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AG1-160 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 11:01

Rogers Road 500 kV

30.0 MW Capacity / 75.0 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 AG1-160 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 Dominion zone Greensville County, Virginia. The installed facilities will have a total capability of 75.0 MW with 30.0 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AG1-160
Project Name Rogers Road 500 kV
Developer Name Virginia Electric & Power Company
State Virginia
County Greensville
Transmission Owner Dominion
MFO 75.0 MW
MWE 75.0 MW
MWC 30.0 MW
Fuel Type Storage
Basecase Study Year 2024

Point of Interconnection

AG1-160 "Rogers Road 500 kV" will interconnect with the Dominion transmission system. The primary POI is a direct connect to the Rogers Road 500 kV substation.

 

Summer Peak Analysis

The Queue Project was evaluated as a 75.0 MW (Capacity 30.0 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 6CARSON-6CHRL249 230.0 kV Ckt 1 line
314282 to 314285 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 163.08 % 164.16 % 684.0 C 1122.83 7.56
DVP 6CHRL249-6LOCKS 230.0 kV Ckt 1 line
314285 to 314316 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 160.26 % 161.34 % 684.0 C 1103.57 7.56
DVP 8CARSON-6CARSON 500.0/230.0 kV Ckt 1 transformer
314902 to 314282 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 153.12 % 154.57 % 1039.7 C 1607.07 16.03
DVP 6LOCKS-6HARR205 230.0 kV Ckt 1 line
314316 to 314301 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 144.54 % 145.42 % 541.0 C 786.72 5.94
DVP 6HARR205-6TYLER 230.0 kV Ckt 1 line
314301 to 314346 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 137.87 % 138.77 % 541.0 C 750.76 5.94
DVP 6POE-6HARROWG 230.0 kV Ckt 1 line
314331 to 314299 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 130.61 % 131.49 % 541.0 C 711.36 5.57
DVP 6HARROWG-6TYLER1 230.0 kV Ckt 1 line
314299 to 314263 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 130.6 % 131.48 % 541.0 C 711.3 5.57

Light Load Analysis

The Queue Project was evaluated as a 75.0 MW (Capacity 30.0 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
b3694.8 Partial wreck and rebuild 10.34 miles of 230 kV line #249 Carson-Locks to achieve a minimum summer emergency rating of 1047 MVA. $15,365,000
b3694.7 Energize in-service spare 500-230 kV Carson Tx#1 $1,000,000
s2609.8 Rebuild approximately 10 miles segment of 230kV Line #205 from Locks to Tyler and upgrade the terminal equipment. The minimum summer normal rating of the line segment will be 1572MVA. $27,000,000
n6179 Rebuild 12.3 miles of 230 kV Line 2003 from Poe to Harrowgate with 2-636 ACSR. $30,750,000
n6178 Rebuild 4.5 miles of 230 kV Line 2003 from Harrowgate to Tyler with 2-636 ACSR. $11,250,000

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-160 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.