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AF2-065 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 11:06

Surry-Hopewell 230 kV

76.5 MW Capacity / 150.0 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 AF2-065 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 an uprate to a planned/existing Solar generating facility located in the Dominion zone Surry County, Virginia. This project is an increase to the Interconnection Customer's original project, which will share the same point of interconnection. The AF2-065 queue position is a 150.0 MW uprate (76.5 MW Capacity uprate) to the previous project. The total installed facilities will have a capability of 300.0 MW.

Project Information
Queue Number AF2-065
Project Name Surry-Hopewell 230 kV
Developer Name Violet Wood Solar LLC
State Virginia
County Surry
Transmission Owner Dominion
MFO 300.0 MW
MWE 150.0 MW
MWC 76.5 MW
Fuel Type Solar
Basecase Study Year 2023

Point of Interconnection

AF2-065 will interconnect with the Dominion on transmission system as an uprate to AE2-270 which is tapping the Surry to Hopewell, Line 240, 230 kV line.

 

Summer Peak Analysis

The Queue Project was evaluated as a 150.0 MW (Capacity 76.5 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential Summer peak period network impacts 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 A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P7-1: LN 2197-5240-B_B
CONTINGENCY 'DVP_P7-1: LN 2197-5240-B_B'
 OPEN BRANCH FROM BUS 314538 TO BUS 313896 CKT 1   /*6SURRY       230.0 - 6COLONIAL TR 230.0
 OPEN BRANCH FROM BUS 942550 TO BUS 314538 CKT 2   /*AE2-270 TAP  230.0 - 6SURRY       230.0
END
Tower AC 135.31 % 147.4 % 549.0 C 809.23 67.77
DVP 6PRGEORG-3PRGEORG 230.0/115.0 kV Ckt 1 transformer
314269 to 314291 ckt 1
DVP_P7-1: LN 211-228
CONTINGENCY 'DVP_P7-1: LN 211-228'
 OPEN BRANCH FROM BUS 314286 TO BUS 314303 CKT 1   /*6CHESTF A    230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314287 TO BUS 314303 CKT 1   /*6CHESTF B    230.0 - 6HOPEWLL     230.0
END
Tower AC 123.81 % 133.69 % 287.5 C 384.36 29.74
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 178.62 % 185.34 % 549.0 C 1017.52 37.62
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P4-2: 228T268
CONTINGENCY 'DVP_P4-2: 228T268'
 OPEN BRANCH FROM BUS 314286 TO BUS 314303 CKT 1   /*6CHESTF A    230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314303 TO BUS 315074 CKT 1   /*6HOPEWLL     230.0 - 1HOPCGN1      13.8
 OPEN BRANCH FROM BUS 314303 TO BUS 315075 CKT 1   /*6HOPEWLL     230.0 - 1HOPCGN2      13.8
 OPEN BUS 315074                                   /*1HOPCGN1      13.8
 OPEN BUS 315075                                   /*1HOPCGN2      13.8
END
Breaker AC 153.35 % 164.19 % 549.0 C 901.4 60.68
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P4-2: G5T228
CONTINGENCY 'DVP_P4-2: G5T228'
 OPEN BRANCH FROM BUS 314286 TO BUS 314303 CKT 1   /*6CHESTF A    230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314286 TO BUS 315060 CKT 1   /*6CHESTF A    230.0 - 1CHESTF5      22.0
 OPEN BUS 315060                                   /*1CHESTF5      22.0
END
Breaker AC 128.84 % 139.68 % 549.0 C 766.84 60.68
DVP 6ELMONT-8ELMONT 230.0/500.0 kV Ckt 1 transformer
314218 to 314908 ckt 1
DVP_P4-2: H2T557
CONTINGENCY 'DVP_P4-2: H2T557'
 OPEN BRANCH FROM BUS 314214 TO BUS 314903 CKT 1   /*6CHCKAHM     230.0 - 8CHCKAHM     500.0
 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
END
Breaker AC 162.99 % 164.41 % 1050.6 C 1727.29 33.18
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P4-2: 211T2124
CONTINGENCY 'DVP_P4-2: 211T2124'
 OPEN BRANCH FROM BUS 314269 TO BUS 314291 CKT 1   /*6PRGEORG     230.0 - 3PRGEORG     115.0
 OPEN BRANCH FROM BUS 314269 TO BUS 314303 CKT 1   /*6PRGEORG     230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314287 TO BUS 314303 CKT 1   /*6CHESTF B    230.0 - 6HOPEWLL     230.0
 OPEN BUS 314269                                   /*6PRGEORG     230.0
END
Breaker AC 145.71 % 157.75 % 549.0 C 866.05 66.8
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 116.38 % 119.11 % 268.1 C 319.33 7.86
DVP 6CHESTF A-3CHESTFLD 230.0/115.0 kV Ckt 1 transformer
314286 to 314284 ckt 1
DVP_P4-2: 211T2124
CONTINGENCY 'DVP_P4-2: 211T2124'
 OPEN BRANCH FROM BUS 314269 TO BUS 314291 CKT 1   /*6PRGEORG     230.0 - 3PRGEORG     115.0
 OPEN BRANCH FROM BUS 314269 TO BUS 314303 CKT 1   /*6PRGEORG     230.0 - 6HOPEWLL     230.0
 OPEN BRANCH FROM BUS 314287 TO BUS 314303 CKT 1   /*6CHESTF B    230.0 - 6HOPEWLL     230.0
 OPEN BUS 314269                                   /*6PRGEORG     230.0
END
Breaker AC 97.31 % 100.19 % 268.1 C 268.61 9.3
DVP 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line
314903 to 314908 ckt 1
DVP_P4-2: 563T576
CONTINGENCY 'DVP_P4-2: 563T576'
 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
END
Breaker AC 114.84 % 114.84 % 3144.0 C 3610.57 39.47
DVP AD1-151 TAP-6HOPEWLL 230.0 kV Ckt 1 line
935160 to 314303 ckt 1
DVP_P4-2: 240T2041
CONTINGENCY 'DVP_P4-2: 240T2041'
 OPEN BRANCH FROM BUS 314303 TO BUS 925330 CKT 2   /*6HOPEWLL     230.0 - AB2-190 TAP  230.0
 OPEN BUS 315077                                   /*1HOPHCF1      13.8
 OPEN BUS 315078                                   /*1HOPHCF2      13.8
 OPEN BUS 315079                                   /*1HOPHCF3      13.8
 OPEN BUS 315080                                   /*1HOPHCF4      13.8
END
Breaker AC 104.69 % 108.66 % 830.0 C 901.88 33.87
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P1-2: LN 259
CONTINGENCY 'DVP_P1-2: LN 259'
 OPEN BRANCH FROM BUS 314276 TO BUS 314287 CKT 1   /*6BASIN       230.0 - 6CHESTF B    230.0
END
Single AC 134.8 % 139.4 % 449.32 B 626.35 20.74
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P1-2: LN 211
CONTINGENCY 'DVP_P1-2: LN 211'
 OPEN BRANCH FROM BUS 314287 TO BUS 314303 CKT 1   /*6CHESTF B    230.0 - 6HOPEWLL     230.0
END
Single AC 131.93 % 138.55 % 449.32 B 622.53 29.92
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
Base Case Single AC 112.03 % 116.22 % 449.32 A 522.2 19.03
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 131.44 % 136.05 % 449.32 B 611.3 21.26
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P1-2: LN 228
CONTINGENCY 'DVP_P1-2: LN 228'
 OPEN BRANCH FROM BUS 314286 TO BUS 314303 CKT 1   /*6CHESTF A    230.0 - 6HOPEWLL     230.0
END
Single AC 129.31 % 135.69 % 449.32 B 609.68 30.95
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
Base Case Single AC 102.06 % 106.39 % 449.32 A 478.03 19.84
DVP 6CHESTF B-6BASIN 230.0 kV Ckt 1 line
314287 to 314276 ckt 1
DVP_P1-2: LN 563
CONTINGENCY 'DVP_P1-2: LN 563'
 OPEN BRANCH FROM BUS 314902 TO BUS 314914 CKT 1   /*8CARSON      500.0 - 8MDLTHAN     500.0
END
Single AC 121.42 % 122.64 % 663.64 B 813.89 8.05

