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AF2-000C Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 11:07

Sherman Ave - West Vineland 69 kV

31.0 MW Capacity / 77.7 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 AF2-000C 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 Storage generating facility located in the AEC zone — Cumberland County, New Jersey. The installed facilities will have a total capability of 77.7 MW with 31.0 MW of this output being recognized by PJM as Capacity. The proposed in-service date for this project is Wednesday, May 31, 2023. This study does not imply a TO commitment to this in-service date.

Project Information

Queue Number

AF2-000C (AF1-238)

Project Name

Sherman Ave - West Vineland 69 kV

Developer Name

Garden Reserve Energy, LLC

State

New Jersey

County

Cumberland

Transmission Owner

AEC

MFO

77.7 MW

MWE

77.7 MW

MWC

31.0 MW

Fuel Type

Storage

Basecase Study Year

2023

 

Point of Interconnection

AF2-000C (AF1-238) will interconnect on the AEC transmission system tapping the Sherman Ave - West Vineland 69 kV line.

Summer Peak Analysis

The Queue Project was evaluated as a 77.7 MW (Capacity 31.0 MW) injection in the AEC 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
PECO RICHRE29-RICHMOND 230.0 kV Ckt 1 line
214206 to 213922 ckt 1
PECO_P2-2_CHI230B1/* $ DELCO $ CHI230B1 $ B
CONTINGENCY 'PECO_P2-2_CHI230B1
 DISCONNECT BUS 213489   /*CHICHST1     230.0
END
Bus AC 102.01 % 103.09 % 1336.0 B 1377.28 17.34
PECO/PSEG CAMDEN-RICHRE29 230.0 kV Ckt 1 line
219125 to 214206 ckt 1
PECO_P2-2_CHI230B1/* $ DELCO $ CHI230B1 $ B
CONTINGENCY 'PECO_P2-2_CHI230B1
 DISCONNECT BUS 213489   /*CHICHST1     230.0
END
Bus AC 101.4 % 102.48 % 1344.0 B 1377.28 17.34
PECO RICHMOND-WANEETA3 230.0 kV Ckt 1 line
213922 to 214012 ckt 1
PECO_P2-2_CHI230B1/* $ DELCO $ CHI230B1 $ B
CONTINGENCY 'PECO_P2-2_CHI230B1
 DISCONNECT BUS 213489   /*CHICHST1     230.0
END
Bus AC 101.1 % 102.33 % 1180.0 B 1207.49 16.33
AE/JCPL CEDAR-28OYSTER C 230.0 kV Ckt 1 line
227955 to 206302 ckt 1
AE_P4-2 AE7
CONTINGENCY 'AE_P4-2 AE7'
 DISCONNECT BRANCH FROM BUS 219100 TO BUS 227900 CKT 1   /*NEWFRDM      230.0 - CARDIFF      230.0
 DISCONNECT BRANCH FROM BUS 227900 TO BUS 227910 CKT 1   /*CARDIFF      230.0 - CARDIFF1      69.0
END
Breaker AC 112.28 % 113.63 % 564.0 B 640.87 9.82
AE/JCPL CEDAR-28OYSTER C 230.0 kV Ckt 1 line
227955 to 206302 ckt 1
AE_P4-2 AE6
CONTINGENCY 'AE_P4-2 AE6'
 DISCONNECT BRANCH FROM BUS 219100 TO BUS 227900 CKT 1   /*NEWFRDM      230.0 - CARDIFF      230.0
 DISCONNECT BRANCH FROM BUS 227900 TO BUS 227911 CKT 1   /*CARDIFF      230.0 - CARDIFF2      69.0
END
Breaker AC 112.27 % 113.62 % 564.0 B 640.82 9.82
AE BLE-SCULL#2 138.0 kV Ckt 1 line
228110 to 227906 ckt 1
AE_P4-2 AE28
CONTINGENCY 'AE_P4-2 AE28'
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 227905 CKT 1   /*BLE          138.0 - SCULL#1      138.0
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 228197 CKT 1   /*BLE          138.0 - MERION       138.0
END
Breaker AC 107.14 % 110.45 % 306.0 B 337.98 10.74
AE BLE-SCULL#1 138.0 kV Ckt 1 line
228110 to 227905 ckt 1
AE_P4-2 AE29
CONTINGENCY 'AE_P4-2 AE29'
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 227906 CKT 1   /*BLE          138.0 - SCULL#2      138.0
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 228111 CKT 1   /*BLE          138.0 - MDLE TP      138.0
END
Breaker AC 105.44 % 108.37 % 306.0 B 331.61 9.5
AE SCULL#2-MILL #2 138.0 kV Ckt 1 line
227906 to 227904 ckt 1
AE_P4-2 AE28
CONTINGENCY 'AE_P4-2 AE28'
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 227905 CKT 1   /*BLE          138.0 - SCULL#1      138.0
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 228197 CKT 1   /*BLE          138.0 - MERION       138.0
END
Breaker AC 102.21 % 105.52 % 306.0 B 322.89 10.74
AE SCULL#1-MILL #1 138.0 kV Ckt 1 line
227905 to 227903 ckt 1
AE_P4-2 AE29
CONTINGENCY 'AE_P4-2 AE29'
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 227906 CKT 1   /*BLE          138.0 - SCULL#2      138.0
 DISCONNECT BRANCH FROM BUS 228110 TO BUS 228111 CKT 1   /*BLE          138.0 - MDLE TP      138.0
END
Breaker AC 98.54 % 101.46 % 306.0 B 310.47 9.5
PECO RICHRE29-RICHMOND 230.0 kV Ckt 1 line
214206 to 213922 ckt 1
PECO_P4_CHICH045/* $ DELCO $ CHICH045 $ STBK
CONTINGENCY 'PECO_P4_CHICH045
 DISCONNECT BUS 213489   /*CHICHST1     230.0
 DISCONNECT BUS 213627   /*FOULK8       230.0
END
Breaker AC 102.01 % 103.09 % 1336.0 B 1377.28 17.34
PECO/PSEG CAMDEN-RICHRE29 230.0 kV Ckt 1 line
219125 to 214206 ckt 1
PECO_P4_CHICH045/* $ DELCO $ CHICH045 $ STBK
CONTINGENCY 'PECO_P4_CHICH045
 DISCONNECT BUS 213489   /*CHICHST1     230.0
 DISCONNECT BUS 213627   /*FOULK8       230.0
END
Breaker AC 101.4 % 102.48 % 1344.0 B 1377.28 17.34
PECO RICHMOND-WANEETA3 230.0 kV Ckt 1 line
213922 to 214012 ckt 1
PECO_P4_CHICH045/* $ DELCO $ CHICH045 $ STBK
CONTINGENCY 'PECO_P4_CHICH045
 DISCONNECT BUS 213489   /*CHICHST1     230.0
 DISCONNECT BUS 213627   /*FOULK8       230.0
END
Breaker AC 101.11 % 102.34 % 1180.0 B 1207.61 16.33
AE S121TAP-CNTRL N 69.0 kV Ckt 1 line
228716 to 228714 ckt 1
AE_P1-2 SHERM-W VINE-A
CONTINGENCY 'AE_P1-2 SHERM-W VINE-A'
 OPEN LINE FROM BUS 228256 TO BUS 945730 CIRCUIT 1   /*SHRMAN#1      69.0 - AF1-239 TAP   69.0
END
Single AC 74.82 % 102.27 % 107.0 B 109.43 30.99
AE/PSEG CARDIFF-NEWFRDM 230.0 kV Ckt 1 line
227900 to 219100 ckt 1
JC-P7-1-JCC-230-13
CONTINGENCY 'JC-P7-1-JCC-230-13'
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 1   /*28MANITOU    230.0 - 28OYSTER C   230.0
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 2   /*28MANITOU    230.0 - 28OYSTER C   230.0
END
Tower AC 119.32 % 120.48 % 692.0 B 833.72 10.4

