Export to CSV

AF1-128 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 11:10

Chesterfield 230 kV

569.0 MW Capacity / 569.0 MW Energy

Introduction

In accordance with Tariff Part VII, Subpart B, section 304, PJM performed load flow analysis (Transition Sort Retool) on all AE1 through AG1 projects that have met eligibility requirements according to Tariff, Part VII, Subpart B, section 303. The purpose of this study is to determine whether a project would be classified as eligible for the Expedited Process (Fast Lane) or if it would be reprioritized to be studied as part of Transition Cycle #1 (TC1) using the criteria from the Expedited Process Eligibility section of Tariff Part VII, section 304. This is not a System Impact Study report.

Below are the results of the study, details of how the study was performed, criterion used in the evaluation of the Expedited Process vs. TC1 determination, and next steps in the interconnection process for your project.

Transition Cycle #1:

The AF1-128 project has not met the Expedited Process Eligibility requirements in Tariff Part VII, Subpart B, section 304 and will therefore be reprioritized to Transition Cycle #1. Please see "Transition Cycle #1 Rules" below.

Transition Sort Retool Study Process and Criteria:

In order to determine Expedited Process vs. Transition Cycle #1 classification, projects which met the Transition Eligibility requirements from Tariff Part VII, Subpart B, section 303 were studied on the base case model that was used for the original System Impact Study analysis. Both a summer peak and light load load flow analysis were performed. Projects that have cost allocation eligibility or are identified as the first to cause a system violation which requires the need for a Network Upgrade with a total estimated cost greater than $5 million will be reprioritized to Transition Cycle #1. All other projects will be eligible for the expedited procedures set forth in Tariff Part VII, Subpart B, section 304 (B).

Expedited Process Eligibility: OATT Tariff Part VII, section 304:

A project is not eligible for the expedited process if it has cost allocation eligibility or is identified as the first to cause, as determined according to Tariff, Part VI, section 217.3, for a Network Upgrade which has a total estimated cost of greater than $5,000,000. Such cost estimate will be based on Transmission Provider's most recently available data.

Not considered in the Transition Sorting: The cost of the Interconnection Facilities is not considered when determining a project's eligibility for the expedited process. Affected Systems upgrade costs are also not considered in the evaluation.

Transition Sort Retool Results Provided:

This report includes a list of:

  1. the overloaded flowgates (overloaded facilities + contingency pair) that the project contributes towards
  2. other interconnection projects that may also contribute to the overloaded facility, and
  3. the total estimated cost for any required Network Upgrades.

Important Notes:

Note for Uprate Projects: Per Tariff Part VII, Subpart B, section 304 (B), if a project is an uprate (project relies on the Interconnection Facilities of a prior project) whose base project does not qualify for the expedited process, the uprate also will not qualify for the expedited process, regardless of analysis results.

Notes regarding Results displayed:

  1. Some flowgate overloads that a New Service Request contributes to, but does not contribute enough to meet cost allocation eligibility (per Manual 14A, Attachment B.3), may be reported in this Transition Sort report. These types of flowgates do not affect the classification of the New Service Request as either Expedited Process or Transition Cycle #1 because cost allocation eligibility has not been met.
  2. For projects that were determined to not meet Expedited Process eligibility and are being reprioritized to Transition Cycle #1, not all reinforcements in excess of $5,000,000 may be shown in this report. This report may only display a subset of those reinforcements determined to be in excess of $5,000,000 which would classify the project as not meeting Expedited Process Eligibility. This is not a formal System Impact Study.

Next Steps for your project:

Transition Cycle #1 Rules:

Refer to Tariff Part VII, Subpart B, section 304 (C) for the Transition Cycle #1 Project Rules.

Transition Cycle #1 will start no later than one year from the Transition Start Date (July 10, 2023). Transition Cycle #1 will run simultaneously with the expedited process, however Transition Cycle #1, Phase III will not begin until all expedited process projects have been completed.

Projects that are reprioritized to Transition Cycle #1 will not need to re-apply to the Interconnection Cycle Process. Therefore, there is no Application Review Phase for Transition Cycle #1. The cycle process for Transition Cycle #1 includes three Study Phases and three Decision Points:

  1. Phase I System Impact Study and Decision Point I; and
  2. Phase II System Impact Study and Decision Point II; and
  3. Phase III System Impact Study and Decision Point III

Refer to Tariff Part VII, Subpart D, section 307 for the Transition Cycle #1 study process.

General

The Interconnection Customer (IC), has proposed a Natural Gas generating facility located in the Dominion zone — Chesterfield County, Virginia. The installed facilities will have a total capability of 569.0 MW with 569.0 MW of this output being recognized by PJM as Capacity. The proposed in-service date for this project is Thursday, June 01, 2023. This study does not imply a TO commitment to this in-service date.

AF1-128 is claiming CIRs from deactivated generators Chesterfield 3, 4 and 5.