Light Load Analysis

The Queue Project was evaluated as a 150.0 MW (Capacity 76.5 MW) injection in the Dominion area. Project was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Potential light load period network impacts 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.

(No impacts were found for this analysis)

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
b2990 PJM Baseline Upgrade b2990. $350,000
n6130 Rebuild 12.4 miles of 230 kV Line 259 from Chesterfield to Basin with 2-636 ACSR. $31,000,000
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
b3694.11 Reconductor approximately 2.9 miles of 230 kV Line #228 Chesterfield Hopewell to achieve a minimum summer emergency rating of 1046 MVA. $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
n8149 Add Additional 500/230 kV Transformer at Elmont Substation $22,000,000
n8056 Wreck and rebuild the existing 115 kV Line and Add new 230 kV Circuit $32,493,499
b3692 Rebuild approximately 27.7-miles of 500 kV transmission line from Elmont to Chickahominy. $0

Attachments

Attachment 1: One Line Diagram for Queue Project AF2-065.

AF2-065.PNG

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Uprate Chain
Project Project Status MFO MWE MWC Disposition
AE2-270 Active 150.0 150.0 150.0 Transition Cycle 1
AF2-065 Active 300.0 150.0 76.5 Transition Cycle 1

Conclusion

The Transition Sort load flow retool results indicate that AF2-065 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.