Export to CSV

AG1-082 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 10:50

Ahoskie 34.5 kV

12.0 MW Capacity / 20.0 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 AG1-082 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 Solar; Storage generating facility located in the Dominion zone Hertford County, North Carolina. The installed facilities will have a total capability of 20.0 MW with 12.0 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AG1-082
Project Name Ahoskie 34.5 kV
Developer Name NC1 Ahoskie Central, LLC
State North Carolina
County Hertford
Transmission Owner Dominion
MFO 20.0 MW
MWE 20.0 MW
MWC 12.0 MW
Fuel Type Solar; Storage
Basecase Study Year 2024

Point of Interconnection

AG1-082 will interconnect with the Dominion transmission system at the Ahoskie 115 kV substation.

 

Summer Peak Analysis

The Queue Project was evaluated as a 20.0 MW (Capacity 12.0 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 3AHOSKIE-3EARLEYS 115.0 kV Ckt 1 line
314551 to 314568 ckt 1
DVP_P1-2: LN 108-A
CONTINGENCY 'DVP_P1-2: LN 108-A'
 OPEN BRANCH FROM BUS 314558 TO BUS 964800 CKT 1   /*3BOYKINS     115.0 - AG1-343 TAP  115.0
END
Single AC 163.51 % 171.6 % 141.0 B 241.96 12.0
DVP 3AHOSKIE-3EARLEYS 115.0 kV Ckt 1 line
314551 to 314568 ckt 1
DVP_P1-2: LN 108-B
CONTINGENCY 'DVP_P1-2: LN 108-B'
 OPEN BRANCH FROM BUS 314580 TO BUS 314589 CKT 1   /*3MAPLETN     115.0 - 3MURPHYS     115.0
 OPEN BRANCH FROM BUS 314580 TO BUS 957520 CKT 1   /*3MAPLETN     115.0 - AF2-046 TAP  115.0
 OPEN BRANCH FROM BUS 964800 TO BUS 314589 CKT 1   /*AG1-343 TAP  115.0 - 3MURPHYS     115.0
 OPEN BUS 314580                                   /*3MAPLETN     115.0
 OPEN BUS 314589                                   /*3MURPHYS     115.0
 OPEN BUS 900672                                   /*V4-068 E     115.0
END
Single AC 137.39 % 145.54 % 141.0 B 205.21 12.0
DVP AG1-343 TAP-3BOYKINS 115.0 kV Ckt 1 line
964800 to 314558 ckt 1
DVP_P1-2: LN 246
CONTINGENCY 'DVP_P1-2: LN 246'
 OPEN BRANCH FROM BUS 314537 TO BUS 314575 CKT 1                /*6SUFFOLK     230.0 - 6NUCO TP     230.0
 OPEN BRANCH FROM BUS 314569 TO BUS 314575 CKT 1                /*6EARLEYS     230.0 - 6NUCO TP     230.0
 OPEN BRANCH FROM BUS 314575 TO BUS 314590 CKT 1                /*6NUCO TP     230.0 - 6NUCOR       230.0
 OPEN BUS 314575                                                /*6NUCO TP     230.0
 OPEN BUS 314590                                                /*6NUCOR       230.0
 SET POSTCONTRATING 876 BRANCH FROM BUS 314537 TO BUS 314648 CKT 1 /*6SUFFOLK     230.0 - 6SUNBURY     230.0
 SET PRECONTRATING 813 BRANCH FROM BUS 314537 TO BUS 314648 CKT 1 /*6SUFFOLK     230.0 - 6SUNBURY     230.0
END
Single AC 115.51 % 117.81 % 116.56 B 137.32 2.7
DVP AG1-343 TAP-3BOYKINS 115.0 kV Ckt 1 line
964800 to 314558 ckt 1
314575 6NUCO TP 230 314537 6SUFFOLK 230 1
CONTINGENCY '314575 6NUCO TP      230  314537 6SUFFOLK   230  1'  /* Auto-generated
  /* 314575 6NUCO TP      230  314537 6SUFFOLK   230  1
END
Single AC 113.31 % 115.61 % 116.56 B 134.75 2.7
DVP AG1-343 TAP-3BOYKINS 115.0 kV Ckt 1 line
964800 to 314558 ckt 1
Base Case Single AC 100.8 % 102.96 % 116.56 A 120.01 2.53
DVP 3EARLEYS-6EARLEYS 115.0/230.0 kV Ckt 2 transformer