Project Information

Queue Number

AF1-128

Project Name

Chesterfield 230 kV

Developer Name

Virginia Electric & Power Company

State

Virginia

County

Chesterfield

Transmission Owner

Dominion

MFO

569.0 MW

MWE

569.0 MW

MWC

569.0 MW

Fuel Type

Natural Gas

Basecase Study Year

2023

 

Point of Interconnection

The AF1-128 project will interconnect with the Dominion transmission system. The Point of Interconnection (POI) is a direct connection at an existing Chesterfield Power station 230 kV. Attachment 1 shows a one-line diagram of the proposed interconnection facilities 

Summer Peak Analysis

The Queue Project was evaluated as a 569.0 MW (Capacity 569.0 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential Summer peak period network impacts are listed below:

Important to Note:

Note for Uprate Projects: Per Tariff Part VII, Subpart B, section 304 (B), if a project is an uprate (project relies on the Interconnection Facilities of a prior project) whose base project does not qualify for the expedited process, the uprate also will not qualify for the expedited process, regardless of analysis results.

Notes regarding Results displayed:

  1. Some flowgate overloads that a New Service Request contributes to, but does not contribute enough to meet cost allocation eligibility (per Manual 14A, Attachment B.3), may be reported in this Transition Sort report. These types of flowgates do not affect the classification of the New Service Request as either Expedited Process or Transition Cycle #1 because cost allocation eligibility has not been met.
  2. For projects that were determined to not meet Expedited Process eligibility and are being reprioritized to Transition Cycle #1, not all reinforcements in excess of $5,000,000 may be shown in this report. This report may only display a subset of those reinforcements determined to be in excess of $5,000,000 which would classify the project as not meeting Expedited Process Eligibility. This is not a formal System Impact Study.
Summer Peak Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Initial Loading Final Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P4-2: 56372
CONTINGENCY 'DVP_P4-2: 56372'
 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
END
Breaker AC 113.14 % 118.88 % 549.0 C 652.65 28.91
DVP 6CHESTF A-3CHESTFLD 230.0/115.0 kV Ckt 1 transformer
314286 to 314284 ckt 1
DVP_P4-2: 208T287
CONTINGENCY 'DVP_P4-2: 208T287'
 OPEN BRANCH FROM BUS 314214 TO BUS 314286 CKT 1   /*6CHCKAHM     230.0 - 6CHESTF A    230.0
 OPEN BRANCH FROM BUS 314286 TO BUS 314309 CKT 1   /*6CHESTF A    230.0 - 6IRON208     230.0
 OPEN BRANCH FROM BUS 314309 TO BUS 314338 CKT 1   /*6IRON208     230.0 - 6SOUWEST     230.0
 OPEN BUS 314309                                   /*6IRON208     230.0
END
Breaker AC 101.88 % 115.38 % 268.1 C 309.33 36.54
DVP 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1
DVP_P4-2: 545T552
CONTINGENCY 'DVP_P4-2: 545T552'
 OPEN BRANCH FROM BUS 314135 TO BUS 314905 CKT 1   /*3CHANCE      115.0 - 8CHANCE      500.0
 OPEN BRANCH FROM BUS 314900 TO BUS 314905 CKT 1   /*8BRISTER     500.0 - 8CHANCE      500.0
 OPEN BRANCH FROM BUS 314900 TO BUS 314916 CKT 1   /*8BRISTER     500.0 - 8MORRSVL     500.0
END
Breaker AC 102.04 % 102.98 % 3637.0 C 3745.38 40.43
DVP 8MDLTHAN-8NO ANNA 500.0 kV Ckt 1 line
314914 to 314918 ckt 1
DVP_P1-2: LN 557
CONTINGENCY 'DVP_P1-2: LN 557'
 OPEN BRANCH FROM BUS 314214 TO BUS 314903 CKT 1   /*6CHCKAHM     230.0 - 8CHCKAHM     500.0
 OPEN BRANCH FROM BUS 314903 TO BUS 314908 CKT 1   /*8CHCKAHM     500.0 - 8ELMONT      500.0
END
Single AC 99.62 % 101.09 % 2442.12 B 2468.74 40.8
DVP 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1
DVP_P1-2: LN 594
CONTINGENCY 'DVP_P1-2: LN 594'
 OPEN BRANCH FROM BUS 314916 TO BUS 314934 CKT 1   /*8MORRSVL     500.0 - 8SPOTSYL     500.0
END
Single AC 101.88 % 103.42 % 2442.12 B 2525.64 37.23
DVP 8LADYSMITH-8POSSUM 500.0 kV Ckt 1 line
314911 to 314922 ckt 1
DVP_P1-2: LN 573
CONTINGENCY 'DVP_P1-2: LN 573'
 OPEN BRANCH FROM BUS 314918 TO BUS 314934 CKT 1   /*8NO ANNA     500.0 - 8SPOTSYL     500.0
END
Single AC 99.62 % 101.14 % 2442.12 B 2469.96 37.39
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P1-3: 6CHESTF B-GSU-6
CONTINGENCY 'DVP_P1-3: 6CHESTF B-GSU-6'
 OPEN BRANCH FROM BUS 314287 TO BUS 315065 CKT 1   /*6CHESTF B    230.0 - 1CHESTF6      24.0
 OPEN BUS 315065                                   /*1CHESTF6      24.0
END
Single AC 94.23 % 101.15 % 449.32 B 454.49 31.58

Light Load Analysis

The Queue Project was evaluated as a 569.0 MW (Capacity 569.0 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential light load period network impacts are listed below:

Important to Note:

Note for Uprate Projects: Per Tariff Part VII, Subpart B, section 304 (B), if a project is an uprate (project relies on the Interconnection Facilities of a prior project) whose base project does not qualify for the expedited process, the uprate also will not qualify for the expedited process, regardless of analysis results.

