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AG1-153 Phase I Study Report

v1.00 released 2024-05-16 00:10

Heritage 500 kV

30.0 MW Capacity / 75.0 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 Storage facility located in the Virginia Electric and Power Company zone — Brunswick County, Virginia. The installed facilities will have a total capability of 75.0 MW with 30.0 MW of this output being recognized by PJM as Capacity.

Project Information
New Service Request Number AG1-153
Project Name Heritage 500 kV
Developer Name Virginia Electric & Power Company
State Virginia
County Brunswick
Transmission Owner Virginia Electric and Power Company
MFO 75.0 MW
MWE 75.0 MW
MWC 30.0 MW
Fuel Type Storage
Basecase Study Year 2027

Point of Interconnection

AG1-153 will interconnect on the Dominion transmission system as direct connect at Heritage 500 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 AG1-153 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 AG1-153 Cost Subject to Readiness*
Transmission Owner Interconnection Facilities (TOIF) $900,000 $0
Physical Interconnection Network Upgrades
Stand Alone Network Upgrades $0 $0
Network Upgrades $5,000,000 $5,000,000
System Reliability Network Upgrades
Steady State Thermal & Voltage (SP & LL) $1,428,508 $1,428,508
Transient Stability $0 $0
Short Circuit $0 $0
Transmission Owner Analysis
SubRegional $0 $0
Distribution $0 $0
Affected System Study Reinforcements $0 $0
Total $7,328,508 $6,428,508

* 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 AG1-153

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 AG1-153 Project due at DP1
A B A - B
AG1-153 $642,851 $300,000 $342,851

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 direct connect to the Heritage 500 kV Sub. 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 one span of overhead line to the point of interconnection ("POI"), metering, and associated protection equipment. $900,000 $900,000
Network Upgrades
RTEP ID Description Total Cost ($USD) Allocated Cost ($USD)
(Pending) Add one new 500 breaker to the existing Heritage 500 kV Substation. Additional substation modifications may be required. $5,000,000 $5,000,000

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.

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.
 
