request.
AB2-169 generator tripped for overvoltage’s above 1.25 p.u. The unit rode through when the pickup timer was increased from 0.0 seconds to 0.0125 seconds.
Executive Summary for Dynamic Stability Analysis using PSCAD/EMT
The EMT dynamic performance analysis was revelated with the latest PSCAD models pprovided by CVOW (AF1-123, 124 & 125) generation developer. A detailed model quality testing was performed. Below are some deficiency and corresponding update that were applied to the plant model.
- CVOW initialization issues were cured by using a stiff voltage source model at POI during the initialization period and disconnected later in the simulation.
- Pi-circuit equivalents for 66 kV IAC cables were updated to Bergeron models using best available data.
- Onshore cable section was updated into onshore and HDD sections using best available data.
- Earthing transformer model was included at the 66 kV delta winding of OSS transformer.
- OSS LTC transformer taps were set to match values used for TC1 analysis.
- Harpers STATCOM model was updated to latest OEM model.
Preliminary results of CVOW performance for Summer peak and Light Load system conditions for select TPL contingencies indicate the following:
- Instability of the project post-fault was observed for select P1 and P6 contingencies prior to the inclusion of all proposed upgrades.
- With the inclusion of the proposed upgrades namely the 500 kV Line 5005 between Fentress and Yadkin and two GIL circuits between new and existing Fentress 230 kV, CVOW fully recovers post-fault for a severe P4 contingency.
- The preliminary results demonstrate the impact of the weak system strength and the improvements provided by the proposed upgrades.
- Analysis of CVOW performance for severe P6 contingencies with the proposed upgrades is ongoing.
- Investigation of partial nuisance tripping of CVOW post-fault is also on-going for other contingencies and system conditions.
CVOW Flicker
Preliminary analysis shows flicker issue induced by CVOW project. Preliminary flicker analysis was conducted using a range of ramp rates in the absence of data on power fluctuation in response to wind speed variation. To assess flicker impact, MEPPI evaluated multiple wind profiles, spanning from conservative scenarios to less conservative ramp rates. Results indicate that the ramp rate significantly influences the flicker observed at the POI and we violate the criteria of 1 Pst for various profiles considered. Flicker analysis was performed in PSCAD using detailed models of the CVOW project and a system equivalent at the POI. In order to mitigate the flicker issue an addition of 300 MVAR STATCOM will need to be installed at Fentress 230 kV Substation.
Note:
TC1 Phase 3 Dynamic Stability analysis has been completed by using library model provided in TC1 Phase 2. For TC1 Phase 3, a PSSE User Defined Model was requested due to low SCR concerns in the area. The CVOW project developer provided a User Defined Model that did not work properly in the TC1 base case. The CVOW project development team is actively working on getting an updated User Defined Model for the AF1-123/AF1-124/AF1-125 projects from Siemens Gamesa Renewable Energy (SGRE). This updated model was not ready at the time TC1 Phase 3 studies concluded, and CVOW will need to initiate a Necessary Study request post GIA to have the updated User Defined Model provided to PJM to perform a Dynamic Stability analysis for the AF1-123/AF1-124/AF1-125 projects.
Also, CVOW notified PJM of a change for nineteen (19) of the GSUs that are planned to be installed for the CVOW Project for Queue Position AF1-123 (OSS T1L11). Note that these 19 GSUs – installed in 19 of the 59 wind turbine generators – have been manufactured and have higher impedance values that was in the original design. Following evaluation, it has been determined that these changes in impedances to these 19 units do not affect the MFO/gross output, have very limited changes for the losses, and the MW output at the POI will be changed, but insubstantially. The other queues AF1-124 & AF1-125 are unchanged/unaffected. This GSU change for AF1-123 will also be evaluated as part of the Necessary Study being requested above.
Bellow are some of the item that will be captured during post GIA Necessary study request for CVOW project.
- The User Defined Model dynamic stability analysis for AF1-123/AF1-124/AF1-125 as well as the GSU change for AF1-123.
- The EMT Analysis is based on PSCAD Models provided to PJM & DEV-ET on May 19th, the developers needs to confirm that these models are still valid and if updates to these models need to be made to represent changes made in the UDM please provide updated EMT models.
- As identified in the TC1 Phase 2 Reports and the June 2025 “EMT Generation Model Review” Report Nuisance Tripping is still occurring which can result in up to 1600 MW Tripping Off-Line. This tripping is being initiated by the DC Protection Scheme of the WTGs, the developer needs to provide a solution to PJM & DEV-ET for this deficiency. This solution will be evaluated in the NSA to determine if it resolves the nuisance tripping issue.
- The developer needs to indicate if margin can be increased in the Over-Voltage Ride Through, Under Voltage Ride Through & Frequency Ride-Through to increase the margins from the PRC-024 & IEEE 2800 Requirements as identified in the TC1 Phase 2 Reports and the June 2025 “EMT Generation Model Review” Report.
- Preliminary Study Results indicate that the CVOW Project will result in a Pst Value greater than 1. This will adversely impact Dominion’s Customers the proposed solution to this flicker issue will be to install a 300 MVAR STATCOM at Fentress Substation on the 230 kV Bus. The developer can provide updated Ramp Rates as part of the NSA to determine if mitigation is still required.
Reactive Power Analysis
The reactive power capability of AF1-123 meets the 0.95 leading and lagging PF requirement at the high side of the main transformer.