314568 to 314569 ckt 2
DVP_P1-3: 6EARLEYS-TX#3
CONTINGENCY 'DVP_P1-3: 6EARLEYS-TX#3'
 OPEN BRANCH FROM BUS 314568 TO BUS 314569 CKT 1   /*3EARLEYS     115.0 - 6EARLEYS     230.0
END
Single AC 108.83 % 112.38 % 175.78 B 197.53 6.19
DVP 3MURPHYS-AG1-343 TAP 115.0 kV Ckt 1 line
314589 to 964800 ckt 1
DVP_P1-2: LN 246
CONTINGENCY 'DVP_P1-2: LN 246'
 OPEN BRANCH FROM BUS 314537 TO BUS 314575 CKT 1                /*6SUFFOLK     230.0 - 6NUCO TP     230.0
 OPEN BRANCH FROM BUS 314569 TO BUS 314575 CKT 1                /*6EARLEYS     230.0 - 6NUCO TP     230.0
 OPEN BRANCH FROM BUS 314575 TO BUS 314590 CKT 1                /*6NUCO TP     230.0 - 6NUCOR       230.0
 OPEN BUS 314575                                                /*6NUCO TP     230.0
 OPEN BUS 314590                                                /*6NUCOR       230.0
 SET POSTCONTRATING 876 BRANCH FROM BUS 314537 TO BUS 314648 CKT 1 /*6SUFFOLK     230.0 - 6SUNBURY     230.0
 SET PRECONTRATING 813 BRANCH FROM BUS 314537 TO BUS 314648 CKT 1 /*6SUFFOLK     230.0 - 6SUNBURY     230.0
END
Single AC 115.87 % 118.18 % 116.56 B 137.76 2.7
DVP 3MURPHYS-AG1-343 TAP 115.0 kV Ckt 1 line
314589 to 964800 ckt 1
314575 6NUCO TP 230 314537 6SUFFOLK 230 1
CONTINGENCY '314575 6NUCO TP      230  314537 6SUFFOLK   230  1'  /* Auto-generated
  /* 314575 6NUCO TP      230  314537 6SUFFOLK   230  1
END
Single AC 113.6 % 115.91 % 116.56 B 135.11 2.7
DVP 8CHCKAHM-8ELMONT 500.0 kV Ckt 1 line
314903 to 314908 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
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TAP  500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314902 TO BUS 940640 CKT 1 /*8CARSON      500.0 - AE2-051 TAP  500.0
END
Single AC 99.92 % 100.02 % 2442.12 B 2442.71 2.81
DVP 3WITAKRS-3CONSLDL 115.0 kV Ckt 1 line
314623 to 313854 ckt 1
DVP_P1-2: LN 239
CONTINGENCY 'DVP_P1-2: LN 239'
 OPEN BRANCH FROM BUS 314579 TO BUS 314583 CKT 1   /*6HORNRTN     230.0 - 6LAKEVEW     230.0
 OPEN BRANCH FROM BUS 314579 TO BUS 314605 CKT 1   /*6HORNRTN     230.0 - 6ROSEMRY     230.0
 OPEN BUS 314605                                   /*6ROSEMRY     230.0
 OPEN BUS 314627                                   /*1ROSEMRY      13.8
 OPEN BUS 315136                                   /*1ROSEMG1      13.8
 OPEN BUS 315137                                   /*1ROSEMS1      13.8
 OPEN BUS 315138                                   /*1ROSEMG2      13.8
END
Single AC 100.0 % 100.57 % 165.44 B 166.39 0.96
DVP 3CONSLDL-3BTLEBRO 115.0 kV Ckt 1 line
313854 to 314554 ckt 1
DVP_P1-2: LN 239
CONTINGENCY 'DVP_P1-2: LN 239'
 OPEN BRANCH FROM BUS 314579 TO BUS 314583 CKT 1   /*6HORNRTN     230.0 - 6LAKEVEW     230.0
 OPEN BRANCH FROM BUS 314579 TO BUS 314605 CKT 1   /*6HORNRTN     230.0 - 6ROSEMRY     230.0
 OPEN BUS 314605                                   /*6ROSEMRY     230.0
 OPEN BUS 314627                                   /*1ROSEMRY      13.8
 OPEN BUS 315136                                   /*1ROSEMG1      13.8
 OPEN BUS 315137                                   /*1ROSEMS1      13.8
 OPEN BUS 315138                                   /*1ROSEMG2      13.8
END
Single AC 99.99 % 100.57 % 165.44 B 166.38 0.96
DVP 3MURPHYS-AG1-343 TAP 115.0 kV Ckt 1 line
