Export to CSV

AF1-123 Phase I Study Report

v1.00 released 2024-05-16 00:11

Oceana 230 kV

267.5 MW Capacity / 880.0 MW Energy

Introduction

This Phase I System Impact Study Report (PH1) has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, sections 307 and 308 for New Service Requests (projects) in Transition Cycle #1. The Project Developer/Eligible Customer (developer) is Virginia Electric & 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 I System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase I System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.

In accordance with PJM Manual 14H, section 4.3, PJM takes the following actions during the Phase I System Impact Study:
  1. PJM studies each New Service Request on a summer peak, winter peak[1] and light load RTEP base case study. The case year is dependent on the new services cycle under study. PJM will identify the base case year to be used in the study of a specific cycle on its website.
  2. PJM will only perform load flow analysis during the Phase I System Impact Study.
  3. In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with Affected System impacts and provides each Affected System Operator with a list of New Service Request in the Cycle with potential impacts to their respective system.
  4. PJM will create both the short circuit and stability base cases to be used in the Phase II System Impact Study.
  5. The Phase I System Impact Study results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase I System Impact Study:
  1. Identify required Interconnection Facilities to accommodate the New Service Request.
  2. Identify required Network Upgrades to mitigate system violations from the Phase I System Impact Study.
  3. Provide planning-level preliminary estimates of Interconnection Facilities and Network Upgrades including scope, cost and elapsed time to complete the work.

Decision Point I Requirements

At the close of Phase I System Impact Study, PJM will initiate Decision Point I (DP1). During DP1, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.A.1. Additional information on these elements is available in PJM Manual 14H sections 4.4, 6, and 7.

Allowable project modifications at Decision Point I are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 309.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.

General

The 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 880.0 MW with 267.5 MW of this output being recognized by PJM as Capacity.

Project Information
New Service Request Number AF1-123
Project Name Oceana 230 kV
Developer Name Virginia Electric & Power Company
State Virginia
County City of Chesapeake
Transmission Owner Virginia Electric and Power Company
MFO 880.0 MW
MWE 880.0 MW
MWC 267.5 MW
Fuel Type Offshore Wind
Basecase Study Year 2027

Point of Interconnection

AF1-123 will interconnect on the Dominion transmission system at the Oceana 230 kV Substation.

Cost Summary

The table below shows a summary of the total planning level cost estimates for this New Service Request project. These network upgrade costs are subject to change as a result of a facility study performed by the TO during the Phase II or Phase III System Impact Study.

Based on the Phase I SIS results, the AF1-123 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit are also shown below.

Cost Summary
Description Cost Allocated to AF1-123 Cost Subject to Readiness*
Transmission Owner Interconnection Facilities (TOIF) $4,833,333 $0
Physical Interconnection Network Upgrades
Stand Alone Network Upgrades $263,300,000 $263,300,000
Network Upgrades $0 $0
System Reliability Network Upgrades
Steady State Thermal & Voltage (SP & LL) $217,174,869 $217,174,869
Transient Stability $0 $0
Short Circuit $0 $0
Transmission Owner Analysis
SubRegional $0 $0
Distribution $0 $0
Affected System Study Reinforcements $0 $0
Total $485,308,203 $480,474,869

* Contributes to calculation for Readiness Deposit #2 (RD2). See Readiness Deposit section of report for additional detail.

Definitions

Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.

Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.

Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.

Notes

Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.

Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.

Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.

Readiness Deposit

Per Tariff Part VII, Subpart D, section 309 (Decision Point I) A.1.a.i and PJM Manual 14H, section 6.2, Readiness Deposit #2 (RD2) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below and not used to fund studies nor to offset Security.

During Decision Point I (DP1), the Project Developer or Eligible Customer is required to submit Readiness Deposit #2, which is calculated as 10% of cost allocation for required Phase I Network Upgrades minus Readiness Deposit #1.

Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.

Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))

Note 3: Readiness Deposit #2 can be zero, but may not be a negative number.

Readiness Deposit #2 Due for Project AF1-123

Readiness Deposit #2 has been calculated for the project based on the Phase I System Impact Study results and is shown in the table below. This Readiness Deposit #2 must be provided at Decision Point I through either a wire transfer or letter of credit per Manual 14H, Section 6.2.

Readiness Deposit
Project ID 10% of cost allocation for Phase I Network Upgrades Readiness Deposit #1 Received (RD1) Readiness Deposit #2 (RD2) for AF1-123 Project due at DP1
A B A - B
AF1-123 $48,047,487 $3,520,000 $44,527,487

Note: Failure to provide an acceptable form of Readiness Deposit #2 by the end of Decision Point I will result in withdrawal and termination of the New Service Request.

For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.

Transmission Owner Scope of Work

The 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 Interconnection Facilities
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending)
Install nine (9) Export Circuits to the point of interconnection ("POI"), metering, and associated protection equipment.
$14,500,000 $4,833,333 (See Note 1)
Stand-Alone Network Upgrades
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending)
Build a new Harpers 230 kV substation.  Add three (3) 300 MVAR STATCOMs.
$228,300,000 $76,100,000 (See Note 1)
(Pending)
Install three (3) new 230 kV lines beween New Fentress and Harpers.
$304,500,000 $101,500,000 (See Note 1)
(Pending)
Build a New Fentress 230 kV double breaker double bus substation.
$99,600,000 $33,200,000 (See Note 1)
(Pending)
Upgrade the Fentress 500 kV substation to be a double breaker double bus substation. Install three (3) new 230/500 kV transformers.
$157,500,000 $52,500,000 (See Note 1)

Based on the scope of work for the Interconnection Facilities, it is expected to take a range of 36 to 40 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 36 to 40 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

System Protection
The Project Developer must design its Generating Facility in accordance with all applicable standards, including the standards in Dominion’s “Dominion Energy Electric Transmission Generator Interconnection Requirements” documented in Dominion’s Facility Interconnection Requirements located at: https://www.pjm.com/-/media/planning/plan-standards/private-dominion/facility-connection-requirements1.ashx. Preliminary Protection requirements will be provided as part of the Facilities Study. Detailed Protection Requirements will be provided once the project enters the construction phase.


Compliance Issues and Project Developer Requirements
The proposed Generating Facility must be designed in accordance with Dominion’s “Dominion’s Facility Interconnection Requirements” document located at: https://www.pjm.com/-/media/planning/plan-standards/private-dominion/facility-connection-requirements1.ashx.

In particular, the Project Developer is responsible for the following:

  1. The purchase and installation of a fully rated protection device (circuit breaker, circuit switcher, fuse) to protect the Project Developer’s GSU transformer(s).
  2. The purchase and installation of the minimum required Dominion generation interconnection relaying and control facilities as described in the System Protection section noted above. This includes over/under voltage protection, over/under frequency protection, and zero sequence voltage protection relays.
  3. The purchase and installation of supervisory control and data acquisition (“SCADA”) equipment to provide information in a compatible format to the Dominion Transmission System Control Center.
  4. Compliance with the Dominion and PJM generator power factor and voltage control requirements. The GSU(s) associated with the Project Developer New Service Request Project shall meet the grounding requirements as noted in Dominion’s  “Dominion’s Facility Interconnection Requirements” document located at: https://www.pjm.com/-/media/planning/plan-standards/private-dominion/facility-connection-requirements1.ashx.
  5. IBR Resources are required to meet Dominion’s Ride-Through Requirements for Bulk Power System (BPS) Generators
     

 

The Project Developer will also be required to meet all PJM, SERC, and NERC reliability criteria and operating procedures for standards compliance. For example, the Project Developer will need to properly locate and report the over and under voltage and over and under frequency system protection elements for its units as well as the submission of the generator model and protection data required to satisfy the PJM and SERC audits.  Failure to comply with these requirements may result in a disconnection of service if the violation is found to compromise the reliability of the Dominion system.

 

Power Factor Requirements

The Project Developer shall design its non-synchronous Generator Facility with the ability to maintain a power factor of at least 0.95 leading (absorbing VARs) to 0.95 lagging (supplying VARs) measured at the high-side of the facility substation transformer(s) connected to the Dominion transmission system.

Revenue Metering and SCADA Requirements

PJM Requirements
The developer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for their generating Resource. See PJM Manual 01, PJM Manual 14D, and PJM Tariff Part IX, Subpart B, Appendix 2, section 8.
Meteorological Data Reporting Requirement
The wind generation facility shall provide the Transmission Provider with site-specific meteorological data including:
  • 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)
Transmission Owner Requirements
The Project Developer will be required to comply with all interconnected Transmission Owner’s revenue metering requirements located at the following link: PJM - Transmission Owner Engineering & Construction Standards.

Summer Peak Analysis

The New Service Request project was evaluated as a 880.0 MW (Capacity 267.5 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 summer peak period network impacts were as follows:

Note: The capacity portion of New Service Requests are evaluated for single or N-1 contingencies. The full energy output of New Service Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).

Summer Peak Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Final Cycle Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
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 168.82 % 663.64 B 1120.36 15.97
DVP 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1
DVP_P1-2: LN 575_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S-1'
 OPEN BRANCH FROM BUS 314911 TO BUS 962840 CKT 1                /*8LADYSMITH   500.0 - AG1-133 TP   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 139.37 % 3220.44 B 4488.27 42.16
DVP 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1
DVP_P1-2: LN 575_SRT-S-2
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S-2'
 OPEN BRANCH FROM BUS 962840 TO BUS 314918 CKT 1                /*AG1-133 TP   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 139.07 % 3220.44 B 4478.58 42.16
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 136.87 % 3220.44 B 4407.84 73.2
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 133.6 % 4070.2 B 5437.98 85.41
DVP 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1
DVP_P1-2: LN 575_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S-1'
 OPEN BRANCH FROM BUS 314911 TO BUS 962840 CKT 1                /*8LADYSMITH   500.0 - AG1-133 TP   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 133.53 % 3220.44 B 4300.2 43.23
DVP 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1
DVP_P1-2: LN 575_SRT-S-2
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S-2'
 OPEN BRANCH FROM BUS 962840 TO BUS 314918 CKT 1                /*AG1-133 TP   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 132.25 % 3220.44 B 4259.06 43.23
DVP AG1-133 TP-8LADYSMITH 500.0 kV Ckt 1 line
962840 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 131.42 % 3220.44 B 4232.21 36.01
DVP 8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line
314918 to 962840 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 129.78 % 3220.44 B 4179.52 36.01
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 129.59 % 3220.44 B 4173.53 66.06
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 125.87 % 1058.16 B 1331.91 20.22
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 121.55 % 2442.12 B 2968.32 79.3
DVP 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 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 119.58 % 3220.44 B 3850.88 69.59
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
Single AC 117.94 % 879.84 B 1037.67 29.27
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 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 117.11 % 888.3 B 1040.26 29.34
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 116.86 % 4070.2 B 4756.36 73.89
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 111.8 % 3220.44 B 3600.5 42.16
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 111.07 % 3220.44 B 3576.8 69.41
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
Single AC 110.35 % 663.64 B 732.33 15.38
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 110.35 % 3220.44 B 3553.69 42.04
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 108.62 % 2686.52 B 2918.03 28.98
DVP 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 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 107.54 % 2442.12 B 2626.33 75.66
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
Single AC 103.64 % 663.64 B 687.83 15.36
DVP 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1
Base Case Single AC 102.55 % 3220.44 A 3302.58 38.7
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
Single AC 102.03 % 984.18 B 1004.18 14.83
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
Single AC 102.01 % 984.18 B 1003.96 14.83
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
Single AC 101.78 % 4070.2 B 4142.78 51.8
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
Single AC 101.62 % 4070.2 B 4136.33 52.82
DVP 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1
Base Case Single AC 101.53 % 3220.44 A 3269.62 53.38
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
Single AC 100.99 % 1058.16 B 1068.58 20.36
DVP 8LADYSMITH-8CHANCE 500.0 kV Ckt 1 line
314911 to 314905 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 100.78 % 4070.2 B 4101.97 50.84
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
Single AC 100.29 % 2442.12 B 2449.18 50.14
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 172.23 % 1065.0 C 1834.24 146.92
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 159.34 % 1056.8 C 1683.95 62.28
DVP 6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 2 transformer
314214 to 314903 ckt 2
DVP_P4-2: H1T567_SRT-A
CONTINGENCY 'DVP_P4-2: H1T567_SRT-A'
 OPEN BRANCH FROM BUS 314214 TO BUS 314903 CKT 1   /*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 124.85 % 1107.1 C 1382.24 96.28
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 314922 CKT 1   /*8LADYSMITH   500.0 - 8POSSUM      500.0
 OPEN BRANCH FROM BUS 314911 TO BUS 962840 CKT 1   /*8LADYSMITH   500.0 - AG1-133 TP   500.0
END
Breaker AC 123.51 % 3940.0 C 4866.16 147.35
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 123.05 % 3940.0 C 4848.2 243.43
DVP AG1-133 TP-8LADYSMITH 500.0 kV Ckt 1 line
962840 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 119.9 % 3940.0 C 4724.16 117.61
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 DC 119.17 % 3940.0 C 4695.26 260.6
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 DC 119.09 % 3940.0 C 4692.14 245.83
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 118.25 % 3144.0 C 3717.81 265.31
DVP 8MORRSVL-8LOUDOUN 500.0 kV Ckt 1 line
314916 to 314913 ckt 1
DVP_P4-2: 559T584_SRT-S
CONTINGENCY 'DVP_P4-2: 559T584_SRT-S'
 OPEN BRANCH FROM BUS 314904 TO BUS 314930 CKT 1                /*8CLIFTON     500.0 - 8MOSBY       500.0
 OPEN BRANCH FROM BUS 314913 TO BUS 314930 CKT 1                /*8LOUDOUN     500.0 - 8MOSBY       500.0
 SET POSTCONTRATING 2809 BRANCH FROM BUS 314913 TO BUS 314916 CKT 1 /*8LOUDOUN     500.0 - 8MORRSVL     500.0
 SET PRECONTRATING 2538 BRANCH FROM BUS 314913 TO BUS 314916 CKT 1 /*8LOUDOUN     500.0 - 8MORRSVL     500.0
END
Breaker AC 118.23 % 2809.0 C 3321.05 67.42
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 314922 CKT 1   /*8LADYSMITH   500.0 - 8POSSUM      500.0
 OPEN BRANCH FROM BUS 314911 TO BUS 962840 CKT 1   /*8LADYSMITH   500.0 - AG1-133 TP   500.0
END
Breaker AC 118.23 % 3940.0 C 4658.24 149.77
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 118.13 % 1107.1 C 1307.85 96.22
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 118.04 % 3144.0 C 3711.09 264.55
DVP 8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line
314918 to 962840 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 117.88 % 3940.0 C 4644.38 117.61
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 962840 CKT 1                /*8LADYSMITH   500.0 - AG1-133 TP   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 117.87 % 3940.0 C 4644.19 138.82
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 DC 116.9 % 3940.0 C 4605.89 218.8
DVP 6LANDSTN-6LYNHAVN 230.0 kV Ckt 1 line
314481 to 314486 ckt 1
DVP_P4-2: 231T2128_SRT-S
CONTINGENCY 'DVP_P4-2: 231T2128_SRT-S'
 OPEN BRANCH FROM BUS 314466 TO BUS 314508 CKT 1                /*6FENTRES     230.0 - 6THRASHER    230.0
 OPEN BRANCH FROM BUS 314481 TO BUS 314502 CKT 1                /*6LANDSTN     230.0 - 6STUMPY      230.0
 OPEN BRANCH FROM BUS 314502 TO BUS 314508 CKT 1                /*6STUMPY      230.0 - 6THRASHER    230.0
 OPEN BUS 314502                                                /*6STUMPY      230.0
 SET POSTCONTRATING 1166 BRANCH FROM BUS 314480 TO BUS 314508 CKT 1 /*6HUNTSMN     230.0 - 6THRASHER    230.0
 SET PRECONTRATING 1051 BRANCH FROM BUS 314480 TO BUS 314508 CKT 1 /*6HUNTSMN     230.0 - 6THRASHER    230.0
END
Breaker AC 113.9 % 830.0 C 945.39 56.54
DVP 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 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 962840 CKT 1                /*8LADYSMITH   500.0 - AG1-133 TP   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 112.65 % 3940.0 C 4438.32 142.36
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 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   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 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   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 112.22 % 5011.0 C 5623.44 280.86
DVP AG1-133 TP-8LADYSMITH 500.0 kV Ckt 1 line
962840 to 314911 ckt 1
DVP_P4-2: H1T573_SRT-A
CONTINGENCY 'DVP_P4-2: H1T573_SRT-A'
 OPEN BRANCH FROM BUS 314755 TO BUS 314934 CKT 1   /*3SPOTSYL     115.0 - 8SPOTSYL     500.0
 OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1   /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 111.72 % 3940.0 C 4401.9 118.82
DVP AG1-133 TP-8LADYSMITH 500.0 kV Ckt 1 line
962840 to 314911 ckt 1
DVP_P4-2: 515T573_SRT-A
CONTINGENCY 'DVP_P4-2: 515T573_SRT-A'
 OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1   /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 OPEN BRANCH FROM BUS 314934 TO BUS 314944 CKT 1   /*8SPOTSYL     500.0 - 8SPOTSYL EC  500.0
 OPEN BUS 314944                                   /*8SPOTSYL EC  500.0
END
Breaker AC 111.55 % 3940.0 C 4395.24 118.45
DVP 8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line
314918 to 962840 ckt 1
DVP_P4-2: H1T573_SRT-A
CONTINGENCY 'DVP_P4-2: H1T573_SRT-A'
 OPEN BRANCH FROM BUS 314755 TO BUS 314934 CKT 1   /*3SPOTSYL     115.0 - 8SPOTSYL     500.0
 OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1   /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 109.72 % 3940.0 C 4322.98 118.82
DVP 8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line
314918 to 962840 ckt 1
DVP_P4-2: 515T573_SRT-A
CONTINGENCY 'DVP_P4-2: 515T573_SRT-A'
 OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1   /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 OPEN BRANCH FROM BUS 314934 TO BUS 314944 CKT 1   /*8SPOTSYL     500.0 - 8SPOTSYL EC  500.0
 OPEN BUS 314944                                   /*8SPOTSYL EC  500.0
END
Breaker AC 109.55 % 3940.0 C 4316.23 118.45
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 108.38 % 3940.0 C 4270.18 144.41
DVP 6SUFFOLK-6KINGFORK 230.0 kV Ckt 1 line
314537 to 314525 ckt 1
DVP_P4-2: 531T582_SRT-A
CONTINGENCY 'DVP_P4-2: 531T582_SRT-A'
 OPEN BRANCH FROM BUS 314924 TO BUS 314928 CKT 1   /*8SURRY       500.0 - 8SUFFOLK     500.0
 OPEN BRANCH FROM BUS 314924 TO BUS 314931 CKT 1   /*8SURRY       500.0 - 8SKIFF CREEK 500.0
END
Breaker AC 104.63 % 830.0 C 868.43 56.26
DVP 6SUFFOLK-8SUFFOLK 230.0/500.0 kV Ckt 2 transformer
314537 to 314928 ckt 2
DVP_P4-2: H7T565_SRT-A
CONTINGENCY 'DVP_P4-2: H7T565_SRT-A'
 OPEN BRANCH FROM BUS 314537 TO BUS 314928 CKT 1   /*6SUFFOLK     230.0 - 8SUFFOLK     500.0
 OPEN BRANCH FROM BUS 314927 TO BUS 314928 CKT 1   /*8YADKIN      500.0 - 8SUFFOLK     500.0
END
Breaker AC 102.54 % 1004.3 C 1029.79 84.36
DVP 6KINGFORK-6CHCKTUK 230.0 kV Ckt 1 line
314525 to 314522 ckt 1
DVP_P4-2: 531T582_SRT-A
CONTINGENCY 'DVP_P4-2: 531T582_SRT-A'
 OPEN BRANCH FROM BUS 314924 TO BUS 314928 CKT 1   /*8SURRY       500.0 - 8SUFFOLK     500.0
 OPEN BRANCH FROM BUS 314924 TO BUS 314931 CKT 1   /*8SURRY       500.0 - 8SKIFF CREEK 500.0
END
Breaker AC 102.43 % 830.0 C 850.15 56.22
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 100.98 % 3940.0 C 3978.51 127.02
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 106.64 % 3144.0 C 3352.73 71.72