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 |
| AA1-063A | Carolina–Seaboard 115kV | In Service |
| AA1-065 | Earleys 230kV | In Service |
| AA1-067 | Everetts 34.5kV | In Service |
| AA1-139 | Hickory-Shawboro 230kV | In Service |
| AA1-145 | Four Rivers 230kV | In Service |
| AA2-053 | Carolina-Jackson 115kV | In Service |
| AA2-057 | Hornertown-Whitakers 115kV | In Service |
| AA2-088 | Boykins-Handsome 115kV | In Service |
| AA2-178 | Mackeys 230kV | In Service |
| AB1-027 | Old Church 34.5 KV | In Service |
| AB1-081 | Anaconda-Mayo Dunbar 115kV | In Service |
| AB1-132 | Thelma 230kV | In Service |
| AB1-173 | Brink-Trego 115kV | In Service |
| 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 |
| AB2-040 | Brink 115kV | In Service |
| AB2-043 | Chase City 115kV | In Service |
| AB2-059 | Benson-Dunbar 115kV | In Service |
| AB2-060 | Chase City-Lunenburg 115kV | In Service |
| AB2-077 | Buggs Island-Chase City 115kV | In Service |
| AB2-078 | Buggs Island-Chase City 115kV | In Service |
| AB2-079 | Buggs Island-Chase City 115kV | In Service |
| AB2-099 | Ahoskie 34.5kV | In Service |
| AB2-100 | Clubhouse-Lakeview 230kV | In Service |
| AB2-134 | Hopewell-Surry 230kV | In Service |
| AB2-161 | Waverly #2 DP 115kV | In Service |
| AB2-169 | Pantago-Five Points 115kV | In Service |
| AB2-174 | Emporia-Trego 115kV | In Service |
| AB2-190 | Hopewell-Surry 230kV | In Service |
| AC1-027 | Pendleton 34.5kV | In Service |
| AC1-034 | Heartsease DP - Mayo Dunbar 115kV | Suspended |
| AC1-036 | Twittys Creek 34.5kV | In Service |
| AC1-054 | Kerr Dam–Eatons Ferry 115 kV | In Service |
| AC1-065 | Harmony Village-Shackleford 115kV | Under Construction |
| AC1-086 | Thelma 230kV | Suspended |
| AC1-098 | Dawson-South Justice 115kV | Partially in Service - Under Construction |
| AC1-099 | Dawson-South Justice 115kV | Partially in Service - Under Construction |
| AC1-105 | Halifax-Mt. Laurel 115kV | In Service |
| AC1-112 | Old Church 34.5kV | In Service |
| AC1-118 | Westmoreland 34.5kV | In Service |
| AC1-147 | Grassfield 34.5kV | In Service |
| AC1-161 | Septa 500kV | In Service |
| AC1-164 | Chickahominy 230kV | Partially in Service - Under Construction |
| AC1-189 | Chinquapin-Everetts 230kV | Under Construction |
| AC1-191 | Elmont 115kV | Engineering & Procurement |
| AC1-208 | Cox-Whitakers 115kV | Under Construction |
| AC1-216 | Hopewell-Surry 230kV | In Service |
| AC1-221 | Halifax-Person 230kV | In Service |
| AC1-222 | Crystal Hill-Halifax 115kV | In Service |
| AC2-012 | Grassfield-Great Bridge 115kV | In Service |
| AC2-079 | Ivor-Oak Ridge 115kV | Suspended |
| AC2-084 | Dawson-South Justice 115kV | Partially in Service - Under Construction |
| AC2-100 | Halifax-Person 230kV | In Service |
| 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 |
| AD1-022 | Cashie-Trowbridge 230 kV | Engineering & Procurement |
| AD1-025 | Hopewell-Surry 230 kV | Partially in Service - Under Construction |
| AD1-033 | Fentress-Landstown 230 kV | In Service |
| AD1-041 | Harmony Village-Shackleford 115 kV | In Service |
| AD1-056 | Hornertown-Hathaway 230 kV | Suspended |
| AD1-057 | Hornertown-Hathaway 230 kV | Suspended |
| 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 |
| AD1-087 | Clover-Sedge Hill 230 kV | In Service |
| AD1-088 | Briery-Clover 230 kV | Suspended |
| AD1-105 | Kings Dominion DP 115 kV | Under Construction |
| AD1-144 | Kings Fork 34.5 kV | In Service |
| AD1-151 | Hopewell-Surry 230 kV | Suspended |
| AD1-152 | Clover-Sedge Hill 230 kV | In Service |
| AD2-022 | East Danville - Roxborough 230 kV | Engineering & Procurement |
| AD2-023 | East Danville - Roxborough 230 kV | Engineering & Procurement |
| AD2-030 | Wan 34.5 kV | In Service |
| AD2-033 | Chase City-Lunenburg 115 kV | Under Construction |
| 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 |
| AD2-202 | Clover-Sedge Hill 230kV | 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 |
| AE1-103 | Holland-Union Camp 115 kV | Suspended |
| AE1-108 | Bremo-Scottsville 138 kV | Engineering & Procurement |
| AE1-149 | Disputanta-Poe 115 kV | Suspended |
| AE1-155 | Garner-Northern Neck 115 kV | In Service |
| 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 |
| AE1-190 | Harmony Village-Shackleford 115 kV | In Service |
| AE1-191 | Harmony Village-Shackleford 115 kV | In Service |
| AE2-027 | Harrowgate-Locks 115kV | Under Construction |
| AE2-033 | Clubhouse-Sapony 230 kV | Suspended |
| AE2-034 | Mackeys 230 kV | Partially in Service - Under Construction |
| AE2-040 | Sapony 34.5 kV | Partially in Service - Under Construction |
| AE2-041 | Harmony Village 230 kV | Engineering & Procurement |
| AE2-051 | Carson-Septa 500 kV | Engineering & Procurement |
| AE2-092 | Kidds Store-Sherwood 115 kV | Engineering & Procurement |
| AE2-094 | Carson-Rogers Road 500 kV | Engineering & Procurement |
| AE2-104 | Suffolk 115 kV | Suspended |
| AE2-156 | Yadkin 115 kV | Active |
| AE2-212 | Harrowgate 34 kV | Engineering & Procurement |
| AE2-247 | Myrtle-Windsor 115 kV | Engineering & Procurement |
| AE2-253 | Hickory-Moyock 230 kV | In Service |
| AE2-259 | Curdsville-Willis Mtn 115 kV | Engineering & Procurement |
| AE2-346 | Ahoskie 34.5 kV | In Service |
| AF1-017 | Myrtle-Windsor 115 kV | Engineering & Procurement |
| AF1-018 | Harmony Village 230 kV | Engineering & Procurement |
| AF1-028 | Endless Caverns 115 kV | Under Construction |
| AF1-032 | Suffolk 34.5 kV | In Service |
| AF1-042 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AF1-058 | Welco 34.5 kV | In Service |
| AF1-069 | Carson-Rogers Rd 500 kV | Engineering & Procurement |
| AF1-114 | Oak Grove-Dahlgren 230 kV | Engineering & Procurement |
| 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 |
| AF1-291 | Tyler 34.5 kV | Engineering & Procurement |
| AF1-292 | Fields 34.5kV | Engineering & Procurement |
| AF1-294 | Jetersville-Ponton 115 kV | Active |
| AF2-013 | Arnold's Corner-Dahlgren 230 kV | Engineering & Procurement |
| AF2-042 | Clover-Rawlings 500 kV | Active |
| AF2-043 | Suffolk 34.5 kV | In Service |
| AF2-054 | Wan 34.5 kV | In Service |
| AF2-077 | White Marsh 34.5 kV | In Service |
| AF2-080 | Chinquapin-Everetts 230 kV | Active |