314589 to 964800 ckt 1
Base Case Single AC 100.92 % 103.08 % 116.56 A 120.15 2.53
DVP 3EARLEYS-6EARLEYS 115.0/230.0 kV Ckt 2 transformer
314568 to 314569 ckt 2
DVP_P4-2: 201262
CONTINGENCY 'DVP_P4-2: 201262'
 OPEN BRANCH FROM BUS 314266 TO BUS 314569 CKT 1   /*6NORTHAMPTON 230.0 - 6EARLEYS     230.0
 OPEN BRANCH FROM BUS 314266 TO BUS 314599 CKT 1   /*6NORTHAMPTON 230.0 - 6ROA VAL     230.0
 OPEN BRANCH FROM BUS 314568 TO BUS 314569 CKT 1   /*3EARLEYS     115.0 - 6EARLEYS     230.0
 OPEN BUS 314266                                   /*6NORTHAMPTON 230.0
END
Breaker AC 157.01 % 161.12 % 208.0 C 335.14 10.05
DVP 3EARLEYS-6EARLEYS 115.0/230.0 kV Ckt 2 transformer
314568 to 314569 ckt 2
DVP_P4-2: WT2171
CONTINGENCY 'DVP_P4-2: WT2171'
 OPEN BRANCH FROM BUS 313709 TO BUS 313710 CKT 1    /*6HOLLOMAN    230.0 - 1HOLLOMAN     34.5
 OPEN BRANCH FROM BUS 313709 TO BUS 313710 CKT 2    /*6HOLLOMAN    230.0 - 1HOLLOMAN     34.5
 OPEN BRANCH FROM BUS 313709 TO BUS 314569 CKT Z1   /*6HOLLOMAN    230.0 - 6EARLEYS     230.0
 OPEN BRANCH FROM BUS 313710 TO BUS 315602 CKT 1    /*1HOLLOMAN     34.5 - 1HOLLOMANSOL   0.7
 OPEN BRANCH FROM BUS 314568 TO BUS 314569 CKT 1    /*3EARLEYS     115.0 - 6EARLEYS     230.0
 OPEN BUS 313709                                    /*6HOLLOMAN    230.0
 OPEN BUS 313710                                    /*1HOLLOMAN     34.5
 OPEN BUS 315602                                    /*1HOLLOMANSOL   0.7
 OPEN BUS 918512                                    /*AA1-065 E OP   0.7
END
Breaker AC 137.87 % 142.79 % 208.0 C 297.0 10.32
DVP 3EARLEYS-6EARLEYS 115.0/230.0 kV Ckt 1 transformer
314568 to 314569 ckt 1
DVP_P4-2: 217162
CONTINGENCY 'DVP_P4-2: 217162'
 OPEN BRANCH FROM BUS 313709 TO BUS 313710 CKT 1    /*6HOLLOMAN    230.0 - 1HOLLOMAN     34.5
 OPEN BRANCH FROM BUS 313709 TO BUS 313710 CKT 2    /*6HOLLOMAN    230.0 - 1HOLLOMAN     34.5
 OPEN BRANCH FROM BUS 313709 TO BUS 314569 CKT Z1   /*6HOLLOMAN    230.0 - 6EARLEYS     230.0
 OPEN BRANCH FROM BUS 313710 TO BUS 315602 CKT 1    /*1HOLLOMAN     34.5 - 1HOLLOMANSOL   0.7
 OPEN BRANCH FROM BUS 314568 TO BUS 314569 CKT 2    /*3EARLEYS     115.0 - 6EARLEYS     230.0
 OPEN BUS 313709                                    /*6HOLLOMAN    230.0
 OPEN BUS 313710                                    /*1HOLLOMAN     34.5
 OPEN BUS 315602                                    /*1HOLLOMANSOL   0.7
 OPEN BUS 918512                                    /*AA1-065 E OP   0.7
END
Breaker AC 123.92 % 128.34 % 231.7 C 297.37 10.33
CPLE/DVP 3BTLEBRO-3ROCKYMT115T 115.0 kV Ckt 1 line
314554 to 304223 ckt 1
DVP_P7-1: LN 2058-2181
CONTINGENCY 'DVP_P7-1: LN 2058-2181'
 OPEN BRANCH FROM BUS 304222 TO BUS 313845 CKT 1   /*6ROCKYMT230T 230.0 - 6HATHAWAY    230.0
 OPEN BRANCH FROM BUS 304226 TO BUS 314591 CKT 1   /*6PA-RMOUNT#4 230.0 - 6NASH        230.0
 OPEN BRANCH FROM BUS 313844 TO BUS 313845 CKT 2   /*3HATHAWAY    115.0 - 6HATHAWAY    230.0
 OPEN BRANCH FROM BUS 313845 TO BUS 314591 CKT 1   /*6HATHAWAY    230.0 - 6NASH        230.0
 OPEN BUS 304226                                   /*6PA-RMOUNT#4 230.0
 OPEN BUS 314591                                   /*6NASH        230.0
END
Tower AC 250.72 % 251.66 % 164.0 B 412.73 1.83

