AG1-153 Phase II Study Report
v1.00 released 2024-12-18 14:08
Heritage 500 kV
30.0 MW Capacity / 75.0 MW Energy
Introduction
This Phase II System Impact Study Report (PH2) has been prepared in accordance with the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 310 for New Service Requests (projects) in Transition Cycle #1. The Project Developer/Eligible Customer (developer) is Virginia Electric and Power Company, and the Transmission Provider (TP) is PJM Interconnection, LLC (PJM). The interconnected Transmission Owner (TO) is Virginia Electric and Power Company.
Preface
The Phase II System Impact Study is conducted on an aggregate basis within a New Services Request’s Cycle, and results are provided in both (i) a single Cycle executive summary format and (ii) an individual project-level basis. The Phase II System Impact Study Results (for both the executive summary and individual reports) will be publicly available on PJM’s website. Developers must obtain the results from the website.
In accordance with PJM Manual 14H, section 4.5, PJM takes the following actions during the Phase II System Impact Study:
- PJM will retool load flow results from Phase I System Impact Study (summer peak, winter peak[1] and light load) based on decisions made by Project Developers or Eligible Customers during Decision Point I.
- PJM will conduct any required voltage analyses.
- PJM will perform short circuit and stability analyses as required.
- PJM will coordinate with the Affected System to confirm which projects in PJM Cycle will require Affected System studies. If the Affected System Operator indicates that an Affected System study is required, PJM will:
- Notify the Project Developer or Eligible Customer of the need for an Affected System study and the requirement to execute an Affected System study agreement with the impacted Affected System Operator, and;
- Include the results of the Affected System Operator’s Affected System Study in the Phase II System Impact Study results, if applicable and available
- The Phase II System Impact Study Results will be publicly available on PJM’s website. Project Developers and Eligible Customers must obtain the results from the website.
The Transmission Owner takes the following actions during the Phase II System Impact Study:
- Verify Interconnection Facilities and Network Upgrades required to accommodate the New Service Request.
- Perform a Facilities Study. The Facilities Study in Phase II System Impact Study phase will be for the physical Interconnection Facilities. The Facilities Study requirements are outlined in Attachment C of PJM Manual 14H. The study will be conducted pursuant to Tariff, Part VII, Subpart D, section 307(A)(7).
Decision Point II Requirements
At the close of Phase II System Impact Study, PJM will initiate Decision Point II (DP2). During DP2, the Project Developer will have 30 days to decide whether to proceed with their project. If the Project Developer elects to proceed, they should provide the elements defined in the PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.A. Additional information on these elements is available in PJM Manual 14H sections 4.6, 6, and 7.
Allowable project modifications at Decision Point II are defined in PJM Open Access Transmission Tariff, Part VII, Subpart D, section 311.B. Additional information regarding allowable project modifications can be found in PJM Manual 14H, section 9.8.
Adverse Test Eligibility
This New Service Request does not meet the Adverse Study Impact Criteria and has the option to either move forward in the Cycle process or withdraw at DP2 with Readiness Deposit #1 forfeited. See adverse study impact calculation below.
This section details whether a Project Developer or Eligible Customer qualifies for the Adverse Study Impact clause outlined in the PJM OATT, Part VII, Subpart D, section 311.B and Manual 14H, section 6.2.2. In order to qualify for an Adverse Study Impact at Decision Point II, the Network Upgrade cost from Phase I to Phase II must:
- Increase overall by 25% or more
- Increases by more than $10,000 per MW (Includes Costs identified in Affected System studies)
If a New Service Request meets the criteria above and chooses to withdraw the request, PJM will refund the cumulative Readiness Deposit amounts paid at the Application Phase and at Decision Point I (RD1 and RD2, respectively).
The below calculations show the computation of this New Service Request's Adverse Study Impact
General
The Project Developer has proposed a 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 |
| Project Developer Name | Virginia Electric and 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 |
| Battery Storage Specification | 300.0 MWh, 4.0-hour class |
| Grid Charging | Yes |
| Fuel Type | Storage |
| Basecase Study Year | 2027 |
Physical Interconnection Facility Study
The transmission owner has completed the Physical Interconnection Facilities Study. This report is available for download.
Point of Interconnection
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 cost estimates for this New Service Request project. In Phase II SIS, the interconnected Transmission Owner has performed a facilities study for both the Transmission Owner Interconnection Facilities (TOIF) and Physical Interconnection Network Upgrades. The System Reliability Network Upgrade shown in the table are planning level cost estimates which are subject to change as a result of a facility study performed by the TO during Phase III System Impact Study.
Based on the Phase II SIS results, the AG1-153 project has the following allocation of costs for interconnection. The cost contribution towards Readiness Deposit #3 are also shown below.
| Cost Summary | |||
|---|---|---|---|
| Description | Cost Allocated to AG1-153 | Cost Subject to Readiness* | |
| Transmission Owner Interconnection Facilities (TOIF) | $4,822,863 | $0 | |
| Other Scope | $0 | $0 | |
| Physical Interconnection Network Upgrades | |||
| Stand Alone Network Upgrades | $0 | $0 | |
| Network Upgrades | $1,958,524 | $1,958,524 | |
| System Reliability Network Upgrades | |||
| Steady State Thermal & Voltage (SP & LL) | $2,404,347 | $2,404,347 | |
| Transient Stability | $0 | $0 | |
| Short Circuit | $0 | $0 | |
| Transmission Owner Analysis | |||
| SubRegional | $0 | $0 | |
| Distribution | $0 | $0 | |
| Affected System Study Reinforcements | $0 | $0 | |
| Total | $9,185,734 | $4,362,871 | |
* Contributes to calculation for Readiness Deposit #3 (RD3). See Readiness Deposit section of report for additional detail.
Definitions
Transmission Owner Interconnection Facilities: Facilities that are owned, controlled, operated and maintained by the Transmission Owner on the Transmission Owner’s side of the Point of Change of Ownership to the Point of Interconnection, including any modifications, additions or upgrades made to such facilities and equipment, that are necessary to physically and electrically interconnect the Generating Facility with the Transmission System or interconnected distribution facilities.
Stand Alone Network Upgrades: Network Upgrades, which are not part of an Affected System, which a Project Developer may construct without affecting day-to-day operations (e.g. taking a transmission outage) of the Transmission System during their construction.
Network Upgrades: Modifications or additions to transmission-related facilities that are integrated with and support the Transmission Provider’s overall Transmission System for the general benefit of all users of such Transmission System. Network Upgrades have no impact or potential impact on the Transmission System until the final tie-in is complete.
Notes
Note 1: PJM Open Access Transmission Tariff (OATT), Part VII, Subpart D, section 307.5 outlines cost allocation rules. The rules are further clarified in PJM Manual 14H, section 4.2.6. PJM shall identify the New Service Requests in the Cycle contributing to the need for the required Network Upgrades within the Cycle. All New Service Requests that contribute to the need for a Network Upgrade will receive cost allocation for that upgrade pursuant to each New Service Request’s contribution to the reliability violation identified on the transmission system in accordance with PJM Manuals.
