AF1-125 Phase II Study Report
v1.00 released 2024-12-18 13:31
Oceana 230 kV
249.3 MW Capacity / 820.0 MW Energy
Introduction
This Phase II System Impact Study Report (PH2) has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 310 for New Service Requests (projects) in Transition Cycle #1. The Project Developer/Eligible Customer (developer) is Virginia Electric and Power Company, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Virginia Electric and Power Company.
Preface
The Phase II System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase II System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.5, PJM takes the following actions during the Phase II System Impact Study:
- PJM will retool load flow results from Phase I System Impact Study (summer peak, winter peak[1] and light load) based on decisions made by Project Developers or Eligible Customers during Decision Point I.
- PJM will conduct any required voltage analyses.
- PJM will perform short circuit and stability analyses as required.
- PJM will coordinate with the Affected System to confirm which projects in PJM Cycle will require Affected System studies. If the Affected System Operator indicates that an Affected System study is required, PJM will:
- Notify the Project Developer or Eligible Customer of the need for an Affected System study and the requirement to execute an Affected System study agreement with the impacted Affected System Operator, and;
- Include the results of the Affected System Operator’s Affected System Study in the Phase II System Impact Study results, if applicable and available
- The Phase II System Impact Study Results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase II System Impact Study:
- Verify Interconnection Facilities and Network Upgrades required to accommodate the New Service Request.
- Perform a Facilities Study. The Facilities Study in Phase II System Impact Study phase will be for the physical Interconnection Facilities. The Facilities Study requirements are outlined in Attachment C of PJM Manual 14H. The study will be conducted pursuant to Tariff, Part VII, Subpart D, section 307(A)(7).
Decision Point II Requirements
At the close of Phase II System Impact Study, PJM will initiate Decision Point II (DP2). During DP2, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.A. Additional information on these elements is available in PJM Manual 14H sections 4.6, 6, and 7.
Allowable project modifications at Decision Point II are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
Adverse Test Eligibility
This New Service Request does not meet the Adverse Study Impact Criteria and has the option to either move forward in the Cycle process or withdraw at DP2 with Readiness Deposit #1 forfeited. See adverse study impact calculation below.
This section details whether a Project Developer or Eligible Customer qualifies for the Adverse Study Impact clause outlined in the PJM OATT, Part VII, Subpart D, section 311.B and Manual 14H, section 6.2.2. In order to qualify for an Adverse Study Impact at Decision Point II, the Network Upgrade cost from Phase I to Phase II must:
- Increase overall by 25% or more
- Increases by more than $10,000 per MW (Includes Costs identified in Affected System studies)
If a New Service Request meets the criteria above and chooses to withdraw the request, PJM will refund the cumulative Readiness Deposit amounts paid at the Application Phase and at Decision Point I (RD1 and RD2, respectively).
The below calculations show the computation of this New Service Request's Adverse Study Impact
General
The Project Developer has proposed a Offshore Wind generating facility located in the Virginia Electric and Power Company zone — City of Chesapeake County, Virginia. The installed facilities will have a total capability of 820.0 MW with 249.3 MW of this output being recognized by PJM as Capacity.
| Project Information | |
|---|---|
| New Service Request Number | AF1-125 |
| Project Name | Oceana 230 kV |
| Project Developer Name | Virginia Electric and Power Company |
| State | Virginia |
| County | City of Chesapeake |
| Transmission Owner | Virginia Electric and Power Company |
| MFO | 820.0 MW |
| MWE | 820.0 MW |
| MWC | 249.3 MW |
| Fuel Type | Offshore Wind |
| Basecase Study Year | 2027 |
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 (Oceana) 230 kV Substation.
Cost Summary
The table below shows a summary of the total cost estimates for this New Service Request project. In Phase II SIS, the interconnected Transmission Owner has performed a facilities study for both the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades. The System Reliability Network Upgrade shown in the table are planning level cost estimates which are subject to change as a result of a facility study performed by the TO during Phase III System Impact Study.
Based on the Phase II SIS results, the AF1-125 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit #3 are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AF1-125 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $7,308,561 | $0 | |
| Other Scope | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $98,140,632 | $98,140,632 | |
| Network Upgrades | $148,258,344 | $148,258,344 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $270,359,808 | $270,359,808 | |
| Transient Stability | $48,396,143 | $48,396,143 | |
| Short Circuit | $489,929 | $489,929 | |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | |
| Distribution | $0 | $0 | |
| Affected System Study Reinforcements | $0 | $0 | |
| Total | $572,953,418 | $565,644,857 | |
* Contributes to calculation for Readiness Deposit #3 (RD3). See Readiness Deposit section of report for additional detail.
Definitions
Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.
Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.
Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.
Notes
Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.
Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.
Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.
Note 4: Please see the ‘Affected Systems Studies’ section of this Phase 2 SIS report for details on your project’s need for an Affected Systems Study. If your project requires an Affected Systems Study, the Affected Systems impacts may not be available from the Affected System Operator at the time of the PJM Phase II SIS. Therefore, the cost in this section would not reflect any required upgrades by the Affected System until the study is completed. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 311 (Decision Point II) A.1.b and PJM Manual 14H, section 6.2, Readiness Deposit #3 (RD3) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point II (DP2), the Project Developer or Eligible Customer is required to submit Readiness Deposit #3, which is calculated as 20% of cost allocation for required Phase II Network Upgrades minus Readiness Deposit #1 & Readiness Deposit #2.
Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.
Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (RD2) = 10% of cost allocation for required Network Upgrades minus RD1. Readiness Deposit #2 (RD2) can be zero, but may not be a negative number.
Note 4: Readiness Deposit #3 can be zero, but may not be a negative number.
Readiness Deposit #3 Due for Project AF1-125
Readiness Deposit #3 has been calculated for the AF1-125 project based on the Phase II System Impact Study results and is shown in the table below. This Readiness Deposit #3 must be provided at Decision Point II through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
| Readiness Deposit | |||
|---|---|---|---|
| Project ID | 20% of cost allocation for Phase II Network Upgrades | Sum of Readiness Deposit #1 & Readiness Deposit #2 Received (RD1+RD2) | Readiness Deposit #3 (RD3) for AF1-125 Project due at DP2 |
| A | B | A - B | |
| AF1-125 | $113,128,971 | $48,113,867 | $65,015,104 |
Note: Failure to provide an acceptable form of Readiness Deposit #3 by the end of Decision Point II will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The New Service Request Project will interconnect with the Dominion transmission system via a new Harpers switching station that connects at Fentress 230/500 kV substation. The required work for the interconnection of the New Service Request Project to the Dominion Transmission System is detailed in the following tables.
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
Transmission Owner Build Option
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| 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 |
$83,591,823 | $116,537,866 | $6,666,499 | $11,434,449 | $218,230,637 | $72,743,546 (See Note 1) |
| Stand-Alone Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($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) |
Transmission Owner Interconnection Facilities |
$1,493,879 | $18,556,359 | $317,295 | $1,558,150 | $21,925,683 | $7,308,561 (See Note 1) |
Developer Build Option
Project Developer has the option ("Option to Build") to assume responsibility for the design, procurement and construction of Transmission Owner Interconnection Facilities and/or Stand-Alone Network Upgrades.
If Option to Build is elected, the Project Developer must fulfill additional requirements in accordance to PJM Manual 14C, section 5.1 and PJM Manual 14H, section 8.6.2.
The cost estimates for eligible facilities and Option to Build oversight are highlighted below:
(No Developer Build Option for this project.)
| Build Option Price Comparison | |||||||
|---|---|---|---|---|---|---|---|
| Build Option | Total Cost | Allocated Cost | |||||
| Transmission Owner Build Option | $761,122,612 | $253,707,537 | |||||
| Developer Build Option | (No Developer Build Option) | ||||||
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.
The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.
Note 1: A Common Use Upgrade is a Network Upgrade that is needed for the interconnection of Generating Facilities or Merchant Transmission Facilities of more than one Project Developer or Eligible Customer and which is the shared responsibility of each Project Developer or Eligible Customer. If multiple Project Developers request to connect to the same interconnection substation, the Transmission Owner will determine the cost to accommodate all the requests at the substation. The cost for the interconnection will be allocated in proportion to the number of required terminations into the substation.
It is estimated to take 10 months to complete this work upon execution of the Generator Interconnection Agreement (GIA).This estimated time to complete is dependent on major equipment lead times. These preliminary cost estimates are based on typical engineering costs. A more detailed engineering cost estimates are normally done when the Project Developer provides an exact site plan location for the generation substation during a future study phase. As shown in the one line diagram, this Interconnection Request is sharing the Point of Interconnection (POI) and Interconnection Facilities with one or more other Interconnection Requests. Should other requests withdraw from Transition Cycle 1, the cost allocation for Transmission Owner Interconnection Facilities, Stand Alone Network Upgrades, and applicable Network Upgrades identified in the study report will be updated for the remaining project(s). Refer to the one line for other Interconnection Requests at this POI.
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 2 of the PJM interconnection process, TO’s System Protection Engineering Department will review transmission line protection as well as anti-islanding required to accommodate the new generation and interconnection substation. System Protection Engineering will determine the minimal acceptable protection requirements to reliably interconnect the proposed generating facility with the transmission system. The review is based on maintaining system reliability by reviewing TO’s protection requirements with the known transmission system configuration which includes generating facilities in the area. This review may determine that transmission line protection and communication upgrades are required at remote substations.
Transmission Owner Analysis
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. Refer to AF1-125 Physical Interconnection Facilities Study for additional requirements found in the General Section of the report.
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 and in the Physical Interconnection Facilities Study.