| AF2-081 | Moyock 230 kV | Active |
| AF2-085 | Midlothian 34.5 kV | In Service |
| AF2-091 | Oak Grove-Dahlgren 230 kV | Engineering & Procurement |
| AF2-110 | Suffolk 115 kV | Suspended |
| AF2-115 | Jetersville-Ponton 115 kV | Active |
| AF2-120 | Garner-Northern Neck 115 kV | Active |
| AF2-144 | Powhatan 34.5 kV | In Service |
| AF2-222 | Madisonville DP-Twitty's Creek 115 kV | Active |
| AF2-299 | Fields 34.5 kV | Active |
| AG1-007 | Tar River 12.5 kV | Engineering & Procurement |
| AG1-021 | Jetersville-Ponton 115 kV | Active |
| AG1-037 | Ahoskie 34.5 kV | Engineering & Procurement |
| AG1-038 | Garner DP-Lancaster 115 kV | Engineering & Procurement |
| AG1-105 | Mount Laurel-Barnes Junction 115 kV | Active |
| AG1-106 | Thelma 230 kV | Active |
| AG1-135 | Garner-Lancaster 115 kV | Active |
| AG1-145 | Lightfoot 34.5 kV | In Service |
| AG1-153 | Heritage 500 kV | Active |
| AG1-210 | Northern Neck 34.5 kV | Withdrawn |
| AG1-282 | Dunnsville 34.5 kV | Engineering & Procurement |
| AG1-285 | Chase City-Central 115 kV | Active |
| AG1-342 | Dryburg 115 kV | Active |
| AG1-532 | Fields 34.5 kV | Engineering & Procurement |
| AG1-536 | Garner-Northern Neck 115 kV | Active |
| AG1-558 | Buckner 34.5 kV | Engineering & Procurement |
| AG1-559 | Caroline Pines 22 kV | Engineering & Procurement |
| V4-068 | Murphy's 34.5kV | In Service |
| W1-029 | Winfall 230kV | In Service |
| Y1-086 | Morgans Corner | In Service |
| Z1-036 | WinFall-Chowan 230kV | In Service |
| Z1-068 | Birdneck 34.5kV | In Service |
| Z2-027 | Pasquotank 34.5kV | In Service |
| Z2-044 | Whitakers 34.5kV | In Service |
| Z2-088 | Tarboro-Everetts 230kV | 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 accordance with PJM Tariff Part VII, Subpart D, section 312.A.1.b and as outlined in PJM Manual 14H, Section 13, in Phase III of the Cycle, PJM coordinates with the Affected System Operators to conduct any studies required to determine the impact of the New Service Request on any Affected System and will include the Affected System Study results in Phase III System Impact Study, if available from the Affected System Operator.
If your project required an Affected System Study, the results are shown below from the Affected System Operator.
For more details, please refer to your Affected System Study report by the Affected System Operator. If the Affected System Operator identified the need for a system reinforcement on their system due to their planning criteria, Project Developer must follow the Affected System Operator Tariff for construction of the network upgrade. PJM will list any required network upgrades identified by the Affected System Operator in the PJM Project Developer’s GIA under Schedule F.
System Reinforcements
Based on the Final System Impact Study analysis results, this project is contingent on and may have cost responsibility for the following System Reinforcements:
PJM evaluated the impact of topology changing reinforcements to mitigate the impacts driven by New Service Requests. PJM determined which reinforcements were eliminated as a result of modeling the topology changing reinforcements. PJM then grouped the topology changing and eliminated reinforcements by region and computed a discount factor to apply to reinforcements to reduce the cost of all these reinforcements down to the cost of contstructing only the topology changing reinforcements. For additional details, please click the icon below
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: n8492
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492
- Title
- Wreck and rebuild the existing Yadkin to Fentress 500 kV Line #588 to share the right of way with the new Yadkin to Fentress #5005 line.
- Description
- Wreck and rebuild one (1) overhead 500kV transmission line that will start at the existing Fentress 500 kV Substation and terminate at the existing Yadkin 500 kV Substation, located approximately 13.5 miles away.
- Total Cost ($USD)
- $80,172,278
- Discounted Total Cost ($USD)
- $20,969,183
- Allocated Cost ($USD)
- $7,017,810
- Time Estimate
- 26 to 27 Months
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 | 833.0 MW | 33.5% | $7,017,810 |
| AF1-124 | 836.0 MW | 33.6% | $7,043,084 |
| AF1-125 | 820.0 MW | 32.9% | $6,908,288 |
System Reinforcement: n8492
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492
- Title
- Wreck and rebuild the existing Yadkin to Fentress 500 kV Line #588 to share the right of way with the new Yadkin to Fentress #5005 line.
- Description
- Wreck and rebuild one (1) overhead 500kV transmission line that will start at the existing Fentress 500 kV Substation and terminate at the existing Yadkin 500 kV Substation, located approximately 13.5 miles away.
- Total Cost ($USD)
- $80,172,278
- Allocated Cost ($USD)
- $11,942,551
- Time Estimate
- 26 to 27 Months
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $11,942,551 |
| AF1-124 | 14.9488 % | $11,984,808 |
| AF1-125 | 14.6652 % | $11,757,438 |
| AF1-294 | 0.3084 % | $247,283 |
| AF2-042 | 29.0898 % | $23,321,957 |
| AF2-115 | 0.1881 % | $150,784 |
| AF2-120 | 5.5338 % | $4,436,535 |
| AF2-222 | 3.7926 % | $3,040,619 |
| AG1-021 | 0.1505 % | $120,627 |
| AG1-124 | 3.0179 % | $2,419,500 |
| AG1-135 | 5.3024 % | $4,251,075 |
| AG1-285 | 2.8388 % | $2,275,893 |
| AG1-536 | 5.2677 % | $4,223,208 |
System Reinforcement: n9647.0
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n9647.0
- Title
- Install a 300 MVAR STATCOM at Fentress Substation.
- Description
- Install a 300 MVAR STATCOM at Fentress Substation.
- Total Cost ($USD)
- $49,163,341
- Discounted Total Cost ($USD)
- $49,163,341
- Allocated Cost ($USD)
- $16,453,621
- Time Estimate
- Mar 31 2029
Contributor
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 | 833.0 MW | 33.5% | $16,453,621 |
| AF1-124 | 836.0 MW | 33.6% | $16,512,878 |
| AF1-125 | 820.0 MW | 32.9% | $16,196,842 |
System Reinforcement: n9259.0
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n9259.0
- Title
- Install two 230 kV gas insulated switchgear ("GIS") bus ties at the Fentress 230 kV substation.
- Description
- Install two 230 kV gas insulated switchgear ("GIS") bus ties at the Fentress 230 kV substation.