Note 2: There will be no inter-Cycle cost allocation for Interconnection Facilities or Network Upgrades identified in the System Impact Study costs identified in a Cycle; all such costs shall be allocated to New Service Requests in that Cycle.
Note 3: For Project Developers with System Reinforcements listed: If this project presents cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as other projects withdrawing, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to this project. In addition, although this project presents cost allocation to a System Reinforcement is presently $0, this project may need this system reinforcement completed to be deliverable to the PJM system. If this project desires to come into service prior to completion of the system reinforcement, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the system reinforcement is complete.
Note 4: Please see the ‘Affected Systems Studies’ section of this Phase 2 SIS report for details on your project’s need for an Affected Systems Study. If your project requires an Affected Systems Study, the Affected Systems impacts may not be available from the Affected System Operator at the time of the PJM Phase II SIS. Therefore, the cost in this section would not reflect any required upgrades by the Affected System until the study is completed. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
Readiness Deposit
Per Tariff Part VII, Subpart D, section 311 (Decision Point II) A.1.b and PJM Manual 14H, section 6.2, Readiness Deposit #3 (RD3) are funds committed by the Project Developer or Eligible Customer based upon the applicable contribution to Network Upgrades as defined below. Readiness Deposits are not used to fund studies nor to offset Security.
During Decision Point II (DP2), the Project Developer or Eligible Customer is required to submit Readiness Deposit #3, which is calculated as 20% of cost allocation for required Phase II Network Upgrades minus Readiness Deposit #1 & Readiness Deposit #2.
Note 1: “Network Upgrades” referred to in the calculation include both (i) the Physical Interconnection Network Upgrades and (ii) the System Reliability Network Upgrades as shown in the Cost Summary table.
Note 2: Readiness Deposit #1 (RD1) = ($4,000 * Project Size (MW))
Note 3: Readiness Deposit #2 (RD2) = 10% of cost allocation for required Network Upgrades minus RD1. Readiness Deposit #2 (RD2) can be zero, but may not be a negative number.
Note 4: Readiness Deposit #3 can be zero, but may not be a negative number.
Readiness Deposit #3 Due for Project AG1-153
Readiness Deposit #3 has been calculated for the AG1-153 project based on the Phase II System Impact Study results and is shown in the table below. This Readiness Deposit #3 must be provided at Decision Point II through either a wire transfer or letter of credit per Manual 14H, Section 6.2.
| Readiness Deposit | |||
|---|---|---|---|
| Project ID | 20% of cost allocation for Phase II Network Upgrades | Sum of Readiness Deposit #1 & Readiness Deposit #2 Received (RD1+RD2) | Readiness Deposit #3 (RD3) for AG1-153 Project due at DP2 |
| A | B | A - B | |
| AG1-153 | $872,574 | $642,851 | $229,723 |
Note: Failure to provide an acceptable form of Readiness Deposit #3 by the end of Decision Point II will result in withdrawal and termination of the New Service Request.
For additional detail regarding Readiness Deposit Refunds, reference PJM Manual 14H, section 6.2.1. The Readiness Deposit Letter of Credit template can be found here.
Transmission Owner Scope of Work
The New Service Request Project will interconnect with the Dominion transmission system via a direct connect to the Heritage 500 kV Sub. The required work for the interconnection of the New Service Request Project to the Dominion Transmission System is detailed in the following tables.
The total preliminary cost estimate for the Transmission Owner scope of work (including TOIF and Physical Interconnection Network Upgrades) is given in the table below. These costs do not include CIAC Tax Gross-up.
Transmission Owner Build Option
| Network Upgrades | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) |
Expansion of Existing Heritage 500 kV Substation |
$875,457 | $738,668 | $270,404 | $73,995 | $1,958,524 | $1,958,524 |
| Transmission Owner Interconnection Facilities | |||||||
|---|---|---|---|---|---|---|---|
| RTEP ID | Description | Direct | Indirect | Total Cost ($USD) | Allocated Cost ($USD) | ||
| Labor | Materials | Labor | Materials | ||||
| (Pending) |
Transmission Owner Interconnection Facilities |
$3,362,312 | $838,141 | $553,656 | $68,754 | $4,822,863 | $4,822,863 |
Developer Build Option
Project Developer has the option ("Option to Build") to assume responsibility for the design, procurement and construction of Transmission Owner Interconnection Facilities and/or Stand-Alone Network Upgrades.
If Option to Build is elected, the Project Developer must fulfill additional requirements in accordance to PJM Manual 14C, section 5.1 and PJM Manual 14H, section 8.6.2.
The cost estimates for eligible facilities and Option to Build oversight are highlighted below:
(No Developer Build Option for this project.)
| Build Option Price Comparison | |||||||
|---|---|---|---|---|---|---|---|
| Build Option | Total Cost | Allocated Cost | |||||
| Transmission Owner Build Option | $6,781,387 | $6,781,387 | |||||
| Developer Build Option | (No Developer Build Option) | ||||||
Based on the scope of work for the Interconnection Facilities, it is expected to take 62 month(s) after the signing of a Generator Interconnection Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.
The schedule for any required Network Impact Reinforcements will be more clearly identified in the Phase II and Phase III System Impact Studies.
Transmission Owner Analysis
PJM performed a power flow analysis of the transmission system using a 2027 load flow model and the results were verified by Dominion.
Developer Requirements
The developer is responsible for all design and construction related activities on the developer’s side of the Point of Change in Ownership. Dominion interconnection requirements can be found here. Refer to AG1-153 Physical Interconnection Facilities Study for additional requirements found in the General Section of the report.
To the extent that these Applicable Technical Requirements and Standards may conflict with the terms and conditions of the Tariff, the Tariff shall control.
Revenue Metering and SCADA Requirements
The developer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for their generating Resource. See PJM Manual 01, PJM Manual 14D, and PJM Tariff Part IX, Subpart B, Appendix 2, section 8.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 and in the Physical Interconnection Facilities Study.
Summer Peak Analysis
The New Service Request was evaluated as a 75.0 MW (30.0 MW Capacity) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential summer peak period network impacts were as follows:
Note: The capacity portion of Generation Interconnection Requests are evaluated for single or N-1 contingencies. The full energy output of Generation Interconnection Requests are evaluated for multiple facility contingencies (double circuit tower line, fault with a stuck breaker, and bus fault).