Summer Peak Analysis
The New Service Request was evaluated as a 820.0 MW (249.3 MW Capacity) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential summer peak period network impacts were as follows:
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.
| Summer Peak Analysis | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 ckt 1 |
DVP_P4-2: H2T557_SRT-S
CONTINGENCY 'DVP_P4-2: H2T557_SRT-S' OPEN BRANCH FROM BUS 314218 TO BUS 314908 CKT 2 /*6ELMONT 230.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 127.4 | 1065.0 | C | 1356.77 | 107.44 | ||
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Summer Peak Analysis - Eliminated Flowgates | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P4-2: 568T575_SRT-A
CONTINGENCY 'DVP_P4-2: 568T575_SRT-A' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.64 | 3940.0 | C | 4556.09 | 139.51 | ||
| DVP |
8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 105.86 | 3220.44 | B | 3409.14 | 39.23 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 130.64 | 3220.44 | B | 4207.12 | 48.75 | ||
| DVP |
8OX-8CLIFTON 500.0 kV Ckt 1 line
314919 to 314904 ckt 1 |
DVP_P1-2: LN 569_SRT-S
CONTINGENCY 'DVP_P1-2: LN 569_SRT-S' OPEN BRANCH FROM BUS 314913 TO BUS 314916 CKT 1 /*8LOUDOUN 500.0 - 8MORRSVL 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 END |
Single | AC | 101.58 | 2686.52 | B | 2728.9 | 27.02 | ||
| DVP |
8BRISTER-8OX 500.0 kV Ckt 1 line
314900 to 314919 ckt 1 |
DVP_P4-2: 541T569_SRT-S
CONTINGENCY 'DVP_P4-2: 541T569_SRT-S' OPEN BRANCH FROM BUS 314913 TO BUS 314916 CKT 1 /*8LOUDOUN 500.0 - 8MORRSVL 500.0 OPEN BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 END |
Breaker | AC | 102.37 | 3940.0 | C | 4033.4 | 118.26 | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 126.76 | 3220.44 | B | 4082.33 | 50.57 | ||
| DVP |
8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1 |
DVP_P4-2: 545T552_SRT-S
CONTINGENCY 'DVP_P4-2: 545T552_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 END |
Breaker | AC | 109.79 | 3940.0 | C | 4325.61 | 134.33 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P4-2: 557T574_SRT-S
CONTINGENCY 'DVP_P4-2: 557T574_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 126.3 | 3940.0 | C | 4976.42 | 242.56 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P4-2: 57602_SRT-S
CONTINGENCY 'DVP_P4-2: 57602_SRT-S' OPEN BRANCH FROM BUS 314232 TO BUS 314918 CKT 1 /*6NO ANNA 230.0 - 8NO ANNA 500.0 OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA 500.0 - 8SPOTSYL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA 500.0 - 8SPOTSYL 500.0 END |
Breaker | AC | 113.73 | 5011.0 | C | 5699.19 | 261.33 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 122.75 | 4070.2 | B | 4996.17 | 79.48 | ||
| DVP |
8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer
314914 to 314322 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 112.19 | 1058.16 | B | 1187.18 | 18.83 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P1-2: LN 552_SRT-S
CONTINGENCY 'DVP_P1-2: LN 552_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 130.95 | 3220.44 | B | 4217.23 | 49.51 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P4-2: H1T594_SRT-S
CONTINGENCY 'DVP_P4-2: H1T594_SRT-S' OPEN BRANCH FROM BUS 314063 TO BUS 314916 CKT 1 /*6MORRSVL 230.0 - 8MORRSVL 500.0 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 OPEN BUS 314897 /*8MORRS_1 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 END |
Breaker | AC | 113.7 | 3940.0 | C | 4479.66 | 103.94 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P1-2: LN 594_SRT-S
CONTINGENCY 'DVP_P1-2: LN 594_SRT-S' OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 119.79 | 3220.44 | B | 3857.63 | 31.52 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 106.97 | 3220.44 | B | 3444.92 | 64.63 | ||
| DVP |
8CARSON-6CARSON 500.0/230.0 kV Ckt 2 transformer
314902 to 314282 ckt 2 |
DVP_P4-2: 56372_SRT-S
CONTINGENCY 'DVP_P4-2: 56372_SRT-S' OPEN BRANCH FROM BUS 314282 TO BUS 314902 CKT 1 /*6CARSON 230.0 - 8CARSON 500.0 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 132.78 | 1056.8 | C | 1403.21 | 58.03 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P4-2: H2T574_SRT-S
CONTINGENCY 'DVP_P4-2: H2T574_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 2 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 123.28 | 3940.0 | C | 4857.22 | 226.56 | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P1-2: LN 575_SRT-S
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Single | AC | 128.15 | 3220.44 | B | 4127.12 | 40.28 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
Single | AC | 104.94 | 3220.44 | B | 3379.63 | 65.21 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P4-2: SPOTS H1T594_SRT-S
CONTINGENCY 'DVP_P4-2: SPOTS H1T594_SRT-S' OPEN BRANCH FROM BUS 314755 TO BUS 314934 CKT 1 /*3SPOTSYL 115.0 - 8SPOTSYL 500.0 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Breaker | AC | 116.8 | 3940.0 | C | 4602.03 | 109.59 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P4-2: 563T576_SRT-S
CONTINGENCY 'DVP_P4-2: 563T576_SRT-S' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 111.33 | 3144.0 | C | 3500.17 | 247.14 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P4-2: H1T575_SRT-S
CONTINGENCY 'DVP_P4-2: H1T575_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 1 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.3 | 3940.0 | C | 4542.79 | 129.34 | ||
| DVP |
8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1 |
DVP_P1-2: LN 552_SRT-S
CONTINGENCY 'DVP_P1-2: LN 552_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 104.85 | 3220.44 | B | 3376.72 | 39.12 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 108.51 | 4070.2 | B | 4416.63 | 68.76 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P1-2: LN 573_SRT-A
CONTINGENCY 'DVP_P1-2: LN 573_SRT-A' OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA 500.0 - 8SPOTSYL 500.0 END |
Single | AC | 122.44 | 3220.44 | B | 3943.26 | 33.55 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 102.87 | 2442.12 | B | 2512.29 | 73.88 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1-2: LN 574_SRT-S
CONTINGENCY 'DVP_P1-2: LN 574_SRT-S' OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 130.89 | 3220.44 | B | 4215.14 | 68.14 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1-2: LN 574_SRT-S
CONTINGENCY 'DVP_P1-2: LN 574_SRT-S' OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 113.49 | 3220.44 | B | 3654.86 | 61.51 | ||
| DVP |
8OX-8CLIFTON 500.0 kV Ckt 1 line
314919 to 314904 ckt 1 |
DVP_P7-1: LN 2101-569_SRT-S
CONTINGENCY 'DVP_P7-1: LN 2101-569_SRT-S' OPEN BRANCH FROM BUS 313712 TO BUS 313716 CKT 1 /*6VINTHIL TP 230.0 - 6VINTHIL DP 230.0 OPEN BRANCH FROM BUS 313712 TO BUS 314119 CKT 1 /*6VINTHIL TP 230.0 - 6NOKESVL 230.0 OPEN BRANCH FROM BUS 313712 TO BUS 314125 CKT 1 /*6VINTHIL TP 230.0 - 6VINTHIL 230.0 OPEN BRANCH FROM BUS 314119 TO BUS 314130 CKT 1 /*6NOKESVL 230.0 - 6BRISTER 230.0 OPEN BRANCH FROM BUS 314913 TO BUS 314916 CKT 1 /*8LOUDOUN 500.0 - 8MORRSVL 500.0 OPEN BUS 313712 /*6VINTHIL TP 230.0 OPEN BUS 313716 /*6VINTHIL DP 230.0 OPEN BUS 314119 /*6NOKESVL 230.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 END |
Tower | AC | 106.47 | 3144.0 | C | 3347.47 | 96.05 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P4-2: 56372_SRT-S
CONTINGENCY 'DVP_P4-2: 56372_SRT-S' OPEN BRANCH FROM BUS 314282 TO BUS 314902 CKT 1 /*6CARSON 230.0 - 8CARSON 500.0 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 111.53 | 3144.0 | C | 3506.36 | 246.43 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P4-2: H2T574_SRT-S
CONTINGENCY 'DVP_P4-2: H2T574_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 2 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.19 | 3940.0 | C | 4538.63 | 203.68 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P4-2: 568T575_SRT-A
CONTINGENCY 'DVP_P4-2: 568T575_SRT-A' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 121.21 | 3940.0 | C | 4775.7 | 137.27 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P4-2: 557T574_SRT-S
CONTINGENCY 'DVP_P4-2: 557T574_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 119.69 | 3940.0 | C | 4715.74 | 228.87 | ||
| DVP |
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer
314214 to 314903 ckt 1 |
DVP_P4-2: H4T567_SRT-A
CONTINGENCY 'DVP_P4-2: H4T567_SRT-A' OPEN BRANCH FROM BUS 314214 TO BUS 314903 CKT 2 /*6CHCKAHM 230.0 - 8CHCKAHM 500.0 OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
Breaker | AC | 115.67 | 1107.1 | C | 1280.58 | 89.6 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 155.32 | 663.64 | B | 1030.78 | 14.88 | ||
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.