Light Load Analysis

The Queue Project was evaluated as a 77.7 MW (Capacity 31.0 MW) injection in the AEC 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
AE VINE G10-WEST VLD 69.0 kV Ckt 1 line
228705 to 228706 ckt 1
AE_P1-2 SHERM-W VINE-A
CONTINGENCY 'AE_P1-2 SHERM-W VINE-A'
 OPEN LINE FROM BUS 228256 TO BUS 945730 CIRCUIT 1   /*SHRMAN#1      69.0 - AF1-239 TAP   69.0
END
Single AC 33.93 % 108.26 % 107.0 B 115.84 77.7
AE S121TAP-VINE G10 69.0 kV Ckt 1 line
228716 to 228705 ckt 1
AE_P1-2 SHERM-W VINE-A
CONTINGENCY 'AE_P1-2 SHERM-W VINE-A'
 OPEN LINE FROM BUS 228256 TO BUS 945730 CIRCUIT 1   /*SHRMAN#1      69.0 - AF1-239 TAP   69.0
END
Single AC 33.93 % 108.26 % 107.0 B 115.84 77.7
AE CNTRL N-S121TAP 69.0 kV Ckt 1 line
228714 to 228716 ckt 1
AE_P1-2 SHERM-W VINE-A
CONTINGENCY 'AE_P1-2 SHERM-W VINE-A'
 OPEN LINE FROM BUS 228256 TO BUS 945730 CIRCUIT 1   /*SHRMAN#1      69.0 - AF1-239 TAP   69.0
END
Single AC 33.93 % 108.26 % 107.0 B 115.84 77.7

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
(TBD) AEC Rating: 650/799 MVA (SN/SE) $0
n6587 Reconductor 0.08 miles of Oyster creek Cedar 230 kV Line transmission line. Upgrade Cedar Terminal of Oyster Creek 230 kV Substation. $645,190
n8460 Double Ckt line rebuild & terminal upgrades. $3,125,630
(TBD) Rebuild circuit and terminal reinforcements are required at Central North & Vineland G-10. $1,250,000
s0811 Rebuild the BL England - Scull - Mill - Lewis 138 kV #1 circuit '1407' $11,460,000
s0812 s0812: Rebuild the BL England - Scull - Mill - Lewis 138 kV #2 circuit '1408' $9,550,000
n6342 Rebuild Cardiff New Freedom 230 kV line. $105,000,000
(TBD) PSEG emergency rating 887 MVA. $0
n8310 Replacement of PSEG equipment for the 2310 line termination at New Freedom Switching Station to accomodate (AEC rebuild - n6342) $2,730,000
b3737.26 To mitigate the relay limits on this line the relay settings will be changed (Projected ISD 4/30/2028) $300,000
n6850 Replace down drops and disconnect switch at Camden 230kV $200,000
n6471 Replace 1 piece of station cable in Richmond substation on Richmond-Camden tie line $45,000
n6473 Replace reactor in Richmond substation on Richmond-Camden tie line $2,254,000
n8461 Double Ckt line rebuild & terminal upgrades. $2,532,540
n8462 Double Ckt line rebuild & terminal upgrades. $4,047,500
b3737.23 Rebuild the underground portion of Richmond-Waneeta 230 kV (Projected ISD 6/1/2029) $16,000,000

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AF2-000C 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.