- Total Cost ($USD)
- $25,304,902
- Discounted Total Cost ($USD)
- $6,618,536
- Allocated Cost ($USD)
- $2,215,042
- Time Estimate
- 38 to 39 Months
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 | 833.0 MW | 33.5% | $2,215,042 |
| AF1-124 | 836.0 MW | 33.6% | $2,223,020 |
| AF1-125 | 820.0 MW | 32.9% | $2,180,474 |
System Reinforcement: n9259.0
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n9259.0
- Title
- Install two 230 kV gas insulated switchgear ("GIS") bus ties at the Fentress 230 kV substation.
- Description
- Install two 230 kV gas insulated switchgear ("GIS") bus ties at the Fentress 230 kV substation.
- Total Cost ($USD)
- $25,304,902
- Allocated Cost ($USD)
- $3,769,446
- Time Estimate
- 38 to 39 Months
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $3,769,446 |
| AF1-124 | 14.9488 % | $3,782,784 |
| AF1-125 | 14.6652 % | $3,711,019 |
| AF1-294 | 0.3084 % | $78,050 |
| AF2-042 | 29.0898 % | $7,361,146 |
| AF2-115 | 0.1881 % | $47,592 |
| AF2-120 | 5.5338 % | $1,400,310 |
| AF2-222 | 3.7926 % | $959,715 |
| AG1-021 | 0.1505 % | $38,074 |
| AG1-124 | 3.0179 % | $763,670 |
| AG1-135 | 5.3024 % | $1,341,774 |
| AG1-285 | 2.8388 % | $718,344 |
| AG1-536 | 5.2677 % | $1,332,978 |
System Reinforcement: n8492.1
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492.1
- Title
- Two Breaker Additions at Fentress Substation.
- Description
- Install Two 5000 amp GIS Breakers at Fentress Substation to connect the new 500 kV line 5005.
- Total Cost ($USD)
- $19,945,879
- Discounted Total Cost ($USD)
- $5,216,875
- Allocated Cost ($USD)
- $1,745,945
- Time Estimate
- 30 to 36 Months
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 | 833.0 MW | 33.5% | $1,745,945 |
| AF1-124 | 836.0 MW | 33.6% | $1,752,233 |
| AF1-125 | 820.0 MW | 32.9% | $1,718,697 |
System Reinforcement: n8492.1
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492.1
- Title
- Two Breaker Additions at Fentress Substation.
- Description
- Install Two 5000 amp GIS Breakers at Fentress Substation to connect the new 500 kV line 5005.
- Total Cost ($USD)
- $19,945,879
- Allocated Cost ($USD)
- $2,971,160
- Time Estimate
- 30 to 36 Months
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $2,971,160 |
| AF1-124 | 14.9488 % | $2,981,673 |
| AF1-125 | 14.6652 % | $2,925,106 |
| AF1-294 | 0.3084 % | $61,521 |
| AF2-042 | 29.0898 % | $5,802,217 |
| AF2-115 | 0.1881 % | $37,513 |
| AF2-120 | 5.5338 % | $1,103,755 |
| AF2-222 | 3.7926 % | $756,469 |
| AG1-021 | 0.1505 % | $30,011 |
| AG1-124 | 3.0179 % | $601,942 |
| AG1-135 | 5.3024 % | $1,057,615 |
| AG1-285 | 2.8388 % | $566,214 |
| AG1-536 | 5.2677 % | $1,050,682 |
System Reinforcement: n8492.2
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492.2
- Title
- Expand Yadkin Substation to accommodate the new 500 kV line.
- Description
- Expansion of yadkins 500 kV switchyard to accommodate the new 500 kV line which includes addition of 5000 amp GIS breakers and relocation of the existing suffolk -yadkin 500 kV line#565
- Total Cost ($USD)
- $16,207,123
- Discounted Total Cost ($USD)
- $4,238,998
- Allocated Cost ($USD)
- $1,418,676
- Time Estimate
- 15 to 16 Months
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 | 833.0 MW | 33.5% | $1,418,676 |
| AF1-124 | 836.0 MW | 33.6% | $1,423,786 |
| AF1-125 | 820.0 MW | 32.9% | $1,396,536 |
System Reinforcement: n8492.2
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n8492.2
- Title
- Expand Yadkin Substation to accommodate the new 500 kV line.
- Description
- Expansion of yadkins 500 kV switchyard to accommodate the new 500 kV line which includes addition of 5000 amp GIS breakers and relocation of the existing suffolk -yadkin 500 kV line#565
- Total Cost ($USD)
- $16,207,123
- Allocated Cost ($USD)
- $2,414,231
- Time Estimate
- 15 to 16 Months
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $2,414,231 |
| AF1-124 | 14.9488 % | $2,422,773 |
| AF1-125 | 14.6652 % | $2,376,810 |
| AF1-294 | 0.3084 % | $49,989 |
| AF2-042 | 29.0898 % | $4,714,620 |
| AF2-115 | 0.1881 % | $30,482 |
| AF2-120 | 5.5338 % | $896,862 |
| AF2-222 | 3.7926 % | $614,672 |
| AG1-021 | 0.1505 % | $24,385 |
| AG1-124 | 3.0179 % | $489,111 |
| AG1-135 | 5.3024 % | $859,371 |
| AG1-285 | 2.8388 % | $460,080 |
| AG1-536 | 5.2677 % | $853,737 |
System Reinforcement: n9139.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9139.0 / TC1-PH1-DOM-073
- Title
- Wreck and rebuild 37.41 miles of 500kV line 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" and associated substation work.
- Description
- Wreck and rebuild 37.41 miles of 500kV transmission line 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA. Remove wave traps.
- Total Cost ($USD)
- $245,455,768
- Discounted Total Cost ($USD)
- $245,455,768
- Allocated Cost ($USD)
- $67,622,418
- Time Estimate
- 69 to 70 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (Any) |
| |||||||||||||
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S | No new ratings for this Flowgate. |
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 205.2 MW | 27.5% | $67,622,418 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 205.9 MW | 27.6% | $67,865,939 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 202.0 MW | 27.1% | $66,566,940 |
| AF2-042 | 131.7 MW | 17.7% | $43,400,471 |
System Reinforcement: n9191.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9191.0 / TC1-PH1-DOM-090
- Title
- Rebuild 41.13 miles of line 576 between North Anna and Midlothian with triple bundled (3) 1351.5 ACSR (45/7) "Dipper" conductor and associated substation work.
- Description
- Rebuild 41.13 miles of line 576 between North Anna and Midlothian with triple bundled (3) 1351.5 ACSR (45/7) "Dipper" conductor at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA.