| Summer Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6FENTRES-6THRASHER 230.0 kV Ckt 1 line
314466 to 314508 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 269.76 | 678.68 | B | 1830.8 | 465.96 | ||
| DVP |
6POCATY-6LANDSTN 230.0 kV Ckt 1 line
316171 to 314481 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 164.07 | 678.68 | B | 1113.54 | 236.37 | ||
| DVP |
6FENTRES-6POCATY 230.0 kV Ckt 1 line
314466 to 316171 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 157.19 | 678.68 | B | 1066.84 | 236.55 | ||
| DVP |
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer
314218 to 314908 ckt 2 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 102.24 | 879.84 | B | 899.51 | 71.24 | ||
| DVP |
6THRASHER-6YADKIN 230.0 kV Ckt 1 line
314508 to 314514 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 136.38 | 818.74 | B | 1116.58 | 291.77 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 105.29 | 2858.0 | B | 3009.3 | 123.94 | ||
| DVP |
8FENTRES-6FENTRES 500.0/230.0 kV Ckt 1 transformer
314909 to 314466 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 117.53 | 1115.59 | B | 1311.19 | 412.54 | ||
| DVP |
8FENTRES-6FENTRES 500.0/230.0 kV Ckt 2 transformer
314909 to 314466 ckt 2 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 117.38 | 1103.28 | B | 1295.03 | 407.46 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 2 line
314902 to 314914 ckt 2 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 110.71 | 4094.64 | B | 4533.15 | 202.4 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1: Carson-Midlothian_SRT-A
CONTINGENCY 'DVP_P1: Carson-Midlothian_SRT-A' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 2 /*8CARSON 500.0 - 8MDLTHAN 500.0 END |
OP | AC | 110.71 | 4094.64 | B | 4533.15 | 202.4 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 2 line
314914 to 314918 ckt 2 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 104.42 | 4094.64 | B | 4275.43 | 202.01 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1: Midlothian-NorthAnna_SRT-A
CONTINGENCY 'DVP_P1: Midlothian-NorthAnna_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 2 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 104.42 | 4094.64 | B | 4275.43 | 202.01 | ||
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Summer Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6KINGS M-6PENNIMAN 230.0 kV Ckt 1 line
314386 to 314296 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 100.49 | 984.18 | B | 989.02 | 77.04 | ||
| DVP |
6CHARCTY-6LAKESIDE 230.0 kV Ckt 1 line
314225 to 314227 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 108.48 | 984.18 | B | 1067.68 | 31.62 | ||
| DVP |
6IRON208-6SOUWEST 230.0 kV Ckt 1 line
314309 to 314338 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 126.31 | 663.64 | B | 838.26 | 47.06 | ||
| DVP |
6CHESTF A-6IRON208 230.0 kV Ckt 1 line
314286 to 314309 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 131.62 | 663.64 | B | 873.47 | 47.13 | ||
| DVP |
8CHANCE-8BRISTER 500.0 kV Ckt 1 line
314905 to 314900 ckt 1 |
DVP_P1-2: LN 594_SRT-S
CONTINGENCY 'DVP_P1-2: LN 594_SRT-S' OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
OP | AC | 104.61 | 4070.2 | B | 4257.94 | 158.72 | ||
| DVP |
6CHCKAHM-6ELKO 230.0 kV Ckt 1 line
314214 to 314258 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 100.74 | 678.68 | B | 683.69 | 49.43 | ||
| DVP |
8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer
314914 to 314322 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 142.35 | 1058.16 | B | 1506.29 | 61.95 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
Base Case | OP | AC | 100.12 | 4070.2 | A | 4075.17 | 172.49 | ||
| DVP |
6SKIFF CREEK-6KINGS M 230.0 kV Ckt 1 line
314209 to 314386 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 103.83 | 984.18 | B | 1021.91 | 77.04 | ||
| DVP |
6NRTHEST-6ELMONT 230.0 kV Ckt 1 line
314236 to 314218 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
OP | AC | 130.36 | 678.68 | B | 884.72 | 60.73 | ||
| DVP |
8LADYSMITH-8CHANCE 500.0 kV Ckt 1 line
314911 to 314905 ckt 1 |
DVP_P1-2: LN 573_SRT-A
CONTINGENCY 'DVP_P1-2: LN 573_SRT-A' OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA 500.0 - 8SPOTSYL 500.0 END |
OP | AC | 104.67 | 4070.2 | B | 4260.16 | 161.83 | ||
| DVP |
6GARYSVILLE-6HOPEWLL 230.0 kV Ckt 1 line
313902 to 314303 ckt 1 |
DVP_P1-2: LN 2197_SRT-A-2
CONTINGENCY 'DVP_P1-2: LN 2197_SRT-A-2' OPEN BRANCH FROM BUS 935160 TO BUS 314303 CKT 1 /*AD1-151 TP 230.0 - 6HOPEWLL 230.0 END |
OP | AC | 102.27 | 678.68 | B | 694.09 | 55.43 | ||
| DVP |
6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer
314322 to 314914 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 112.54 | 1058.16 | B | 1190.85 | 62.33 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
Base Case | OP | AC | 112.87 | 3220.44 | A | 3634.93 | 163.5 | ||
| DVP |
6CHESTF B-6VARINA 230.0 kV Ckt 1 line
314287 to 314260 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 112.12 | 984.18 | B | 1103.43 | 31.62 | ||
| DVP |
6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 102.7 | 984.18 | B | 1010.78 | 61.21 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
Base Case | OP | AC | 103.1 | 3193.18 | A | 3292.2 | 161.4 | ||
| DVP |
6SKIFF CREEK-6WALR285 230.0 kV Ckt 1 line
314209 to 314413 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 103.53 | 678.68 | B | 702.63 | 66.68 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
Base Case | OP | AC | 107.11 | 3220.44 | A | 3449.34 | 118.61 | ||
| DVP |
8SEPTA-8SURRY 500.0 kV Ckt 1 line
314923 to 314924 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 120.61 | 2442.12 | B | 2945.47 | 153.64 | ||
| DVP |
6LIGH209-6LANEXA 230.0 kV Ckt 1 line
314391 to 314388 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 130.6 | 663.64 | B | 866.7 | 77.04 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 186.29 | 663.64 | B | 1236.32 | 48.92 | ||
| DVP |
6VARINA-6CHARCTY 230.0 kV Ckt 1 line
314260 to 314225 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 112.08 | 984.18 | B | 1103.08 | 31.62 | ||
| DVP |
8MORRSVL-8LOUDOUN 500.0 kV Ckt 1 line
314916 to 314913 ckt 1 |
DVP_P1-2: LN 568_SRT-S
CONTINGENCY 'DVP_P1-2: LN 568_SRT-S' OPEN BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 END |
OP | AC | 115.98 | 3220.44 | B | 3734.98 | 92.21 | ||
| DVP |
AB2-190 TAP-6GARYSVILLE 230.0 kV Ckt 1 line
316099 to 313902 ckt 1 |
DVP_P1-2: LN 2197_SRT-A-2
CONTINGENCY 'DVP_P1-2: LN 2197_SRT-A-2' OPEN BRANCH FROM BUS 935160 TO BUS 314303 CKT 1 /*AD1-151 TP 230.0 - 6HOPEWLL 230.0 END |
OP | AC | 102.3 | 678.68 | B | 694.31 | 55.43 | ||
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 was evaluated as a 820.0 MW injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential light load period network impacts were as follows:
The following flowgates remain after considering the topology reinforcements required by the cycle.
| Light Load Analysis | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6FENTRES-6THRASHER 230.0 kV Ckt 1 line
314466 to 314508 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
Single | AC | 170.54 | 678.68 | B | 1157.41 | 373.19 | ||
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Light Load Analysis | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
Single | AC | 132.37 | 678.68 | B | 898.39 | 37.38 | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 127.88 | 678.68 | B | 867.92 | 38.44 | ||
| DVP |
6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
Single | AC | 131.89 | 678.68 | B | 895.11 | 37.38 | ||
| DVP |
6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 127.41 | 678.68 | B | 864.68 | 38.44 | ||
| DVP |
6BREMO-3BREMO 230.0/115.0 kV Ckt 1 transformer
314747 to 314744 ckt 1 |
DVP_P1-2: LN 2193_SRT-A
CONTINGENCY 'DVP_P1-2: LN 2193_SRT-A' OPEN BRANCH FROM BUS 313707 TO BUS 313867 CKT 1 /*6FORK UNION 230.0 - 6BREMODIST 230.0 OPEN BRANCH FROM BUS 313867 TO BUS 314747 CKT 1 /*6BREMODIST 230.0 - 6BREMO 230.0 OPEN BUS 313867 /*6BREMODIST 230.0 END |
Single | AC | 127.73 | 307.38 | B | 392.62 | 17.12 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 110.04 | 661.76 | B | 728.22 | 33.89 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 103.54 | 661.76 | B | 685.16 | 33.4 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 108.77 | 661.76 | B | 719.8 | 33.89 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 102.26 | 661.76 | B | 676.74 | 33.4 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-L-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-L-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 108.12 | 663.64 | B | 717.53 | 38.31 | ||
| DVP |
6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 107.1 | 661.76 | B | 708.72 | 33.89 | ||
| DVP |
6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 100.59 | 661.76 | B | 665.67 | 33.4 | ||
| DVP |
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 ckt 1 |
DVP_P4-2: H2T557_SRT-L
CONTINGENCY 'DVP_P4-2: H2T557_SRT-L' OPEN BRANCH FROM BUS 314218 TO BUS 314908 CKT 2 /*6ELMONT 230.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 3300 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 3300 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 113.74 | 1065.0 | C | 1211.33 | 108.19 | ||
Light Load Potential Congestion due to Local Energy Deliverability
The following flowgates remain after considering the topology reinforcements required by the cycle.
| Light Load Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6FENTRES-6THRASHER 230.0 kV Ckt 1 line
314466 to 314508 ckt 1 |
DVP_P1-2: LN 588_SRT-A
CONTINGENCY 'DVP_P1-2: LN 588_SRT-A' OPEN BRANCH FROM BUS 314909 TO BUS 314927 CKT 1 /*8FENTRES 500.0 - 8YADKIN 500.0 END |
OP | AC | 170.37 | 678.68 | B | 1156.29 | 373.19 | ||
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Light Load Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
OP | AC | 124.21 | 678.68 | B | 842.96 | 37.38 | ||
| DVP |
6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
OP | AC | 123.75 | 678.68 | B | 839.87 | 37.38 | ||
| DVP |
6BREMO-3BREMO 230.0/115.0 kV Ckt 1 transformer
314747 to 314744 ckt 1 |
DVP_P1-2: LN 2193_SRT-A
CONTINGENCY 'DVP_P1-2: LN 2193_SRT-A' OPEN BRANCH FROM BUS 313707 TO BUS 313867 CKT 1 /*6FORK UNION 230.0 - 6BREMODIST 230.0 OPEN BRANCH FROM BUS 313867 TO BUS 314747 CKT 1 /*6BREMODIST 230.0 - 6BREMO 230.0 OPEN BUS 313867 /*6BREMODIST 230.0 END |
OP | AC | 124.97 | 307.38 | B | 384.13 | 17.12 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 101.66 | 661.76 | B | 672.73 | 33.89 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 100.38 | 661.76 | B | 664.26 | 33.89 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-L-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-L-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 100.69 | 663.64 | B | 668.21 | 38.31 | ||
Short Circuit Analysis
Short Circuit Analysis is complete and requires a cost allocation for this project.
Bus Name | Project Contributor | Project ID | Breaker Overdutied | Breaker Capacity (Amps) | Duty Percent With All TC1 Online | Duty Percent Without TC1 Studied Project | Duty Percent Difference (%) | Duty Amps With All TC1 Online | Duty Amps Without TC1 Studied Project | Duty Amps Difference (Amps) | Full Amps Contribution | Contribution % | Cost Allocated |
Yadkin 2&4 230kV | 1 | AF1-125 | 210512 | 40000 | 101.97% | 100.11% | 1.86% | 40786 | 40043.3 | 742.70 | 742.7 | 32.7% | $489,929 |
Reinforcement ID: n6588
Reinforcement project: Replace 230kV Breaker 210512 at Yadkin 230kV with a 63 kA breaker
Total cost: $1,500,000
Period: 42-48 months
AF1-125 total cost allocated: $489,929
Stability Analysis
Analysis Complete - Issues Found
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
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 scenario for the analysis was based on the Regional Transmission Expansion Plan (RTEP) 2027 summer peak case, modified to include applicable projects. Cluster 29 projects have been dispatched online at maximum power output with near unity power factor measured at the high-side of the main substation transformer.
Cluster 29 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. 124 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 were observed to diverge. It was discovered that the dynamic models supplied for the power plant controller (PPC) PLNTBU1 were modeled at the Harpers 230 kV POI for all three queue projects. PSS/E disregard two PPCs as duplicates. Therefore, one PPC was attempting to control 2903.97 MVA with a base of 973.5 MVA. Modifications to Cluster 29 projects dynamic models to allowed the generators to converge.