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Summer Peak Analysis - Eliminated Flowgates | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P4-2: 568T575_SRT-A
CONTINGENCY 'DVP_P4-2: 568T575_SRT-A' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.64 | 3940.0 | C | 4556.09 | 14.83 | ||
| 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 | 100.59 | 3144.0 | C | 3162.54 | 20.75 | ||
| DVP |
8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 105.86 | 3220.44 | B | 3409.14 | 4.28 | ||
| 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 | 154.9 | 812.0 | C | 1257.8 | 5.94 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 130.64 | 3220.44 | B | 4207.12 | 5.7 | ||
| 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 | 110.33 | 4070.2 | B | 4490.83 | 17.57 | ||
| 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 | 106.47 | 4070.2 | B | 4333.62 | 17.43 | ||
| 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 | 114.58 | 4070.2 | B | 4663.68 | 17.57 | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P1-2: LN 581_SRT-S
CONTINGENCY 'DVP_P1-2: LN 581_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 2 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 126.76 | 3220.44 | B | 4082.33 | 5.91 | ||
| 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 | 134.78 | 1204.0 | C | 1622.78 | 10.07 | ||
| 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 | 109.86 | 4070.2 | B | 4471.55 | 17.57 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P4-2: 557T574_SRT-S
CONTINGENCY 'DVP_P4-2: 557T574_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 126.3 | 3940.0 | C | 4976.42 | 23.12 | ||
| 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 | 111.55 | 4070.2 | B | 4540.37 | 17.43 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 122.75 | 4070.2 | B | 4996.17 | 8.39 | ||
| DVP |
8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer
314914 to 314322 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 112.19 | 1058.16 | B | 1187.18 | 3.73 | ||
| 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 | 114.28 | 984.18 | B | 1124.74 | 3.12 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P1-2: LN 552_SRT-S
CONTINGENCY 'DVP_P1-2: LN 552_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 130.95 | 3220.44 | B | 4217.23 | 5.79 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P4-2: H1T594_SRT-S
CONTINGENCY 'DVP_P4-2: H1T594_SRT-S' OPEN BRANCH FROM BUS 314063 TO BUS 314916 CKT 1 /*6MORRSVL 230.0 - 8MORRSVL 500.0 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 OPEN BUS 314897 /*8MORRS_1 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314916 TO BUS 314929 CKT 1 /*8MORRSVL 500.0 - 8FRONT ROYAL 500.0 END |
Breaker | AC | 113.7 | 3940.0 | C | 4479.66 | 12.89 | ||
| DVP |
6BUCKING-6BREMO 230.0 kV Ckt 1 line
314677 to 314747 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 108.17 | 571.52 | B | 618.23 | 1.83 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P1-2: LN 594_SRT-S
CONTINGENCY 'DVP_P1-2: LN 594_SRT-S' OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 119.79 | 3220.44 | B | 3857.63 | 5.14 | ||
| 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 | 116.35 | 984.18 | B | 1145.12 | 3.12 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1-2: LN 557_SRT-S
CONTINGENCY 'DVP_P1-2: LN 557_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 106.97 | 3220.44 | B | 3444.92 | 8.43 | ||
| DVP |
8CARSON-6CARSON 500.0/230.0 kV Ckt 2 transformer
314902 to 314282 ckt 2 |
DVP_P4-2: 56372_SRT-S
CONTINGENCY 'DVP_P4-2: 56372_SRT-S' OPEN BRANCH FROM BUS 314282 TO BUS 314902 CKT 1 /*6CARSON 230.0 - 8CARSON 500.0 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 132.78 | 1056.8 | C | 1403.21 | 11.97 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P4-2: H2T574_SRT-S
CONTINGENCY 'DVP_P4-2: H2T574_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 2 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 123.28 | 3940.0 | C | 4857.22 | 22.23 | ||
| DVP |
8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line
314918 to 314934 ckt 1 |
DVP_P1-2: LN 575_SRT-S
CONTINGENCY 'DVP_P1-2: LN 575_SRT-S' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Single | AC | 128.15 | 3220.44 | B | 4127.12 | 5.72 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
Single | AC | 104.94 | 3220.44 | B | 3379.63 | 9.38 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P4-2: SPOTS H1T594_SRT-S
CONTINGENCY 'DVP_P4-2: SPOTS H1T594_SRT-S' OPEN BRANCH FROM BUS 314755 TO BUS 314934 CKT 1 /*3SPOTSYL 115.0 - 8SPOTSYL 500.0 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1 /*8MORRSVL 500.0 - 8SPOTSYL 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Breaker | AC | 116.8 | 3940.0 | C | 4602.03 | 13.42 | ||
| 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 | 107.46 | 4070.2 | B | 4374.02 | 17.43 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P4-2: 563T576_SRT-S
CONTINGENCY 'DVP_P4-2: 563T576_SRT-S' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 111.33 | 3144.0 | C | 3500.17 | 16.91 | ||
| 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 | 109.26 | 830.0 | C | 906.85 | 7.04 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P4-2: H1T575_SRT-S
CONTINGENCY 'DVP_P4-2: H1T575_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 1 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.3 | 3940.0 | C | 4542.79 | 13.88 | ||
| DVP |
8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1 |
DVP_P1-2: LN 552_SRT-S
CONTINGENCY 'DVP_P1-2: LN 552_SRT-S' OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1 /*3CHANCE 115.0 - 8CHANCE 500.0 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1 /*8BRISTER 500.0 - 8CHANCE 500.0 SET POSTCONTRATING 2831 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 SET PRECONTRATING 2552 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314900 TO BUS 314916 CKT 1 /*8BRISTER 500.0 - 8MORRSVL 500.0 END |
Single | AC | 104.85 | 3220.44 | B | 3376.72 | 4.27 | ||
| DVP |
8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line
314908 to 314911 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 108.51 | 4070.2 | B | 4416.63 | 7.12 | ||
| DVP |
8NO ANNA-8LADYSMITH 500.0 kV Ckt 1 line
314918 to 314911 ckt 1 |
DVP_P1-2: LN 573_SRT-A
CONTINGENCY 'DVP_P1-2: LN 573_SRT-A' OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1 /*8NO ANNA 500.0 - 8SPOTSYL 500.0 END |
Single | AC | 122.44 | 3220.44 | B | 3943.26 | 5.4 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 102.87 | 2442.12 | B | 2512.29 | 6.62 | ||
| 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 | 105.58 | 4070.2 | B | 4297.21 | 17.57 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1-2: LN 574_SRT-S
CONTINGENCY 'DVP_P1-2: LN 574_SRT-S' OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 130.89 | 3220.44 | B | 4215.14 | 8.83 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1-2: LN 574_SRT-S
CONTINGENCY 'DVP_P1-2: LN 574_SRT-S' OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Single | AC | 113.49 | 3220.44 | B | 3654.86 | 9.27 | ||
| 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 | 102.52 | 4070.2 | B | 4172.82 | 17.43 | ||
| DVP |
6FARMVIL-6BUCKING 230.0 kV Ckt 1 line
314692 to 314677 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 | 109.07 | 559.3 | B | 610.01 | 1.84 | ||
| DVP |
8SURRY-8CHCKAHM 500.0 kV Ckt 1 line
314924 to 314903 ckt 1 |
DVP_P4-2: 56372_SRT-S
CONTINGENCY 'DVP_P4-2: 56372_SRT-S' OPEN BRANCH FROM BUS 314282 TO BUS 314902 CKT 1 /*6CARSON 230.0 - 8CARSON 500.0 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 END |
Breaker | AC | 111.53 | 3144.0 | C | 3506.36 | 17.25 | ||
| 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 | 125.19 | 541.0 | C | 677.28 | 5.53 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P4-2: H2T574_SRT-S
CONTINGENCY 'DVP_P4-2: H2T574_SRT-S' OPEN BRANCH FROM BUS 314196 TO BUS 314911 CKT 2 /*6LADYSMITH 230.0 - 8LADYSMITH 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 115.19 | 3940.0 | C | 4538.63 | 23.25 | ||
| 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 | 133.03 | 1204.0 | C | 1601.71 | 10.07 | ||
| 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 | 102.17 | 441.8 | B | 451.37 | 1.75 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
DVP_P4-2: 568T575_SRT-A
CONTINGENCY 'DVP_P4-2: 568T575_SRT-A' OPEN BRANCH FROM BUS 314911 TO BUS 314918 CKT 1 /*8LADYSMITH 500.0 - 8NO ANNA 500.0 OPEN BRANCH FROM BUS 314911 TO BUS 314922 CKT 1 /*8LADYSMITH 500.0 - 8POSSUM 500.0 END |
Breaker | AC | 121.21 | 3940.0 | C | 4775.7 | 14.48 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P4-2: 557T574_SRT-S
CONTINGENCY 'DVP_P4-2: 557T574_SRT-S' OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 2650 BRANCH FROM BUS 314905 TO BUS 314911 CKT 1 /*8CHANCE 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 119.69 | 3940.0 | C | 4715.74 | 24.67 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 155.32 | 663.64 | B | 1030.78 | 2.04 | ||
Summer Potential Congestion due to Local Energy Deliverability
PJM also studied the delivery of the energy portion of this interconnection request. Any problems identified below are likely to result in operational restrictions to the project under study. The developer can proceed with network upgrades to eliminate the operational restriction at their discretion by submitting an Upgrade Request into the New Service Request process.
