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AG1-000B Transition Sort Retool Results -- Qualifies for Expedited Process

v1.00 released 2023-12-14 10:56

Surry-Hopewell 230 kV

89.0 MW Capacity / 89.0 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, 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.

Eligible for Expedited Process:

The AG1-000B project has been determined to meet the initial screen to be eligible for the Expedited Process according to the Expedited Process Eligibility requirements in Tariff Part VII, Subpart B, section 304. Though your project initially screens as eligible for the Expedited Process, there are several conditions identified under Tariff Part VII, Subpart B, section 304 (B) that could shift your project from the Expedited Process into TC1. Please see "Expedited Process 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 to Note: 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.

Next Steps for your project:

Refreshed Retool for Projects in Expedited Process:

After the initial sorting retool, PJM will conduct a refreshed analysis of the projects in the Expedited Process with the Transition Cycle #1 projects lifted from the study case model. After this refreshed analysis (including load flow, short circuit and stability analysis), retooled System Impact Study reports can be delivered to the Project Developers. Once the project's Facilities Study report is completed (and no conditions exist that would require the project to shift to TC1, see "Expedited Process Rules" below), the final GIA will be tendered along with the Facilities Study report.

Expedited Process Rules:

Though your project initially screens to be eligible for the Expedited Process, there are several conditions identified under Tariff Part VII, Subpart B, section 304 (B) that could shift your project into TC1 until the final GIA is tendered.

  • If stability analysis or a sag study is completed during the expedited process, and it is determined that a project has an estimated Network Upgrade cost greater than $5,000,000, the project will be removed from the expedited process and shifted to Transition Cycle #1.
  • If it is determined during the Facilities Study that the cost of a Network Upgrade is now estimated to be greater than $5,000,000, the project will be removed from the expedited process and shifted to Transition Cycle #1.
  • 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.
  • If the interconnected Transmission Owner identifies the need for a Network Upgrade due to a violation of their criteria that is in excess of $5M, the project will be removed from the expedited process and shifted to Transition Cycle #1.

General

The Interconnection Customer (IC), has proposed a Solar; Storage generating facility located in the Dominion zone — Surry County, Virginia. The installed facilities will have a total capability of 89.0 MW with 89.0 MW of this output being recognized by PJM as Capacity. The proposed in-service date for this project is Thursday, August 03, 2023. This study does not imply a TO commitment to this in-service date.

AF2-304 slid queues and is now identified as AG1-000B.  AG1-000B is claiming CIRs from deactivated generator Hopewell Co-generation.

Project Information

Queue Number

AG1-000B (AF2-304)

Project Name

Surry-Hopewell 230 kV

Developer Name

Bear Island Solar LLC

State

Virginia

County

Surry

Transmission Owner

Dominion

MFO

89.0 MW

MWE

89.0 MW

MWC

89.0 MW

Fuel Type

Solar; Storage

Basecase Study Year

2024

 

Point of Interconnection

AG1-000B (AF2-304) will interconnect with the Dominion transmission system. The primary Point of Interconnection (POI) is a single line tap between Surry 230 kV substation and Hopewell 230 kV substation.

 

Summer Peak Analysis

The Queue Project was evaluated as a 89.0 MW (Capacity 89.0 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: 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.

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 6WALR209-6LIGH209 230.0 kV Ckt 1 line
314415 to 314391 ckt 1
DVP_P1-2: LN 567
CONTINGENCY 'DVP_P1-2: LN 567'
 OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1                /*8CHCKAHM     500.0 - 8SURRY       500.0
 SET POSTCONTRATING 2598 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
 SET PRECONTRATING 2538 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
END
Single AC 100.01 % 101.1 % 441.8 B 446.66 5.66
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 BRANCH FROM BUS 942550 TO BUS 925330 CKT 2   /*AE2-270 TAP  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
 OPEN BUS 316132                                   /*AB2-190 C    230.0
 OPEN BUS 925332                                   /*AB2-190 E    230.0
END
Breaker AC 107.42 % 109.84 % 830.0 C 911.66 20.04

Light Load Analysis

The Queue Project was evaluated as a 89.0 MW (Capacity 89.0 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: 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.