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.
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 75.0 MW (Capacity 30.0 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential 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 2.05
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 5.55
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 5.55
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 8.84
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 8.4
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 5.72
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 5.72
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 5.4
DVP 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line
314282 to 314285 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 130.03 % 984.18 B 1279.76 3.12
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 5.4
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 9.27
DVP 6POE-6TYLER1 230.0 kV Ckt 1 line
314331 to 314263 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 128.68 % 441.8 B 568.49 1.75
DVP 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line
314285 to 314316 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 127.93 % 984.18 B 1259.02 3.12
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 3.73
DVP 6POE-6TYLER1 230.0 kV Ckt 1 line
314331 to 314263 ckt 1
DVP_P1-2: LN 249_SRT-A
CONTINGENCY 'DVP_P1-2: LN 249_SRT-A'
 OPEN BRANCH FROM BUS 313014 TO BUS 314285 CKT 1   /*6CHAPARRAL   230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314282 TO BUS 314285 CKT 1   /*6CARSON      230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314285 TO BUS 314316 CKT 1   /*6CHAPARRAL T 230.0 - 6LOCKS       230.0
 OPEN BRANCH FROM BUS 314314 TO BUS 314316 CKT 2   /*3LOCKS       115.0 - 6LOCKS       230.0
 OPEN BUS 313014                                   /*6CHAPARRAL   230.0
 OPEN BUS 314285                                   /*6CHAPARRAL T 230.0
END
Single AC 124.47 % 441.8 B 549.92 1.62
DVP 8NO ANNA-AG1-133 TP 500.0 kV Ckt 1 line
314918 to 962840 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 123.36 % 3220.44 B 3972.89 5.14
DVP AE2-313 TP-8CARSON 500.0 kV Ckt 1 line
942930 to 314902 ckt 1
DVP_P1-2: LN 585_SRT-A-1
CONTINGENCY 'DVP_P1-2: LN 585_SRT-A-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 941030 CKT 1   /*8CARSON      500.0 - AE2-094 TP   500.0
END
Single AC 123.28 % 4070.2 B 5017.84 17.58
DVP AG1-133 TP-8LADYSMITH 500.0 kV Ckt 1 line
962840 to 314911 ckt 1
DVP_P1-2: LN 594_SRT-S
CONTINGENCY 'DVP_P1-2: LN 594_SRT-S'
 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1                /*8MORRSVL     500.0 - 8SPOTSYL     500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER     500.0 - 8MORRSVL     500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER     500.0 - 8MORRSVL     500.0
END
Single AC 122.96 % 3220.44 B 3959.72 5.14
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 6.62
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 9.44
DVP 6CARSON-6POE 230.0 kV Ckt 1 line
314282 to 314331 ckt 1
DVP_P1-2: LN 249_SRT-A
CONTINGENCY 'DVP_P1-2: LN 249_SRT-A'
 OPEN BRANCH FROM BUS 313014 TO BUS 314285 CKT 1   /*6CHAPARRAL   230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314282 TO BUS 314285 CKT 1   /*6CARSON      230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314285 TO BUS 314316 CKT 1   /*6CHAPARRAL T 230.0 - 6LOCKS       230.0
 OPEN BRANCH FROM BUS 314314 TO BUS 314316 CKT 2   /*3LOCKS       115.0 - 6LOCKS       230.0
 OPEN BUS 313014                                   /*6CHAPARRAL   230.0
 OPEN BUS 314285                                   /*6CHAPARRAL T 230.0
END
Single AC 119.52 % 678.68 B 811.13 2.02
DVP AE2-094 TP-8CARSON 500.0 kV Ckt 1 line
941030 to 314902 ckt 1
DVP_P1-2: LN 511_SRT-S-A
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-A'
 OPEN BRANCH FROM BUS 314902 TO BUS 942930 CKT 1                /*8CARSON      500.0 - AE2-313 TP   500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
Single AC 119.48 % 4070.2 B 4862.91 17.44
DVP AE2-313 TP-8CARSON 500.0 kV Ckt 1 line
942930 to 314902 ckt 1
DVP_P1-2: LN 585_SRT-A-2
CONTINGENCY 'DVP_P1-2: LN 585_SRT-A-2'
 OPEN BRANCH FROM BUS 314940 TO BUS 941030 CKT 1   /*8ROGERS RD   500.0 - AE2-094 TP   500.0
END
Single AC 118.55 % 4070.2 B 4825.21 17.58
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 2.52
DVP 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line
314936 to 942930 ckt 1
DVP_P1-2: LN 585_SRT-A-1
CONTINGENCY 'DVP_P1-2: LN 585_SRT-A-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 941030 CKT 1   /*8CARSON      500.0 - AE2-094 TP   500.0
END
Single AC 117.44 % 4070.2 B 4780.16 17.58
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 2.53
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 7.13
DVP AE2-094 TP-8CARSON 500.0 kV Ckt 1 line
941030 to 314902 ckt 1
DVP_P1-2: LN 511_SRT-S-C
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-C'
 OPEN BRANCH FROM BUS 942930 TO BUS 314936 CKT 1                /*AE2-313 TP   500.0 - 8RAWLINGS    500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
Single AC 114.48 % 4070.2 B 4659.4 17.44
DVP 8ROGERS RD-AE2-094 TP 500.0 kV Ckt 1 line
314940 to 941030 ckt 1
DVP_P1-2: LN 511_SRT-S-A
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-A'
 OPEN BRANCH FROM BUS 314902 TO BUS 942930 CKT 1                /*8CARSON      500.0 - AE2-313 TP   500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
Single AC 114.29 % 4070.2 B 4651.95 17.44
DVP 6CARSON-6POE 230.0 kV Ckt 1 line
314282 to 314331 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 114.27 % 678.68 B 775.52 2.13
DVP 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line
314936 to 942930 ckt 1
DVP_P1-2: LN 585_SRT-A-2