Note: Only the most severely overloaded conditions are listed below. There is no guarantee of full delivery of energy for this project by fixing only the conditions listed in this section. With an Upgrade Request, a subsequent analysis will be performed which shall study all overload conditions associated with the overloaded element(s) identified.
The following flowgates remain after considering the topology reinforcements required by the cycle.
| Summer Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 2 line
314902 to 314914 ckt 2 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 110.71 | 4094.64 | B | 4533.15 | 25.45 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
DVP_P1: Carson-Midlothian_SRT-A
CONTINGENCY 'DVP_P1: Carson-Midlothian_SRT-A' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 2 /*8CARSON 500.0 - 8MDLTHAN 500.0 END |
OP | AC | 110.71 | 4094.64 | B | 4533.15 | 25.45 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 2 line
314914 to 314918 ckt 2 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 104.42 | 4094.64 | B | 4275.43 | 23.11 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
DVP_P1: Midlothian-NorthAnna_SRT-A
CONTINGENCY 'DVP_P1: Midlothian-NorthAnna_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 2 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 104.42 | 4094.64 | B | 4275.43 | 23.11 | ||
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Summer Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6KINGS M-6PENNIMAN 230.0 kV Ckt 1 line
314386 to 314296 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 100.49 | 984.18 | B | 989.02 | 3.89 | ||
| DVP |
6CHARCTY-6LAKESIDE 230.0 kV Ckt 1 line
314225 to 314227 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 108.48 | 984.18 | B | 1067.68 | 4.72 | ||
| DVP |
8MDLTHAN-6MDLTHAN 500.0/230.0 kV Ckt 1 transformer
314914 to 314322 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 142.35 | 1058.16 | B | 1506.29 | 9.31 | ||
| 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 | 108.11 | 879.84 | B | 951.17 | 5.36 | ||
| DVP |
6SKIFF CREEK-6KINGS M 230.0 kV Ckt 1 line
314209 to 314386 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 103.83 | 984.18 | B | 1021.91 | 3.89 | ||
| DVP |
8CARSON-8MDLTHAN 500.0 kV Ckt 1 line
314902 to 314914 ckt 1 |
Base Case | OP | AC | 112.87 | 3220.44 | A | 3634.93 | 20.69 | ||
| DVP |
6CHESTF B-6VARINA 230.0 kV Ckt 1 line
314287 to 314260 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 112.12 | 984.18 | B | 1103.43 | 4.72 | ||
| 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 | 107.34 | 888.3 | B | 953.54 | 5.37 | ||
| DVP |
8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1 |
Base Case | OP | AC | 103.1 | 3193.18 | A | 3292.2 | 18.08 | ||
| DVP |
8SPOTSYL-8MORRSVL 500.0 kV Ckt 1 line
314934 to 314916 ckt 1 |
Base Case | OP | AC | 107.11 | 3220.44 | A | 3449.34 | 10.91 | ||
| DVP |
8SEPTA-8SURRY 500.0 kV Ckt 1 line
314923 to 314924 ckt 1 |
DVP_P1-2: LN 563_SRT-S-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-S-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3118 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 2858 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 120.61 | 2442.12 | B | 2945.47 | 16.59 | ||
| 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 | 124.28 | 4070.2 | B | 5058.27 | 43.58 | ||
| DVP |
6LIGH209-6LANEXA 230.0 kV Ckt 1 line
314391 to 314388 ckt 1 |
DVP_P1-2: LN 567_SRT-A
CONTINGENCY 'DVP_P1-2: LN 567_SRT-A' OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1 /*8CHCKAHM 500.0 - 8SURRY 500.0 END |
OP | AC | 130.6 | 663.64 | B | 866.7 | 3.89 | ||
| 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 |
OP | AC | 112.08 | 984.18 | B | 1103.08 | 4.72 | ||
| 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 |
OP | AC | 128.52 | 4070.2 | B | 5231.06 | 43.93 | ||
| 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 |
OP | AC | 120.59 | 4070.2 | B | 4908.14 | 43.93 | ||
| 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 | 117.11 | 4070.2 | B | 4766.54 | 43.58 | ||
Winter Peak Analysis
PJM will start performing Winter Peak analysis in Transition Cycle #2.
Winter Potential Congestion due to Local Energy Deliverability
PJM will start performing Winter Peak analysis in Transition Cycle #2.