- AF1-123
- PLNTBU1 ICON (M) (Bus number for voltage control) set to 946798
- ICON (M+1) (FROM bus number of the monitored branch) set to 946798
- ICON (M+2) (TO bus number of the monitored branch) set to 314963
- AF1-124
- PLNTBU1 ICON (M) (Bus number for voltage control) set to 946808
- ICON (M+1) (FROM bus number of the monitored branch) set to 946808
- ICON (M+2) (TO bus number of the monitored branch) set to 314963
- AF1-125
- PLNTBU1 ICON (M) (Bus number for voltage control) set to 946818
- ICON (M+1) (FROM bus number of the monitored branch) set to 946818
- ICON (M+2) (TO bus number of the monitored branch) set to 314963
The results of the analysis identified the addition of the Cluster 29 queue projects resulted in instability for an outage of the updated Fentress to Yadkins 500 kV circuit 588. Mitigation is required to connect Cluster 29 queue projects to resolve this instability. An additional 500 kV line from Updated Fentress 500 kV to Yadkin 500 kV mitigated the instability by allowing for an outlet to Yadkin’s to remain when the other circuit was lost. Dominion Energy provided details on the location and parameters that connect this line at Yadkins and Fentress. The EMT analysis performed for Cluster 29 confirms the additional needed outlet.
The results of the analysis identified the addition of the Cluster 29 queue projects resulted in instability after the modification to the impedances for the three (3) lines from Harpers to Fentress, using the planned impedances, for the contingencies listed in report. Mitigation is required to connect Cluster 29 queue projects to resolve this instability. Two (2) gas-insulated lines (GILs) between existing Fentress 230 kV and New Fentress 235 kV (represented as a zero-impedance branch because of the short physical distance), stable operation was observed for outages resulting in weak system conditions. Additionally, P4 contingencies at the Fentress 500 and 230 kV, Yadkin 230 and 500 kV, and Harpers 230 kV will require a generator station clearing time to maintain stability. The P4 delayed clearing time needed to be at 14 cycles at 230 kV and 13.5 cycles at 500 kV. The P5 contingencies at Fentress 230 kV substation required dual plot protection be installed to eliminate the delayed clearing for the outage to maintain stability.
Additionally, the Composite Short Circuit Ratio (CSCR) was less than 3 for an outage of the updated Fentress to Yadkin 500 kV circuit 588 transmission line prior to the mitigation.
Additionally, the AF1-123, AF1-124 and AF1-125 queue projects exhibited slow active power recovery after the fault was 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.
Additionally, the AF1-123, AF1-124 and AF1-125 queue projects exhibited oscillations during the faults for some contingencies. These oscillations were resolved after the fault was cleared and did not cause any recovery concerns. This can be examined further in the EMT analysis to determine the response after fault clearing incase this needs tuned.
The parameters are not consistent across all STATCOM’s and reactive recovery should be coordinated in future model submissions.
CVOW should work with SGRE to review the observed tripping of WTG’s (Protection Trip) under peak load conditions for the following P6 scenario an outage of one of the Yadkin – Fentress 500 kV Circuits followed by an outage of one of the Fentress – Harpers 230 kV Circuits. Under Light Loading Conditions CVOW remained Stable however a Protection Trip was observed for peak loading conditions for the same scenario. This appears to a “model” issue which may require the tunning of the SGRE WTG’s to mitigate. CVOW and SGRE should evaluate this operating condition and provide a response back to PJM and Dominion.
Lastly, for post fault oscillations a user defined model is recommended for lower SCR values less than 3.
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 Stability analysis.
AE2-051 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 any PJM or Dominion criteria . The models can be tuned to achieve a faster recovery upon request.
AE2-313 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 any PJM or Dominion criteria . The models can be tuned to achieve a recovery upon request.
AB2-169 generator tripped for overvoltages above 1.25 p.u. The unit rode through when the pickup timer was increased from 0.0 seconds to 0.0125 seconds.
AE2-051, AE2-156, and AE2-313 responses were not caused by the addition of the Cluster 29 queue projects. Cluster 29 queue projects were GNET and a sample of contingencies were simulated. Reactive and terminal voltage responses remain that same.
Dominion energy as an Interconnection Transmission Owner had performed EMT (PSCAD) analysis. Addition to the need for a second Yadkin to Fentress 500 kV Line they also identified a need for two 230 kV GIS bus ties. This reinforcement will be tested during phase 3.
Note:
The stability study results in this report may need some parameter changes. Analysis will be revisited during phase III SIS of Transition Cycle #1 to reflect the impacts of any parameter modifications. The high level findings indicate that the scope of the system reinforcement is not expected to change with the parameter modifications.
Reactive Power Analysis
The reactive power capability of Cluster 29 met the 0.95 leading and lagging power factor requirement measured at the point of interconnection (POI) Harper 230 kV substation.
Steady-State Voltage Analysis
Steady State Voltage Analysis is Not Required.
New Service Request Dependencies
The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.
| New Service Requests Dependencies | ||
|---|---|---|
| Project ID | Project Name | Status |
| AA1-139 | Hickory-Shawboro 230kV | In Service |
| AA1-145 | Four Rivers 230kV | In Service |
| AA2-088 | Boykins-Handsome 115kV | In Service |
| AA2-178 | Mackeys 230kV | In Service |
| AB1-027 | Old Church 34.5 KV | 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 |
| AB2-100 | Clubhouse-Lakeview 230kV | In Service |
| AB2-134 | Hopewell-Surry 230kV | In Service |
| AB2-161 | Waverly #2 DP 115kV | In Service |
| AB2-190 | Hopewell-Surry 230kV | In Service |
| AC1-027 | Pendleton 34.5kV | In Service |
| AC1-065 | Harmony Village-Shackleford 115kV | Under Construction |
| 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 | Suspended |
| AC1-191 | Elmont 115kV | Suspended |
| AC1-216 | Hopewell-Surry 230kV | In Service |
| AC2-012 | Grassfield-Great Bridge 115kV | In Service |
| AC2-079 | Ivor-Oak Ridge 115kV | Suspended |
| AC2-137 | Elko 34.5kV | In Service |
| AC2-138 | Northern Neck 34.5kV | In Service |
| AC2-141 | Septa 500kV | Engineering & Procurement |
| AD1-022 | Cashie-Trowbridge 230 kV | Engineering & Procurement |
| AD1-025 | Hopewell-Surry 230 kV | Engineering & Procurement |
| AD1-033 | Fentress-Landstown 230 kV | In Service |
| AD1-041 | Harmony Village-Shackleford 115 kV | In Service |
| AD1-063 | Harmony Village 34.5 kV | In Service |
| AD1-074 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-075 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-076 | Trowbridge 230 kV | Engineering & Procurement |
| AD1-082 | Bakers Pond-Ivor 115kV | In Service |
| AD1-105 | Kings Dominion DP 115 kV | Under Construction |
| AD1-144 | Kings Fork 34.5 kV | In Service |
| AD1-151 | Hopewell-Surry 230 kV | Suspended |
| AD2-030 | Wan 34.5 kV | In Service |
| AD2-073 | Sanders DP 230 kV | In Service |
| AD2-074 | Garner DP-Lancaster 115 kV | Suspended |
| AD2-085 | Myrtle-Windsor DP 115kV | Engineering & Procurement |
| AE1-072 | Shawboro-Sligo 230 kV | Engineering & Procurement |
| AE1-074 | Winterpock 34.5 kV | Suspended |
| AE1-075 | Powhatan 34.5 kV | Partially in Service - Under Construction |
| AE1-103 | Holland-Union Camp 115 kV | Engineering & Procurement |
| AE1-149 | Disputanta-Poe 115 kV | Suspended |
| AE1-155 | Garner-Northern Neck 115 kV | Partially in Service - Under Construction |
| AE1-162 | Smithfield 34.5 kV | In Service |
| AE1-175 | Light Foot 34.5 kV | In Service |
| AE1-190 | Harmony Village-Shackleford 115 kV | Under Construction |
| AE1-191 | Harmony Village-Shackleford 115 kV | Under Construction |
| AE2-027 | Harrowgate-Locks 115kV | Suspended |
| AE2-033 | Clubhouse-Sapony 230 kV | Suspended |
| AE2-034 | Mackeys 230 kV | Partially in Service - Under Construction |
| AE2-040 | Sapony 34.5 kV | Suspended |
| AE2-041 | Harmony Village 230 kV | Suspended |
| AE2-104 | Suffolk 115 kV | Suspended |
| AE2-122 | Birdneck-Landstown 230 kV | Active |
| AE2-147 | Swamp 230 kV | Active |
| AE2-156 | Yadkin 115 kV | Active |
| AE2-212 | Harrowgate 34 kV | Engineering & Procurement |
| AE2-227 | Iron Bridge 34 kV | Withdrawn |
| AE2-228 | Tyler 34 kv | Withdrawn |
| AE2-231 | St. Johns 115 kV | Active |
| AE2-247 | Myrtle-Windsor 115 kV | Engineering & Procurement |
| AE2-250 | Purdy Sw.-Reams 115 kV | Active |
| AE2-253 | Hickory-Moyock 230 kV | In Service |
| AF1-017 | Myrtle-Windsor 115 kV | Engineering & Procurement |
| AF1-018 | Harmony Village 230 kV | Suspended |
| AF1-032 | Suffolk 34.5 kV | In Service |
| AF1-042 | Garner DP-Lancaster 115 kV | Suspended |
| AF1-114 | Oak Grove-Dahlgren 230 kV | Suspended |
| AF1-123 | Oceana 230 kV | Active |
| AF1-124 | Oceana 230 kV | Active |
| AF1-128 | Chesterfield 230 kV | Active |
| AF1-129 | Chesterfield 230 kV | Engineering & Procurement |
| AF1-152 | Swamp 230 kV | Active |
| AF1-291 | Tyler 34.5 kV | Engineering & Procurement |
| AF2-013 | Arnold's Corner-Dahlgren 230 kV | Active |
| AF2-035 | St. Johns 115 kV | Active |
| AF2-043 | Suffolk 34.5 kV | In Service |
| AF2-046 | Tunis-Mapleton 115 kV | Active |
| AF2-054 | Wan 34.5 kV | Engineering & Procurement |
| AF2-077 | White Marsh 34.5 kV | In Service |
| AF2-081 | Moyock 230 kV | Active |
| AF2-091 | Oak Grove-Dahlgren 230 kV | Active |
| AF2-110 | Suffolk 115 kV | Suspended |
| AF2-120 | Garner-Northern Neck 115 kV | Active |
| AF2-144 | Powhatan 34.5 kV | In Service |
| AF2-300 | St. Johns 115 kV | Active |
| AG1-008 | Tunis-Mapleton 115 kV | Active |
| AG1-038 | Garner DP-Lancaster 115 kV | Active |
| AG1-075 | Purdy-Sapony 115 kV | Active |
| AG1-135 | Garner-Lancaster 115 kV | Active |
| AG1-145 | Lightfoot 34.5 kV | In Service |
| AG1-146 | Garner DP-Lancaster 115 kV | Active |
| AG1-147 | Garner DP-Lancaster 115 kV | Active |
| AG1-171 | Hopewell-Surry 230kV | Active |
| AG1-172 | Hopewell-Surry 230 kV | Active |
| AG1-173 | Hopewell-Surry 230 kV | Active |
| AG1-210 | Northern Neck 34.5 kV | Engineering & Procurement |
| AG1-213 | St Johns 13.2 kV | Withdrawn |
| AG1-282 | Dunnsville 34.5 kV | Engineering & Procurement |
| AG1-343 | Boykins-Murphy 115 kV | Active |
| AG1-393 | Fort Pickett DP 34.5 kV | Active |
| AG1-394 | Boykins 34.5 kV | Active |
| AG1-437 | Cashie-Earleys 230 kV | Active |
| AG1-438 | Cashie-Earleys 230 kV | Active |
| AG1-442 | Cashie-Earleys 230 kV | Active |
| AG1-443 | Cashie-Earleys 230 kV | Active |
| 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 | Partially in Service - Under Construction |
| Z1-068 | Birdneck 34.5kV | In Service |
| Z2-027 | Pasquotank 34.5kV | In Service |
Affected Systems
In Phase II of the Cycle, PJM provides the Affected System Operator any updates on the PJM projects that require an Affected Systems Study based on their response at DP1. New Service Requests that require an Affected Systems Study are required to enter into an Affected Systems Study Agreement with the Affected System Operator, as applicable, prior to the close of DP2 or they will be withdrawn from the Cycle.