- Total Cost ($USD)
- $256,706,175
- Discounted Total Cost ($USD)
- $256,706,175
- Allocated Cost ($USD)
- $61,806,471
- Time Estimate
- 74 to 75 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: WT576_SRT-S | No new ratings for this Flowgate. | |||||||||||||
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-S | No new ratings for this Flowgate. | |||||||||||||
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S | No new ratings for this Flowgate. | |||||||||||||
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 69.0 MW | 24.1% | $61,806,471 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 69.2 MW | 24.2% | $62,026,005 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 67.9 MW | 23.7% | $60,854,858 |
| AF2-042 | 80.4 MW | 28.1% | $72,018,840 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC1-PH2-DOM-040
- Title
- ELIM TC1: Wreck and rebuild 18.75 miles of Line 594 btwn Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) Dipper at 110 degrees C and assoc substation work (new rating: 4356/4356/5009 MVA)
- Description
- Wreck and rebuild 18.75 miles of Line 594 between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA.
- Total Cost ($USD)
- $128,018,212
- Discounted Total Cost ($USD)
- $33,483,361
- Allocated Cost ($USD)
- $7,848,603
- Time Estimate
- 60 to 61 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 39.9 MW | 23.4% | $7,848,603 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 40.1 MW | 23.5% | $7,876,529 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 39.3 MW | 23.1% | $7,727,852 |
| AF2-042 | 51.0 MW | 30.0% | $10,030,376 |
System Reinforcement: n9112.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9112.0 / TC1-PH2-DOM-063
- Title
- Wreck and Rebuild 12.4 miles of 230 kV line 259 with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C and replace line lead at Chesterfield.
- Description
- Wreck and Rebuild 12.4 miles of 230 kV line 259 with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C and replace line lead at Chesterfield.
- Total Cost ($USD)
- $87,030,447
- Discounted Total Cost ($USD)
- $87,030,447
- Allocated Cost ($USD)
- $23,513,865
- Time Estimate
- 46 to 47 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 45.5 MW | 27.0% | $23,513,865 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 45.7 MW | 27.1% | $23,598,622 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 44.8 MW | 26.6% | $23,146,929 |
| AF2-042 | 32.5 MW | 19.3% | $16,771,032 |
System Reinforcement: n9247.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9247.0 / TC1-PH2-DOM-041
- Title
- ELIM TC1: Wreck and rebuild 14.02 miles of Line 573 btwn Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work (new rating: 4356/4356/5009 MVA)
- Description
- Wreck and rebuild 14.02 miles of Line 573 between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
- Total Cost ($USD)
- $99,636,684
- Discounted Total Cost ($USD)
- $26,060,128
- Allocated Cost ($USD)
- $6,102,509
- Time Estimate
- 48 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 40.9 MW | 23.4% | $6,102,509 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 41.0 MW | 23.5% | $6,124,291 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 40.3 MW | 23.1% | $6,008,516 |
| AF2-042 | 52.4 MW | 30.0% | $7,824,812 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC1-PH2-DOM-062
- Title
- ELIMINATED FOR TC1: Wreck and Rebuild 14.83 miles of 230 kV line 256 with (2) 768.2 ACSS/TW (20/7) ""Maumee"" conductor @ 250 degrees C.
- Description
- Wreck and Rebuild 14.83 miles of 230 kV line 256 with (2) 768.2 ACSS/TW (20/7) ""Maumee"" conductor @ 250 degrees C.
- Total Cost ($USD)
- $41,037,004
- Discounted Total Cost ($USD)
- $10,733,292
- Allocated Cost ($USD)
- $3,591,996
- Time Estimate
- 46 to 47 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.7 MW | 33.5% | $3,591,996 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.8 MW | 33.6% | $3,604,666 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.4 MW | 33.0% | $3,536,630 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / dom-369
- Title
- ELIM FOR TC1: Wreck and rebuild 6.47 miles of 230 kV transmission line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle.
- Description
- Wreck and rebuild 6.47 miles of 230 kV transmission line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle.
- Total Cost ($USD)
- $36,802,018
- Discounted Total Cost ($USD)
- $9,625,624
- Allocated Cost ($USD)
- $3,221,524
- Time Estimate
- 43 to 44 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.7 MW | 33.5% | $3,221,524 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.9 MW | 33.6% | $3,232,652 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.2 MW | 32.9% | $3,171,449 |
System Reinforcement: n9380.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9380.0 / TC1-PH3-DOM-012
- Title
- Replace existing Ladysmith 230/500 kV transformer 1 with four (4) 480 MVA single phase transformers.
- Description
- Replace existing Ladysmith 230/500 kV transformer 1 with four (4) 480 MVA single phase transformers.
- Total Cost ($USD)
- $37,587,605
- Discounted Total Cost ($USD)
- $37,587,605
- Allocated Cost ($USD)
- $11,614,950
- Time Estimate
- Dec 31 2029
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6LADYSMITH-8LADYSMITH 230.0/500.0 kV Ckt 1 transformer | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 70.3 MW | 30.9% | $11,614,950 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 70.5 MW | 31.0% | $11,656,754 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 69.2 MW | 30.4% | $11,433,686 |
| AF2-120 ⧉ AE1-155 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-120, AG1-536 | 7.9 MW | 3.5% | $1,304,375 |
| AG1-536 ⧉ AE1-155 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-120, AG1-536 | 9.5 MW | 4.2% | $1,577,841 |
System Reinforcement: n9207.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9207.0 / TC1-PH2-DOM-018
- Title
- Replace 6ELMONT 230 kV to 8ELMONT 500 kV circuit 1 with larger transformer (3-480 MVA single phase transformer).
- Description
- Replace 6ELMONT 230 KV to 8ELMONT 500 kV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM).
- Total Cost ($USD)
- $38,254,469
- Discounted Total Cost ($USD)
- $38,254,469
- Allocated Cost ($USD)
- $11,275,111
- Time Estimate
- 59 to 60 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AE2-156 | 14.4 MW | 3.6% | $1,375,093 |
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 118.1 MW | 29.5% | $11,275,111 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 118.6 MW | 29.6% | $11,315,765 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 116.3 MW | 29.0% | $11,099,228 |
| AF2-081 | 11.2 MW | 2.8% | $1,072,666 |
| AF2-120 ⧉ AE1-155 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-120, AG1-536 | 10.0 MW | 2.5% | $957,860 |
| AG1-536 ⧉ AE1-155 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-120, AG1-536 | 12.1 MW | 3.0% | $1,158,746 |
System Reinforcement: n9153.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9153.0 / TC1-PH1-DOM-043
- Title
- Wreck and rebuild 5.9 miles of 230 kV line 2128 between Fentress and Thrasher with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C and replace line lead at Fentress.
- Description
- Wreck and rebuild 5.9 miles of 230 kV line 2128 between Fentress and Thrasher with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C and replace line lead at Fentress.