Notes regarding Results displayed:

  1. Some flowgate overloads that a New Service Request contributes to, but does not contribute enough to meet cost allocation eligibility (per Manual 14A, Attachment B.3), may be reported in this Transition Sort report. These types of flowgates do not affect the classification of the New Service Request as either Expedited Process or Transition Cycle #1 because cost allocation eligibility has not been met.
  2. For projects that were determined to not meet Expedited Process eligibility and are being reprioritized to Transition Cycle #1, not all reinforcements in excess of $5,000,000 may be shown in this report. This report may only display a subset of those reinforcements determined to be in excess of $5,000,000 which would classify the project as not meeting Expedited Process Eligibility. This is not a formal System Impact Study.
Light Load Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Initial Loading Final Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P1-2: LN 208
CONTINGENCY 'DVP_P1-2: LN 208'
 OPEN BRANCH FROM BUS 314286 TO BUS 314309 CKT 1   /*6CHESTF A    230.0 - 6IRON208     230.0
 OPEN BRANCH FROM BUS 314309 TO BUS 314338 CKT 1   /*6IRON208     230.0 - 6SOUWEST     230.0
 OPEN BUS 314309                                   /*6IRON208     230.0
END
Single AC 87.98 % 104.9 % 449.32 B 471.34 79.1
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P1-3: 6CHESTF B-GSU-6
CONTINGENCY 'DVP_P1-3: 6CHESTF B-GSU-6'
 OPEN BRANCH FROM BUS 314287 TO BUS 315065 CKT 1   /*6CHESTF B    230.0 - 1CHESTF6      24.0
 OPEN BUS 315065                                   /*1CHESTF6      24.0
END
Single AC 89.68 % 102.97 % 449.32 B 462.66 59.12

System Reinforcements

The table below lists all network upgrades which resolve the identified overloaded facilities in this report.

Important to Note:

Note for Uprate Projects: Per Tariff Part VII, Subpart B, section 304 (B), if a project is an uprate (project relies on the Interconnection Facilities of a prior project) whose base project does not qualify for the expedited process, the uprate also will not qualify for the expedited process, regardless of analysis results.

Notes regarding Results displayed:

  1. Some flowgate overloads that a New Service Request contributes to, but does not contribute enough to meet cost allocation eligibility (per Manual 14A, Attachment B.3), may be reported in this Transition Sort report. These types of flowgates do not affect the classification of the New Service Request as either Expedited Process or Transition Cycle #1 because cost allocation eligibility has not been met.
  2. For projects that were determined to not meet Expedited Process eligibility and are being reprioritized to Transition Cycle #1, not all reinforcements in excess of $5,000,000 may be shown in this report. This report may only display a subset of those reinforcements determined to be in excess of $5,000,000 which would classify the project as not meeting Expedited Process Eligibility. This is not a formal System Impact Study.
  3. Reinforcements previously identified by Transmission Owners for violations on lower voltage facilities are included in this report. Transmission Owner analysis will be updated as part of the Expedited Process and Transition Cycle 1 retools.
System Reinforcements
RTEP ID Title Total Cost
n7643 Add Additional 230/115 kV Transformer at Chesterfield Sub. $6,000,000
b3694.12 Upgrade equipment at Chesterfield substation to not limit ratings on Lines 211 and 228. $0
b3694.13 Upgrade equipment at Hopewell substation to not limit ratings on Lines 211 and 228. $0
b2922 PJM Baseline Upgrade b2922. Rebuild 8 of 11 miles of 230kV Lines #211 $0
b3694.10 Reconductor approximately 2.9 miles of 230 kV Line #211 Chesterfield Hopewell to achieve a minimum summer emergency rating of 1046 MVA. $0
n6063 Replace Wave traps at Ladysmith and Possum Pt 500 kV substations. $500,000
n6157 Relay Change Outs (CT) at Ladysmith and Possum Pt 500 kV substations. $120,000
n6055 Replace Wave traps at Midlothian and North Anna 500kV substations $300,000

Attachments

Attachment 1: One Line Diagram for Queue Project AF1-128.

AF1-128.PNG

Export to CSV Download all tables in report

Conclusion

The Transition Sort load flow retool results indicate that AF1-128 is not eligible for the Expedited Process per PJM Tariff Part VII, Subpart B, section 304 (A) will be reprioritized to Transition Cycle #1. See next steps for your project in the "Introduction" section above.