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.

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 Details
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 330.1 % 678.68 B 2240.3 499.84
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 207.73 % 818.74 B 1700.78 312.77
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 177.66 % 678.68 B 1205.72 253.56
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 170.72 % 678.68 B 1158.65 253.76
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 158.1 % 678.68 B 1072.98 59.45
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 158.06 % 678.68 B 1072.74 59.45
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 151.01 % 663.64 B 1002.17 50.59
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 146.2 % 663.64 B 970.23 50.52
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 146.07 % 663.64 B 969.39 82.66
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 145.21 % 1058.16 B 1536.52 66.52
DVP AE2-270 TP-AB2-190 TAP 230.0 kV Ckt 2 line
942550 to 316099 ckt 2
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 141.39 % 678.68 B 959.56 59.95
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 136.44 % 879.84 B 1200.43 96.27
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 132.03 % 678.68 B 896.07 65.2
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 129.97 % 984.18 B 1279.11 65.67
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 128.41 % 678.68 B 871.51 71.58
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 124.4 % 1115.59 B 1387.75 442.73
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 124.28 % 2442.12 B 3034.97 164.94
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 124.23 % 1103.28 B 1370.64 437.27
DVP 6ELIZ R-6YADKIN 230.0 kV Ckt 1 line
314465 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 121.68 % 548.02 B 666.85 87.97
DVP 6LIGH285-6CHCKAHM 230.0 kV Ckt 1 line
314390 to 314214 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 121.16 % 678.68 B 822.27 71.46
DVP 6WALR285-6LIGH285 230.0 kV Ckt 1 line
314413 to 314390 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 120.59 % 678.68 B 818.45 71.58
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 118.3 % 678.68 B 802.87 53.09
DVP AG1-000B TP-AE2-270 TP 230.0 kV Ckt 2 line
961610 to 942550 ckt 2
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 117.44 % 678.68 B 797.05 59.95
DVP 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1
Base Case OP DC 115.71 % 3220.44 A 3726.4 175.62
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 114.27 % 984.18 B 1124.62 82.66
DVP 6SURRY-AG1-000B TP 230.0 kV Ckt 2 line
314538 to 961610 ckt 2
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 112.74 % 678.68 B 765.13 59.95
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 110.93 % 984.18 B 1091.71 82.66
DVP 8YADKIN-8SUFFOLK 500.0 kV Ckt 1 line
314927 to 314928 ckt 1
DVP_P1-2: LN 579_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 579_SRT-S-1'
 OPEN BRANCH FROM BUS 314923 TO BUS 314927 CKT 1                /*8SEPTA       500.0 - 8YADKIN      500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 940640 TO BUS 314902 CKT 1 /*AE2-051 TP   500.0 - 8CARSON      500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 940640 TO BUS 314923 CKT 1 /*AE2-051 TP   500.0 - 8SEPTA       500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 940640 TO BUS 314902 CKT 1 /*AE2-051 TP   500.0 - 8CARSON      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 940640 TO BUS 314923 CKT 1 /*AE2-051 TP   500.0 - 8SEPTA       500.0
END
OP AC 110.35 % 2442.12 B 2694.93 609.06
DVP 6PENNIMAN-6WALR209 230.0 kV Ckt 1 line
314296 to 314415 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 109.2 % 984.18 B 1074.74 82.66
DVP 8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1
Base Case OP AC 106.05 % 3220.44 A 3415.13 127.32
DVP 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1
Base Case OP AC 105.39 % 2442.12 A 2573.65 210.5
DVP 6CHESTF B-6VARINA 230.0 kV Ckt 1 line
314287 to 314260 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 105.31 % 984.18 B 1036.39 51.75
DVP 6VARINA-6CHARCTY 230.0 kV Ckt 1 line
314260 to 314225 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 105.27 % 984.18 B 1036.03 51.75
DVP 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1
Base Case OP DC 104.82 % 3193.18 A 3347.18 173.38
DVP AB2-190 TAP-6GARYSVILLE 230.0 kV Ckt 1 line
316099 to 313902 ckt 1
Base Case OP AC 104.32 % 678.68 A 708.03 44.16
DVP 6GARYSVILLE-6HOPEWLL 230.0 kV Ckt 1 line
313902 to 314303 ckt 1
Base Case OP AC 104.29 % 678.68 A 707.79 44.16
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 104.11 % 4070.2 B 4237.54 170.41
DVP 6OLDCHRC-6PEARSON 230.0 kV Ckt 1 line
314241 to 314242 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 104.02 % 898.64 B 934.76 69.28
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 103.99 % 4070.2 B 4232.55 173.77
DVP 6WALR209-6LIGH209 230.0 kV Ckt 1 line
314415 to 314391 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 103.05 % 984.18 B 1014.15 82.66
DVP 6CHARCTY-6LAKESIDE 230.0 kV Ckt 1 line
314225 to 314227 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 101.68 % 984.18 B 1000.73 51.75

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 Queue Project was evaluated as a 880.0 MW (Capacity 267.5 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:

Light Load Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Final Cycle Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
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 217.92 % 678.68 B 1478.96 400.32
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 157.6 % 678.68 B 1069.57 40.16
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 155.57 % 678.68 B 1055.81 41.3
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 157.11 % 678.68 B 1066.3 40.16
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 155.07 % 678.68 B 1052.42 41.3
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 156.67 % 307.38 B 481.57 18.39
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
Single AC 143.44 % 818.74 B 1174.38 250.6
DVP 6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line
313707 to 961060 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 136.2 % 661.76 B 901.33 36.41
DVP 6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line
313707 to 961060 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 128.01 % 661.76 B 847.12 35.09
DVP AF2-397 TP-6CUNNING 230.0 kV Ckt 1 line
961060 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 135.61 % 661.76 B 897.38 36.41
DVP AF2-397 TP-6CUNNING 230.0 kV Ckt 1 line
961060 to 313373 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 127.82 % 661.76 B 845.89 35.09
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 135.59 % 663.64 B 899.86 41.13
DVP 6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1
DVP_P1-2: LN 217_SRT-A
CONTINGENCY 'DVP_P1-2: LN 217_SRT-A'
 OPEN BRANCH FROM BUS 314225 TO BUS 314227 CKT 1   /*6CHARCTY     230.0 - 6LAKESIDE    230.0
 OPEN BRANCH FROM BUS 314225 TO BUS 314260 CKT 1   /*6CHARCTY     230.0 - 6VARINA      230.0
 OPEN BRANCH FROM BUS 314260 TO BUS 314287 CKT 1   /*6VARINA      230.0 - 6CHESTF B    230.0
 OPEN BUS 314225                                   /*6CHARCTY     230.0
 OPEN BUS 314260                                   /*6VARINA      230.0
END
Single AC 106.06 % 663.64 B 703.86 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 134.38 % 661.76 B 889.25 36.41
DVP 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 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 126.59 % 661.76 B 837.72 35.09
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 132.71 % 661.76 B 878.23 36.41
DVP 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 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 124.92 % 661.76 B 826.65 35.09
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer
314218 to 314908 ckt 2
DVP_P1-2: LN 557_SRT-L
CONTINGENCY 'DVP_P1-2: LN 557_SRT-L'
 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 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
END
Single AC 113.45 % 879.84 B 998.17 76.12
DVP 3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 2 transformer
314666 to 314667 ckt 2
DVP_P1-3: 4ALTVSTA-TX#3_SRT-A
CONTINGENCY 'DVP_P1-3: 4ALTVSTA-TX#3_SRT-A'
 OPEN BRANCH FROM BUS 314666 TO BUS 314667 CKT 1   /*3ALTVSTA     115.0 - 4ALTVSTA     138.0
END
Single AC 112.91 % 130.47 B 147.31 8.84
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 ckt 1
DVP_P1-2: LN 557_SRT-L
CONTINGENCY 'DVP_P1-2: LN 557_SRT-L'
 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 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
END
Single AC 112.65 % 888.3 B 1000.66 76.31
DVP 3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer
314666 to 314667 ckt 1
DVP_P1-3: 4ALTVSTA-TX#4_SRT-A
CONTINGENCY 'DVP_P1-3: 4ALTVSTA-TX#4_SRT-A'
 OPEN BRANCH FROM BUS 314666 TO BUS 314667 CKT 2   /*3ALTVSTA     115.0 - 4ALTVSTA     138.0
END
Single AC 109.59 % 126.52 B 138.66 8.32
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
Single AC 106.77 % 678.68 B 724.62 203.06
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
Single AC 106.75 % 678.68 B 724.51 203.06
DVP 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 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 104.41 % 2442.12 B 2549.9 205.74
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
Single AC 104.08 % 663.64 B 690.74 65.13
DVP 6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer
314269 to 314291 ckt 1
DVP_P7-1: LN 211-228_SRT-L
CONTINGENCY 'DVP_P7-1: LN 211-228_SRT-L'
 OPEN BRANCH FROM BUS 314286 TO BUS 314303 CKT 1                /*6CHESTF A    230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314287 TO BUS 314303 CKT 1                /*6CHESTF B    230.0 - 6HOPEWLL     230.0
 SET POSTCONTRATING 1012 BRANCH FROM BUS 314269 TO BUS 314303 CKT 1 /*6PRGEORG     230.0 - 6HOPEWLL     230.0
 SET PRECONTRATING 908 BRANCH FROM BUS 314269 TO BUS 314303 CKT 1 /*6PRGEORG     230.0 - 6HOPEWLL     230.0
END
Tower AC 119.92 % 287.5 C 344.78 20.56
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 132.17 % 1065.0 C 1407.61 116.16
DVP 6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1
DVP_P4-2: 534T549_SRT-L
CONTINGENCY 'DVP_P4-2: 534T549_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BRANCH FROM BUS 314907 TO BUS 314926 CKT 1                /*8DOOMS       500.0 - 8VALLEY      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
Breaker AC 120.25 % 830.0 C 998.05 39.49
DVP 6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1
DVP_P4-2: 534T549_SRT-L
CONTINGENCY 'DVP_P4-2: 534T549_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BRANCH FROM BUS 314907 TO BUS 314926 CKT 1                /*8DOOMS       500.0 - 8VALLEY      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
Breaker AC 119.87 % 830.0 C 994.9 39.49
DVP 6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line
313707 to 961060 ckt 1
DVP_P4-2: 534T564_SRT-L
CONTINGENCY 'DVP_P4-2: 534T564_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BUS 315216                                                /*1CUNINGA      18.0
 OPEN BUS 315219                                                /*1CUNINGD      22.0
 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
Breaker AC 104.65 % 809.0 C 846.63 35.24
DVP 6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line
313707 to 961060 ckt 1
DVP_P4-2: 57602_SRT-L
CONTINGENCY 'DVP_P4-2: 57602_SRT-L'
 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 3300 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET POSTCONTRATING 3559 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET PRECONTRATING 3377 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 103.87 % 809.0 C 840.34 36.45
DVP AF2-397 TP-6CUNNING 230.0 kV Ckt 1 line
961060 to 313373 ckt 1
DVP_P4-2: 534T564_SRT-L
CONTINGENCY 'DVP_P4-2: 534T564_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BUS 315216                                                /*1CUNINGA      18.0
 OPEN BUS 315219                                                /*1CUNINGD      22.0
 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
Breaker AC 104.0 % 809.0 C 841.37 35.24
DVP AF2-397 TP-6CUNNING 230.0 kV Ckt 1 line
961060 to 313373 ckt 1
DVP_P4-2: 57602_SRT-L
CONTINGENCY 'DVP_P4-2: 57602_SRT-L'
 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 3300 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET POSTCONTRATING 3559 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET PRECONTRATING 3377 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 103.41 % 809.0 C 836.56 36.45
DVP 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1
DVP_P4-2: 534T564_SRT-L
CONTINGENCY 'DVP_P4-2: 534T564_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BUS 315216                                                /*1CUNINGA      18.0
 OPEN BUS 315219                                                /*1CUNINGD      22.0
 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
Breaker AC 103.0 % 809.0 C 833.26 35.24
DVP 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1
DVP_P4-2: 57602_SRT-L
CONTINGENCY 'DVP_P4-2: 57602_SRT-L'
 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 3300 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET POSTCONTRATING 3559 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET PRECONTRATING 3377 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 102.4 % 809.0 C 828.45 36.45
DVP 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1
DVP_P4-2: 534T564_SRT-L
CONTINGENCY 'DVP_P4-2: 534T564_SRT-L'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 OPEN BUS 315216                                                /*1CUNINGA      18.0
 OPEN BUS 315219                                                /*1CUNINGD      22.0
 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
Breaker AC 101.65 % 809.0 C 822.31 35.24
DVP 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1
DVP_P4-2: 57602_SRT-L
CONTINGENCY 'DVP_P4-2: 57602_SRT-L'
 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 3300 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET POSTCONTRATING 3559 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 962840 TO BUS 314918 CKT 1 /*AG1-133 TP   500.0 - 8NO ANNA     500.0
 SET PRECONTRATING 3377 BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Breaker AC 101.05 % 809.0 C 817.49 36.45
DVP 6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1
DVP_P4-2: 562T563_SRT-L
CONTINGENCY 'DVP_P4-2: 562T563_SRT-L'
 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1                /*8CARSON      500.0 - 8MDLTHAN     500.0
 OPEN BRANCH FROM BUS 314902 TO BUS 940640 CKT 1                /*8CARSON      500.0 - AE2-051 TP   500.0
 SET POSTCONTRATING 3300 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 101.49 % 812.0 C 824.11 36.17
DVP 8CARSON-6CARSON 500.0/230.0 kV Ckt 2 transformer
314902 to 314282 ckt 2
DVP_P4-2: 56372_SRT-L
CONTINGENCY 'DVP_P4-2: 56372_SRT-L'
 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 3559 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      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
END
Breaker AC 101.48 % 1056.8 C 1072.48 47.01