- Total Cost ($USD)
- $33,297,247
- Discounted Total Cost ($USD)
- $33,297,247
- Allocated Cost ($USD)
- $10,791,585
- Time Estimate
- 43 to 44 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AE2-156 | 18.7 MW | 1.6% | $532,288 |
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 378.9 MW | 32.4% | $10,791,585 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 380.3 MW | 32.5% | $10,830,603 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 373.0 MW | 31.9% | $10,623,269 |
| AF2-081 | 18.2 MW | 1.6% | $519,501 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC1-PH2-DOM-008
- Title
- ELIMINATED FOR TC1: Wreck and rebuild 10.74 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "MAUMEE" @ 250C.
- Description
- Wreck and rebuild 10.74 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "MAUMEE" @ 250C.
- Total Cost ($USD)
- $29,539,973
- Discounted Total Cost ($USD)
- $7,726,225
- Allocated Cost ($USD)
- $2,585,829
- Time Estimate
- 45 to 46 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.7 MW | 33.5% | $2,585,829 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.9 MW | 33.6% | $2,594,761 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.2 MW | 32.9% | $2,545,635 |
System Reinforcement: n9379.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9379.0 / TC1-PH3-DOM-011
- Title
- Replace existing 230/500 kV Transformer 1 at Midlothian with (4)-480 MVA Single Phase transformers.
- Description
- Replace existing 230/500 kV Transformer 1 at Midlothian with (4)-480 MVA Single Phase 500/230 kV transformers.
- Total Cost ($USD)
- $37,836,293
- Discounted Total Cost ($USD)
- $37,836,293
- Allocated Cost ($USD)
- $8,463,643
- Time Estimate
- Dec 31 2029
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 19.1 MW | 22.4% | $8,463,643 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 19.2 MW | 22.4% | $8,493,744 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 18.8 MW | 22.0% | $8,333,502 |
| AF2-042 | 28.3 MW | 33.2% | $12,545,404 |
System Reinforcement: n9378.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9378.0 / TC1-PH3-DOM-010
- Title
- Replace existing 230/500 kV Carson transformer 2 with (4)-480 MVA single phase transformers.
- Description
- Replace Existing 230/500 kV Carson transformer 2 with (4)-480 MVA Single Phase transformers.
- Total Cost ($USD)
- $37,801,301
- Discounted Total Cost ($USD)
- $37,801,301
- Allocated Cost ($USD)
- $8,456,365
- Time Estimate
- Dec 31 2029
Contributor
| Facility | Contingency | ||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 56.2 MW | 22.4% | $8,456,365 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 56.5 MW | 22.5% | $8,486,733 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 55.4 MW | 22.0% | $8,324,368 |
| AF2-042 | 59.5 MW | 23.7% | $8,947,219 |
| AF2-222 | 12.2 MW | 4.8% | $1,827,058 |
| AG1-153 | 11.7 MW | 4.7% | $1,759,557 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / dom-490
- Title
- ELIMINATED FOR TC1: Upgrade a 3.78 mile segment of 230kV transmission line 2028 between Mt. Eagle and Grape Vine Substations at structure 2080/73.
- Description
- Uograde 3.78 miles of transmission line 2028 between Mt. Eagle and Grape Vine with (2) 768.2 ACSS/TW (20/7) "MAUMEE". The segment runs from Mt Eagle to structure 2080/73.
- Total Cost ($USD)
- $13,360,242
- Discounted Total Cost ($USD)
- $3,494,392
- Allocated Cost ($USD)
- $1,169,510
- Time Estimate
- 43 to 44 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.7 MW | 33.5% | $1,169,510 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.9 MW | 33.6% | $1,173,550 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.2 MW | 32.9% | $1,151,331 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC1-PH3-DOM-006
- Title
- ELIM FOR TC1: Upgrade a 2.73 mile segment of 230kV transmission line 2028 between Mt. Eagle and Grape Vine. This segment runs from Grape Vine substation to structure 2080/73.
- Description
- Rebuild a 2.73 mile segment of 230kV line 2028 between Mt. Eagle and Grape Vinew with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C.
- Total Cost ($USD)
- $8,415,380
- Discounted Total Cost ($USD)
- $2,201,056
- Allocated Cost ($USD)
- $736,654
- Time Estimate
- 42 to 43 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.7 MW | 33.5% | $736,654 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.9 MW | 33.6% | $739,198 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 34.2 MW | 32.9% | $725,203 |
System Reinforcement: n9199.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9199.0 / TC1-PH2-DOM-004
- Title
- Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo with (2) 768.2 ACSS/TW (20/7) "MAUMEE" @ 250C and replace line lead at Bremo.
- Description
- Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo with (2) 768.2 ACSS/TW (20/7) "MAUMEE" @ 250C and replace line lead at Bremo.
- Total Cost ($USD)
- $7,947,612
- Discounted Total Cost ($USD)
- $7,947,612
- Allocated Cost ($USD)
- $2,659,940
- Time Estimate
- 42 to 43 Months
Contributor
| Facility | Contingency | ||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | (Any) |
| |||||||||||||||||||||||||||||||
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 67.7 MW | 33.5% | $2,659,940 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 68.0 MW | 33.6% | $2,669,367 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 66.7 MW | 32.9% | $2,618,305 |
System Reinforcement: n9146.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9146.0 / TC1-PH1-DOM-004
- Title
- ELIMINATED FOR TC1: Wreck and rebuild 1.51 miles of 115 kV Line No. 5 between Bremo and Fork Union with (1) 768.2 ACSS/TW (20/7) "MAUMEE" at 250 degrees Celsius. Replace line lead at Bremo.
- Description
- Wreck and rebuild 1.51 miles of 115 kV Line No. 5 between Bremo and Fork Union with (1) 768.2 ACSS/TW (20/7) "MAUMEE" at 250 degrees Celsius. Replace line lead at Bremo.
- Total Cost ($USD)
- $7,535,533
- Discounted Total Cost ($USD)
- $1,970,930
- Allocated Cost ($USD)
- $659,804
- Time Estimate
- 42 to 43 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 3FORK UNION-3BREMO 115.0 kV Ckt 2 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 7.0 MW | 33.5% | $659,804 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 7.0 MW | 33.6% | $661,690 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 6.9 MW | 33.0% | $649,436 |
System Reinforcement: n6605
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n6605 / dom-101
- Title
- Wreck and rebuild 0.99 miles of line 271 between Pocaty and Landstown with (2)-768 ACSS (20/7) “MAUMEE” conductor @ 250 degrees C. Replace the line lead at Landstown.
- Description
- Wreck and rebuild 0.99 miles of line 271 between Pocaty and Landstown with (2)-768 ACSS (20/7) “MAUMEE” conductor @ 250 degrees C. Replace the line lead at Landstown.