CONTINGENCY 'DVP_P1-2: LN 585_SRT-A-2'
 OPEN BRANCH FROM BUS 314940 TO BUS 941030 CKT 1   /*8ROGERS RD   500.0 - AE2-094 TP   500.0
END
Single AC 113.04 % 4070.2 B 4600.9 17.58
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 4.28
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 8.44
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 4.28
DVP 8ROGERS RD-AE2-094 TP 500.0 kV Ckt 1 line
314940 to 941030 ckt 1
DVP_P1-2: LN 511_SRT-S-C
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-C'
 OPEN BRANCH FROM BUS 942930 TO BUS 314936 CKT 1                /*AE2-313 TP   500.0 - 8RAWLINGS    500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
Single AC 109.31 % 4070.2 B 4449.12 17.44
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 5.85
DVP 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line
314282 to 314285 ckt 1
DVP_P1-2: LN 2002_SRT-A
CONTINGENCY 'DVP_P1-2: LN 2002_SRT-A'
 OPEN BRANCH FROM BUS 314282 TO BUS 314331 CKT 1   /*6CARSON      230.0 - 6POE         230.0
 OPEN BRANCH FROM BUS 314329 TO BUS 314331 CKT 1   /*3POE         115.0 - 6POE         230.0
END
Single AC 107.23 % 984.18 B 1055.36 2.45
DVP 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line
314285 to 314316 ckt 1
DVP_P1-2: LN 2002_SRT-A
CONTINGENCY 'DVP_P1-2: LN 2002_SRT-A'
 OPEN BRANCH FROM BUS 314282 TO BUS 314331 CKT 1   /*6CARSON      230.0 - 6POE         230.0
 OPEN BRANCH FROM BUS 314329 TO BUS 314331 CKT 1   /*3POE         115.0 - 6POE         230.0
END
Single AC 105.02 % 984.18 B 1033.62 2.45
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 4.36
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 1.89
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 1.89
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 5.36
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 5.46
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 8.28
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 5.23
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 6.64
DVP 6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 165.32 % 812.0 C 1342.36 5.94
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 11.97
DVP 6POE-6TYLER1 230.0 kV Ckt 1 line
314331 to 314263 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 152.41 % 541.0 C 824.56 5.54
DVP 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line
314282 to 314285 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 150.51 % 1204.0 C 1812.13 10.07
DVP 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line
314285 to 314316 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 148.73 % 1204.0 C 1790.76 10.07
DVP 6CARSON-6POE 230.0 kV Ckt 1 line
314282 to 314331 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 127.05 % 830.0 C 1054.55 7.05
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 14.48
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 22.25
DVP 6POE-6TYLER1 230.0 kV Ckt 1 line
314331 to 314263 ckt 1
DVP_P4-5: L722_SRT-A
CONTINGENCY 'DVP_P4-5: L722_SRT-A'
 OPEN BRANCH FROM BUS 313014 TO BUS 314285 CKT 1   /*6CHAPARRAL   230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314282 TO BUS 314285 CKT 1   /*6CARSON      230.0 - 6CHAPARRAL T 230.0
 OPEN BRANCH FROM BUS 314285 TO BUS 314316 CKT 1   /*6CHAPARRAL T 230.0 - 6LOCKS       230.0
 OPEN BRANCH FROM BUS 314302 TO BUS 314314 CKT 1   /*3HARVELL     115.0 - 3LOCKS       115.0
 OPEN BRANCH FROM BUS 314314 TO BUS 314316 CKT 2   /*3LOCKS       115.0 - 6LOCKS       230.0
 OPEN BUS 313014                                   /*6CHAPARRAL   230.0
 OPEN BUS 314285                                   /*6CHAPARRAL T 230.0
END
Breaker AC 120.45 % 541.0 C 651.66 4.18
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 13.42
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 23.15
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 24.69
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 14.83
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 13.42
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 13.88
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 23.27
DVP AE2-313 TP-8CARSON 500.0 kV Ckt 1 line
942930 to 314902 ckt 1
DVP_P4-2: 58572_SRT-A-1
CONTINGENCY 'DVP_P4-2: 58572_SRT-A-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 941030 CKT 1   /*8CARSON      500.0 - AE2-094 TP   500.0
END
Breaker AC 113.22 % 5046.0 C 5712.94 43.94
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 14.3
DVP AE1-173 TP-8SUFFOLK 500.0 kV Ckt 1 line
939410 to 314928 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 111.94 % 3144.0 C 3519.31 20.75
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 13.52
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 13.49
DVP 8CARSON-6CARSON 500.0/230.0 kV Ckt 2 transformer
314902 to 314282 ckt 2
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 110.71 % 1056.8 C 1169.99 10.02
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 13.52
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 13.49
DVP 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line
314936 to 942930 ckt 1
DVP_P4-2: 58572_SRT-A-1
CONTINGENCY 'DVP_P4-2: 58572_SRT-A-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 941030 CKT 1   /*8CARSON      500.0 - AE2-094 TP   500.0
END
Breaker AC 107.55 % 5046.0 C 5427.07 43.94
DVP 8CARSON-6CARSON 500.0/230.0 kV Ckt 1 transformer
314902 to 314282 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 100.4 % 1039.5 C 1043.67 9.35
DVP 6TYLER-6CHESTF B 230.0 kV Ckt 1 line
314346 to 314287 ckt 1
DVP_P4-2: 562T563_SRT-S
CONTINGENCY 'DVP_P4-2: 562T563_SRT-S'
 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 2858 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314923 TO BUS 314927 CKT 1 /*8SEPTA       500.0 - 8YADKIN      500.0
END
Breaker AC 100.11 % 1204.0 C 1205.29 7.74