Light Load Analysis
The New Service Request was evaluated as a 75.0 MW injection and 75.0 MW withdrawal in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential light load period network impacts were as follows:
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Light Load Analysis | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
Single | AC | 132.37 | 678.68 | B | 898.39 | 4.56 | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 127.88 | 678.68 | B | 867.92 | 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 | 131.89 | 678.68 | B | 895.11 | 4.56 | ||
| DVP |
6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 127.41 | 678.68 | B | 864.68 | 5.33 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 110.04 | 661.76 | B | 728.22 | 4.78 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 103.54 | 661.76 | B | 685.16 | 4.13 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 108.77 | 661.76 | B | 719.8 | 4.78 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 102.26 | 661.76 | B | 676.74 | 4.13 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-L-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-L-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
Single | AC | 108.12 | 663.64 | B | 717.53 | 5.01 | ||
| DVP |
6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
Single | AC | 107.1 | 661.76 | B | 708.72 | 4.78 | ||
| DVP |
6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1 |
DVP_P1-2: LN 553_SRT-L
CONTINGENCY 'DVP_P1-2: LN 553_SRT-L' OPEN BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 END |
Single | AC | 100.59 | 661.76 | B | 665.67 | 4.13 | ||
| DVP |
6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 ckt 1 |
DVP_P4-2: H2T557_SRT-L
CONTINGENCY 'DVP_P4-2: H2T557_SRT-L' OPEN BRANCH FROM BUS 314218 TO BUS 314908 CKT 2 /*6ELMONT 230.0 - 8ELMONT 500.0 OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM 500.0 - 8ELMONT 500.0 SET POSTCONTRATING 3300 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 3300 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314910 CKT 1 /*8ELMONT 500.0 - 8CUNINGHAM 500.0 SET PRECONTRATING 3118 BRANCH FROM BUS 314908 TO BUS 314911 CKT 1 /*8ELMONT 500.0 - 8LADYSMITH 500.0 END |
Breaker | AC | 113.74 | 1065.0 | C | 1211.33 | 9.46 | ||
Light Load Potential Congestion due to Local Energy Deliverability
The following flowgates remain after considering the topology reinforcements required by the cycle.
(No impacts were found for this analysis)
The following flowgates were eliminated after considering the topology reinforcements required by the cycle.
| Light Load Potential Congestion due to Local Energy Deliverability | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Area | Facility Description | Contingency Name | Contingency Type | DC|AC | Final Cycle Loading | Rating (MVA) | Rating Type | MVA to Mitigate | MW Contribution | ||
| DVP |
6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
OP | AC | 124.21 | 678.68 | B | 842.96 | 4.56 | ||
| DVP |
6BREMODIST-6FORK UNION 230.0 kV Ckt 1 line
313867 to 313707 ckt 1 |
DVP_P1-2: LN 534_SRT-L
CONTINGENCY 'DVP_P1-2: LN 534_SRT-L' OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1 /*8DOOMS 500.0 - 8CUNINGHAM 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET POSTCONTRATING 1663 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET POSTCONTRATING 4399 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314942 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAEAS 500.0 SET PRECONTRATING 1481 BRANCH FROM BUS 314910 TO BUS 314943 CKT 1 /*8CUNINGHAM 500.0 - 8FLUVANNAWES 500.0 SET PRECONTRATING 4157 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS 500.0 - 8VALLEY 500.0 END |
OP | AC | 123.75 | 678.68 | B | 839.87 | 4.56 | ||
| DVP |
6FORK UNION-6CUNNING 230.0 kV Ckt 1 line
313707 to 313373 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 101.66 | 661.76 | B | 672.73 | 4.78 | ||
| DVP |
6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line
313373 to 314765 ckt 1 |
DVP_P1-2: LN 576_SRT-A
CONTINGENCY 'DVP_P1-2: LN 576_SRT-A' OPEN BRANCH FROM BUS 314914 TO BUS 314918 CKT 1 /*8MDLTHAN 500.0 - 8NO ANNA 500.0 END |
OP | AC | 100.38 | 661.76 | B | 664.26 | 4.78 | ||
| DVP |
6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1 |
DVP_P1-2: LN 563_SRT-L-1
CONTINGENCY 'DVP_P1-2: LN 563_SRT-L-1' OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1 /*8CARSON 500.0 - 8MDLTHAN 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET POSTCONTRATING 3559 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON 500.0 - AE2-051 TP 500.0 SET PRECONTRATING 3377 BRANCH FROM BUS 314923 TO BUS 940640 CKT 1 /*8SEPTA 500.0 - AE2-051 TP 500.0 END |
OP | AC | 100.69 | 663.64 | B | 668.21 | 5.01 | ||
Short Circuit Analysis
Based on PJM Short Circuit Analysis, this project did not contribute >1% fault duty to previously identified overduty breakers, nor did it cause any new overduty breakers.
Stability Analysis
Analysis Complete - No Issues
New Service Requests (projects) in PJM Transition Cycle 1 Cluster 47 are listed in Table 1 below. This report will cover the dynamic analysis of Cluster 47 projects.
Table 1: Transition Cycle 1 Cluster 47 Projects
Cluster | Project | Fuel Type | Transmission Owner | MFO (MW) | MWE (MW) | MWC (MW) | Point of Interconnection |
47 | AE2-313 | Solar | Dominion | 314 | 314 | 188.4 | Carson to Rawling 500 kV |
AG1-449 | Battery | Dominion | 436 | 122 | 122 | Carson to Rawling 500 kV | |
AG1-153 | Battery | Dominion | 75 | 75 | 30 | Heritage 500 kV |
This analysis is effectively a screening study to determine whether the addition of the Cluster 47 projects will meet the dynamics requirements of the NERC, Dominion Energy, and PJM reliability standards.
The load flow scenario for the analysis was based on the Regional Transmission Expansion Plan (RTEP) 2027 summer peak case, modified to include applicable projects. Cluster 47 projects have been dispatched online at maximum power output with near unity power factor measured at the high-side of the main substation transformer.
Cluster 47 projects were tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. 107 contingencies were studied, each with a 30 second simulation time period. The studied contingencies included:
- Steady-state operation (30 seconds)
- Three-phase faults with normal clearing time
- Single-phase bus faults with normal clearing time
- Single-phase faults with stuck breaker
- Single-phase faults with delayed clearing at remote end
- Three-phase faults with loss of multiple-circuit tower line.
For all simulations, the projects under study along with the rest of the PJM system were required to maintain synchronism and with all states returning to an acceptable new condition following the disturbance.
For all of the fault contingencies tested on the RTEP 2027 summer peak case:
- Cluster 47 projects were able to ride through the faults (except for faults where protective action trips a generator(s)),
- The system with Cluster 47 projects included is transiently stable and post-contingency oscillations were positively damped with a damping margin of at least 3% for interarea modes and 4% for local modes.
- Following fault clearing, all bus voltages recovered to a minimum of 0.7 per unit after 2.5 seconds (except where protective action isolates that bus) and the final voltages are within the steady-state voltage ranges below per Dominion Energy’s transmission planning criteria.
- P1 Category Contingencies:
- 0.93 to 1.05 p.u. for 230, 115, 69 kV facilities
- 0.93 to 1.03 p.u. for 138 kV facilities due to legacy switches
- 1.01 to 1.096 p.u. for 500 kV facilities
- P2, P4, P5, and P7 Category Contingencies:
- No transmission element tripped, other than those either directly connected or designed to trip as a consequence of that fault.
The following changes were needed to improve the reactive power recovery due to the units not reaching a steady state within the 20 seconds simulation.