- Total Cost ($USD)
- $6,555,756
- Discounted Total Cost ($USD)
- $6,555,756
- Allocated Cost ($USD)
- $2,134,014
- Time Estimate
- Dec 31 2026
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6LANDSTN-6POCATY 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 129.1 MW | 32.6% | $2,134,014 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 129.6 MW | 32.7% | $2,141,702 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 127.1 MW | 32.0% | $2,100,719 |
| AF2-081 | 10.8 MW | 2.7% | $179,321 |
System Reinforcement: n6161
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n6161 / dom-039
- Title
- ELIMINATED FOR TC1: Replace 500 kV circuit breaker H1T561 at Clifton with a higher rated device (Clifton - Ox).
- Description
- Replace 500 kV circuit breaker H1T561 at Clifton with a higher rated device (Clifton - Ox).
- Total Cost ($USD)
- $2,634,901
- Discounted Total Cost ($USD)
- $689,162
- Allocated Cost ($USD)
- $230,644
- Time Estimate
- Dec 31 2029
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8CLIFTON-8OX 500.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 97.5 MW | 33.5% | $230,644 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 97.8 MW | 33.6% | $231,475 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 96.0 MW | 32.9% | $227,044 |
System Reinforcement: n9264.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9264.0 / TC1-PH1-DOM-080
- Title
- Replace Line Lead at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1.
- Description
- Replace Line Lead at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1.
- Total Cost ($USD)
- $582,006
- Discounted Total Cost ($USD)
- $582,006
- Allocated Cost ($USD)
- $172,233
- Time Estimate
- 12 to 13 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 249.6 MW | 29.6% | $172,233 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 250.5 MW | 29.7% | $172,853 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 245.7 MW | 29.1% | $169,545 |
| AF2-042 | 97.7 MW | 11.6% | $67,376 |
System Reinforcement
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- (Pending) / TC1-PH2-DOM-061
- Title
- ELIMINATED FOR TC1: Replace wave trap 256WT at Four River 230 kV station (Four River - St. John).
- Description
- Replace wave trap 256WT at Four River 230 kV station (Four River - St. John).
- Total Cost ($USD)
- $514,454
- Discounted Total Cost ($USD)
- $134,556
- Allocated Cost ($USD)
- $45,030
- Time Estimate
- 14 to 15 Months
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.7 MW | 33.5% | $45,030 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.8 MW | 33.6% | $45,189 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 20.4 MW | 33.0% | $44,336 |
System Reinforcement: n9265.0
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- n9265.0 / TC1-PH2-DOM-064
- Title
- Replace 230 kV wave trap 259WT at Basin 230 kV (Basin - Chesterfield B).
- Description
- Replace 230 kV wave trap 259WT at Basin 230 kV (Basin - Chesterfield B).
- Total Cost ($USD)
- $396,021
- Discounted Total Cost ($USD)
- $396,021
- Allocated Cost ($USD)
- $96,938
- Time Estimate
- 14 to 15 Months
Contributor
| Facility | Contingency | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|---|
| AF1-123 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 15.4 MW | 24.5% | $96,938 |
| AF1-124 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 15.5 MW | 24.6% | $97,278 |
| AF1-125 ⧉ CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 | 15.2 MW | 24.1% | $95,442 |
| AF2-042 | 16.9 MW | 26.9% | $106,363 |
System Reinforcement: b3800.373
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.373
- Title
- Wreck and rebuild approximately 7.14 miles of 230kV line #256 from St. Johns to structure 256/108 to achieve a summer rating of 1573 MVA. Line switch 25666 at St. Johns to be upgraded to 4000A.
- Description
- Wreck and rebuild approximately 7.14 miles of 230kV line #256 from St. Johns to structure 256/108 to achieve a summer rating of 1573 MVA. Line switch 25666 at St. Johns to be upgraded to 4000A.
- Cost Information
- Time Estimate
- Jun 15 2027
Contingent Note: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6STJOHN-AE1-157 TP 230.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3800.374
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.374
- Title
- Reconductor approximately 5.30 miles of 230kV line #256 from Ladysmith CT to structure 256/107 to achieve a summer rating of 1573 MVA.
- Description
- Reconductor approximately 5.30 miles of 230kV line #256 from Ladysmith CT to structure 256/107 to achieve a summer rating of 1573 MVA. Terminal equipment at remote end substations will be upgraded to 4000A.
- Cost Information
- Time Estimate
- Jun 15 2027
Contingent Note: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 6STJOHN-AE1-157 TP 230.0 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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
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
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||
|---|---|---|---|
| 6STJOHN-6FOUR RIVERS 230.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8BRISTER-8CHANCE 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 8SEPTA-8SURRY 500.0 kV Ckt 1 line | (Any) | No new ratings for this Flowgate. | |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer | (Any) | No new ratings for this Flowgate. |
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
- Cost Alloc Type
- Contingent
System Reinforcement: b3692
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3692
- Title
- Rebuild approximately 27.7-miles of 500 kV transmission line from Elmont to Chickahominy.
- Description
- Rebuild approximately 27.7-miles of 500 kV transmission line from Elmont to Chickahominy with current 500 kV standards construction practices to achieve a summer rating of 4330 MVA. Projected ISD: 06/01/2026
- Cost Information
- Time Estimate
- Jun 01 2026
Contingent Note: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3800.312
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.312
- Title
- Rebuild 500 kV Line #569 Loudoun - Morrisville to accommodate the new 500 kV line in the existing right-of-way.
- Description
- Rebuild 500kV Line #569 Loudoun - Morrisville to accommodate the new 500 kV line in the existing right-of-way. New conductor to have a summer rating of 4357 MVA.
- Cost Information
- Time Estimate
- Jun 30 2030
ContingentTopology Changing Note 1: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 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 | ||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 8LOUDOUN-8MORRSVL 500.0 kV Ckt 1 line | (Any) |
|
System Reinforcement: b3800.312
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.312
- Title
- Rebuild 500 kV Line #569 Loudoun - Morrisville to accommodate the new 500 kV line in the existing right-of-way.
- Description
- Rebuild 500kV Line #569 Loudoun - Morrisville to accommodate the new 500 kV line in the existing right-of-way. New conductor to have a summer rating of 4357 MVA.
- Cost Information
- Time Estimate
- Jun 30 2030
- Cost Alloc Type
- Contingent
System Reinforcement: n9630.0
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: n9630.0
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n9630.0 / TC1-PH3-DOM-013
- Title
- Construct a new 230 kV line from the AG1-285 substation to the Finneywood 230 kV Substation. Expand AG1-285 substation and add two (2) new 230/115 kV transformers.