Light Load Analysis

The Queue Project was evaluated as a 20.0 MW (Capacity 12.0 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.

(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
n7540 Reconductor 115 kV Line #136 from Earleys to Ahoskie. $4,676,000
n8237 Reconductor 2.15 miles of 115 kV Line 108 from Boykins to AG1-343 with 768.2 ACSS 250 C. Replace Wave Trap and Breaker Switch at Boykins terminal. $1,640,000
n7201 Reconductor 3.98 miles of 115 kV Line 1001 from Consolidated DSL to Battleboro with 636 ACSR. $2,388,000
n7203 Rebuild 0.41 miles of 115 kV Line 1001 from Whitakers to Consolidated Diesel with 636 ACSR. $533,000
n7541 230/115 kV Transformer Addition $6,000,000
n8235 Reconductor 10.36 miles of 115 kV Line 108 from Murphys to AG1-343 with 768.2 ACSS 250 C. $6,216,000
n6618.1 Hathaway 115 kV Bus Split. $20,749
n6118 Upgrade the breaker leads at DVPs Battleboro terminal will bring the rating to 239/239/239 MVA (Limited by terminal equipment at Rocky Mount) $100,000
(TBD) Reconductor 8.5 miles RockyMt-Battleborro with single 795 ACSS-TW per phase, upgrade disconnect switches and CT ratios. $31,000,000
s2825.2 Rebuild line #55 Tarboro to Hart Mills. $3,500,000
s2825.1 Rebuild entire line#2167 Edgecombe NUG to Hathaway. $39,500,000
b3692 Rebuild approximately 27.7-miles of 500 kV transmission line from Elmont to Chickahominy. $0

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-082 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.