- AG1-449 Gen1:
- REPCAU1 CON(J+2) Kp, Reactive Power PI to 1
- REPCAU1 CON(J+16) Kpg, Proportional Gain for Power Control to 0.01
- REPCAU1 ICON (M) Remote Bus to 965810
- REPCAU1 ICON (M+1) Monitored Branch From 965810
- REPCAU1 ICON (M+2) Monitored Branch To 942932
- AG1-449 Gen2:
- REPCAU1 CON(J+2) Kp, Reactive Power PI to 1
- REPCAU1 CON(J+16) Kpg, Proportional Gain for Power Control to 0.01
- REPCAU1 ICON (M) Remote Bus to 965812
- REPCAU1 ICON (M+1) Monitored Branch From 965812
- REPCAU1 ICON (M+1) Monitored Branch TO 942936
- AE2-313 Gen1:
- REPCAU1 ICON (M) Remote Bus to 942934
- REPCAU1 ICON (M+1) Monitored Branch From 942934
- REPCAU1 ICON (M+1) Monitored Branch To 942932
- AE2-313 Gen2:
- REPCAU1 ICON (M) Remote Bus to 942938
- REPCAU1 ICON (M+1) Monitored Branch From 942938
- REPCAU1 ICON (M+1) Monitored Branch To 942936
AE1-173:
AE1-173, a nearby generator tripped for undervoltage protection for voltages under 0.64 p.u for 0.31 seconds. The unit rode through all contingencies when pickup time was increased to 0.4375 seconds
AB2-169:
AB2-169, nearby generator, tripped for overvoltage protection for voltages over 1.25 p.u. for 0.0 seconds. The unit rode through all contingencies when pickup time was increased to 0.0125 seconds.
Note:
The stability study results in this report may need some parameter changes. Analysis will be revisited during phase III SIS of Transition Cycle #1 to reflect the impacts of any parameter modifications. The parameter modifications are not expected to change the ultimate results of the stability analysis.
Reactive Power Analysis
The reactive power capability of AG1-153 meet the 0.95 leading and lagging PF requirement at the high side of the main transformer.
Steady-State Voltage Analysis
Steady State Voltage Analysis is Not Required.
New Service Request Dependencies
The New Service Requests below are listed in one or more dispatch for the overloads identified in this report. These projects contribute to the loading of the overloaded facilities identified in this report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of other projects. The status of each project at the time of the analysis is presented in the table. This list may change as other projects withdraw or modify their requests. This table is valid for load flow analyses only.
(No dependencies were identified)
Affected Systems
In Phase II of the Cycle, PJM provides the Affected System Operator any updates on the PJM projects that require an Affected Systems Study based on their response at DP1. New Service Requests that require an Affected Systems Study are required to enter into an Affected Systems Study Agreement with the Affected System Operator, as applicable, prior to the close of DP2 or they will be withdrawn from the Cycle.
If the Project Developer already entered into the necessary agreement and the results are available, PJM will supply them in the Phase II SIS report. See below for the status of any required Affected Systems Study. A status of “Pending” means that the study is not yet completed by the Affected System Operator. If your project requires an Affected Systems Study and your results are not provided for Phase II SIS, PJM anticipates providing them in the Phase III SIS per Tariff Part VII.D.312.
System Reinforcements
Based on the Phase II analysis results, this project has potential cost responsibility for the following System Reinforcements:
| AG1-153 System Reinforcements Cost Breakdown: | Type | TO | RTEP ID / TO ID | Title | MW Impact | Percent Allocation | Allocated Cost ($USD) | |||
|---|---|---|---|---|---|---|---|---|---|---|
| Load Flow | Dominion | n9139 / TC1-PH1-DOM-073 | Wreck and rebuild 37.26 miles of LN 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA | 17.5 MW | 0.6% | $1,230,571 | ||||
| Load Flow | Dominion | n9249 / TC1-PH2-DOM-043 | Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. | 17.5 MW | 0.6% | $1,173,776 | ||||
| Grand Total: | $2,404,347 | |||||||||
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9139 / TC1-PH1-DOM-073 | Wreck and rebuild 37.26 miles of LN 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA | $242,190,000 | $1,230,571 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Wreck and rebuild 37.26 miles of Line 563 between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (Any) |
| 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6CARSON-6POE 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6TYLER1-6POE 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6TYLER1-6POE 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer | DVP_P4-2: 56372_SRT-S |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-147, AF1-152 |
40.1 MW | 1.4% | $2,816,410 |
|
AE2-313
⧉
AE2-313 500 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-313, AG1-449 |
438.8 MW | 15.1% | $30,841,818 |
|
AF1-123
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
361.3 MW | 12.4% | $25,396,403 |
|
AF1-124
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
362.6 MW | 12.5% | $25,487,644 |
|
AF1-125
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
355.7 MW | 12.2% | $25,001,138 |
|
AF1-152
⧉
Swamp 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-147, AF1-152 |
13.4 MW | 0.5% | $938,780 |
| AF2-042 | 584.2 MW | 20.1% | $41,066,329 |
|
AF2-046
⧉
AF2-046 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-046, AG1-008 |
87.2 MW | 3.0% | $6,129,660 |
| AF2-222 | 34.1 MW | 1.2% | $2,397,175 |
|
AG1-008
⧉
AF2-046 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-046, AG1-008 |
87.2 MW | 3.0% | $6,129,660 |
| AG1-153 | 17.5 MW | 0.6% | $1,230,571 |
|
AG1-437
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,778,106 |
|
AG1-438
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,778,106 |
|
AG1-439
⧉
Chinquapin 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-439, AG1-444 |
134.0 MW | 4.6% | $9,420,767 |
|
AG1-442
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,558,916 |
|
AG1-443
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,558,916 |
|
AG1-444
⧉
Chinquapin 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-439, AG1-444 |
56.3 MW | 1.9% | $3,955,880 |
|
AG1-449
⧉
AE2-313 500 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-313, AG1-449 |
182.3 MW | 6.3% | $12,817,877 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9249 / TC1-PH2-DOM-043 | Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. | $231,012,000 | $1,173,776 | 48 to 60 Months | |||
ContributorTopology Changing Note: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement. Hence, this project is receiving a cost allocation based on its MW contribution to the need for this topology changing reinforcement but at a reduced amount considering the other reinforcements that were able to be eliminated. This project's cost allocation is based on the pro rata share of the MW impacts from all cost allocated contributors multiplied by the relevant regional discount factor listed in the executive summary report.