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 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
 SET POSTCONTRATING 876 BRANCH FROM BUS 314269 TO BUS 314303 CKT 1 /*6PRGEORG     230.0 - 6HOPEWLL     230.0
 SET PRECONTRATING 797 BRANCH FROM BUS 314269 TO BUS 314303 CKT 1 /*6PRGEORG     230.0 - 6HOPEWLL     230.0
END
Single AC 132.5 % 136.59 % 449.32 B 613.73 19.63
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P1-2: LN 567
CONTINGENCY 'DVP_P1-2: LN 567'
 OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1                /*8CHCKAHM     500.0 - 8SURRY       500.0
 SET POSTCONTRATING 2598 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
 SET PRECONTRATING 2538 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
END
Single AC 137.21 % 139.74 % 449.32 B 627.88 13.44
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 110.29 % 114.29 % 549.0 C 627.45 22.26
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
DVP_P4-2: 562T563
CONTINGENCY 'DVP_P4-2: 562T563'
 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 TAP  500.0
END
Breaker AC 100.74 % 103.03 % 549.0 C 565.63 12.9
DVP 6HOPEWLL-6CHESTF A 230.0 kV Ckt 1 line
314303 to 314286 ckt 1
Base Case Single AC 99.95 % 102.44 % 449.32 A 460.28 12.33
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 128.71 % 133.14 % 449.32 B 598.22 20.53
DVP 6HOPEWLL-6CHESTF B 230.0 kV Ckt 1 line
314303 to 314287 ckt 1
DVP_P1-3: 8CARSON-TX#2
CONTINGENCY 'DVP_P1-3: 8CARSON-TX#2'
 OPEN BRANCH FROM BUS 314282 TO BUS 314902 CKT 1   /*6CARSON      230.0 - 8CARSON      500.0
END
Single AC 98.19 % 100.98 % 449.32 B 453.72 12.68
DVP 6WALR209-6LIGH209 230.0 kV Ckt 1 line
314415 to 314391 ckt 1
DVP_P1-2: LN 567
CONTINGENCY 'DVP_P1-2: LN 567'
 OPEN BRANCH FROM BUS 314903 TO BUS 314924 CKT 1                /*8CHCKAHM     500.0 - 8SURRY       500.0
 SET POSTCONTRATING 2598 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
 SET PRECONTRATING 2538 BRANCH FROM BUS 314903 TO BUS 314908 CKT 1 /*8CHCKAHM     500.0 - 8ELMONT      500.0
END
Single AC 113.48 % 114.36 % 441.8 B 505.24 4.74
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 107.27 % 111.65 % 219.8 C 245.41 9.85
DVP 6FORK UNION-AF2-397 TAP 230.0 kV Ckt 1 line
313707 to 961060 ckt 1
DVP_P1-2: LN 534
CONTINGENCY 'DVP_P1-2: LN 534'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS       500.0 - 8VALLEY      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS       500.0 - 8VALLEY      500.0
END
Single AC 99.63 % 100.01 % 661.76 B 661.83 3.87
DVP AF2-397 TAP-6MTEAGLE 230.0 kV Ckt 1 line
961060 to 314765 ckt 1
DVP_P1-2: LN 534
CONTINGENCY 'DVP_P1-2: LN 534'
 OPEN BRANCH FROM BUS 314907 TO BUS 314910 CKT 1                /*8DOOMS       500.0 - 8CUNINGHAM   500.0
 SET POSTCONTRATING 2858 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS       500.0 - 8VALLEY      500.0
 SET PRECONTRATING 2650 BRANCH FROM BUS 314907 TO BUS 314926 CKT 1 /*8DOOMS       500.0 - 8VALLEY      500.0
END
Single AC 99.66 % 100.04 % 661.76 B 662.02 3.87

System Reinforcements

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

Important to Note: 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.

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
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
b3694.12 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
n7199 Rebuild 1.63 miles of 230 kV Line 2197 from Hopewell to Colonial Trail with 2-636 ACSR. $2,445,000
n6185.2 Rebuild 17.42 miles of 230 kV Line 2028 from Fork Union to Mount Eagle with 2-636 ACSR. $26,130,000
b3056 PJM Baseline Upgrade b3056. Partial Rebuild 230 kV Line #2113 Waller to Lightfoot. $0

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-000B is eligible for the Expedited Process per PJM Tariff Part VII, Subpart B, section 304 (A). See next steps for your project in the "Introduction" section above.