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 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 9.32
DVP AE2-094 TP-8CARSON 500.0 kV Ckt 1 line
941030 to 314902 ckt 1
DVP_P1-2: LN 511_SRT-S-A
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-A'
 OPEN BRANCH FROM BUS 314902 TO BUS 942930 CKT 1                /*8CARSON      500.0 - AE2-313 TP   500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
OP AC 134.73 % 4070.2 B 5483.68 43.59
DVP 8ROGERS RD-AE2-094 TP 500.0 kV Ckt 1 line
314940 to 941030 ckt 1
DVP_P1-2: LN 511_SRT-S-A
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-A'
 OPEN BRANCH FROM BUS 314902 TO BUS 942930 CKT 1                /*8CARSON      500.0 - AE2-313 TP   500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
OP AC 127.99 % 4070.2 B 5209.33 43.59
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 16.6
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 20.7
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
OP AC 113.53 % 984.18 B 1117.37 4.72
DVP 6VARINA-6CHARCTY 230.0 kV Ckt 1 line
314260 to 314225 ckt 1
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1                /*8CARSON      500.0 - 8MDLTHAN     500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA       500.0 - AE2-051 TP   500.0
 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TP   500.0
 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TP   500.0
 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA       500.0 - AE2-051 TP   500.0
END
OP AC 113.5 % 984.18 B 1117.01 4.72
DVP 8HERITAGE-8ROGERS RD 500.0 kV Ckt 1 line
314935 to 314940 ckt 1
DVP_P1-2: LN 511_SRT-S-A
CONTINGENCY 'DVP_P1-2: LN 511_SRT-S-A'
 OPEN BRANCH FROM BUS 314902 TO BUS 942930 CKT 1                /*8CARSON      500.0 - AE2-313 TP   500.0
 SET POSTCONTRATING 3811 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
 SET PRECONTRATING 3533 BRANCH FROM BUS 314935 TO BUS 314936 CKT 1 /*8HERITAGE    500.0 - 8RAWLINGS    500.0
END
OP AC 113.28 % 3256.16 B 3688.69 44.25
DVP 6CHARCTY-6LAKESIDE 230.0 kV Ckt 1 line
314225 to 314227 ckt 1
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1'
 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1                /*8CARSON      500.0 - 8MDLTHAN     500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA       500.0 - AE2-051 TP   500.0
 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TP   500.0
 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TP   500.0
 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA       500.0 - AE2-051 TP   500.0
END
OP AC 109.9 % 984.18 B 1081.63 4.72
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 2 transformer
314218 to 314908 ckt 2
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A'
 OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1   /*8MDLTHAN     500.0 - 8NO ANNA     500.0
END
OP AC 109.55 % 879.84 B 963.87 5.36
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 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 108.78 % 888.3 B 966.27 5.37
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 10.91
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 18.09
AEP 05EDAN 1-05DANVL2 138.0 kV Ckt 1 line
242631 to 242620 ckt 1
AEP_P1-3_#1377_05J.FERR 765_1_SRT-A
CONTINGENCY 'AEP_P1-3_#1377_05J.FERR 765_1_SRT-A'
 OPEN BRANCH FROM BUS 242514 TO BUS 290022 CKT 1   /*05J.FERR     765.0 - 05J.FERR 1EQ 999.0
 OPEN BRANCH FROM BUS 242520 TO BUS 290022 CKT 1   /*05J.FERR     500.0 - 05J.FERR 1EQ 999.0
 OPEN BRANCH FROM BUS 242520 TO BUS 306719 CKT 1   /*05J.FERR     500.0 - 8ANTIOCH     500.0
 OPEN BRANCH FROM BUS 290022 TO BUS 290023 CKT 1   /*05J.FERR 1EQ 999.0 - 05J.FERR T1   13.8
END
OP AC 101.64 % 415.0 B 421.79 3.77