Description: Construct new 37.26 mile line between Midlothian and Carson with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Midlothian and Carson to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (Any) |
| 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6CARSON-6POE 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 8SUFFOLK-AE1-173 TP 500.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 6TYLER1-6POE 230.0 kV Ckt 1 line | DVP_P4-2: 562T563_SRT-S |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6TYLER1-6POE 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CHAPARRAL T-6LOCKS 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-6CHAPARRAL T 230.0 kV Ckt 1 line | DVP_P1-2: LN 563_SRT-S-1 |
| 6CARSON-8CARSON 230.0/500.0 kV Ckt 2 transformer | DVP_P4-2: 56372_SRT-S |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8CARSON-8MDLTHAN 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| Cost Allocation | |||
|---|---|---|---|
| Project | MW Impact | Percent Allocation | Allocated Cost ($USD) |
|
AE2-147
⧉
Swamp 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-147, AF1-152 |
40.1 MW | 1.4% | $2,686,422 |
|
AE2-313
⧉
AE2-313 500 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-313, AG1-449 |
438.8 MW | 15.1% | $29,418,349 |
|
AF1-123
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
361.3 MW | 12.4% | $24,224,261 |
|
AF1-124
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
362.6 MW | 12.5% | $24,311,292 |
|
AF1-125
⧉
CVOW Harpers 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF1-123, AF1-124, AF1-125 |
355.7 MW | 12.2% | $23,847,239 |
|
AF1-152
⧉
Swamp 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-147, AF1-152 |
13.4 MW | 0.5% | $895,452 |
| AF2-042 | 584.2 MW | 20.1% | $39,170,960 |
|
AF2-046
⧉
AF2-046 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-046, AG1-008 |
87.2 MW | 3.0% | $5,846,752 |
| AF2-222 | 34.1 MW | 1.2% | $2,286,536 |
|
AG1-008
⧉
AF2-046 115 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AF2-046, AG1-008 |
87.2 MW | 3.0% | $5,846,752 |
| AG1-153 | 17.5 MW | 0.6% | $1,173,776 |
|
AG1-437
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,603,732 |
|
AG1-438
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
53.7 MW | 1.8% | $3,603,732 |
|
AG1-439
⧉
Chinquapin 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-439, AG1-444 |
134.0 MW | 4.6% | $8,985,962 |
|
AG1-442
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,486,966 |
|
AG1-443
⧉
AG1-437 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-437, AG1-438, AG1-442, AG1-443 |
22.2 MW | 0.8% | $1,486,966 |
|
AG1-444
⧉
Chinquapin 230 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AG1-439, AG1-444 |
56.3 MW | 1.9% | $3,773,301 |
|
AG1-449
⧉
AE2-313 500 kV - Dominion: This project's cost allocation eligibility was based on the grouped impact of all New Service Requests which shared this POI within this cycle. The following project shared this POI: AE2-313, AG1-449 |
182.3 MW | 6.3% | $12,226,283 |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9112 / TC1-PH2-DOM-063 | Wreck and Rebuild 12.4 miles of 230 kV line 259 with (2) 768.2 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C and replace line lead at Chesterfield. | $35,750,000 | $0 | 42 to 48 Months | |||
Potential Aggregate ContributorEliminated Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle.
Description: Wreck and Rebuild 12.4 miles of 230 kV line 259 with (2) 768.2 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C and replace line lead at Chesterfield.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 797.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 797.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1115.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9265 / TC1-PH2-DOM-064 | Replace 230 kV wave trap at Basin 230 kV (Basin - Chesterfield B). | $200,000 | $0 | 16 to 18 Months | |||
Potential Aggregate ContributorEliminated Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle.
Description: Replace 230 kV wave trap at Basin 230 kV (Basin - Chesterfield B).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 876.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 956.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1163.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9266 / TC1-PH2-DOM-065 | Replace CBSW at Basin 230 kV (Basin - Chesterfield B). | $275,000 | $0 | 12 to 18 Months | |||
Potential Aggregate ContributorEliminated Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle.
Description: Replace CBSW at Basin 230 kV (Basin - Chesterfield B).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | A | 1174.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | B | 1302.0 MVA |
| 6BASIN-6CHESTF B 230.0 kV Ckt 1 line | (All) | C | 1360.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9198 / TC1-PH2-DOM-003 | Replace Circuit Breaker and Circuit Breaker Lead at Bremo 230 kV (Bremo - Fork Union). | $1,600,000 | $0 | 42 to 48 Months | |||
Potential Aggregate ContributorEliminated Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle.
Description: Replace Circuit Breaker and Circuit Breaker Lead at Bremo 230 kV (Bremo - Fork Union).
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | (Any) |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | A | 876.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | B | 956.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | C | 1163.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | A | 876.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | B | 956.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | C | 1163.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | A | 876.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | B | 956.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | C | 1163.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | A | 876.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | B | 956.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | C | 1163.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9220 / TC1-PH2-DOM-033 | Wreck and rebuild 15.41 miles of 230 kV Line 298 from Buckingham to Bremo with (2) 768.2 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C. Replace line lead at Bremo. | $44,418,125 | $0 | 42 to 48 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Wreck and rebuild 15.41 miles of 230 kV Line 298 from Buckingham to Bremo with (2) 768.2 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C. Replace line lead at Bremo.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BUCKING-6BREMO 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BUCKING-6BREMO 230.0 kV Ckt 1 line | (All) | A | 797.0 MVA |
| 6BUCKING-6BREMO 230.0 kV Ckt 1 line | (All) | B | 797.0 MVA |
| 6BUCKING-6BREMO 230.0 kV Ckt 1 line | (All) | C | 1116.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9217 / TC1-PH2-DOM-028 | Rebuild 12.73 miles of 230 kV Line 298 from Buckingham to Farmville with (2) 768 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C and replace line lead at Farmville. | $36,698,750 | $0 | 42 to 48 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Rebuild 12.73 miles of 230 kV Line 298 from Buckingham to Farmville with (2) 768 ACSS/TW (20/7) "Maumee" conductor @ 250 degrees C and replace line lead at Farmville.
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6BUCKING-6FARMVIL 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6BUCKING-6FARMVIL 230.0 kV Ckt 1 line | (All) | A | 797.0 MVA |
| 6BUCKING-6FARMVIL 230.0 kV Ckt 1 line | (All) | B | 797.0 MVA |
| 6BUCKING-6FARMVIL 230.0 kV Ckt 1 line | (All) | C | 1116.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n7568 / dom-369 | Wreck and rebuild 6.47 miles of line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle | $18,701,250 | $0 | 36 to 40 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Wreck and rebuild 6.47 miles of line 2028 between Charlottesville and Mt. Eagle with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Mt. Eagle
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | A | 781.0 MVA |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | B | 869.0 MVA |
| 6CHARLVL-6MTEAGLE 230.0 kV Ckt 1 line | (All) | C | 909.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9203 / TC1-PH2-DOM-008 | Wreck and rebuild 10.86 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C | $31,222,500 | $0 | 42 to 48 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Wreck and rebuild 10.86 miles of line 2028 between Fork Union and Cunningham (Grape Vine) with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | A | 1174.0 MVA |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | B | 1195.0 MVA |
| 6CUNNING-6FORK UNION 230.0 kV Ckt 1 line | (All) | C | 1360.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n7569 / dom-490 | Reconductor 6.51 miles of line between Mt. Eagle and Cunningham with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C | $18,716,250 | $0 | 36 to 40 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Reconductor 6.51 miles of line between Mt. Eagle and Cunningham with (2) 768.2 ACSS/TW (20/7) "MAUMEE" conductor @250 degrees C
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | A | 1315.0 MVA |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | B | 1435.0 MVA |
| 6CUNNING-6MTEAGLE 230.0 kV Ckt 1 line | (All) | C | 1745.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | A | 1315.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | B | 1435.0 MVA |
| 6CUNNING-AF2-397 TP 230.0 kV Ckt 1 line | (All) | C | 1745.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9207 / TC1-PH2-DOM-018 | Replace 6ELMONT 230 KV to 8ELMONT 500 KV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM) | $45,000,000 | $0 | 42 to 44 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Replace 6ELMONT 230 KV to 8ELMONT 500 KV ckt 1 with Larger XFRM. (3-480 MVA Single Phase XFRM)
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | A | 1440.0 MVA |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | B | 1440.0 MVA |
| 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer | (All) | C | 1440.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9199 / TC1-PH2-DOM-004 | Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo replace line lead at Bremo | $4,786,250 | $0 | 36 to 42 Months | |||
Potential Aggregate Contributor Note: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor.