Light Load Potential Congestion due to Local Energy Deliverability

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 Details
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 217.73 % 678.68 B 1477.71 400.32
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 153.29 % 307.38 B 471.19 18.39
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 143.24 % 818.74 B 1172.73 250.6
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer
314218 to 314908 ckt 2
DVP_P1-2: LN 557_SRT-L
CONTINGENCY 'DVP_P1-2: LN 557_SRT-L'
 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 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT      500.0 - 8LADYSMITH   500.0
END
OP AC 105.0 % 879.84 B 923.79 76.12
DVP 3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 2 transformer
314666 to 314667 ckt 2
DVP_P1-3: 4ALTVSTA-TX#3_SRT-A
CONTINGENCY 'DVP_P1-3: 4ALTVSTA-TX#3_SRT-A'
 OPEN BRANCH FROM BUS 314666 TO BUS 314667 CKT 1   /*3ALTVSTA     115.0 - 4ALTVSTA     138.0
END
OP AC 112.86 % 130.47 B 147.25 8.84
DVP 3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer
314666 to 314667 ckt 1
DVP_P1-3: 4ALTVSTA-TX#4_SRT-A
CONTINGENCY 'DVP_P1-3: 4ALTVSTA-TX#4_SRT-A'
 OPEN BRANCH FROM BUS 314666 TO BUS 314667 CKT 2   /*3ALTVSTA     115.0 - 4ALTVSTA     138.0
END
OP AC 109.55 % 126.52 B 138.61 8.32
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 106.77 % 678.68 B 724.62 203.06
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 106.75 % 678.68 B 724.51 203.06
DVP 8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 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 101.94 % 2442.12 B 2489.6 205.74

Short Circuit Analysis

Short Circuit analysis is not performed as part of the Phase I System Impact Study. Short Circuit analysis will commence in the Phase II System Impact Study.

Stability Analysis

Stability analysis is not performed as part of the Phase I System Impact Study. Stability analysis will commence in the Phase II System Impact Study.

Reactive Power Analysis

Reactive Power analysis is not performed as part of the Phase I System Impact Study. Reactive Power analysis will commence in the Phase II System Impact Study.

Steady-State Voltage Analysis

Steady State Voltage analysis is not performed as part of the Phase I System Impact Study. Steady State Voltage analysis will commence in the Phase II System Impact Study.

New Service Request Dependencies

The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.

New Service Requests Dependencies
Project ID Project Name Status
AA1-063A Carolina–Seaboard 115kV In Service
AA1-065 Earleys 230kV In Service
AA1-067 Everetts 34.5kV In Service
AA1-139 Hickory-Shawboro 230kV In Service
AA1-145 Four Rivers 230kV In Service
AA2-053 Carolina-Jackson 115kV In Service
AA2-057 Hornertown-Whitakers 115kV In Service
AA2-088 Boykins-Handsome 115kV In Service
AA2-178 Mackeys 230kV In Service
AB1-027 Old Church 34.5 KV In Service
AB1-132 Thelma 230kV Partially in Service - Under Construction
AB1-173 Brink-Trego 115kV In Service
AB2-022 Elizabeth City 34.5kV In Service
AB2-024 Correctional 34.5kV In Service
AB2-025 Sapony 34.5kV In Service
AB2-026 Powhatan 34.5kV In Service
AB2-029 Remington 34.5kV In Service
AB2-040 Brink 115kV Under Construction
AB2-043 Chase City 115kV In Service
AB2-045 Buckingham 34.5kV In Service
AB2-060 Chase City-Lunenburg 115kV In Service
AB2-077 Buggs Island-Chase City 115kV Partially in Service - Under Construction
AB2-078 Buggs Island-Chase City 115kV Partially in Service - Under Construction
AB2-079 Buggs Island-Chase City 115kV Partially in Service - Under Construction
AB2-099 Ahoskie 34.5kV In Service
AB2-100 Clubhouse-Lakeview 230kV In Service
AB2-134 Hopewell-Surry 230kV In Service
AB2-158 Louisa-South Anna 230kV In Service
AB2-160 Reams 115kV Engineering & Procurement
AB2-161 Waverly #2 DP 115kV In Service
AB2-169 Pantago-Five Points 115kV In Service
AB2-174 Emporia-Trego 115kV In Service
AB2-190 Hopewell-Surry 230kV In Service
AC1-027 Pendleton 34.5kV In Service
AC1-034 Heartsease DP - Mayo Dunbar 115kV Engineering & Procurement
AC1-036 Twittys Creek 34.5kV In Service
AC1-043 Mountain Run-Mitchell 115 kV Engineering & Procurement
AC1-054 Kerr Dam–Eatons Ferry 115 kV In Service
AC1-065 Harmony Village-Shackleford 115kV Under Construction
AC1-076 Locust Grove-Paytes 115kV Under Construction
AC1-086 Thelma 230kV Engineering & Procurement
AC1-098 Dawson-South Justice 115kV Engineering & Procurement
AC1-099 Dawson-South Justice 115kV Engineering & Procurement
AC1-105 Halifax-Mt. Laurel 115kV In Service
AC1-112 Old Church 34.5kV In Service
AC1-118 Westmoreland 34.5kV In Service
AC1-120 Mitchell-Mountain Run 115kV Suspended
AC1-121 Mitchell-Mountain Run 115kV Suspended
AC1-143 Brandy-Remington 115kV Suspended
AC1-147 Grassfield 34.5kV In Service
AC1-158 Spotsylvania 500kV In Service
AC1-161 Septa 500kV Partially in Service - Under Construction
AC1-164 Chickahominy 230kV Partially in Service - Under Construction
AC1-189 Chinquapin-Everetts 230kV Suspended
AC1-191 Elmont 115kV Suspended
AC1-208 Cox-Whitakers 115kV Suspended
AC1-216 Hopewell-Surry 230kV In Service
AC1-221 Halifax-Person 230kV Under Construction
AC1-222 Crystal Hill-Halifax 115kV In Service
AC2-012 Grassfield-Great Bridge 115kV In Service
AC2-079 Ivor-Oak Ridge 115kV Suspended
AC2-084 Dawson-South Justice 115kV Engineering & Procurement
AC2-100 Halifax-Person 230kV Partially in Service - Under Construction
AC2-137 Elko 34.5kV In Service
AC2-138 Northern Neck 34.5kV In Service
AC2-141 Septa 500kV Engineering & Procurement
AC2-165 Bremo-Powhatan 230kV 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 Under Construction
AD1-056 Hornertown-Hathaway 230 kV Engineering & Procurement
AD1-057 Hornertown-Hathaway 230 kV Engineering & Procurement
AD1-063 Harmony Village 34.5 kV In Service
AD1-074 Trowbridge 230 kV Engineering & Procurement
AD1-075 Trowbridge 230 kV Engineering & Procurement
AD1-076 Trowbridge 230 kV Engineering & Procurement
AD1-082 Bakers Pond-Ivor 115kV In Service
AD1-087 Clover-Sedge Hill 230 kV In Service
AD1-088 Briery-Clover 230 kV Engineering & Procurement
AD1-105 Kings Dominion DP 115 kV Engineering & Procurement
AD1-115 Mountain Run-Mitchell 115 kV Engineering & Procurement
AD1-144 Kings Fork 34.5 kV In Service
AD1-151 Hopewell-Surry 230 kV Suspended
AD1-152 Clover-Sedge Hill 230 kV In Service
AD2-022 East Danville - Roxborough 230 kV Engineering & Procurement
AD2-023 East Danville - Roxborough 230 kV Engineering & Procurement
AD2-030 Wan 34.5 kV In Service
AD2-033 Chase City-Lunenburg 115 kV Suspended
AD2-073 Sanders DP 230 kV In Service
AD2-074 Garner DP-Lancaster 115 kV Suspended
AD2-085 Myrtle-Windsor DP 115kV Suspended
AD2-202 Clover-Sedge Hill 230kV In Service
AE1-013 Suitland Road 13 kV Withdrawn
AE1-044 Morrisville 230 kV Suspended
AE1-056 Red House-South Creek 115 kV Suspended
AE1-072 Shawboro-Sligo 230 kV Engineering & Procurement
AE1-074 Winterpock 34.5 kV Suspended
AE1-075 Powhatan 34.5 kV Under Construction
AE1-103 Holland-Union Camp 115 kV Suspended
AE1-108 Bremo-Scottsville 138 kV Engineering & Procurement
AE1-148 Kerr Dam-Ridge Rd 115 kV Active
AE1-149 Disputanta-Poe 115 kV Engineering & Procurement
AE1-153 Remington-Gordonsville 230 kV Suspended
AE1-155 Garner-Northern Neck 115 kV Partially in Service - Under Construction
AE1-157 Ladysmith CT-St. Johns 230 kV Suspended
AE1-162 Smithfield 34.5 kV In Service
AE1-173 Carson-Suffolk 500 kV Active
AE1-175 Light Foot 34.5 kV In Service
AE1-190 Harmony Village-Shackleford 115 kV Engineering & Procurement
AE1-191 Harmony Village-Shackleford 115 kV Under Construction
AE2-027 Harrowgate-Locks 115kV Engineering & Procurement
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 Engineering & Procurement
AE2-044 Anaconda-Dunbar 115 kV Withdrawn
AE2-051 Carson-Septa 500 kV Active
AE2-052 Disputanta-Poe 115 kV Active
AE2-053 Kerr Dam-Ridge Road 115 kV Active
AE2-092 Kidds Store-Sherwood 115 kV Engineering & Procurement
AE2-094 Carson-Rogers Road 500 kV Active
AE2-104 Suffolk 115 kV Engineering & Procurement
AE2-122 Birdneck-Landstown 230 kV Active
AE2-123 Birdneck-Landstown 230 kV Active
AE2-124 Landstown 230 kV Active
AE2-147 Swamp 230 kV Active
AE2-156 Yadkin 115 kV Active
AE2-182 Briery-Clover 230 kV Engineering & Procurement
AE2-212 Harrowgate 34 kV Engineering & Procurement
AE2-227 Iron Bridge 34 kV Engineering & Procurement
AE2-228 Tyler 34 kv Engineering & Procurement
AE2-231 St. Johns 115 kV Active
AE2-247 Myrtle-Windsor 115 kV Suspended
AE2-250 Purdy Sw.-Reams 115 kV Active
AE2-253 Hickory-Moyock 230 kV In Service
AE2-259 Curdsville-Willis Mtn 115 kV Active
AE2-270 Hopewell-Surry 230 kV Active
AE2-313 Carson-Rawlings 500 kV Active
AE2-346 Ahoskie 34.5 kV In Service
AF1-017 Myrtle-Windsor 115 kV Suspended
AF1-018 Harmony Village 230 kV Engineering & Procurement
AF1-028 Endless Caverns 115 kV Engineering & Procurement
AF1-032 Suffolk 34.5 kV In Service
AF1-042 Garner DP-Lancaster 115 kV Suspended
AF1-058 Welco 34.5 kV In Service
AF1-069 Carson-Rogers Rd 500 kV Active
AF1-082 Heartsease-Mayo Dunbar DP Withdrawn
AF1-114 Oak Grove-Dahlgren 230 kV Suspended
AF1-124 Oceana 230 kV Active
AF1-125 Oceana 230 kV Active
AF1-128 Chesterfield 230 kV Active
AF1-129 Chesterfield 230 kV Active
AF1-147 Poland Rd-Runway DP 230kV Engineering & Procurement
AF1-152 Swamp 230 kV Active
AF1-201 Hayes-White Marsh 115 kV Active
AF1-246 Clover-Rawlings 500 kV Withdrawn
AF1-266 Clubhouse-Sapony 230 kV Active
AF1-291 Tyler 34.5 kV Engineering & Procurement
AF1-292 Fields 34.5kV Active
AF1-293 Kidds Store-Fort Union 115 kV Active
AF1-294 Jetersville-Ponton 115 kV Active
AF1-301 Louisa-South Anna 230 kV Active
AF1-323 Scottsville-Colleen 138 kV Active
AF2-013 Arnold's Corner-Dahlgren 230 kV Active
AF2-035 St. Johns 115 kV Active
AF2-037 Louisa-North Anna 230 kV Active
AF2-042 Clover-Rawlings 500 kV Active
AF2-043 Suffolk 34.5 kV In Service
AF2-046 Tunis-Mapleton 115 kV Active
AF2-047 Creswell-Riders Creek 115 kV Active
AF2-054 Wan 34.5 kV Active
AF2-063 Louisa-North Anna 230 kV Active
AF2-065 Surry-Hopewell 230 kV Active
AF2-077 White Marsh 34.5 kV Active
AF2-080 Chinquapin-Everetts 230 kV Active
AF2-081 Moyock 230 kV Active
AF2-085 Midlothian 34.5 kV In Service
AF2-091 Oak Grove-Dahlgren 230 kV Active
AF2-110 Suffolk 115 kV Engineering & Procurement
AF2-115 Jetersville-Ponton 115 kV Active
AF2-119 Bristers-Sowego 115 kV Active
AF2-120 Garner-Northern Neck 115 kV Active
AF2-144 Powhatan 34.5 kV In Service
AF2-171 Madisonville 115 kV Active
AF2-222 Madisonville DP-Twitty's Creek 115 kV Active
AF2-297 Sedge Hill 115 kV Active
AF2-299 Fields 34.5 kV Active
AF2-300 St. Johns 115 kV Active
AF2-302 Scottsville-Colleen 138 kV Active
AF2-324 Edgecombe 230 kV Active
AF2-397 Fork Union-Mt. Eagle 230 kV Active
AF2-403 Shockoe DP-Chatham 69 kV Active
AF2-404 Gladys DP-Stonemill 69 kV Active
AG1-007 Tar River 12.5 kV Active
AG1-008 Tunis-Mapleton 115 kV Active
AG1-011 Colonial Trail 230 kV Active
AG1-019 Arnold's Corner-Dahlgren 230 kV Active
AG1-021 Jetersville-Ponton 115 kV Active
AG1-022 Scottsville-Colleen 138 kV Active
AG1-030 Victoria DP-Martin DP 115 kV Active
AG1-037 Ahoskie 34.5 kV Active
AG1-038 Garner DP-Lancaster 115 kV Active
AG1-075 Purdy-Sapony 115 kV Active
AG1-082 Ahoskie 34.5 kV Active
AG1-083 Ahoskie 34.5 kV Active
AG1-098 Briery-Clover 230 kV Active
AG1-102 White Marsh 34.5 kV Active
AG1-105 Mount Laurel-Barnes Junction 115 kV Active
AG1-106 Thelma 230 kV Active
AG1-133 North Anna-Ladysmith 500 kV Active
AG1-134 Kings Dominion DP 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
AG1-151 Endless Caverns 115 kV Active
AG1-152 Remington CT 230 kV Active
AG1-153 Heritage 500 kV Active
AG1-154 Ladysmith CT 230 kV Active
AG1-159 Cox-Whitakers 115 kV Withdrawn
AG1-160 Rogers Road 500 kV Active
AG1-166 Lone Pine 115 kV Active
AG1-167 Lone Pine 115 kV Active
AG1-168 Lone Pine 115 kV Active
AG1-169 Lone Pine 115 kV Active
AG1-170 Lone Pine 115 kV Active
AG1-171 Hopewell-Surry 230kV Active
AG1-172 Hopewell-Surry 230 kV Active
AG1-173 Hopewell-Surry 230 kV Active
AG1-174 Hopewell-Surry 230 kV Active
AG1-178 Carson-Suffolk 500 kV Active
AG1-179 Brunswick-Gasburg 69 kV Active
AG1-180 Brunswick-Gasburg 69 kV Active
AG1-181 Pamplin-Chase City 115 kV Active
AG1-184 Carson-Suffolk 500 kV Active
AG1-185 Pamplin-Chase City 115 kV Active
AG1-195 Valley 230 kV Active
AG1-196 Grottoes 115 kV Active
AG1-210 Northern Neck 34.5 kV Active
AG1-213 St Johns 13.2 kV Engineering & Procurement
AG1-272 Twitty's Creek 115 kV Active
AG1-273 Twitty's Creek 115 kV Active
AG1-274 Twitty's Creek 115 kV Active
AG1-282 Dunnsville 34.5 kV Active
AG1-284 Fork Union 115 kV Active
AG1-285 Chase City-Central 115 kV Active
AG1-288 Lake of the Woods DP-Wilderness DP 115 kV Active
AG1-289 Lake of the Woods DP-Wilderness DP 115 kV Active
AG1-305 Louisa-North Anna 230 kV Active
AG1-342 Dryburg 115 kV Active
AG1-343 Boykins-Murphy 115 kV Active
AG1-359 Fentress 230 kV Active
AG1-364 Deep Creek 115 kV Active
AG1-384 Twitty's Creek 115 kV Active
AG1-393 Fort Pickett DP 34.5 kV Active
AG1-394 Boykins 34.5 kV Active
AG1-412 Ladysmith CT-Mine Road 230 kV Active
AG1-422 Lexington-Dooms 230 kV Active
AG1-426 Bremo-Scottsville 138 kV Active
AG1-427 Chase City-Drakes Branch 115 kV Active
AG1-428 Danieltown DP–Brunswick 69 kV Active
AG1-432 Curdsville DP-Willis Mt. 115 kV Active
AG1-437 Cashie-Earleys 230 kV Active
AG1-438 Cashie-Earleys 230 kV Active
AG1-439 Chinquapin 230 kV Active
AG1-440 Palmer Springs 115 kV Active
AG1-441 Palmer Springs 115 kV Active
AG1-442 Cashie-Earleys 230 kV Active
AG1-443 Cashie-Earleys 230 kV Active
AG1-444 Chinquapin 230 kV Active
AG1-445 Palmer Springs 115 kV Active
AG1-446 Palmer Springs 115 kV Active
AG1-449 Rawlings-Carson 500 kV Active
AG1-451 Curdsville DP-Willis Mt. 115 kV Active
AG1-469 Gordonsville 34.5 kV Active
AG1-494 Boxwood-Riverville 138 kV Active
AG1-502 Oak Green 115 kV Active
AG1-503 Oak Green 115 kV Active
AG1-505 Rawlings-Clover 500 kV Active
AG1-506 Rawlings-Clover 500 kV Active
AG1-531 Poolesville-Winchester 230 kV Active
AG1-532 Fields 34.5 kV Active
AG1-536 Garner-Northern Neck 115 kV Active
AG1-537 Barterbrook-Stuarts Draft 115 kV Active
AG1-538 Remington-Gordonsville 230 kV Active
AG1-539 Grit DP-Perth 115 kV Active
AG1-547 Mount Airy-Chatham 69 kV Active
AG1-551 Parmele 12.5 kV Active
AG1-552 Carolina 13.2 kV Active
AG1-556 Lexington 115 kV Active
AG1-558 Buckner 34.5 kV Active
AG1-559 Caroline Pines 22 kV Active
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 Under Construction
Z1-068 Birdneck 34.5kV In Service
Z2-027 Pasquotank 34.5kV In Service
Z2-044 Whitakers 34.5kV In Service
Z2-088 Tarboro-Everetts 230kV In Service