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 75.0 MW (Capacity 30.0 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential light load period network impacts were as follows:

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 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 4.57
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 5.33
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 4.57
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 5.33
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 4.79
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 4.05
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 4.79
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 4.05
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 5.02
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 4.79
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 4.05
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 4.79
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 4.05
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 16.22
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 3.78
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 4.48
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 4.48
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 4.07
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 4.79
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 4.07
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 4.79
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 4.07
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 4.79
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 4.07
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 4.79
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 5.82
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 11.68

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 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 16.22

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
AB1-081 Anaconda-Mayo Dunbar 115kV 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
AB2-040 Brink 115kV Under Construction
AB2-043 Chase City 115kV In Service
AB2-059 Benson-Dunbar 115kV In Service
AB2-060 Chase City-Lunenburg 115kV In Service
AB2-077 Buggs Island-Chase City 115kV 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
AC1-042 Altavista-Mt. Airy 69kV 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
AC1-075 Perth-Hickory Grove 115kV In Service
AC1-076 Locust Grove-Paytes 115kV Under Construction
AC1-080 Perth-Hickory Grove 115kV In Service
AC1-083 Smith Mountain-Bearskin 138kV In Service
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
AC1-120 Mitchell-Mountain Run 115kV Suspended
AC1-121 Mitchell-Mountain Run 115kV Suspended
AC1-145 Gretna DP 69 kV In Service
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
AC2-141 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
AD1-056 Hornertown-Hathaway 230 kV Engineering & Procurement
AD1-057 Hornertown-Hathaway 230 kV Engineering & Procurement
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
AD2-033 Chase City-Lunenburg 115 kV Suspended
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
AE1-056 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
AE1-157 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
AE1-250 Smith Mountain-E. Danville 138 kV Engineering & Procurement
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
AE2-047 Ridgeway-Solite 69 kV Engineering & Procurement
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
AE2-185 Gladys DP-Stonemill Switching Station 69 kV Active
AE2-187 Shockoe DP-Chatham 69 kV Active
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
AE2-283 Gladys-Stone Mill 69 kV Active
AE2-291 Grit DP-Perth 115 kV Active
AE2-292 Grit DP-Perth 115 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
AF1-049 Berry Hill 138 kV Active
AF1-058 Welco 34.5 kV In Service
AF1-069 Carson-Rogers Rd 500 kV Active
AF1-082 Heartsease-Mayo Dunbar DP Withdrawn
AF1-123 Oceana 230 kV Active
AF1-124 Oceana 230 kV Active
AF1-125 Oceana 230 kV Active
AF1-128 Chesterfield 230 kV Active
AF1-129 Chesterfield 230 kV Active
AF1-152 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
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
AF2-110 Suffolk 115 kV Engineering & Procurement
AF2-115 Jetersville-Ponton 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
AF2-324 Edgecombe 230 kV Active
AF2-397 Fork Union-Mt. Eagle 230 kV Active
AF2-403 Shockoe DP-Chatham 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
AG1-030 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
AG1-154 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
AG1-285 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
AG1-539 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:

AG1-153 System Reinforcements Cost Breakdown:
TO RTEP ID / TO ID Title MW Impact Percent Allocation Allocated Cost ($USD)
Dominion (Pending) / TC1-PH1-DOM-052 Wreck and rebuild 9.02 miles of 230kV line 2003 between Poe and Tyler / additional station upgrades 5.5 MW 3.2% $834,355
Dominion (Pending) / TC1-PH1-DOM-087 Addition of 230/500 kV Transformer at Carson Substation. 12.0 MW 1.5% $594,153
Grand Total: $1,428,508
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-052 Wreck and rebuild 9.02 miles of 230kV line 2003 between Poe and Tyler / additional station upgrades $25,932,500 $834,355 42 to 48 Months

Contributor

Description: Wreck and rebuild 9.02 miles of 230kV line 2003 between Poe and Tyler with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. Replace Circuit Breaker at Poe.

Flowgates Addressed by this Reinforcement
Facility Contingency
6TYLER1-6POE 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6TYLER1-6POE 230.0 kV Ckt 1 line (All) A 813.0 MVA
6TYLER1-6POE 230.0 kV Ckt 1 line (All) B 877.0 MVA
6TYLER1-6POE 230.0 kV Ckt 1 line (All) C 965.0 MVA
Cost Allocation
Project MW Impact Percent Allocation Allocated Cost ($USD)
AE2-313 24.0 MW 13.9% $3,614,683
AF1-266 8.2 MW 4.8% $1,234,429
AF2-042 32.3 MW 18.8% $4,865,235
AF2-046 8.1 MW 4.7% $1,221,620
AG1-008 8.1 MW 4.7% $1,221,620
AG1-153 5.5 MW 3.2% $834,355
AG1-160 5.6 MW 3.3% $847,012
AG1-178 23.6 MW 13.7% $3,558,326
AG1-184 12.7 MW 7.4% $1,917,042
AG1-439 12.9 MW 7.5% $1,944,467
AG1-449 9.3 MW 5.4% $1,404,404
AG1-505 10.8 MW 6.3% $1,634,654
AG1-506 10.8 MW 6.3% $1,634,654
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-087 Addition of 230/500 kV Transformer at Carson Substation. $40,000,000 $594,153 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 (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 $0 36 to 40 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 30 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-033 Replace Wave Trap at Carson f $200,000 $0 16 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Wave Trap at Carson to increase rating of Carson to Chaprral Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) A 877.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) B 957.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) C 1164.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-034 Replace Circuit Breaker Switch at Carson and Line Switch at Chaparral $825,000 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Circuit Breaker Switch at Carson and Line Switch at Chaparral to increase the rating of Carson to Chaprral Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) A 1047.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) B 1047.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) C 1204.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-035 Replace Circuit Breaker at Carson $1,500,000 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Circuit Breaker at Carson to increase the rating of Carson to Chaprral Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) A 1572.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) B 1572.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) C 1818.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion b3694.8 / dom-298 Partial wreck and rebuild 10.34 miles of 230 kV line #249 Carson-Locks to achieve a minimum summer emergency rating of 1047 MVA. $15,365,000 $0 Jun 30 2025