If the Project Developer already entered into the necessary agreement and the results are available, PJM will supply them in the Phase II SIS report. See below for the status of any required Affected Systems Study. A status of “Pending” means that the study is not yet completed by the Affected System Operator. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
System Reinforcements
Based on the Phase II analysis results, this project has potential cost responsibility for the following System Reinforcements:
| AF1-125 System Reinforcements Cost Breakdown: | Type | TO | RTEP ID / TO ID | Title | MW Impact | Percent Allocation | Allocated Cost ($USD) | |||
|---|---|---|---|---|---|---|---|---|---|---|
| Stability | Dominion | n8492 | Construct a 13.5 Mile long 2nd Yadkin - Fentress 500 kV Line | 820.0 MW | 32.9% | $27,311,370 | ||||
| Stability | Dominion | n9259 / (Pending) | Need for Two 230 kV GIS Bus ties for CVOW | 820.0 MW | 32.9% | $9,883,487 | ||||
| Stability | Dominion | n8492.1 | Breaker Addition at Fentress Substation | 820.0 MW | 32.9% | $5,600,643 | ||||
| Stability | Dominion | n8492.2 | Expansion of Yadkin Substation to Accommodate the 500 kV Line | 820.0 MW | 32.9% | $5,600,643 | ||||
| Short Circuit | Dominion | n6588 / TC1-PH2-DOM-034 | Replace 230kV Breaker 210512 at Yadkin 230kV with a 63 kA breaker | 742.7 MW | 32.7% | $489,929 | ||||
| Load Flow | Dominion | n9251 / TC1-PH2-DOM-019 | Construct new 62.03 mile line between North Anna and Possum Point with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Possum Point to accommodate new line. | 167.9 MW | 21.1% | $69,589,978 | ||||
| Load Flow | Dominion | n9191 / TC1-PH1-DOM-090 | Wreck and rebuild 41.13 miles of Line 576 between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work to achieve new rating of 4356/4356/5009 MVA | 166.5 MW | 11.7% | $26,191,915 | ||||
| Load Flow | Dominion | n9248 / TC1-PH2-DOM-042 | Construct new 41.13 mile line between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Midlothian to accommodate new line. | 166.5 MW | 11.7% | $25,064,707 | ||||
| Load Flow | Dominion | n9139 / TC1-PH1-DOM-073 | Wreck and rebuild 37.26 miles of LN 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 | 355.7 MW | 12.2% | $25,001,138 | ||||
| Load Flow | Dominion | n9249 / TC1-PH2-DOM-043 | Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. | 355.7 MW | 12.2% | $23,847,239 | ||||
| Load Flow | Dominion | n9140 / TC1-PH1-DOM-071 | Construct new 14.02 mile line between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Spotsylvania and North Anna to accommodate new line. | 40.3 MW | 9.6% | $12,637,881 | ||||
| Load Flow | Dominion | n9246 / TC1-PH2-DOM-040 | 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 to achieve new rating of 4356/4356/5009 MVA | 49.5 MW | 11.9% | $12,601,911 | ||||
| Load Flow | Dominion | n9137 / TC1-PH1-DOM-069 | Construct new 18.75 mile line between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Morrisville and Spotsylvania to accommodate new line. | 49.5 MW | 11.9% | $11,683,084 | ||||
| Load Flow | Dominion | n9153 / TC1-PH1-DOM-043 | 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 as a double circuit. Replace Line Leads at both ends. | 373.2 MW | 32.9% | $11,242,449 | ||||
| Load Flow | Dominion | n9158 / TC1-PH1-DOM-089 | Expand Morrisville 500 kV substation and relocate line #545 and line #569 | 118.3 MW | 27.7% | $9,352,290 | ||||
| Load Flow | Dominion | n9247 / TC1-PH2-DOM-041 | 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 to achieve new rating of 4356/4356/5009 MVA. | 40.3 MW | 9.6% | $9,175,057 | ||||
| Load Flow | Dominion | n9261 / TC1-PH2-DOM-060 | Replace existing 230/500 kV Transformer #1 at Chickahominy with a larger device (3*480 MVA) with transformer ratings of 1440/1440/1440 MVA. | 89.6 MW | 23.7% | $9,000,559 | ||||
| Load Flow | Dominion | n9207 / TC1-PH2-DOM-018 | Replace 6ELMONT 230 KV to 8ELMONT 500 KV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM) | 107.4 MW | 22.6% | $10,164,791 | ||||
| Load Flow | Dominion | n9203 / TC1-PH2-DOM-008 | Wreck and rebuild 10.86 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C | 33.9 MW | 14.1% | $4,407,959 | ||||
| Load Flow | Dominion | n9112 / TC1-PH2-DOM-063 | 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. | 14.9 MW | 10.8% | $3,246,662 | ||||
| Load Flow | Dominion | n7569 / dom-490 | Reconductor 6.51 miles of line between Mt. Eagle and Cunningham with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C | 33.9 MW | 14.1% | $2,642,340 | ||||
| Load Flow | Dominion | n7568 / dom-369 | Wreck and rebuild 6.47 miles of line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle | 33.9 MW | 13.8% | $2,579,919 | ||||
| Load Flow | Dominion | n9199 / TC1-PH2-DOM-004 | Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo replace line lead at Bremo | 74.8 MW | 14.3% | $686,105 | ||||
| Load Flow | Dominion | n6161 / dom-039 | Replace 500 kV circuit breaker H1T561 at Clifton with a higher rated device (Clifton - Ox). | 96.0 MW | 26.4% | $557,259 | ||||
| Load Flow | Dominion | n9198 / TC1-PH2-DOM-003 | Replace Circuit Breaker and Circuit Breaker Lead at Bremo 230 kV (Bremo - Fork Union). | 74.8 MW | 27.2% | $367,412 | ||||
| Load Flow | Dominion | n9157 / TC1-PH1-DOM-047 | Replace Wave Trap at Fentress and Thrasher 230 kV (Fentress - Thrasher). | 373.2 MW | 32.9% | $131,780 | ||||
| Load Flow | Dominion | n9264 / TC1-PH2-DOM-066 | Replace wave trap and line lead at Surry 500 kV substation (Surry - Chickahominy) | 246.4 MW | 20.6% | $69,612 | ||||
| Load Flow | Dominion | n9156 / TC1-PH1-DOM-045 | Replace CT Relay at Fentress. (Fentress - Thrasher) | 373.2 MW | 32.9% | $49,417 | ||||
| Load Flow | Dominion | n9131 / TC1-PH1-DOM-097 | Substation work to energize the temporary Bremo transformer #7 which is not in service. | 17.1 MW | 29.9% | $25,208 | ||||
| Load Flow | Dominion | n9266 / TC1-PH2-DOM-065 | Replace CBSW at Basin 230 kV (Basin - Chesterfield B). | 14.9 MW | 10.8% | $24,974 | ||||
| Load Flow | Dominion | n9265 / TC1-PH2-DOM-064 | Replace 230 kV wave trap at Basin 230 kV (Basin - Chesterfield B). | 14.9 MW | 10.8% | $18,163 | ||||
| Grand Total: | $319,245,881 | |||||||||
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Stability | Dominion | n8492 | Construct a 13.5 Mile long 2nd Yadkin - Fentress 500 kV Line | $82,900,000 | $27,311,370 | 30 to 36 Months | |||
Contributor
Description: Construct one (1) overhead 500kV transmission line that will start at the existing Fentress 500 kV Substation and terminate at the existing Yadkin 500 kV Substation, located approximately 13.7 miles away.
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
| AF1-123 | 833.0 MW | 33.5% | $27,744,355 |
| AF1-124 | 836.0 MW | 33.6% | $27,844,275 |
| AF1-125 | 820.0 MW | 32.9% | $27,311,370 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Stability | Dominion | n9259 / (Pending) | Need for Two 230 kV GIS Bus ties for CVOW | $30,000,000 | $9,883,487 | 24 to 30 Months | |||
Contributor
Description: Need for two 230 kV GIS Bus Ties for Costal Virginia Offshore Wind Project.
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
| AF1-123 | 833.0 MW | 33.5% | $10,040,177 |
| AF1-124 | 836.0 MW | 33.6% | $10,076,336 |
| AF1-125 | 820.0 MW | 32.9% | $9,883,487 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Stability | Dominion | n8492.1 | Breaker Addition at Fentress Substation | $17,000,000 | $5,600,643 | 30 to 36 Months | |||
Contributor
Description: Install Two 5000 amp GIS Breakers at Fentress Substation .