Affected Systems

In Phase I of the Cycle, PJM conducts an Affected System screen to identify any New Service Request with potential Affected System impacts. PJM initiates coordination with each Affected System Operator by providing a list of New Service Requests in the Cycle with potential impacts to their respective system. If the Affected System Operator indicates an Affected System Study is required, PJM will notify the Project Developer or Eligible Customer of the need for an Affected System Study. See below if any Affected System Operator requires a study for this project:

Midcontinent Independent System Operator (MISO) Not required
New York Independent System Operator (NYISO) Not required
Tennessee Valley Authority (TVA) Not required
Louisville Gas & Electric (LG&E) Not required
Duke Energy Carolinas (DUKE) Not required
Duke Energy Progress – East (CPLE) Not required
Duke Energy Progress – West (CPLW) Not required

System Reinforcements

Based on the Phase I analysis results, this project has potential cost responsibility for the following System Reinforcements:

AF1-123 System Reinforcements Cost Breakdown:
TO RTEP ID / TO ID Title MW Impact Percent Allocation Allocated Cost ($USD)
Dominion (Pending) / TC1-PH1-DOM-074 Wreck and rebuild existing Line 568 Ladysmith - Possum Point for single circuit 144.4 MW 20.0% $54,779,071
Dominion (Pending) / TC1-PH1-DOM-073 Wreck and Rebuild the existing 37.41 mile line to monopole from Midlothian to Carson, and build a second line in existing ROW (Line 563) 319.7 MW 13.6% $29,028,291
Dominion (Pending) / TC1-PH1-DOM-090 Wreck and Rebuild the existing 41.13 mile line to monopole from North Anna to Midlothian and build a second line in existing ROW (Line 576) 328.8 MW 11.2% $26,351,209
Dominion (Pending) / TC1-PH1-DOM-089 Substation Expansion work at Morrisville 500 kV Substation 127.0 MW 29.6% $11,847,578
Dominion (Pending) / TC1-PH1-DOM-069 Build a second 18.75 mile Spotsylvania to Morrisville 500 kV (same ROW as Line 594) 144.8 MW 11.0% $11,792,954
Dominion (Pending) / TC1-PH1-DOM-043 Wreck and rebuild 5.7 miles of 230 kV line 2128 between Fentress and Thrasher 400.3 MW 27.6% $9,379,034
Dominion (Pending) / TC1-PH1-DOM-071 Add a second line between Spotsylvania and North Anna (same ROW as Line 573) 168.1 MW 9.2% $7,330,920
Dominion (Pending) / dom-022 Add additional 500/230 kV transformer at Chickahominy substation. 192.5 MW 14.7% $5,867,936
Dominion (Pending) / TC1-PH1-DOM-051 Wreck and rebuild 10.7 miles of 230 kV line between Lanex and Lightfoot 65.1 MW 17.9% $5,512,013
Dominion n7645 / dom-484 Add additional 500/230 kV transformer Suffolk Substation 84.4 MW 11.3% $4,535,027
Dominion n8149 / dom-013 Add Additional 500/230 kV Transformer at Elmont Substation 176.2 MW 11.0% $4,388,599
Dominion n7611 / dom-413 Rebuild 9.1 miles of 500 kV Line 575 from Ladysmith to AG1-133 Tap with 3-1351.5 113C ACSR. Replace wave Trap, Line lead at Ladysmith terminal. 36.0 MW 7.6% $3,988,137
Dominion (Pending) / dom-216 Rebuild 7.8 miles of 230 kV Line 289 from Kings Fork to Chuckatuck with (2) 768.2 ACSS. 56.2 MW 15.0% $3,370,128
Dominion (Pending) / TC1-PH1-DOM-055 Wreck and rebuild 4.82 miles of 230 kV line 2105 between Thrasher and Yadkin / additional station upgrades 250.6 MW 21.5% $3,294,518
Dominion n8056 Wreck and rebuild the existing 115 kV Line and Add new 230 kV Circuit 20.6 MW 10.0% $3,261,692
Dominion (Pending) / TC1-PH1-DOM-087 Addition of 230/500 kV Transformer at Carson Substation. 62.3 MW 7.7% $3,090,856
Dominion n6605 / dom-101 Wreck and rebuild 7.2 miles of line 271 between Pocaty and Landstown 203.1 MW 13.6% $2,823,546
Dominion n8152 / dom-378 Add additional 500/230 kV transformer at Midlothian Substation 20.2 MW 6.9% $2,769,209
Dominion n7634 / dom-379 Rebuild 500 kV Line #575 from North Anna to AG1-133 Tap. 36.0 MW 8.7% $2,713,343
Dominion (Pending) / dom-311 Rebuild 6.8 miles of 230 kV Line 289 from Suffolk to Kings Fork with (2) 768.2 ACSS/TW (20/7) "MAUMEE" at 250 deg C 56.3 MW 15.0% $2,554,968
Dominion n7569 / dom-490 Reconductor 6.51 miles of line between Mt. Eagle and Cunningham 36.4 MW 6.4% $2,397,367
Dominion (Pending) / dom-301 Rebuild 12.4 miles of 230 kV Line 259 from Chesterfield to Basin with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. And breaker equipment. 16.0 MW 5.6% $2,163,861
Dominion n6551 / dom-159 Rebuild 7.32 miles of 230 kV Line 208 from Chesterfield to Iron Bridge with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. 15.4 MW 9.9% $2,089,521
Dominion (Pending) / dom-164 Rebuild 7.0 miles of 230 kV Line 208 from Iron Bridge to Southwest with (2) 768.2 ACSS 15.4 MW 9.9% $2,020,026
Dominion n6607 / dom-116 Rebuild 5.88 miles of 230 kV Line 2026 from Landstown to Lynnhaven with (2) 768.2 ACSS/TW (20/7) "MAUMEE" 56.5 MW 8.4% $1,426,462
Dominion n7568 / dom-369 Rebuild 6.47 miles of 230 kV Line 2028 from Mt Eagle to Charlottesville with 2-768.2 ACSS 250 C. Replace Wave Trap and CB Switch at Charlottesville terminal 36.4 MW 6.7% $1,291,232
Dominion (Pending) / TC1-PH1-DOM-019 Wreck and rebuild 5.86 miles of 230 kV line 2028 between AF2-397 Tap to Grape Vine (Cunningham) 36.4 MW 6.4% $1,078,999
Dominion n6161 / dom-039 Replace Circuit Breaker at Clifton 71.7 MW 34.7% $866,285
Dominion n7566 / dom-265 Rebuild 5 miles of 230 kV Line 2028 from Fork Union to AF2-397 Tap with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. 36.4 MW 6.7% $835,009
Dominion n8239 / dom-300 Rebuild 9.46 miles of 230 kV Line 217 from Chesterfield to Varina with 2-768.2 ACSS 250 C 14.8 MW 5.2% $739,375
Dominion (Pending) / dom-122 Add additional 138/115 kV transformer at Altavista substation 17.2 MW 10.5% $679,790
Dominion n6606 / dom-100 Rebuild 1.76 miles of 230 kV Line 2240 from Pocaty to Fentress 203.1 MW 12.6% $637,608
Dominion (Pending) / TC1-PH1-DOM-048 Replace Circuit Breaker at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $413,295
Dominion (Pending) / TC1-PH1-DOM-081 Replace Circuit Breaker and Relay at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 265.3 MW 15.2% $403,172
Dominion n7567 / dom-276 Rebuild 1.63 miles of 230 kV Line 2028 from Fork Union to Bremo Dist with 2-795 ACSR (26/7) 150 C 40.2 MW 6.9% $321,565
Dominion n8238 / dom-294 Rebuild 1.38 mi miles of 230 kV Line 217 from Varina to Charles City with 2-768.2 ACSS 250 C 14.8 MW 5.2% $206,728
Dominion (Pending) / TC1-PH1-DOM-044 Replace Circuit Breaker Switch at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $151,541
Dominion (Pending) / TC1-PH1-DOM-082 Replace Circuit Breaker Switch at Surry for increased rating on 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 265.3 MW 15.2% $136,926
Dominion n7789 / dom-363 Rebuild 0.16 miles of Line 2193 from Bremo to Bremo Dist 40.2 MW 6.9% $133,670
Dominion (Pending) / TC1-PH1-DOM-047 Replace Wave Trap at Fentress and Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $110,212
Dominion (Pending) / TC1-PH1-DOM-057 Replace Wave Trap at Yadkin and Thrasher for increased rating on Line 2015 6THRASHER 230 KV to 6YADKIN 230 KV ckt 1 250.6 MW 21.5% $85,809
Dominion (Pending) / TC1-PH1-DOM-049 Replace Circuit Breaker Switch at Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $75,771
Dominion n8260 / dom-457 Replace Wave Traps at Surry and Septa 50.1 MW 12.1% $72,306
Dominion (Pending) / TC1-PH1-DOM-079 Replace Wave Trap at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 265.3 MW 15.2% $45,642
Dominion (Pending) / TC1-PH1-DOM-045 Repalce CT Relay at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $41,329
Dominion (Pending) / TC1-PH1-DOM-046 Replace Circuit Breaker Lead at Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 400.3 MW 27.6% $27,553
Dominion (Pending) / TC1-PH1-DOM-056 Replace Circuit Breaker Lead at Thrasher for increased rating on Line 2105 6THRASHER 230 KV to 6YADKIN 230 KV ckt 1 250.6 MW 21.5% $21,452
Dominion (Pending) / TC1-PH1-DOM-080 Replace Line Lead at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 265.3 MW 15.2% $15,214
Dominion (Pending) / TC1-PH1-DOM-097 Substation work for Energizing the bremo Tx#7 18.4 MW 8.1% $8,120
Grand Total: $217,174,869
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-074 Wreck and rebuild existing Line 568 Ladysmith - Possum Point for single circuit $273,296,000 $54,779,071 48 to 60 Months