Not Contingent

Note: AG1-153 contributes to the loading of an overloaded facility that is being mitigated by a planned baseline upgrade. AG1-153 is not contingent on this baseline upgrade as it does not meet the criteria for being a contingent facility or for having cost allocation for the upgrade.

Description: Partial wreck and rebuild 10.34 miles of 230 kV line #249 Carson-Locks to achieve a minimum summer emergency rating of 1047 MVA. Upgrade terminal equipment at Carson and Locks to not limit the new conductor rating.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6CHRL249 230.0 kV Ckt 1 line (Any)
6CHRL249-6LOCKS 230.0 kV Ckt 1 line (Any)
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (Any)
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) A 797.0 MVA
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) B 797.0 MVA
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) C 1116.0 MVA
6CHRL249-6LOCKS 230.0 kV Ckt 1 line (All) A 797.0 MVA
6CHRL249-6LOCKS 230.0 kV Ckt 1 line (All) B 797.0 MVA
6CHRL249-6LOCKS 230.0 kV Ckt 1 line (All) C 1116.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) A 797.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) B 797.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) C 1116.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 797.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 797.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1116.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n7610 / dom-435 Rebuild Line 230 kV Line #249 from Carson to Chaparral $44,092,500 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Rebuild 7.49 miles of 230 kV Line 249 from Carson to Chaparral with 2-768.2 ACSS 250C. Replace wave trap, circuit breaker switch, and Line Lead at Carson terminal and Line Switch at Chaparral terminal.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6CHRL249 230.0 kV Ckt 1 line (Any)
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) A 1168.0 MVA
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6CARSON-6CHRL249 230.0 kV Ckt 1 line (All) C 1349.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) A 1168.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line (All) C 1349.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n6581 / dom-120 Rebuild 12.68 miles of 230 kV Line 2002 from Carson to Poe with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor at 250 degrees C. $36,455,000 $0 36 to 40 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CARSON-6POE 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CARSON-6POE 230.0 kV Ckt 1 line (All) A 1047.0 MVA
6CARSON-6POE 230.0 kV Ckt 1 line (All) B 1047.0 MVA
6CARSON-6POE 230.0 kV Ckt 1 line (All) C 1204.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-037 Replace Wave Trap at Locks $200,000 $0 16 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Wave Trap at Locks to increase rating of the line Chaparral to Locks Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 877.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 957.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1164.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-038 Replace Line Switch at Chaparral and Circuit Breaker Switch at Locks $825,000 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Line Switch at Chaparral and Circuit Breaker Switch at Locks to increase the rating of Chaparral to Locks Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 1047.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 1047.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1204.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-036 Wreck and rebuild 2.86 miles of 230 kV line between Locks and Chaparal $8,222,500 $0 36 to 42 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Wreck and rebuild 2.86 miles of 230 kV line between Locks and Chaparal with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 957.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 1052.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1339.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-039 Replace CT Relay at Locks $150,000 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace CT Relay at Locks. to increase the rating of Chaparral to Locks Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 1168.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1349.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-040 Replace Circuit Breaker at Locks $1,500,000 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Circuit Breaker at Locks to increase the rating of Chaparral to Locks Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 1435.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 1435.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1435.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-041 Replace SEC Relay at Locks $150,000 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace SEC Relay at Locks to increase rating of Chaparral to Locks Line.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) A 1572.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) B 1572.0 MVA
6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line (All) C 1818.0 MVA
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 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 36 to 40 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-058 Replace the Circuit Breaker at Chesterfield for increased rating on Line 2003 6TYLER 230 KV to 6CHESTF B 230 KV ckt 1 $1,500,000 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace the Circuit Breaker at Chesterfield.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) A 877.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) B 957.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) C 1164.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-059 Replace Circuit Breaker Switch at Chesterfield for increased rating on Line 2003 6TYLER 230 KV to 6CHESTF B 230 KV ckt 1 $550,000 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Replace Circuit Breaker Switch at Chesterfield.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) A 1047.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) B 1047.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) C 1204.0 MVA
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-060 Wreck and rebuild 2.58 miles of 230 kV line between Tyler and Chesterfield $7,417,500 $0 36 to 42 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Wreck and rebuild 2.58 miles of 230 kV line between Tyler and Chesterfield with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @ 250 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) A 1168.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) B 1292.0 MVA
6CHESTF B-6TYLER 230.0 kV Ckt 1 line (All) C 1349.0 MVA
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 $0 36 to 40 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 42 to 44 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 30 to 36 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 36 to 42 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 42 to 44 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion (Pending) / TC1-PH1-DOM-070 Wreck and rebuild the 16.52 miles of 511 Line and build a second circuit between Rawlings and Carson Line 511 $94,164,000 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Wreck and rebuild the 16.52 miles of 511 Line and build a second circuit between Rawlings and Carson Line 511 with (3) 1351.1 ACSR (45/7) "DIPPER" conductor at 110 degrees C.