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
| AF1-123 | 833.0 MW | 33.5% | $5,689,434 |
| AF1-124 | 836.0 MW | 33.6% | $5,709,924 |
| AF1-125 | 820.0 MW | 32.9% | $5,600,643 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Stability | Dominion | n8492.2 | Expansion of Yadkin Substation to Accommodate the 500 kV Line | $17,000,000 | $5,600,643 | 30 to 36 Months | |||
Contributor
Description: Expansion of yadkins 500 kV switchyard to accommodate the new 500 kV line which includes addition of 5000 amp GIS breakers and relocation of the existing suffolk -yadkin 500 kV line#565
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
| AF1-123 | 833.0 MW | 33.5% | $5,689,434 |
| AF1-124 | 836.0 MW | 33.6% | $5,709,924 |
| AF1-125 | 820.0 MW | 32.9% | $5,600,643 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Short Circuit | Dominion | n6588 / TC1-PH2-DOM-034 | Replace 230kV Breaker 210512 at Yadkin 230kV with a 63 kA breaker | $1,500,000 | $489,929 | Dec 01 2028 | |||
Contributor
Description: Replace 230kV Breaker 210512 at Yadkin 230kV with a 63 kA breaker
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
| AF1-123 | 757.3 MW | 33.3% | $499,560 |
| AF1-124 | 773.9 MW | 34.0% | $510,511 |
| AF1-125 | 742.7 MW | 32.7% | $489,929 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9251 / TC1-PH2-DOM-019 | Construct new 62.03 mile line between North Anna and Possum Point with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Possum Point to accommodate new line. | $390,789,000 | $69,589,978 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 62.03 mile line between North Anna and Possum Point with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Possum Point to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
62.6 MW | 7.9% | $25,951,524 |
|
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 |
170.5 MW | 21.4% | $70,690,515 |
|
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 |
171.2 MW | 21.5% | $70,944,198 |
|
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 |
167.9 MW | 21.1% | $69,589,978 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
28.5 MW | 3.6% | $11,805,794 |
| AF2-042 | 89.5 MW | 11.3% | $37,119,795 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
45.4 MW | 5.7% | $18,838,866 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
19.1 MW | 2.4% | $7,912,257 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
40.5 MW | 5.1% | $16,804,842 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9191 / TC1-PH1-DOM-090 | Wreck and rebuild 41.13 miles of Line 576 between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work to achieve new rating of 4356/4356/5009 MVA | $266,474,110 | $26,191,915 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Wreck and rebuild 41.13 miles of Line 576 between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S |
| 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
89.0 MW | 6.2% | $14,007,488 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
135.6 MW | 9.5% | $21,329,945 |
|
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 |
169.1 MW | 11.8% | $26,601,498 |
|
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 |
169.7 MW | 11.9% | $26,696,065 |
|
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 |
166.5 MW | 11.7% | $26,191,915 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
29.7 MW | 2.1% | $4,669,215 |
| AF2-042 | 191.1 MW | 13.4% | $30,062,419 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
55.7 MW | 3.9% | $8,763,944 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
55.7 MW | 3.9% | $8,763,944 |
| AG1-075 | 40.4 MW | 2.8% | $6,361,361 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
36.1 MW | 2.5% | $5,682,552 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
36.1 MW | 2.5% | $5,682,552 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
81.0 MW | 5.7% | $12,739,873 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
21.1 MW | 1.5% | $3,314,900 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
21.1 MW | 1.5% | $3,314,900 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
43.2 MW | 3.0% | $6,794,547 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
87.8 MW | 6.1% | $13,812,374 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9248 / TC1-PH2-DOM-042 | Construct new 41.13 mile line between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Midlothian to accommodate new line. | $255,006,000 | $25,064,707 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 41.13 mile line between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Midlothian to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S |
| 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
89.0 MW | 6.2% | $13,404,655 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
135.6 MW | 9.5% | $20,411,979 |
|
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 |
169.1 MW | 11.8% | $25,456,663 |
|
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 |
169.7 MW | 11.9% | $25,547,160 |
|
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 |
166.5 MW | 11.7% | $25,064,707 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
29.7 MW | 2.1% | $4,468,269 |
| AF2-042 | 191.1 MW | 13.4% | $28,768,638 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
55.7 MW | 3.9% | $8,386,775 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
55.7 MW | 3.9% | $8,386,775 |
| AG1-075 | 40.4 MW | 2.8% | $6,087,590 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
36.1 MW | 2.5% | $5,437,995 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
36.1 MW | 2.5% | $5,437,995 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
81.0 MW | 5.7% | $12,191,594 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
21.1 MW | 1.5% | $3,172,239 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
21.1 MW | 1.5% | $3,172,239 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
43.2 MW | 3.0% | $6,502,133 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
87.8 MW | 6.1% | $13,217,938 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9139 / TC1-PH1-DOM-073 | Wreck and rebuild 37.26 miles of LN 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 | $242,190,000 | $25,001,138 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Wreck and rebuild 37.26 miles of Line 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (Any) |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer | DVP_P4-2: 56372_SRT-S |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
40.1 MW | 1.4% | $2,816,410 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
438.8 MW | 15.1% | $30,841,818 |
|
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 |
361.3 MW | 12.4% | $25,396,403 |
|
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 |
362.6 MW | 12.5% | $25,487,644 |
|
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 |
355.7 MW | 12.2% | $25,001,138 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
13.4 MW | 0.5% | $938,780 |
| AF2-042 | 584.2 MW | 20.1% | $41,066,329 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
87.2 MW | 3.0% | $6,129,660 |
| AF2-222 | 34.1 MW | 1.2% | $2,397,175 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
87.2 MW | 3.0% | $6,129,660 |
| AG1-153 | 17.5 MW | 0.6% | $1,230,571 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,778,106 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,778,106 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
134.0 MW | 4.6% | $9,420,767 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,558,916 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,558,916 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
56.3 MW | 1.9% | $3,955,880 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
182.3 MW | 6.3% | $12,817,877 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9249 / TC1-PH2-DOM-043 | Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. | $231,012,000 | $23,847,239 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (Any) |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer | DVP_P4-2: 56372_SRT-S |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
40.1 MW | 1.4% | $2,686,422 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
438.8 MW | 15.1% | $29,418,349 |
|
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 |
361.3 MW | 12.4% | $24,224,261 |
|
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 |
362.6 MW | 12.5% | $24,311,292 |
|
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 |
355.7 MW | 12.2% | $23,847,239 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
13.4 MW | 0.5% | $895,452 |
| AF2-042 | 584.2 MW | 20.1% | $39,170,960 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
87.2 MW | 3.0% | $5,846,752 |
| AF2-222 | 34.1 MW | 1.2% | $2,286,536 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
87.2 MW | 3.0% | $5,846,752 |
| AG1-153 | 17.5 MW | 0.6% | $1,173,776 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,603,732 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,603,732 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
134.0 MW | 4.6% | $8,985,962 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,486,966 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,486,966 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
56.3 MW | 1.9% | $3,773,301 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
182.3 MW | 6.3% | $12,226,283 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9140 / TC1-PH1-DOM-071 | Construct new 14.02 mile line between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Spotsylvania and North Anna to accommodate new line. | $156,268,121 | $12,637,881 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 14.02 mile line between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Spotsylvania and North Anna to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4295.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4357.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 4996.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
37.1 MW | 8.8% | $11,639,262 |
|
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 | 9.7% | $12,835,848 |
|
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 |
41.1 MW | 9.8% | $12,881,339 |
|
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 | 9.6% | $12,637,881 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
24.1 MW | 5.7% | $7,567,920 |
| AF2-042 | 53.0 MW | 12.6% | $16,616,357 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.9 MW | 4.0% | $5,293,968 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
38.5 MW | 9.2% | $12,076,609 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.9 MW | 4.0% | $5,293,968 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
16.2 MW | 3.8% | $5,072,157 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.9 MW | 2.6% | $3,421,596 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.9 MW | 2.6% | $3,421,596 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
24.0 MW | 5.7% | $7,523,056 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.4 MW | 1.5% | $1,995,983 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.4 MW | 1.5% | $1,995,983 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
12.8 MW | 3.0% | $4,012,359 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
24.0 MW | 5.7% | $7,537,174 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9246 / TC1-PH2-DOM-040 | 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 to achieve new rating of 4356/4356/5009 MVA | $125,300,705 | $12,601,911 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Wreck and rebuild 18.75 miles of Line 594 between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
37.4 MW | 9.0% | $9,526,641 |
|
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 |
50.3 MW | 12.1% | $12,799,158 |
|
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 |
50.5 MW | 12.2% | $12,844,715 |
|
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 |
49.5 MW | 11.9% | $12,601,911 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
14.4 MW | 3.5% | $3,656,320 |
| AF2-042 | 54.2 MW | 13.0% | $13,787,683 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.5 MW | 4.0% | $4,205,557 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
22.9 MW | 5.5% | $5,834,689 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.5 MW | 4.0% | $4,205,557 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
9.6 MW | 2.3% | $2,450,697 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.7 MW | 2.6% | $2,717,171 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.7 MW | 2.6% | $2,717,171 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
23.1 MW | 5.6% | $5,878,211 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.2 MW | 1.5% | $1,585,101 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.2 MW | 1.5% | $1,585,101 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
12.3 MW | 3.0% | $3,135,080 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
24.2 MW | 5.8% | $6,169,118 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9137 / TC1-PH1-DOM-069 | Construct new 18.75 mile line between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Morrisville and Spotsylvania to accommodate new line. | $116,164,820 | $11,683,084 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 18.75 mile line between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Morrisville and Spotsylvania to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4295.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4357.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 4996.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
37.4 MW | 9.0% | $8,832,038 |
|
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 |
50.3 MW | 12.1% | $11,865,950 |
|
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 |
50.5 MW | 12.2% | $11,908,186 |
|
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 |
49.5 MW | 11.9% | $11,683,084 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
14.4 MW | 3.5% | $3,389,732 |
| AF2-042 | 54.2 MW | 13.0% | $12,782,399 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.5 MW | 4.0% | $3,898,923 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
22.9 MW | 5.5% | $5,409,272 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.5 MW | 4.0% | $3,898,923 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
9.6 MW | 2.3% | $2,272,012 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.7 MW | 2.6% | $2,519,057 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.7 MW | 2.6% | $2,519,057 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
23.1 MW | 5.6% | $5,449,621 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.2 MW | 1.5% | $1,469,529 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.2 MW | 1.5% | $1,469,529 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
12.3 MW | 3.0% | $2,906,496 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
24.2 MW | 5.8% | $5,719,317 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9153 / TC1-PH1-DOM-043 | 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 as a double circuit. Replace Line Leads at both ends. | $34,125,000 | $11,242,449 | 42 to 48 Months | |||
Contributor
Description: Wreck and rebuild 5.9 miles of 230 kV line 2128 between Fentress and Thrasher with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C as a double circuit. Replace Line Leads at both Fentress and Thrasher.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | A | 956.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | B | 1052.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | C | 1339.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
379.1 MW | 33.5% | $11,420,790 |
|
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 |
380.5 MW | 33.6% | $11,461,761 |
|
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 |
373.2 MW | 32.9% | $11,242,449 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9158 / TC1-PH1-DOM-089 | Expand Morrisville 500 kV substation and relocate line #545 and line #569 | $40,000,000 | $9,352,290 | 36 to 40 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Expand Morrisville 500 kV substation and relocate line #545 and line #569
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8BRISTER-8OX 500.0 kV Ckt 1 line | DVP_P4-2: 541T569_SRT-S |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