Contributor

Description: Wreck and rebuild existing Line 568 for single circuit with (3) 1351.1 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
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
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 131.0 MW 18.2% $49,707,700
AE2-124 106.7 MW 14.8% $40,471,957
AF1-123 144.4 MW 20.0% $54,779,071
AF1-124 144.4 MW 20.0% $54,779,071
AF1-125 144.4 MW 20.0% $54,779,071
AG1-178 49.5 MW 6.9% $18,779,131
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-073 Wreck and Rebuild the existing 37.41 mile line to monopole from Midlothian to Carson, and build a second line in existing ROW (Line 563) $213,237,000 $29,028,291 48 to 60 Months

Contributor

Description: Wreck and Rebuild the existing 37.41 mile line to monopole from Midlothian to Carson, and build a second line in existing ROW (Line 563) with (3) 1351.1 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

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
New Ratings
Facility Rating Set Rating Type Rating Value
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line (All) A 4295.0 MVA
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line (All) B 4357.0 MVA
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line (All) C 4996.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 263.9 MW 11.2% $23,961,734
AE2-124 260.0 MW 11.1% $23,603,741
AE2-313 152.9 MW 6.5% $13,883,822
AF1-123 319.7 MW 13.6% $29,028,291
AF1-124 319.7 MW 13.6% $29,028,291
AF1-125 319.7 MW 13.6% $29,028,291
AF2-042 209.8 MW 8.9% $19,045,257
AG1-011 43.4 MW 1.8% $3,941,462
AG1-178 189.2 MW 8.1% $17,177,030
AG1-184 101.9 MW 4.3% $9,254,066
AG1-359 32.6 MW 1.4% $2,961,454
AG1-449 39.0 MW 1.7% $3,543,975
AG1-505 48.4 MW 2.1% $4,389,793
AG1-506 48.4 MW 2.1% $4,389,793
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-090 Wreck and Rebuild the existing 41.13 mile line to monopole from North Anna to Midlothian and build a second line in existing ROW (Line 576) $234,441,000 $26,351,209 48 to 60 Months

Contributor

Description: Wreck and Rebuild the existing 41.13 mile line to monopole from North Anna to Midlothian and build a second line in existing ROW (Line 576) with (3) 1351.1 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
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)
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line DVP_P4-2: 57602_SRT-S
New Ratings
Facility Rating Set Rating Type Rating Value
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line (All) A 4295.0 MVA
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line (All) B 4357.0 MVA
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line (All) C 4996.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 489.6 MW 16.7% $39,232,996
AE2-124 489.5 MW 16.7% $39,228,910
AE2-270 86.9 MW 3.0% $6,965,140
AE2-313 154.0 MW 5.3% $12,344,238
AF1-123 328.8 MW 11.2% $26,351,209
AF1-124 328.8 MW 11.2% $26,351,209
AF1-125 328.8 MW 11.2% $26,351,209
AF2-042 160.2 MW 5.5% $12,840,117
AG1-011 92.7 MW 3.2% $7,429,366
AG1-178 198.9 MW 6.8% $15,940,000
AG1-184 107.2 MW 3.7% $8,587,565
AG1-359 34.7 MW 1.2% $2,777,898
AG1-449 37.1 MW 1.3% $2,970,304
AG1-505 44.1 MW 1.5% $3,535,420
AG1-506 44.1 MW 1.5% $3,535,420
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-089 Substation Expansion work at Morrisville 500 kV Substation $40,000,000 $11,847,578 36 to 40 Months

Contributor

Description: Expand Morrisville 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)
AF1-123 127.0 MW 29.6% $11,847,578
AF1-124 127.0 MW 29.6% $11,847,578
AF1-125 127.0 MW 29.6% $11,847,578
AG1-178 47.8 MW 11.1% $4,457,265
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-069 Build a second 18.75 mile Spotsylvania to Morrisville 500 kV (same ROW as Line 594) $106,875,000 $11,792,954 48 to 60 Months

Contributor

Description: Build a second 18.75 mile Spotsylvania to Morrisville 500 kV (same ROW as Line 594) with (3) 1351.1 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line (Any)
8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line DVP_P1-2: LN 594_SRT-S
8BRISTER-8CHANCE 500.0 kV Ckt 1 line DVP_P1-2: LN 594_SRT-S
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)
AE2-123 132.8 MW 10.1% $10,814,701
AE2-124 132.8 MW 10.1% $10,816,818
AE2-313 36.0 MW 2.7% $2,932,236
AF1-123 144.8 MW 11.0% $11,792,954
AF1-124 144.8 MW 11.0% $11,792,954
AF1-125 144.8 MW 11.0% $11,792,954
AF2-037 39.9 MW 3.0% $3,253,352
AF2-042 150.3 MW 11.5% $12,239,895
AF2-063 38.0 MW 2.9% $3,091,124
AG1-133 44.3 MW 3.4% $3,604,113
AG1-178 186.0 MW 14.2% $15,150,712
AG1-184 33.9 MW 2.6% $2,762,271
AG1-288 33.7 MW 2.6% $2,746,879
AG1-305 50.1 MW 3.8% $4,084,037
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-043 Wreck and rebuild 5.7 miles of 230 kV line 2128 between Fentress and Thrasher $34,040,000 $9,379,034 42 to 48 Months

Contributor

Description: Wreck and rebuild 5.7 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.

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 877.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 957.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 1164.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $1,925,382
AE2-124 97.3 MW 6.7% $2,278,924
AF1-123 400.3 MW 27.6% $9,379,034
AF1-124 400.3 MW 27.6% $9,379,034
AF1-125 400.3 MW 27.6% $9,379,034
AG1-359 72.5 MW 5.0% $1,698,591
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-071 Add a second line between Spotsylvania and North Anna (same ROW as Line 573) $79,914,000 $7,330,920 48 to 60 Months

Contributor

Description: Add a second line between Spotsylvania and North Anna (same ROW as Line 573) with (3) 1351.5 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line (Any)
8CHANCE-8LADYSMITH 500.0 kV Ckt 1 line DVP_P1-2: LN 573_SRT-A
8LADYSMITH-AG1-133 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 573_SRT-A
8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 573_SRT-A
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)
AE2-123 107.4 MW 5.9% $4,684,918
AE2-124 135.0 MW 7.4% $5,887,531
AE2-313 107.3 MW 5.9% $4,678,942
AF1-123 168.1 MW 9.2% $7,330,920
AF1-124 168.1 MW 9.2% $7,330,920
AF1-125 168.1 MW 9.2% $7,330,920
AF2-037 40.2 MW 2.2% $1,752,471
AF2-042 202.7 MW 11.1% $8,842,049
AF2-063 128.5 MW 7.0% $5,604,664
AG1-011 32.3 MW 1.8% $1,410,588
AG1-133 103.5 MW 5.7% $4,515,808
AG1-178 249.4 MW 13.6% $10,877,127
AG1-184 100.2 MW 5.5% $4,369,467
AG1-305 121.5 MW 6.6% $5,297,675
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-022 Add additional 500/230 kV transformer at Chickahominy substation. $40,000,000 $5,867,936 42 to 44 Months

Contributor

Description: Add additional 500/230 kV transformer at Chickahominy substation.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer (Any)
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 2 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer (All) A 1133.0 MVA
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer (All) B 1203.0 MVA
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 1 transformer (All) C 1365.0 MVA
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 2 transformer (All) A 1133.0 MVA
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 2 transformer (All) B 1203.0 MVA
6CHCKAHM-8CHCKAHM 230.0/500.0 kV Ckt 2 transformer (All) C 1365.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 177.0 MW 13.5% $5,394,675
AE2-124 176.8 MW 13.5% $5,389,097
AE2-156 22.3 MW 1.7% $680,537
AE2-270 39.7 MW 3.0% $1,208,635
AF1-123 192.5 MW 14.7% $5,867,936
AF1-124 192.5 MW 14.7% $5,867,936
AF1-125 192.5 MW 14.7% $5,867,936
AF1-201 50.7 MW 3.9% $1,544,454
AF2-065 39.7 MW 3.0% $1,208,635
AF2-120 23.6 MW 1.8% $719,219
AG1-011 42.3 MW 3.2% $1,289,382
AG1-075 33.8 MW 2.6% $1,031,566
AG1-135 22.9 MW 1.7% $698,064
AG1-147 27.2 MW 2.1% $827,948
AG1-359 28.0 MW 2.1% $853,369
AG1-364 22.3 MW 1.7% $680,598
AG1-536 28.5 MW 2.2% $870,013
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-051 Wreck and rebuild 10.7 miles of 230 kV line between Lanex and Lightfoot $30,762,500 $5,512,013 42 to 48 Months

Contributor

Description: Wreck and rebuild 10.7 miles of 230 kV line between Lanex and Lightfoot with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C. Replace the line lead at Light Foot.

Flowgates Addressed by this Reinforcement
Facility Contingency
6LANEXA-6LIGH209 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6LANEXA-6LIGH209 230.0 kV Ckt 1 line (All) A 877.0 MVA
6LANEXA-6LIGH209 230.0 kV Ckt 1 line (All) B 957.0 MVA
6LANEXA-6LIGH209 230.0 kV Ckt 1 line (All) C 1164.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 58.1 MW 16.0% $4,913,672
AE2-124 58.1 MW 16.0% $4,914,519
AE2-156 9.1 MW 2.5% $765,910
AF1-123 65.1 MW 17.9% $5,512,013
AF1-124 65.1 MW 17.9% $5,512,013
AF1-125 65.1 MW 17.9% $5,512,013
AG1-184 10.6 MW 2.9% $900,473
AG1-359 11.6 MW 3.2% $980,873
AG1-364 9.1 MW 2.5% $765,910
AG1-536 11.6 MW 3.2% $985,104
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7645 / dom-484 Add additional 500/230 kV transformer Suffolk Substation $40,000,000 $4,535,027 Dec 31 2024

Contributor

Description: Add additional 500/230 kV transformer Suffolk Substation

Flowgates Addressed by this Reinforcement
Facility Contingency
6SUFFOLK-8SUFFOLK 230.0/500.0 kV Ckt 2 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6SUFFOLK-8SUFFOLK 230.0/500.0 kV Ckt 2 transformer (All) A 1133.0 MVA
6SUFFOLK-8SUFFOLK 230.0/500.0 kV Ckt 2 transformer (All) B 1203.0 MVA
6SUFFOLK-8SUFFOLK 230.0/500.0 kV Ckt 2 transformer (All) C 1365.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 108.2 MW 14.5% $5,817,424
AE2-124 109.4 MW 14.7% $5,880,160
AE2-147 38.0 MW 5.1% $2,043,557
AE2-156 11.7 MW 1.6% $630,044
AE2-270 11.3 MW 1.5% $609,132
AF1-123 84.4 MW 11.3% $4,535,027
AF1-124 84.4 MW 11.3% $4,535,027
AF1-125 84.4 MW 11.3% $4,535,027
AF1-152 12.7 MW 1.7% $681,168
AF2-046 26.7 MW 3.6% $1,435,823
AF2-047 31.1 MW 4.2% $1,669,993
AF2-081 12.6 MW 1.7% $678,319
AG1-008 26.7 MW 3.6% $1,435,823
AG1-343 11.5 MW 1.6% $620,744
AG1-359 17.0 MW 2.3% $914,962
AG1-364 11.8 MW 1.6% $632,624
AG1-437 18.9 MW 2.5% $1,016,564
AG1-438 18.9 MW 2.5% $1,016,564
AG1-439 24.4 MW 3.3% $1,312,018
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8149 / dom-013 Add Additional 500/230 kV Transformer at Elmont Substation $40,000,000 $4,388,599 42 to 44 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer (Any)
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer (All) A 1133.0 MVA
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer (All) B 1203.0 MVA
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer (All) C 1365.0 MVA
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer (All) A 1133.0 MVA
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer (All) B 1203.0 MVA
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer (All) C 1365.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 152.7 MW 9.5% $3,803,667
AE2-124 150.9 MW 9.4% $3,759,777
AE2-147 19.0 MW 1.2% $474,163
AE2-156 28.1 MW 1.7% $699,488
AE2-250 17.7 MW 1.1% $441,981
AE2-270 50.5 MW 3.1% $1,258,141
AE2-313 32.8 MW 2.0% $816,086
AF1-123 176.2 MW 11.0% $4,388,599
AF1-124 223.0 MW 13.9% $5,555,699
AF1-125 223.0 MW 13.9% $5,555,699
AF1-201 39.9 MW 2.5% $994,407
AF1-266 11.6 MW 0.7% $287,945
AF2-046 18.5 MW 1.2% $460,588
AF2-047 19.5 MW 1.2% $486,891
AF2-065 40.7 MW 2.5% $1,014,110
AF2-120 11.3 MW 0.7% $281,917
AG1-008 18.5 MW 1.2% $461,534
AG1-011 53.7 MW 3.3% $1,337,326
AG1-075 45.4 MW 2.8% $1,130,808
AG1-134 33.9 MW 2.1% $843,834
AG1-135 11.0 MW 0.7% $274,096
AG1-147 13.2 MW 0.8% $328,248
AG1-178 61.1 MW 3.8% $1,521,377
AG1-184 41.2 MW 2.6% $1,025,070
AG1-359 35.3 MW 2.2% $879,752
AG1-364 28.0 MW 1.7% $696,374
AG1-449 26.5 MW 1.7% $660,207
AG1-536 22.6 MW 1.4% $562,216
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7611 / dom-413 Rebuild 9.1 miles of 500 kV Line 575 from Ladysmith to AG1-133 Tap with 3-1351.5 113C ACSR. Replace wave Trap, Line lead at Ladysmith terminal. $52,170,000 $3,988,137 Dec 01 2024