Description: Wreck and rebuild 1.63 miles of line 2193 between Fork Union and Bremo with (2) 768.2 ACSS/TW (20/7) "Maumee" @ 250C and replace line lead at Bremo
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | (Any) |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | A | 781.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | B | 869.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | LL | C | 909.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | A | 781.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | B | 869.0 MVA |
| 6FORK UNION-6BREMODIST 230.0 kV Ckt 1 line | SUM | C | 909.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | A | 781.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | B | 869.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | LL | C | 909.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | A | 781.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | B | 869.0 MVA |
| 6BREMODIST-6BREMO 230.0 kV Ckt 1 line | SUM | C | 909.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9138 / TC1-PH1-DOM-070 | Wreck and rebuild 22.59 miles of Line 511 between Carson and Rawlings with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA | $146,835,000 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Wreck and rebuild 22.59 miles of Line 511 between Carson and Rawlings with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CARSON-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 | 4356.0 MVA |
| 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9250 / TC1-PH2-DOM-044 | Construct new 22.59 mile line between Carson and Rawlings with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Carson and Rawlings to accommodate new line. | $140,058,000 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Construct new 22.59 mile line between Carson and Rawlings with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Carson and Rawlings to accommodate new line. New Rating = 4356/4356/5009 MVA
| 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 | 4356.0 MVA |
| 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8RAWLINGS-AE2-313 TP 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9264 / TC1-PH2-DOM-066 | Replace wave trap and line lead at Surry 500 kV substation (Surry - Chickahominy) | $400,000 | $0 | 16 to 18 Months | |||
Potential Aggregate ContributorEliminated Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: The topology changing reinforcements listed in the Cycle executive summary report eliminated the need for this reinforcement and it is no longer required by the Cycle.
Description: Replace wave trap and line lead at Surry 500 kV substation (Surry - Chickahominy)
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | A | 2598.0 MVA |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | B | 2858.0 MVA |
| 8CHCKAHM-8SURRY 500.0 kV Ckt 1 line | (All) | C | 3637.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9191 / TC1-PH1-DOM-090 | Wreck and rebuild 41.13 miles of Line 576 between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work to achieve new rating of 4356/4356/5009 MVA | $266,474,110 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Wreck and rebuild 41.13 miles of Line 576 between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S |
| 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9251 / TC1-PH2-DOM-019 | Construct new 62.03 mile line between North Anna and Possum Point with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Possum Point to accommodate new line. | $390,789,000 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Construct new 62.03 mile line between North Anna and Possum Point with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Possum Point to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8LADYSMITH-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9248 / TC1-PH2-DOM-042 | Construct new 41.13 mile line between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Midlothian to accommodate new line. | $255,006,000 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Construct new 41.13 mile line between North Anna and Midlothian with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at North Anna and Midlothian to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (Any) |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P1-2: LN 576_SRT-A |
| 8ELMONT-8LADYSMITH 500.0 kV Ckt 1 line | DVP_P4-2: 57602_SRT-S |
| 6MDLTHAN-8MDLTHAN 230.0/500.0 kV Ckt 1 transformer | DVP_P1-2: LN 576_SRT-A |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9246 / TC1-PH2-DOM-040 | Wreck and rebuild 18.75 miles of Line 594 btwn Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work to achieve new rating of 4356/4356/5009 MVA | $125,300,705 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Wreck and rebuild 18.75 miles of Line 594 between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9137 / TC1-PH1-DOM-069 | Construct new 18.75 mile line between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Morrisville and Spotsylvania to accommodate new line. | $116,164,820 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Construct new 18.75 mile line between Morrisville and Spotsylvania with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Morrisville and Spotsylvania to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4295.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4357.0 MVA |
| 8MORRSVL-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 4996.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9247 / TC1-PH2-DOM-041 | Wreck and rebuild 14.02 miles of Line 573 btwn Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and assoc substation work to achieve new rating of 4356/4356/5009 MVA. | $113,450,107 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: Based on PJM cost allocation criteria, AG1-153 currently does not receive cost allocation towards this upgrade. As changes to the PJM process occur (such as other projects withdrawing from the cycle or reducing in size) AG1-153 could receive cost allocation. Although AG1-153 may not presently have cost responsibility for this upgrade, AG1-153 is a potential Aggregate Pool Contributor. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Wreck and rebuild 14.02 miles of Line 573 between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C and associated substation work to achieve new rating of 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4356.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4356.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 5009.0 MVA |
| System Reinforcement | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Type | TO | RTEP ID / TO ID | Title | Total Cost ($USD) | Allocated Cost ($USD) | Time Estimate | |||
| Load Flow | Dominion | n9140 / TC1-PH1-DOM-071 | Construct new 14.02 mile line between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Spotsylvania and North Anna to accommodate new line. | $156,268,121 | $0 | 48 to 60 Months | |||
Potential Aggregate ContributorTopology Changing Note 1: 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. Note 2: This topology changing reinforcement was developed by the transmission owner and modeled in PJM analysis to address cycle overload(s). A flowgate that this project contributed to was identified as requiring this topology reinforcement.
Description: Construct new 14.02 mile line between Spotsylvania and North Anna with (3) 1351.5 ACSR (45/7) "Dipper" at 110 degrees C. Station upgrades at Spotsylvania and North Anna to accommodate new line. New Rating = 4356/4356/5009 MVA
| Flowgates Addressed by this Reinforcement | |
|---|---|
| Facility | Contingency |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (Any) |
| New Ratings | |||
|---|---|---|---|
| Facility | Rating Set | Rating Type | Rating Value |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | A | 4295.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | B | 4357.0 MVA |
| 8NO ANNA-8SPOTSYL 500.0 kV Ckt 1 line | (All) | C | 4996.0 MVA |
Attachments
[1]Winter load flow analysis will be performed starting in Transition Cycle #2.