120.1 MW | 28.2% | $9,500,571 |
|
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 |
120.6 MW | 28.3% | $9,534,814 |
|
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 |
118.3 MW | 27.7% | $9,352,290 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
20.7 MW | 4.9% | $1,639,709 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
33.1 MW | 7.8% | $2,616,465 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
13.9 MW | 3.3% | $1,098,939 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9247 / TC1-PH2-DOM-041 | 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 to achieve new rating of 4356/4356/5009 MVA. | $113,450,107 | $9,175,057 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Wreck and rebuild 14.02 miles of Line 573 between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
37.1 MW | 8.8% | $8,450,063 |
|
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 | 9.7% | $9,318,780 |
|
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 |
41.1 MW | 9.8% | $9,351,807 |
|
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 | 9.6% | $9,175,057 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
24.1 MW | 5.7% | $5,494,284 |
| AF2-042 | 53.0 MW | 12.6% | $12,063,417 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.9 MW | 4.0% | $3,843,402 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
38.5 MW | 9.2% | $8,767,576 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
16.9 MW | 4.0% | $3,843,402 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
16.2 MW | 3.8% | $3,682,368 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.9 MW | 2.6% | $2,484,067 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
10.9 MW | 2.6% | $2,484,067 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
24.0 MW | 5.7% | $5,461,712 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.4 MW | 1.5% | $1,449,077 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.4 MW | 1.5% | $1,449,077 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
12.8 MW | 3.0% | $2,912,959 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
24.0 MW | 5.7% | $5,471,962 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9261 / TC1-PH2-DOM-060 | Replace existing 230/500 kV Transformer #1 at Chickahominy with a larger device (3*480 MVA) with transformer ratings of 1440/1440/1440 MVA. | $45,000,000 | $9,000,559 | 42 to 44 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Replace existing 230/500 kV Transformer #1 at Chickahominy with a larger device (3*480 MVA) with transformer ratings of 1440/1440/1440 MVA.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer | (All) | A | 1440.0 MVA |
| 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer | (All) | B | 1440.0 MVA |
| 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer | (All) | C | 1440.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
15.7 MW | 4.2% | $1,581,610 |
| AE2-156 | 11.2 MW | 3.0% | $1,120,236 |
|
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 |
91.0 MW | 24.1% | $9,143,200 |
|
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 |
91.3 MW | 24.2% | $9,176,148 |
|
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 |
89.6 MW | 23.7% | $9,000,559 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
5.2 MW | 1.4% | $527,170 |
|
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 |
11.8 MW | 3.1% | $1,184,223 |
| AG1-075 | 16.9 MW | 4.5% | $1,698,033 |
| AG1-135 | 11.4 MW | 3.0% | $1,149,367 |
|
AG1-146
⧉
AG1-146 115 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: AG1-146, AG1-147 |
5.8 MW | 1.5% | $584,226 |
|
AG1-147
⧉
AG1-146 115 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: AG1-146, AG1-147 |
13.6 MW | 3.6% | $1,363,328 |
|
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 |
14.3 MW | 3.8% | $1,432,539 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9207 / TC1-PH2-DOM-018 | Replace 6ELMONT 230 KV to 8ELMONT 500 KV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM) | $45,000,000 | $10,164,791 | 42 to 44 Months | |||
Contributor
Description: Replace 6ELMONT 230 KV to 8ELMONT 500 KV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM)
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | A | 1440.0 MVA |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | B | 1440.0 MVA |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | C | 1440.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
19.0 MW | 4.0% | $1,798,361 |
| AE2-156 | 13.4 MW | 2.8% | $1,270,244 |
| AE2-250 | 15.3 MW | 3.2% | $1,451,424 |
|
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 |
109.1 MW | 22.9% | $10,325,913 |
|
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 |
109.5 MW | 23.0% | $10,363,095 |
|
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 |
107.4 MW | 22.6% | $10,164,791 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
6.3 MW | 1.3% | $599,454 |
|
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 |
9.9 MW | 2.1% | $939,012 |
| AG1-075 | 27.9 MW | 5.9% | $2,638,883 |
|
AG1-146
⧉
AG1-146 115 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: AG1-146, AG1-147 |
4.9 MW | 1.0% | $466,715 |
|
AG1-147
⧉
AG1-146 115 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: AG1-146, AG1-147 |
11.5 MW | 2.4% | $1,088,875 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.6 MW | 1.4% | $626,512 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
6.6 MW | 1.4% | $626,512 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
15.9 MW | 3.3% | $1,504,311 |
|
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 |
12.0 MW | 2.5% | $1,135,897 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9203 / TC1-PH2-DOM-008 | Wreck and rebuild 10.86 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C | $31,222,500 | $4,407,959 | 42 to 48 Months | |||
Contributor
Description: Wreck and rebuild 10.86 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | A | 1174.0 MVA |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | B | 1195.0 MVA |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | C | 1360.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
34.4 MW | 14.3% | $4,478,195 |
|
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 |
34.5 MW | 14.4% | $4,493,803 |
|
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 |
33.9 MW | 14.1% | $4,407,959 |
|
AF1-294
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
6.2 MW | 2.6% | $804,983 |
|
AF1-323
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
10.8 MW | 4.5% | $1,404,850 |
| AF2-042 | 18.2 MW | 7.6% | $2,362,271 |
|
AF2-115
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.8 MW | 1.6% | $490,872 |
| AF2-171 | 22.6 MW | 9.4% | $2,933,003 |
| AF2-222 | 20.6 MW | 8.6% | $2,677,682 |
|
AF2-302
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
3.9 MW | 1.6% | $510,902 |
|
AG1-021
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.0 MW | 1.3% | $392,671 |
|
AG1-022
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
3.9 MW | 1.6% | $510,902 |
| AG1-098 | 13.4 MW | 5.6% | $1,749,006 |
| AG1-285 | 11.8 MW | 4.9% | $1,539,469 |
| AG1-427 | 11.0 MW | 4.6% | $1,425,400 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.0 MW | 3.3% | $1,040,533 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9112 / TC1-PH2-DOM-063 | 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. | $35,750,000 | $3,246,662 | 42 to 48 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Wreck and Rebuild 12.4 miles of 230 kV line 259 with (2) 768.2 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C and replace line lead at Chesterfield.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 797.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 797.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1115.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
5.6 MW | 4.0% | $1,221,182 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
13.3 MW | 9.6% | $2,893,949 |
|
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 |
15.1 MW | 10.9% | $3,297,299 |
|
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 |
15.2 MW | 11.0% | $3,309,085 |
|
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 |
14.9 MW | 10.8% | $3,246,662 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
1.9 MW | 1.3% | $407,061 |
| AF2-042 | 17.8 MW | 12.8% | $3,874,605 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $1,348,211 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $1,348,211 |
| AG1-075 | 8.2 MW | 5.9% | $1,792,158 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $829,836 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $829,836 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
8.7 MW | 6.3% | $1,902,599 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $484,107 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $484,107 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
4.6 MW | 3.4% | $1,014,705 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.6 MW | 6.2% | $1,874,006 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n7569 / dom-490 | Reconductor 6.51 miles of line between Mt. Eagle and Cunningham with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C | $18,716,250 | $2,642,340 | 36 to 40 Months | |||
Contributor
Description: Reconductor 6.51 miles of line between Mt. Eagle and Cunningham with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | A | 1315.0 MVA |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | B | 1435.0 MVA |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | C | 1745.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | A | 1315.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | B | 1435.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | C | 1745.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
34.4 MW | 14.3% | $2,684,443 |
|
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 |
34.5 MW | 14.4% | $2,693,799 |
|
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 |
33.9 MW | 14.1% | $2,642,340 |
|
AF1-294
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
6.2 MW | 2.6% | $482,545 |
|
AF1-323
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
10.8 MW | 4.5% | $842,134 |
| AF2-042 | 18.2 MW | 7.6% | $1,416,057 |
|
AF2-115
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.8 MW | 1.6% | $294,252 |
| AF2-171 | 22.6 MW | 9.4% | $1,758,181 |
| AF2-222 | 20.6 MW | 8.6% | $1,605,130 |
|
AF2-302
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
3.9 MW | 1.6% | $306,259 |
|
AG1-021
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.0 MW | 1.3% | $235,386 |
|
AG1-022
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
3.9 MW | 1.6% | $306,259 |
| AG1-098 | 13.4 MW | 5.6% | $1,048,437 |
| AG1-285 | 11.8 MW | 4.9% | $922,831 |
| AG1-427 | 11.0 MW | 4.6% | $854,453 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.0 MW | 3.3% | $623,745 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n7568 / dom-369 | Wreck and rebuild 6.47 miles of line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle | $18,701,250 | $2,579,919 | 36 to 40 Months | |||
Contributor
Description: Wreck and rebuild 6.47 miles of line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | A | 781.0 MVA |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | B | 869.0 MVA |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | C | 909.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
34.4 MW | 14.0% | $2,621,027 |
|
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 |
34.5 MW | 14.1% | $2,630,162 |
|
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 |
33.9 MW | 13.8% | $2,579,919 |
|
AF1-294
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
6.3 MW | 2.6% | $481,422 |
|
AF1-323
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
10.9 MW | 4.4% | $827,188 |
| AF2-042 | 21.0 MW | 8.5% | $1,596,063 |
|
AF2-115
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.9 MW | 1.6% | $293,543 |
| AF2-171 | 23.0 MW | 9.4% | $1,754,101 |
| AF2-222 | 21.2 MW | 8.6% | $1,611,440 |
|
AF2-302
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
4.0 MW | 1.6% | $300,775 |
|
AG1-021
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
3.1 MW | 1.3% | $234,849 |
|
AG1-022
⧉
AF1-323 138kV - AEP: 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: AF1-323, AF2-302, AG1-022 |
4.0 MW | 1.6% | $300,775 |
| AG1-098 | 13.9 MW | 5.6% | $1,056,556 |
| AG1-285 | 12.3 MW | 5.0% | $936,429 |
| AG1-427 | 11.4 MW | 4.6% | $867,991 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.0 MW | 3.3% | $609,010 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9199 / TC1-PH2-DOM-004 | Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo replace line lead at Bremo | $4,786,250 | $686,105 | 36 to 42 Months | |||
Contributor
Description: Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Bremo
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | (Any) |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | A | 781.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | B | 869.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | C | 909.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | A | 781.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | B | 869.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | C | 909.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | A | 781.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | B | 869.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | C | 909.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | A | 781.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | B | 869.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | C | 909.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
75.9 MW | 14.6% | $696,934 |
|
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 |
76.2 MW | 14.6% | $699,504 |
|
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 |
74.8 MW | 14.3% | $686,105 |
|
AF1-294
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
13.8 MW | 2.6% | $126,777 |
| AF2-042 | 40.9 MW | 7.8% | $375,283 |
|
AF2-115
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
8.4 MW | 1.6% | $77,311 |
| AF2-171 | 50.3 MW | 9.7% | $461,882 |
| AF2-222 | 45.9 MW | 8.8% | $421,226 |
|
AG1-021
⧉
AF1-294 115 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: AF1-294, AF2-115, AG1-021 |
6.7 MW | 1.3% | $61,838 |
| AG1-098 | 30.1 MW | 5.8% | $275,947 |
| AG1-285 | 26.3 MW | 5.1% | $241,752 |
| AG1-427 | 24.4 MW | 4.7% | $223,782 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
15.4 MW | 2.9% | $141,149 |
| AG1-451 | 14.4 MW | 2.8% | $132,118 |
| AG1-537 | 17.9 MW | 3.4% | $164,643 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n6161 / dom-039 | Replace 500 kV circuit breaker H1T561 at Clifton with a higher rated device (Clifton - Ox). | $2,500,000 | $557,259 | Dec 31 2029 | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Replace 500 kV circuit breaker H1T561 at Clifton with a higher rated device (Clifton - Ox).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CLIFTON-8OX 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CLIFTON-8OX 500.0 kV Ckt 1 line | (All) | A | 2857.0 MVA |
| 8CLIFTON-8OX 500.0 kV Ckt 1 line | (All) | B | 3117.0 MVA |
| 8CLIFTON-8OX 500.0 kV Ckt 1 line | (All) | C | 3793.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
19.2 MW | 5.3% | $111,332 |
|
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 |
97.6 MW | 26.8% | $566,095 |
|
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 |
97.9 MW | 26.9% | $568,131 |
|
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 | 26.4% | $557,259 |
|
AF2-037
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
12.3 MW | 3.4% | $71,653 |
|
AF2-063
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
19.7 MW | 5.4% | $114,338 |
|
AG1-305
⧉
AF2-037 230 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: AF2-037, AF2-063, AG1-305, AH1-012 |
8.3 MW | 2.3% | $48,022 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
12.4 MW | 3.4% | $72,094 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9198 / TC1-PH2-DOM-003 | Replace Circuit Breaker and Circuit Breaker Lead at Bremo 230 kV (Bremo - Fork Union). | $1,600,000 | $367,412 | 42 to 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.