Flowgates Addressed by this Reinforcement
Facility Contingency
8CARSON-AE2-313 TP 500.0 kV Ckt 1 line (Any)
8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line (Any)
8CARSON-AE2-094 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 511_SRT-S-A
8CARSON-AE2-094 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 511_SRT-S-C
8ROGERS RD-AE2-094 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 511_SRT-S-A
8ROGERS RD-AE2-094 TP 500.0 kV Ckt 1 line DVP_P1-2: LN 511_SRT-S-C
New Ratings
Facility Rating Set Rating Type Rating Value
8CARSON-AE2-313 TP 500.0 kV Ckt 1 line (All) A 4356.0 MVA
8CARSON-AE2-313 TP 500.0 kV Ckt 1 line (All) B 4356.0 MVA
8CARSON-AE2-313 TP 500.0 kV Ckt 1 line (All) C 5009.0 MVA
8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line (All) A 4295.0 MVA
8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line (All) B 4357.0 MVA
8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line (All) C 4996.0 MVA
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 $0 16 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 42 to 48 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 12 to 18 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 48 to 60 Months

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
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 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool 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
System Reinforcement
TO RTEP ID / TO ID Title Total Cost ($USD) Allocated Cost ($USD) Time Estimate
Dominion n8425 / dom-509 Rebuild 35.68 miles of 500 kV Line 544 from AE1-173 Tap to Suffolk with 3-1351.5 ACSR 110 C. $203,376,000 $0 Dec 01 2024

Potential Aggregate Contributor

Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.

Description: Rebuild 35.68 miles of 500 kV Line 544 from AE1-173 Tap to Suffolk with 3-1351.5 ACSR 110 C.

Flowgates Addressed by this Reinforcement
Facility Contingency
8SUFFOLK-AE1-173_POI 500.0 kV Ckt 1 line (Any)
8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line (Any)
New Ratings
Facility Rating Set Rating Type Rating Value
8SUFFOLK-AE1-173_POI 500.0 kV Ckt 1 line (All) A 3463.0 MVA
8SUFFOLK-AE1-173_POI 500.0 kV Ckt 1 line (All) B 3464.0 MVA
8SUFFOLK-AE1-173_POI 500.0 kV Ckt 1 line (All) C 4850.0 MVA
8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line (All) A 3463.0 MVA
8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line (All) B 3464.0 MVA
8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line (All) C 4850.0 MVA

Attachments


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