- Description
- n9630.0 addresses both stability and load flow violations. Construct a new 230 kV Line from the AG1-285 substation to the 230 kV Finneywood substation following the Line 1012 ROW for approximately 1.0 miles, then following the Line 556 ROW for approximately 3.5 miles to terminate at Finneywood. Expand the AG1-285 115 kV substation to accommodate two (2) new 115/230 kV transformers. Build a 230 kV substation at AG1-285 to connect the 115/230 kV transformers and the new 230 kV line to Finneywood. Expand the Finneywood 230 kV substation to accommodate the new line. The existing 1.0 miles of 115 kV from AG1-285 to Chase City does not need to be rebuilt to accommodate a new structure in the same right of way and therefore will be unchanged. The existing 3.5 miles of 500 kV towers from Structure 556/46 to Finneywood substation will need to be rebuilt as a double circuit tower to accommodate the new 230 kV line.
- Total Cost ($USD)
- $71,697,833
- Allocated Cost ($USD)
- $10,680,188
- Time Estimate
- Dec 31 2029
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $10,680,181 |
| AF1-124 | 14.9488 % | $10,717,966 |
| AF1-125 | 14.6652 % | $10,514,631 |
| AF1-294 | 0.3084 % | $221,116 |
| AF2-042 | 29.0898 % | $20,856,756 |
| AF2-115 | 0.1881 % | $134,864 |
| AF2-120 | 5.5338 % | $3,967,615 |
| AF2-222 | 3.7926 % | $2,719,212 |
| AG1-021 | 0.1505 % | $107,905 |
| AG1-124 | 3.0179 % | $2,163,769 |
| AG1-135 | 5.3024 % | $3,801,706 |
| AG1-285 | 2.8388 % | $2,035,358 |
| AG1-536 | 5.2677 % | $3,776,827 |
System Reinforcement: n9267.0
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: n9267.0
- Type
- Stability
- TO
- Dominion
- RTEP ID / TO ID
- n9267.0 / TC1-PH2-DOM-067
- Title
- Construct new 10.21 mile 115 kV line between Northern Neck and Moon Corner.
- Description
- Construct new 10.21 mile 115 kV line between Northern Neck and Moon Corner substations with single (1) 768.2 ACSS/TW “Maumee” at 250 degrees C. This new line will be on separate transmission towers from the existing Northern Neck and Moon Corner line 1059. Station expansion is required at Northern Neck and Moon Corner to accommodate the new line.
- Total Cost ($USD)
- $45,730,074
- Allocated Cost ($USD)
- $6,812,002
- Time Estimate
- 45 to 46 Months
- Cost Alloc Type
- Cost Allocated
| Project | Percent Allocation | Allocated Cost ($USD) |
|---|---|---|
| AF1-123 | 14.8961 % | $6,811,998 |
| AF1-124 | 14.9488 % | $6,836,097 |
| AF1-125 | 14.6652 % | $6,706,407 |
| AF1-294 | 0.3084 % | $141,032 |
| AF2-042 | 29.0898 % | $13,302,787 |
| AF2-115 | 0.1881 % | $86,018 |
| AF2-120 | 5.5338 % | $2,530,611 |
| AF2-222 | 3.7926 % | $1,734,359 |
| AG1-021 | 0.1505 % | $68,824 |
| AG1-124 | 3.0179 % | $1,380,088 |
| AG1-135 | 5.3024 % | $2,424,791 |
| AG1-285 | 2.8388 % | $1,298,185 |
| AG1-536 | 5.2677 % | $2,408,923 |
System Reinforcement: b4000.325
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
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
- Cost Alloc Type
- Contingent
System Reinforcement: s3047.2
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: s3047.2
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- s3047.2
- Title
- Install two (2) 1400 MVA 500-230 kV transformers at Vint Hill Substation and loop 500 kV line #535 and #569 into the proposed 500 kV ring bus at Vint Hill Substation.
- Description
- Install (2) 1400 MVA 500-230 kV transformers and associated 500 kV and 230 kV equipment (breakers, switches, leads) at Vint Hill Substation to supply the area with a 500 kV source Cut and loop 500 kV line #535 Loudoun – Meadowbrook and #569 Loudoun - Morrisville as the 500 kV sources into the proposed 500 kV ring bus Vint Hill Substation will be expanded to the north of the existing site to accommodate the 500 kV ring required for the addition of the new transformers Existing terminations for 230 kV line #2174 Wheeler – Vint Hill, line #2101 Bristers – Vint Hill, and line #2163 Liberty – Vint Hill will be rearranged to terminate into the expanded Vint Hill Substation 230 kV line #2114 Remington CT – Rollins Ford will also be cut and looped into the expanded Vint Hill Substation due to spatial constraints along the existing right-of-way.
- Cost Information
- Cost Alloc Type
- Contingent
System Reinforcement: b3800.313
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: b3800.313
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.313
- Title
- Rebuild approximately 10.29 miles line segment of Line #535 (Meadow Brook to Loudoun) to accommodate the new 500 kV line in the existing ROW.
- Description
- Rebuild approximately 10.29 miles line segment of Line #535 (Meadow Brook to Loudoun) to accommodate the new 500 kV line in the existing ROW.
- Cost Information
- Cost Alloc Type
- Contingent
System Reinforcement: b3800.356
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: b3800.356
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.356
- Title
- Build a new 500 kV line from Vint Hill to Wishing Star.
- Description
- Build a new 500kV line from Vint Hill to Wishing Star. The line will be supported on single circuit monopoles. New conductor to have a summer rating of 4357 MVA. Line length is approximately 16.59 miles
- Cost Information
- Cost Alloc Type
- Contingent
System Reinforcement: b3800.357
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: b3800.357
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.357
- Title
- Build a new 500 kV line from Morrisville to Vint Hill.
- Description
- Build a new 500kV line from Morrisville to Vint Hill. New conductor to have a summer rating of 4357 MVA. Line length is approximately 19.71 miles.
- Cost Information
- Cost Alloc Type
- Contingent
System Reinforcement: b3800.354
AF1-123 did not load into this reinforcement directly however this project contributed to an topology or eliminated upgrade and therefore this project is responsible for relevant regional upgrades.
System Reinforcement: b3800.354
- Type
- Load Flow
- TO
- Dominion
- RTEP ID / TO ID
- b3800.354
- Title
- Install terminal equipment at Wishing Star Substation to support a 5000A line to Vint Hill. Update relay settings for 500 kV Lines #546 and #590.
- Description
- Install terminal equipment at Wishing Star substation to support a 5000A line to Vint Hill. Update relay settings for 500kV Lines #546 and #590.
- Cost Information
- Cost Alloc Type
- Contingent
Attachments
AF1-123 One Line Diagram