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
8LADYSMITH-AG1-133 TAP 500.0 kV Ckt 1 line (Any)
8LADYSMITH-AG1-133 TP 500.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
8LADYSMITH-AG1-133 TAP 500.0 kV Ckt 1 line (All) A 3897.0 MVA
8LADYSMITH-AG1-133 TAP 500.0 kV Ckt 1 line (All) B 4287.0 MVA
8LADYSMITH-AG1-133 TAP 500.0 kV Ckt 1 line (All) C 5011.0 MVA
8LADYSMITH-AG1-133 TP 500.0 kV Ckt 1 line (All) A 3897.0 MVA
8LADYSMITH-AG1-133 TP 500.0 kV Ckt 1 line (All) B 4287.0 MVA
8LADYSMITH-AG1-133 TP 500.0 kV Ckt 1 line (All) C 5011.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-313 35.1 MW 7.4% $3,885,790
AF1-123 36.0 MW 7.6% $3,988,137
AF1-124 36.0 MW 7.6% $3,988,137
AF1-125 36.0 MW 7.6% $3,988,137
AF2-037 47.1 MW 10.0% $5,221,408
AF2-042 49.5 MW 10.5% $5,483,924
AF2-063 45.1 MW 9.6% $4,999,987
AG1-133 57.4 MW 12.2% $6,362,190
AG1-178 60.5 MW 12.9% $6,706,119
AG1-184 32.6 MW 6.9% $3,612,862
AG1-305 35.5 MW 7.5% $3,933,308
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-216 Rebuild 7.8 miles of 230 kV Line 289 from Kings Fork to Chuckatuck with (2) 768.2 ACSS. $22,425,000 $3,370,128 42 to 48 Months

Contributor

Description: Rebuild 7.8 miles of 230 kV Line 289 from Kings Fork to Chuckatuck with (2) 768.2 ACSS.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHCKTUK-6KINGFORK 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHCKTUK-6KINGFORK 230.0 kV Ckt 1 line (All) A 797.0 MVA
6CHCKTUK-6KINGFORK 230.0 kV Ckt 1 line (All) B 797.0 MVA
6CHCKTUK-6KINGFORK 230.0 kV Ckt 1 line (All) C 1115.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 49.2 MW 13.1% $2,948,225
AE2-124 50.6 MW 13.5% $3,032,030
AE2-147 18.6 MW 5.0% $1,113,325
AF1-123 56.2 MW 15.0% $3,370,128
AF1-124 56.2 MW 15.0% $3,370,128
AF1-125 56.2 MW 15.0% $3,370,128
AF2-046 14.0 MW 3.7% $838,411
AF2-047 15.7 MW 4.2% $942,777
AG1-008 14.0 MW 3.7% $838,411
AG1-359 8.7 MW 2.3% $522,313
AG1-437 9.8 MW 2.6% $587,235
AG1-438 9.8 MW 2.6% $587,235
AG1-439 15.1 MW 4.0% $904,652
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-055 Wreck and rebuild 4.82 miles of 230 kV line 2105 between Thrasher and Yadkin / additional station upgrades $15,357,500 $3,294,518 36 to 42 Months

Contributor

Description: Wreck and rebuild 4.82 miles of 230 kV line 2105 between Thrasher and Yadkin with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. Replace Circuit Breaker and Circuit Breaker Lead at Yadkin, and Line Lead at Thrasher.

Flowgates Addressed by this Reinforcement
Facility Contingency
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) A 1051.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) B 1166.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) C 1218.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 176.5 MW 15.1% $2,320,361
AE2-124 194.5 MW 16.6% $2,556,866
AF1-123 250.6 MW 21.5% $3,294,518
AF1-124 250.6 MW 21.5% $3,294,518
AF1-125 250.6 MW 21.5% $3,294,518
AG1-359 45.4 MW 3.9% $596,720
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8056 Wreck and rebuild the existing 115 kV Line and Add new 230 kV Circuit $32,493,499 $3,261,692 36 to 42 Months

Contributor

Description: 1. Wreck and rebuild of an existing 115 kV line as a double circuit line from Prince George-Poe substation. 2. Add one 230 kV Circuit Breaker at Prince George Substation. 3. Add three 230 kV Circuit Breaker at Poe Substation. New Rating: 1047/1047/1204

Flowgates Addressed by this Reinforcement
Facility Contingency
6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer (All) A 1047.0 MVA
6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer (All) B 1047.0 MVA
6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer (All) C 1204.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 23.5 MW 11.5% $3,731,274
AE2-124 23.2 MW 11.3% $3,680,509
AE2-270 31.4 MW 15.3% $4,985,027
AF1-123 20.6 MW 10.0% $3,261,692
AF1-124 20.6 MW 10.0% $3,261,692
AF1-125 20.6 MW 10.0% $3,261,692
AF2-065 31.4 MW 15.3% $4,985,027
AG1-011 33.6 MW 16.4% $5,326,585
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-087 Addition of 230/500 kV Transformer at Carson Substation. $40,000,000 $3,090,856 42 to 44 Months

Contributor

Description: Add an 230/500 kV Transformer at carson Substation. Rating for new transformer is: 1133/1203/1365 MVA

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer (Any)
6CARSON-8CARSON 230.0/500.0 kV Ckt 1 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-8CARSON 230.0/500.0 kV Ckt 1 transformer (All) A 1133.0 MVA
6CARSON-8CARSON 230.0/500.0 kV Ckt 1 transformer (All) B 1203.0 MVA
6CARSON-8CARSON 230.0/500.0 kV Ckt 1 transformer (All) C 1365.0 MVA
6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer (All) A 1133.0 MVA
6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer (All) B 1203.0 MVA
6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer (All) C 1365.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 48.6 MW 6.0% $2,412,540
AE2-124 48.8 MW 6.0% $2,419,835
AE2-313 94.2 MW 11.7% $4,676,405
AF1-123 62.3 MW 7.7% $3,090,856
AF1-124 62.3 MW 7.7% $3,090,856
AF1-125 62.3 MW 7.7% $3,090,856
AF1-266 23.8 MW 2.9% $1,179,572
AF2-042 113.4 MW 14.1% $5,629,541
AG1-153 12.0 MW 1.5% $594,153
AG1-160 12.3 MW 1.5% $608,891
AG1-178 95.6 MW 11.9% $4,742,257
AG1-184 51.5 MW 6.4% $2,554,863
AG1-449 36.6 MW 4.5% $1,816,948
AG1-505 41.2 MW 5.1% $2,046,213
AG1-506 41.2 MW 5.1% $2,046,213
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6605 / dom-101 Wreck and rebuild 7.2 miles of line 271 between Pocaty and Landstown $20,700,000 $2,823,546 Dec 31 2026

Contributor

Description: Wreck and rebuild 7.2 miles of line 271 between Pocaty and Landstown with (2)-768 ACSS (20/7) “MAUMEE” conductor @ 250 degrees C. Replace the line lead at Landstown.

Flowgates Addressed by this Reinforcement
Facility Contingency
6LANDSTN-6POCATY 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6LANDSTN-6POCATY 230.0 kV Ckt 1 line (All) A 1168.0 MVA
6LANDSTN-6POCATY 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6LANDSTN-6POCATY 230.0 kV Ckt 1 line (All) C 1349.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 301.6 MW 20.3% $4,193,604
AE2-124 543.5 MW 36.5% $7,557,984
AE2-156 8.7 MW 0.6% $120,278
AF1-123 203.1 MW 13.6% $2,823,546
AF1-124 203.1 MW 13.6% $2,823,546
AF1-125 203.1 MW 13.6% $2,823,546
AG1-359 16.8 MW 1.1% $233,326
AG1-364 8.9 MW 0.6% $124,171
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8152 / dom-378 Add additional 500/230 kV transformer at Midlothian Substation $40,000,000 $2,769,209 42 to 44 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer (All) A 1133.0 MVA
6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer (All) B 1203.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 11.7 MW 4.0% $1,608,387
AE2-124 10.7 MW 3.7% $1,465,681
AE2-270 14.2 MW 4.9% $1,951,046
AE2-313 24.4 MW 8.3% $3,337,431
AF1-123 20.2 MW 6.9% $2,769,209
AF1-124 20.2 MW 6.9% $2,769,209
AF1-125 20.2 MW 6.9% $2,769,209
AF1-293 10.6 MW 3.6% $1,454,314
AF2-042 30.0 MW 10.3% $4,108,892
AG1-011 15.2 MW 5.2% $2,081,974
AG1-178 42.3 MW 14.5% $5,793,562
AG1-184 22.8 MW 7.8% $3,121,180
AG1-432 12.2 MW 4.2% $1,664,538
AG1-449 15.8 MW 5.4% $2,161,133
AG1-505 10.7 MW 3.7% $1,472,118
AG1-506 10.7 MW 3.7% $1,472,118
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7634 / dom-379 Rebuild 500 kV Line #575 from North Anna to AG1-133 Tap. $31,165,500 $2,713,343 48 to 60 Months

Contributor

Description: Rebuild 5.415 miles of 500 kV Line 575 from North Anna to AG1-133 Tap with 3-1351.5 113C ACSR. Replace Wave trap, Line Lead at North Anna terminal.

Flowgates Addressed by this Reinforcement
Facility Contingency
8NO ANNA-AG1-133 TAP 500.0 kV Ckt 1 line (Any)
8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
8NO ANNA-AG1-133 TAP 500.0 kV Ckt 1 line (All) A 3897.0 MVA
8NO ANNA-AG1-133 TAP 500.0 kV Ckt 1 line (All) B 4287.0 MVA
8NO ANNA-AG1-133 TAP 500.0 kV Ckt 1 line (All) C 5011.0 MVA
8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line (All) A 3897.0 MVA
8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line (All) B 4287.0 MVA
8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line (All) C 5011.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-313 35.1 MW 8.5% $2,643,710
AF1-123 36.0 MW 8.7% $2,713,343
AF1-124 36.0 MW 8.7% $2,713,343
AF1-125 36.0 MW 8.7% $2,713,343
AF2-037 47.1 MW 11.4% $3,552,403
AF2-042 49.5 MW 12.0% $3,731,007
AF2-063 45.1 MW 10.9% $3,401,758
AG1-178 60.5 MW 14.6% $4,562,531
AG1-184 32.6 MW 7.9% $2,458,023
AG1-305 35.5 MW 8.6% $2,676,040
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-311 Rebuild 6.8 miles of 230 kV Line 289 from Suffolk to Kings Fork with (2) 768.2 ACSS/TW (20/7) "MAUMEE" at 250 deg C $17,000,000 $2,554,968 36 to 40 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6KINGFORK-6SUFFOLK 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6KINGFORK-6SUFFOLK 230.0 kV Ckt 1 line (All) A 797.0 MVA
6KINGFORK-6SUFFOLK 230.0 kV Ckt 1 line (All) B 797.0 MVA
6KINGFORK-6SUFFOLK 230.0 kV Ckt 1 line (All) C 956.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 49.2 MW 13.1% $2,235,234
AE2-124 50.6 MW 13.5% $2,298,717
AE2-147 18.6 MW 5.0% $843,679
AF1-123 56.3 MW 15.0% $2,554,968
AF1-124 56.3 MW 15.0% $2,554,968
AF1-125 56.3 MW 15.0% $2,554,968
AF2-046 14.0 MW 3.7% $635,472
AF2-047 15.7 MW 4.2% $714,532
AG1-008 14.0 MW 3.7% $635,472
AG1-359 8.7 MW 2.3% $395,978
AG1-437 9.8 MW 2.6% $445,067
AG1-438 9.8 MW 2.6% $445,067
AG1-439 15.1 MW 4.0% $685,878
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7569 / dom-490 Reconductor 6.51 miles of line between Mt. Eagle and Cunningham $37,432,500 $2,397,367 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)
AE2-123 33.0 MW 5.8% $2,176,132
AE2-124 33.1 MW 5.8% $2,176,790
AF1-123 36.4 MW 6.4% $2,397,367
AF1-124 36.4 MW 6.4% $2,397,367
AF1-125 36.4 MW 6.4% $2,397,367
AF1-293 23.0 MW 4.1% $1,516,379
AF1-323 11.0 MW 1.9% $721,251
AF2-042 21.3 MW 3.7% $1,403,325
AF2-171 23.0 MW 4.1% $1,517,169
AF2-222 21.2 MW 3.7% $1,393,844
AF2-397 49.5 MW 8.7% $3,257,416
AG1-011 8.2 MW 1.4% $539,259
AG1-030 21.5 MW 3.8% $1,413,926
AG1-098 13.9 MW 2.4% $913,844
AG1-151 7.5 MW 1.3% $497,119
AG1-181 19.7 MW 3.5% $1,298,700
AG1-184 10.7 MW 1.9% $704,527
AG1-185 9.5 MW 1.7% $628,346
AG1-195 9.0 MW 1.6% $593,251
AG1-196 11.1 MW 2.0% $733,498
AG1-284 19.9 MW 3.5% $1,309,827
AG1-285 12.4 MW 2.2% $814,222
AG1-427 11.4 MW 2.0% $750,683
AG1-432 39.2 MW 6.9% $2,584,231
AG1-449 8.0 MW 1.4% $527,407
AG1-505 13.6 MW 2.4% $897,054
AG1-506 13.6 MW 2.4% $897,054
AG1-537 6.7 MW 1.2% $439,835
AG1-556 8.1 MW 1.4% $535,309
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-301 Rebuild 12.4 miles of 230 kV Line 259 from Chesterfield to Basin with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. And breaker equipment. $38,450,000 $2,163,861 36 to 40 Months

Contributor

Description: Rebuild 12.4 miles of 230 kV Line 259 from Chesterfield to Basin with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. Replace Circuit Breakre and Circuit Breaker Switch at Chesterfield, and Circuit Breaker Switch and Wave Trap at Basin.