Description: Replace Circuit Breaker and Circuit Breaker Lead at Bremo 230 kV (Bremo - Fork Union).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | (Any) |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | A | 876.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | B | 956.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | C | 1163.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | A | 876.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | B | 956.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | C | 1163.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | A | 876.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | B | 956.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | C | 1163.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | A | 876.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | B | 956.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | C | 1163.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| 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 |
75.9 MW | 27.7% | $373,211 |
|
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 |
76.2 MW | 27.8% | $374,587 |
|
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 |
74.8 MW | 27.2% | $367,412 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
15.4 MW | 5.6% | $75,586 |
| AG1-451 | 14.4 MW | 5.2% | $70,750 |
| AG1-537 | 17.9 MW | 6.5% | $88,167 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9157 / TC1-PH1-DOM-047 | Replace Wave Trap at Fentress and Thrasher 230 kV (Fentress - Thrasher). | $400,000 | $131,780 | 16 to 18 Months | |||
Contributor
Description: Replace Wave Trap at Fentress and Thrasher 230 kV (Fentress - Thrasher).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | A | 1572.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | B | 1572.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | C | 1808.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
379.1 MW | 33.5% | $133,870 |
|
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 |
380.5 MW | 33.6% | $134,350 |
|
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 |
373.2 MW | 32.9% | $131,780 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9264 / TC1-PH2-DOM-066 | Replace wave trap and line lead at Surry 500 kV substation (Surry - Chickahominy) | $400,000 | $69,612 | 16 to 18 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Replace wave trap and line lead at Surry 500 kV substation (Surry - Chickahominy)
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | A | 2598.0 MVA |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | B | 2858.0 MVA |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | C | 3637.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
40.2 MW | 3.4% | $11,358 |
| AE2-156 | 28.2 MW | 2.4% | $7,979 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
74.7 MW | 6.3% | $21,111 |
|
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 |
250.3 MW | 21.0% | $70,715 |
|
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 |
251.2 MW | 21.0% | $70,970 |
|
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 |
246.4 MW | 20.6% | $69,612 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
13.4 MW | 1.1% | $3,786 |
| AF2-042 | 101.0 MW | 8.5% | $28,544 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
29.4 MW | 2.5% | $8,301 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
29.4 MW | 2.5% | $8,301 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.3 MW | 1.9% | $6,294 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
22.3 MW | 1.9% | $6,294 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
26.7 MW | 2.2% | $7,536 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
7.8 MW | 0.7% | $2,203 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
7.8 MW | 0.7% | $2,203 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
14.2 MW | 1.2% | $4,019 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
29.0 MW | 2.4% | $8,202 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9156 / TC1-PH1-DOM-045 | Replace CT Relay at Fentress. (Fentress - Thrasher) | $150,000 | $49,417 | 12 to 18 Months | |||
Contributor
Description: Repalce CT Relay at Fentress.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | A | 1195.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | B | 1195.0 MVA |
| 6FENTRES-6THRASHER 230.0 kV Ckt 1 line | (All) | C | 1673.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
379.1 MW | 33.5% | $50,201 |
|
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 |
380.5 MW | 33.6% | $50,381 |
|
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 |
373.2 MW | 32.9% | $49,417 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9131 / TC1-PH1-DOM-097 | Substation work to energize the temporary Bremo transformer #7 which is not in service. | $100,000 | $25,208 | 6 to 12 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: There is a Temporary transformer at Bremo substation which is not in service. The cost is to energizing the temporary transformer #7 Ratings are 290/290/332 MVA.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 3BREMO-6BREMO 115.0/230.0 kV Ckt 1 transformer | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 3BREMO-6BREMO 115.0/230.0 kV Ckt 1 transformer | (All) | A | 290.0 MVA |
| 3BREMO-6BREMO 115.0/230.0 kV Ckt 1 transformer | (All) | B | 290.0 MVA |
| 3BREMO-6BREMO 115.0/230.0 kV Ckt 1 transformer | (All) | C | 332.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($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 |
17.4 MW | 30.4% | $25,606 |
|
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 |
17.4 MW | 30.5% | $25,694 |
|
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 |
17.1 MW | 29.9% | $25,208 |
| AG1-537 | 5.3 MW | 9.3% | $7,848 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9266 / TC1-PH2-DOM-065 | Replace CBSW at Basin 230 kV (Basin - Chesterfield B). | $275,000 | $24,974 | 12 to 18 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Replace CBSW at Basin 230 kV (Basin - Chesterfield B).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 1174.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 1302.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1360.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
5.6 MW | 4.0% | $9,394 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
13.3 MW | 9.6% | $22,261 |
|
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 |
15.1 MW | 10.9% | $25,364 |
|
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 |
15.2 MW | 11.0% | $25,455 |
|
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 |
14.9 MW | 10.8% | $24,974 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
1.9 MW | 1.3% | $3,131 |
| AF2-042 | 17.8 MW | 12.8% | $29,805 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $10,371 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $10,371 |
| AG1-075 | 8.2 MW | 5.9% | $13,786 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $6,383 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $6,383 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
8.7 MW | 6.3% | $14,635 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $3,724 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $3,724 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
4.6 MW | 3.4% | $7,805 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.6 MW | 6.2% | $14,415 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9265 / TC1-PH2-DOM-064 | Replace 230 kV wave trap at Basin 230 kV (Basin - Chesterfield B). | $200,000 | $18,163 | 16 to 18 Months | |||
ContributorEliminated Note: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle. However, this project is receiving cost allocation based on its MW contribution to this eliminated reinforcement to fund the topology reinforcements which together alleviated the need for this reinforcement. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report. Since this project contributed to a violation with a reinforcement that was eliminated by the topology changing reinforcements, this project is contingent on all of the topology changing reinforcements within the region in which the eliminated reinforcement belongs.
Description: Replace 230 kV wave trap at Basin 230 kV (Basin - Chesterfield B).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 876.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 956.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1163.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 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: AE2-147, AF1-152 |
5.6 MW | 4.0% | $6,832 |
|
AE2-313
⧉
AE2-313 500 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: AE2-313, AG1-449 |
13.3 MW | 9.6% | $16,190 |
|
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 |
15.1 MW | 10.9% | $18,446 |
|
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 |
15.2 MW | 11.0% | $18,512 |
|
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 |
14.9 MW | 10.8% | $18,163 |
|
AF1-152
⧉
Swamp 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: AE2-147, AF1-152 |
1.9 MW | 1.3% | $2,277 |
| AF2-042 | 17.8 MW | 12.8% | $21,676 |
|
AF2-046
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $7,542 |
|
AG1-008
⧉
AF2-046 115 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: AF2-046, AG1-008 |
6.2 MW | 4.5% | $7,542 |
| AG1-075 | 8.2 MW | 5.9% | $10,026 |
|
AG1-437
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $4,642 |
|
AG1-438
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
3.8 MW | 2.8% | $4,642 |
|
AG1-439
⧉
Chinquapin 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: AG1-439, AG1-444 |
8.7 MW | 6.3% | $10,644 |
|
AG1-442
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $2,708 |
|
AG1-443
⧉
AG1-437 230 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: AG1-437, AG1-438, AG1-442, AG1-443 |
2.2 MW | 1.6% | $2,708 |
|
AG1-444
⧉
Chinquapin 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: AG1-439, AG1-444 |
4.6 MW | 3.4% | $5,677 |
|
AG1-449
⧉
AE2-313 500 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: AE2-313, AG1-449 |
8.6 MW | 6.2% | $10,484 |
Attachments
[1]Winter load flow analysis will be performed starting in Transition Cycle #2.