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 1168.0 MVA
6BASIN-6CHESTF B 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6BASIN-6CHESTF B 230.0 kV Ckt 1 line (All) C 1349.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 10.1 MW 3.6% $1,365,422
AE2-124 9.2 MW 3.2% $1,240,073
AE2-147 8.7 MW 3.1% $1,179,228
AE2-270 14.9 MW 5.3% $2,024,283
AE2-313 25.7 MW 9.1% $3,485,919
AF1-123 16.0 MW 5.6% $2,163,861
AF1-124 16.0 MW 5.6% $2,163,861
AF1-125 16.0 MW 5.6% $2,163,861
AF1-266 7.7 MW 2.7% $1,048,188
AF2-042 17.6 MW 6.2% $2,388,134
AF2-046 10.1 MW 3.5% $1,364,338
AF2-047 9.1 MW 3.2% $1,229,097
AF2-065 7.6 MW 2.7% $1,032,333
AG1-008 6.6 MW 2.3% $900,344
AG1-011 15.9 MW 5.6% $2,161,151
AG1-075 8.2 MW 2.9% $1,113,098
AG1-178 23.4 MW 8.3% $3,176,138
AG1-184 12.6 MW 4.5% $1,711,114
AG1-359 7.8 MW 2.7% $1,055,099
AG1-439 8.7 MW 3.1% $1,181,939
AG1-449 8.6 MW 3.0% $1,164,051
AG1-505 11.6 MW 4.1% $1,569,233
AG1-506 11.6 MW 4.1% $1,569,233
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6551 / dom-159 Rebuild 7.32 miles of 230 kV Line 208 from Chesterfield to Iron Bridge with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. $21,045,000 $2,089,521 36 to 40 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHESTF A-6IRON208 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHESTF A-6IRON208 230.0 kV Ckt 1 line (All) A 876.0 MVA
6CHESTF A-6IRON208 230.0 kV Ckt 1 line (All) B 956.0 MVA
6CHESTF A-6IRON208 230.0 kV Ckt 1 line (All) C 1163.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 9.7 MW 6.3% $1,316,837
AE2-124 8.8 MW 5.7% $1,194,691
AE2-270 14.9 MW 9.6% $2,023,353
AF1-123 15.4 MW 9.9% $2,089,521
AF1-124 15.4 MW 9.9% $2,089,521
AF1-125 15.4 MW 9.9% $2,089,521
AF1-128 37.7 MW 24.4% $5,128,010
AF1-201 6.7 MW 4.3% $910,047
AF2-065 7.6 MW 4.9% $1,031,921
AG1-011 15.9 MW 10.3% $2,159,901
AG1-359 7.4 MW 4.8% $1,011,677
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-164 Rebuild 7.0 miles of 230 kV Line 208 from Iron Bridge to Southwest with (2) 768.2 ACSS $20,355,000 $2,020,026 42 to 48 Months

Contributor

Description: Rebuild 7.08 miles of 230 kV Line 208 from Iron Bridge to Southwest with (2) 768.2 ACSS at 250 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
6IRON208-6SOUWEST 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6IRON208-6SOUWEST 230.0 kV Ckt 1 line (All) A 1046.0 MVA
6IRON208-6SOUWEST 230.0 kV Ckt 1 line (All) B 1046.0 MVA
6IRON208-6SOUWEST 230.0 kV Ckt 1 line (All) C 1203.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 9.7 MW 6.3% $1,273,072
AE2-124 8.8 MW 5.7% $1,154,958
AE2-270 14.9 MW 9.6% $1,957,155
AF1-123 15.4 MW 9.9% $2,020,026
AF1-124 15.4 MW 9.9% $2,020,026
AF1-125 15.4 MW 9.9% $2,020,026
AF1-128 37.7 MW 24.4% $4,964,237
AF1-201 6.7 MW 4.3% $880,062
AF2-065 7.6 MW 4.9% $998,175
AG1-011 15.9 MW 10.3% $2,089,210
AG1-359 7.4 MW 4.8% $978,051
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6607 / dom-116 Rebuild 5.88 miles of 230 kV Line 2026 from Landstown to Lynnhaven with (2) 768.2 ACSS/TW (20/7) "MAUMEE" $16,905,000 $1,426,462 Dec 31 2026

Contributor

Description: Rebuild 5.88 miles of 230 kV Line 2026 from Landstown to Lynnhaven with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C and circuit breaker lead.

Flowgates Addressed by this Reinforcement
Facility Contingency
6LANDSTN-6LYNHAVN 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6LANDSTN-6LYNHAVN 230.0 kV Ckt 1 line (All) A 877.0 MVA
6LANDSTN-6LYNHAVN 230.0 kV Ckt 1 line (All) B 957.0 MVA
6LANDSTN-6LYNHAVN 230.0 kV Ckt 1 line (All) C 1164.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 227.1 MW 33.9% $5,728,728
AE2-124 227.1 MW 33.9% $5,728,728
AE2-147 9.3 MW 1.4% $234,666
AF1-123 56.5 MW 8.4% $1,426,462
AF1-124 56.5 MW 8.4% $1,426,462
AF1-125 56.5 MW 8.4% $1,426,462
AF2-081 12.9 MW 1.9% $326,141
AG1-359 24.1 MW 3.6% $607,351
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7568 / dom-369 Rebuild 6.47 miles of 230 kV Line 2028 from Mt Eagle to Charlottesville with 2-768.2 ACSS 250 C. Replace Wave Trap and CB Switch at Charlottesville terminal $19,351,250 $1,291,232 36 to 40 Months

Contributor

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 1168.0 MVA
6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line (All) C 1349.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 33.0 MW 6.1% $1,172,074
AE2-124 33.1 MW 6.1% $1,172,429
AF1-123 36.4 MW 6.7% $1,291,232
AF1-124 36.4 MW 6.7% $1,291,232
AF1-125 36.4 MW 6.7% $1,291,232
AF1-293 23.0 MW 4.2% $816,728
AF1-323 11.0 MW 2.0% $388,469
AF2-042 21.3 MW 3.9% $755,837
AF2-171 23.0 MW 4.2% $817,154
AF2-222 21.2 MW 3.9% $750,731
AF2-397 26.6 MW 4.9% $944,398
AG1-011 8.2 MW 1.5% $290,447
AG1-030 21.5 MW 3.9% $761,547
AG1-098 13.9 MW 2.5% $492,200
AG1-151 7.5 MW 1.4% $267,751
AG1-181 19.7 MW 3.6% $699,485
AG1-184 10.7 MW 2.0% $379,461
AG1-185 9.5 MW 1.7% $338,430
AG1-195 9.0 MW 1.7% $319,528
AG1-196 11.1 MW 2.0% $395,065
AG1-284 19.9 MW 3.6% $705,479
AG1-285 12.4 MW 2.3% $438,544
AG1-427 11.4 MW 2.1% $404,321
AG1-432 39.2 MW 7.2% $1,391,878
AG1-449 8.0 MW 1.5% $284,064
AG1-505 13.6 MW 2.5% $483,157
AG1-506 13.6 MW 2.5% $483,157
AG1-537 6.7 MW 1.2% $236,897
AG1-556 8.1 MW 1.5% $288,320
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-019 Wreck and rebuild 5.86 miles of 230 kV line 2028 between AF2-397 Tap to Grape Vine (Cunningham) $16,847,500 $1,078,999 42 to 48 Months

Contributor

Description: Wreck and rebuild 5.86 miles of 230 kV line 2028 between AF2-397 Tap to Grape Vine (Cunningham) with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line (All) A 1175.0 MVA
6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line (All) C 1361.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 33.0 MW 5.8% $979,427
AE2-124 33.1 MW 5.8% $979,723
AF1-123 36.4 MW 6.4% $1,078,999
AF1-124 36.4 MW 6.4% $1,078,999
AF1-125 36.4 MW 6.4% $1,078,999
AF1-293 23.0 MW 4.1% $682,487
AF1-323 11.0 MW 1.9% $324,618
AF2-042 21.3 MW 3.7% $631,604
AF2-171 23.0 MW 4.1% $682,843
AF2-222 21.2 MW 3.7% $627,337
AF2-397 49.5 MW 8.7% $1,466,087
AG1-011 8.2 MW 1.4% $242,708
AG1-030 21.5 MW 3.8% $636,375
AG1-098 13.9 MW 2.4% $411,300
AG1-151 7.5 MW 1.3% $223,742
AG1-181 19.7 MW 3.5% $584,515
AG1-184 10.7 MW 1.9% $317,091
AG1-185 9.5 MW 1.7% $282,804
AG1-195 9.0 MW 1.6% $267,009
AG1-196 11.1 MW 2.0% $330,130
AG1-284 19.9 MW 3.5% $589,523
AG1-285 12.4 MW 2.2% $366,463
AG1-427 11.4 MW 2.0% $337,865
AG1-432 39.2 MW 6.9% $1,163,102
AG1-449 8.0 MW 1.4% $237,374
AG1-505 13.6 MW 2.4% $403,743
AG1-506 13.6 MW 2.4% $403,743
AG1-537 6.7 MW 1.2% $197,960
AG1-556 8.1 MW 1.4% $240,930
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6161 / dom-039 Replace Circuit Breaker at Clifton $2,500,000 $866,285 42 to 48 Months

Contributor

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 2858.0 MVA
8CLIFTON-8OX 500.0 kV Ckt 1 line (All) B 3118.0 MVA
8CLIFTON-8OX 500.0 kV Ckt 1 line (All) C 3794.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AF1-123 71.7 MW 34.7% $866,285
AF1-124 71.7 MW 34.7% $866,285
AF1-125 29.0 MW 14.0% $350,063
AG1-178 34.6 MW 16.7% $417,367
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7566 / dom-265 Rebuild 5 miles of 230 kV Line 2028 from Fork Union to AF2-397 Tap with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. $12,500,000 $835,009 36 to 42 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6FORK UNION-AF2-397 TAP 230.0 kV Ckt 1 line (Any)
6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6FORK UNION-AF2-397 TAP 230.0 kV Ckt 1 line (All) A 1174.0 MVA
6FORK UNION-AF2-397 TAP 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6FORK UNION-AF2-397 TAP 230.0 kV Ckt 1 line (All) C 1360.0 MVA
6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line (All) A 1174.0 MVA
6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6FORK UNION-AF2-397 TP 230.0 kV Ckt 1 line (All) C 1360.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 33.0 MW 6.1% $757,952
AE2-124 33.1 MW 6.1% $758,182
AF1-123 36.4 MW 6.7% $835,009
AF1-124 36.4 MW 6.7% $835,009
AF1-125 36.4 MW 6.7% $835,009
AF1-293 23.0 MW 4.2% $528,159
AF1-323 11.0 MW 2.0% $251,214
AF2-042 21.3 MW 3.9% $488,782
AF2-171 23.0 MW 4.2% $528,434
AF2-222 21.2 MW 3.9% $485,479
AF2-397 26.0 MW 4.8% $596,730
AG1-011 8.2 MW 1.5% $187,825
AG1-030 21.5 MW 3.9% $492,474
AG1-098 13.9 MW 2.5% $318,294
AG1-151 7.5 MW 1.4% $173,148
AG1-181 19.7 MW 3.6% $452,341
AG1-184 10.7 MW 2.0% $245,389
AG1-185 9.5 MW 1.8% $218,854
AG1-195 9.0 MW 1.7% $206,631
AG1-196 11.1 MW 2.0% $255,479
AG1-284 19.9 MW 3.6% $456,216
AG1-285 12.4 MW 2.3% $283,596
AG1-427 11.4 MW 2.1% $261,465
AG1-432 39.2 MW 7.2% $900,094
AG1-449 8.0 MW 1.5% $183,697
AG1-505 13.6 MW 2.5% $312,446
AG1-506 13.6 MW 2.5% $312,446
AG1-537 6.7 MW 1.2% $153,196
AG1-556 8.1 MW 1.5% $186,449
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8239 / dom-300 Rebuild 9.46 miles of 230 kV Line 217 from Chesterfield to Varina with 2-768.2 ACSS 250 C $14,190,000 $739,375 Dec 01 2024

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6VARINA-6CHESTF B 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6VARINA-6CHESTF B 230.0 kV Ckt 1 line (All) A 1174.0 MVA
6VARINA-6CHESTF B 230.0 kV Ckt 1 line (All) B 1195.0 MVA
6VARINA-6CHESTF B 230.0 kV Ckt 1 line (All) C 1360.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 46.4 MW 16.3% $2,316,119
AE2-124 46.3 MW 16.3% $2,310,583
AE2-270 17.7 MW 6.2% $884,497
AE2-313 12.2 MW 4.3% $610,610
AF1-123 14.8 MW 5.2% $739,375
AF1-124 14.8 MW 5.2% $739,375
AF1-125 14.8 MW 5.2% $739,375
AF1-128 16.1 MW 5.6% $800,565
AF2-042 16.8 MW 5.9% $837,569
AF2-065 17.7 MW 6.2% $884,497
AG1-011 18.9 MW 6.7% $944,540
AG1-075 17.9 MW 6.3% $890,830
AG1-178 18.3 MW 6.4% $913,471
AG1-184 11.6 MW 4.1% $578,593
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / dom-122 Add additional 138/115 kV transformer at Altavista substation $6,500,000 $679,790 42 to 44 Months

Contributor

Description: Add additional 138/115 kV transformer at Altavista substation

Flowgates Addressed by this Reinforcement
Facility Contingency
3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer (Any)
3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 2 transformer (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer (All) A 135.5 MVA
3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer (All) B 138.8 MVA
3ALTVSTA-4ALTVSTA 115.0/138.0 kV Ckt 1 transformer (All) C 146.6 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 15.6 MW 9.5% $616,803
AE2-124 15.6 MW 9.5% $617,199
AF1-123 17.2 MW 10.5% $679,790
AF1-124 17.2 MW 10.5% $679,790
AF1-125 17.2 MW 10.5% $679,790
AF2-403 10.6 MW 6.4% $418,333
AF2-404 10.6 MW 6.4% $418,333
AG1-539 60.3 MW 36.8% $2,389,962
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6606 / dom-100 Rebuild 1.76 miles of 230 kV Line 2240 from Pocaty to Fentress $5,060,000 $637,608 Dec 31 2026

Contributor

Description: Rebuild 1.76 miles of 230 kV Line 2240 from Pocaty to Fentress with (2) 768 ACSS/TW (20/7) “MAUMEE” conductor at 250 degrees C. Replace the line lead at Fentress.

Flowgates Addressed by this Reinforcement
Facility Contingency
6FENTRES-6POCATY 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6FENTRES-6POCATY 230.0 kV Ckt 1 line (All) A 877.0 MVA
6FENTRES-6POCATY 230.0 kV Ckt 1 line (All) B 957.0 MVA
6FENTRES-6POCATY 230.0 kV Ckt 1 line (All) C 1164.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 424.6 MW 26.3% $1,333,126
AE2-124 543.4 MW 33.7% $1,706,161
AE2-156 8.7 MW 0.5% $27,161
AF1-123 203.1 MW 12.6% $637,608
AF1-124 203.1 MW 12.6% $637,608
AF1-125 203.1 MW 12.6% $637,608
AG1-359 16.8 MW 1.0% $52,689
AG1-364 8.9 MW 0.6% $28,040
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-048 Replace Circuit Breaker at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $1,500,000 $413,295 42 to 48 Months

Contributor

Description: Replace Circuit Breaker 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 1315.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 1435.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 1745.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $84,844
AE2-124 97.3 MW 6.7% $100,423
AF1-123 400.3 MW 27.6% $413,295
AF1-124 400.3 MW 27.6% $413,295
AF1-125 400.3 MW 27.6% $413,295
AG1-359 72.5 MW 5.0% $74,850
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-081 Replace Circuit Breaker and Relay at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 $2,650,000 $403,172 42 to 48 Months

Contributor

Description: Replace Circuit Breaker and Relay at Surry

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 2858.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) B 3118.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) C 3794.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 231.7 MW 13.3% $352,040
AE2-124 231.9 MW 13.3% $352,359
AE2-147 40.6 MW 2.3% $61,696
AE2-156 28.3 MW 1.6% $42,938
AE2-313 73.2 MW 4.2% $111,267
AF1-123 265.3 MW 15.2% $403,172
AF1-124 265.3 MW 15.2% $403,172
AF1-125 265.3 MW 15.2% $403,172
AF2-042 58.0 MW 3.3% $88,087
AF2-047 36.7 MW 2.1% $55,815
AG1-178 83.2 MW 4.8% $126,427
AG1-184 44.8 MW 2.6% $68,112
AG1-359 37.2 MW 2.1% $56,604
AG1-364 27.8 MW 1.6% $42,275
AG1-439 26.7 MW 1.5% $40,564
AG1-449 27.8 MW 1.6% $42,300
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7567 / dom-276 Rebuild 1.63 miles of 230 kV Line 2028 from Fork Union to Bremo Dist with 2-795 ACSR (26/7) 150 C $4,686,250 $321,565 30 to 36 Months

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
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 (All) A 1174.0 MVA
6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line (All) B 1225.0 MVA
6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line (All) C 1360.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 36.5 MW 6.2% $292,659
AE2-124 36.5 MW 6.2% $292,659
AF1-123 40.2 MW 6.9% $321,565
AF1-124 40.2 MW 6.9% $321,565
AF1-125 41.3 MW 7.1% $330,693
AF1-293 8.4 MW 1.4% $66,875
AF1-294 7.0 MW 1.2% $56,450
AF2-042 23.8 MW 4.1% $190,537
AF2-171 25.7 MW 4.4% $205,694
AF2-222 23.6 MW 4.0% $188,711
AF2-397 23.9 MW 4.1% $191,530
AG1-011 9.4 MW 1.6% $75,347
AG1-030 23.9 MW 4.1% $191,602
AG1-098 15.5 MW 2.6% $124,062
AG1-151 8.0 MW 1.4% $63,897
AG1-181 21.9 MW 3.7% $175,724
AG1-184 10.5 MW 1.8% $83,914
AG1-185 8.2 MW 1.4% $66,059
AG1-195 13.6 MW 2.3% $108,496
AG1-196 15.3 MW 2.6% $122,589
AG1-285 13.7 MW 2.3% $110,002
AG1-359 7.3 MW 1.2% $58,292
AG1-426 11.8 MW 2.0% $94,163
AG1-427 12.7 MW 2.2% $101,394
AG1-432 43.8 MW 7.5% $350,839
AG1-449 7.7 MW 1.3% $61,655
AG1-451 7.3 MW 1.2% $58,476
AG1-505 14.9 MW 2.6% $119,618
AG1-506 14.9 MW 2.6% $119,618
AG1-537 9.0 MW 1.5% $71,744
AG1-556 8.7 MW 1.5% $69,822
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8238 / dom-294 Rebuild 1.38 mi miles of 230 kV Line 217 from Varina to Charles City with 2-768.2 ACSS 250 C $3,967,500 $206,728 Dec 01 2024

Contributor

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHARCTY-6VARINA 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHARCTY-6VARINA 230.0 kV Ckt 1 line (All) A 1315.0 MVA
6CHARCTY-6VARINA 230.0 kV Ckt 1 line (All) B 1434.0 MVA
6CHARCTY-6VARINA 230.0 kV Ckt 1 line (All) C 1745.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 46.4 MW 16.3% $647,583
AE2-124 46.3 MW 16.3% $646,035
AE2-270 17.7 MW 6.2% $247,304
AE2-313 12.2 MW 4.3% $170,726
AF1-123 14.8 MW 5.2% $206,728
AF1-124 14.8 MW 5.2% $206,728
AF1-125 14.8 MW 5.2% $206,728
AF1-128 16.1 MW 5.6% $223,837
AF2-042 16.8 MW 5.9% $234,183
AF2-065 17.7 MW 6.2% $247,304
AG1-011 18.9 MW 6.7% $264,092
AG1-075 17.9 MW 6.3% $249,075
AG1-178 18.3 MW 6.4% $255,405
AG1-184 11.6 MW 4.1% $161,774
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-044 Replace Circuit Breaker Switch at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $550,000 $151,541 12 to 18 Months

Contributor

Description: Replace Circuit Breaker Switch 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 957.0 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)
AE2-123 82.2 MW 5.7% $31,109
AE2-124 97.3 MW 6.7% $36,822
AF1-123 400.3 MW 27.6% $151,541
AF1-124 400.3 MW 27.6% $151,541
AF1-125 400.3 MW 27.6% $151,541
AG1-359 72.5 MW 5.0% $27,445
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-082 Replace Circuit Breaker Switch at Surry for increased rating on 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 $900,000 $136,926 12 to 18 Months

Contributor

Description: Replace Circuit Breaker Switch at Surry

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 3426.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) B 3426.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) C 3940.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 231.7 MW 13.3% $119,561
AE2-124 231.9 MW 13.3% $119,669
AE2-147 40.6 MW 2.3% $20,953
AE2-156 28.3 MW 1.6% $14,583
AE2-313 73.2 MW 4.2% $37,789
AF1-123 265.3 MW 15.2% $136,926
AF1-124 265.3 MW 15.2% $136,926
AF1-125 265.3 MW 15.2% $136,926
AF2-042 58.0 MW 3.3% $29,916
AF2-047 36.7 MW 2.1% $18,956
AG1-178 83.2 MW 4.8% $42,937
AG1-184 44.8 MW 2.6% $23,132
AG1-359 37.2 MW 2.1% $19,224
AG1-364 27.8 MW 1.6% $14,358
AG1-439 26.7 MW 1.5% $13,777
AG1-449 27.8 MW 1.6% $14,366
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7789 / dom-363 Rebuild 0.16 miles of Line 2193 from Bremo to Bremo Dist $1,948,000 $133,670 30 to 36 Months

Contributor

Description: Rebuild 0.16 miles of Line 2193 from Bremo to Bremo Dist with 2-795 ACSR 150 C. Replace Breaker, Breaker Switch, Breaker Lead, Line Lead at Bremo terminal

Flowgates Addressed by this Reinforcement
Facility Contingency
6BREMODIST-6BREMO 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6BREMODIST-6BREMO 230.0 kV Ckt 1 line (All) A 1225.0 MVA
6BREMODIST-6BREMO 230.0 kV Ckt 1 line (All) B 1225.0 MVA
6BREMODIST-6BREMO 230.0 kV Ckt 1 line (All) C 1409.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 36.5 MW 6.2% $121,654
AE2-124 36.5 MW 6.2% $121,654
AF1-123 40.2 MW 6.9% $133,670
AF1-124 40.2 MW 6.9% $133,670
AF1-125 41.3 MW 7.1% $137,464
AF1-293 8.4 MW 1.4% $27,799
AF1-294 7.0 MW 1.2% $23,465
AF2-042 23.8 MW 4.1% $79,203
AF2-171 25.7 MW 4.4% $85,504
AF2-222 23.6 MW 4.0% $78,444
AF2-397 23.9 MW 4.1% $79,616
AG1-011 9.4 MW 1.6% $31,320
AG1-030 23.9 MW 4.1% $79,646
AG1-098 15.5 MW 2.6% $51,571
AG1-151 8.0 MW 1.4% $26,561
AG1-181 21.9 MW 3.7% $73,046
AG1-184 10.5 MW 1.8% $34,882
AG1-185 8.2 MW 1.4% $27,459
AG1-195 13.6 MW 2.3% $45,100
AG1-196 15.3 MW 2.6% $50,958
AG1-285 13.7 MW 2.3% $45,726
AG1-359 7.3 MW 1.2% $24,231
AG1-426 11.8 MW 2.0% $39,142
AG1-427 12.7 MW 2.2% $42,148
AG1-432 43.8 MW 7.5% $145,838
AG1-449 7.7 MW 1.3% $25,629
AG1-451 7.3 MW 1.2% $24,307
AG1-505 14.9 MW 2.6% $49,723
AG1-506 14.9 MW 2.6% $49,723
AG1-537 9.0 MW 1.5% $29,823
AG1-556 8.7 MW 1.5% $29,024
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-047 Replace Wave Trap at Fentress and Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $400,000 $110,212 16 to 18 Months

Contributor

Description: Replace Wave Trap at 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 1168.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 1349.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $22,625
AE2-124 97.3 MW 6.7% $26,779
AF1-123 400.3 MW 27.6% $110,212
AF1-124 400.3 MW 27.6% $110,212
AF1-125 400.3 MW 27.6% $110,212
AG1-359 72.5 MW 5.0% $19,960
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-057 Replace Wave Trap at Yadkin and Thrasher for increased rating on Line 2015 6THRASHER 230 KV to 6YADKIN 230 KV ckt 1 $400,000 $85,809 16 to 18 Months

Contributor

Description: Replace Wave Trap at Yadkin and Thrasher.

Flowgates Addressed by this Reinforcement
Facility Contingency
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) A 1220.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) B 1315.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) C 1447.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 176.5 MW 15.1% $60,436
AE2-124 194.5 MW 16.6% $66,596
AF1-123 250.6 MW 21.5% $85,809
AF1-124 250.6 MW 21.5% $85,809
AF1-125 250.6 MW 21.5% $85,809
AG1-359 45.4 MW 3.9% $15,542
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-049 Replace Circuit Breaker Switch at Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $275,000 $75,771 12 to 18 Months

Contributor

Description: Replace Circuit Breaker Switch at 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 1594.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 1753.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 2231.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $15,555
AE2-124 97.3 MW 6.7% $18,411
AF1-123 400.3 MW 27.6% $75,771
AF1-124 400.3 MW 27.6% $75,771
AF1-125 400.3 MW 27.6% $75,771
AG1-359 72.5 MW 5.0% $13,722
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8260 / dom-457 Replace Wave Traps at Surry and Septa $600,000 $72,306 Dec 01 2024

Contributor

Description: Replace Wave Traps at Surry and Septa

Flowgates Addressed by this Reinforcement
Facility Contingency
8SEPTA-8SURRY 500.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
8SEPTA-8SURRY 500.0 kV Ckt 1 line (All) A 2539.0 MVA
8SEPTA-8SURRY 500.0 kV Ckt 1 line (All) B 3118.0 MVA
8SEPTA-8SURRY 500.0 kV Ckt 1 line (All) C 3794.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 26.5 MW 6.4% $38,226
AE2-313 43.3 MW 10.4% $62,484
AF1-123 50.1 MW 12.1% $72,306
AF1-124 50.1 MW 12.1% $72,306
AF1-125 50.1 MW 12.1% $72,306
AF2-042 57.3 MW 13.8% $82,625
AG1-178 71.8 MW 17.3% $103,515
AG1-184 38.7 MW 9.3% $55,768
AG1-449 28.1 MW 6.7% $40,463
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-079 Replace Wave Trap at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 $300,000 $45,642 16 to 18 Months

Contributor

Description: Replace Wave Trap at Surry

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 2539.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) B 2809.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) C 2932.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 231.7 MW 13.3% $39,854
AE2-124 231.9 MW 13.3% $39,890
AE2-147 40.6 MW 2.3% $6,984
AE2-156 28.3 MW 1.6% $4,861
AE2-313 73.2 MW 4.2% $12,596
AF1-123 265.3 MW 15.2% $45,642
AF1-124 265.3 MW 15.2% $45,642
AF1-125 265.3 MW 15.2% $45,642
AF2-042 58.0 MW 3.3% $9,972
AF2-047 36.7 MW 2.1% $6,319
AG1-178 83.2 MW 4.8% $14,312
AG1-184 44.8 MW 2.6% $7,711
AG1-359 37.2 MW 2.1% $6,408
AG1-364 27.8 MW 1.6% $4,786
AG1-439 26.7 MW 1.5% $4,592
AG1-449 27.8 MW 1.6% $4,789
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-045 Repalce CT Relay at Fentress for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $150,000 $41,329 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 1051.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 1166.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 1218.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $8,484
AE2-124 97.3 MW 6.7% $10,042
AF1-123 400.3 MW 27.6% $41,329
AF1-124 400.3 MW 27.6% $41,329
AF1-125 400.3 MW 27.6% $41,329
AG1-359 72.5 MW 5.0% $7,485
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-046 Replace Circuit Breaker Lead at Thrasher for increased rating on Line 2128 6FENTRES 230 KV to 6THRASHER 230 KV ckt 1 $100,000 $27,553 12 to 18 Months

Contributor

Description: Replace Circuit Breaker Lead at 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 1196.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6FENTRES-6THRASHER 230.0 kV Ckt 1 line (All) C 1674.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 82.2 MW 5.7% $5,656
AE2-124 97.3 MW 6.7% $6,695
AF1-123 400.3 MW 27.6% $27,553
AF1-124 400.3 MW 27.6% $27,553
AF1-125 400.3 MW 27.6% $27,553
AG1-359 72.5 MW 5.0% $4,990
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-056 Replace Circuit Breaker Lead at Thrasher for increased rating on Line 2105 6THRASHER 230 KV to 6YADKIN 230 KV ckt 1 $100,000 $21,452 12 to 18 Months

Contributor

Description: Replace Circuit Breaker Lead at Thrasher

Flowgates Addressed by this Reinforcement
Facility Contingency
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) A 1196.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) B 1196.0 MVA
6THRASHER-6YADKIN 230.0 kV Ckt 1 line (All) C 1674.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 176.5 MW 15.1% $15,109
AE2-124 194.5 MW 16.6% $16,649
AF1-123 250.6 MW 21.5% $21,452
AF1-124 250.6 MW 21.5% $21,452
AF1-125 250.6 MW 21.5% $21,452
AG1-359 45.4 MW 3.9% $3,886
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-080 Replace Line Lead at Surry for increased rating on Line 567 8SURRY 500 KV to 8CHCKAHM 500 KV ckt 1 $100,000 $15,214 12 to 18 Months

Contributor

Description: Replace Line Lead at Surry

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 2599.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) B 2858.0 MVA
8CHCKAHM-8SURRY 500.0 kV Ckt 1 line (All) C 3144.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-123 231.7 MW 13.3% $13,285
AE2-124 231.9 MW 13.3% $13,297
AE2-147 40.6 MW 2.3% $2,328
AE2-156 28.3 MW 1.6% $1,620
AE2-313 73.2 MW 4.2% $4,199
AF1-123 265.3 MW 15.2% $15,214
AF1-124 265.3 MW 15.2% $15,214
AF1-125 265.3 MW 15.2% $15,214
AF2-042 58.0 MW 3.3% $3,324
AF2-047 36.7 MW 2.1% $2,106
AG1-178 83.2 MW 4.8% $4,771
AG1-184 44.8 MW 2.6% $2,570
AG1-359 37.2 MW 2.1% $2,136
AG1-364 27.8 MW 1.6% $1,595
AG1-439 26.7 MW 1.5% $1,531
AG1-449 27.8 MW 1.6% $1,596
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-097 Substation work for Energizing the bremo Tx#7 $100,000 $8,120 6 to 12 Months

Contributor

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)
AE2-123 16.7 MW 7.4% $7,392
AE2-124 16.7 MW 7.4% $7,392
AF1-123 18.4 MW 8.1% $8,120
AF1-124 18.4 MW 8.1% $8,120
AF1-125 18.4 MW 8.1% $8,120
AF1-293 26.7 MW 11.8% $11,794
AF2-171 11.8 MW 5.2% $5,192
AF2-222 11.0 MW 4.8% $4,839
AF2-397 8.8 MW 3.9% $3,890
AG1-030 11.0 MW 4.9% $4,863
AG1-098 7.3 MW 3.2% $3,216
AG1-181 10.3 MW 4.5% $4,540
AG1-285 6.5 MW 2.9% $2,892
AG1-426 13.3 MW 5.9% $5,890
AG1-427 6.1 MW 2.7% $2,674
AG1-432 19.7 MW 8.7% $8,712
AG1-537 5.3 MW 2.4% $2,353
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion b3211 Rebuild the 1.3 mile section of 500 kV Line No.569 (Loudoun - Morrisville) $0 $0 Dec 31 2025

Contingent

Note: Although AF1-123 may not presently have cost responsibility for this upgrade, AF1-123 may need this upgrade in-service to be deliverable to the PJM system. If AF1-123 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Rebuild the 1.3 mile section of 500 kV Line No.569 (Loudoun - Morrisville) with single-circuit 500 kV structures at the current 500 kV standard. This will increase the rating of the line to 3424 MVA.

Flowgates Addressed by this Reinforcement
Facility Contingency
8LOUDOUN-8MORRSVL 500.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
8LOUDOUN-8MORRSVL 500.0 kV Ckt 1 line (All) A 3426.0 MVA
8LOUDOUN-8MORRSVL 500.0 kV Ckt 1 line (All) B 3426.0 MVA
8LOUDOUN-8MORRSVL 500.0 kV Ckt 1 line (All) C 3940.0 MVA

Attachments


[1]Winter load flow analysis will be performed starting in Transition Cycle #2.