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AG1-302 Transition Sort Retool Results -- Qualifies for Expedited Process

v1.00 released 2023-12-14 10:46

Olive-Reynolds #1 345 kV

180.0 MW Capacity / 300.0 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 AG1-302 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 generating facility located in the AEP zone Pulaski County, Indiana. The installed facilities will have a total capability of 300.0 MW with 180.0 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AG1-302
Project Name Olive-Reynolds #1 345 kV
Developer Name Mammoth Central II LLC
State Indiana
County Pulaski
Transmission Owner AEP
MFO 300.0 MW
MWE 300.0 MW
MWC 180.0 MW
Fuel Type Solar
Basecase Study Year 2024

Point of Interconnection

AG1-302 will interconnect on the AEP transmission system tapping the Reynolds – Olive 345 kV line.

 

Summer Peak Analysis

The Queue Project was evaluated as a 300.0 MW (Capacity 180.0 MW) injection in the AEP 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
AEP AF2-137 TAP-05MARYSV 765.0 kV Ckt 1 line
958430 to 242928 ckt 1
AEP_P1-2_#709_546
CONTINGENCY 'AEP_P1-2_#709_546'
 OPEN BRANCH FROM BUS 242924 TO BUS 243208 CKT 1   /*05HANG R     765.0 - 05JEFRSO     765.0
END
Single AC 101.17 % 101.95 % 4142.0 B 4222.69 41.57
AEP/OVEC 05JEFRSO-06CLIFTY 345.0 kV Ckt Z1 line
242865 to 248000 ckt Z1
AEP_P4_#6189_05HANG R 765_D1
CONTINGENCY 'AEP_P4_#6189_05HANG R 765_D1'
 OPEN BRANCH FROM BUS 242921 TO BUS 242924 CKT 1   /*05CORNU      765.0 - 05HANG R     765.0
 OPEN BRANCH FROM BUS 242921 TO BUS 242934 CKT 1   /*05CORNU      765.0 - 05CORNU      345.0
 OPEN BRANCH FROM BUS 242924 TO BUS 243208 CKT 1   /*05HANG R     765.0 - 05JEFRSO     765.0
 REMOVE UNIT 1A FROM BUS 247245                    /*05HRKG1A      18.0
 REMOVE UNIT 1B FROM BUS 247246                    /*05HRKG1B      18.0
 REMOVE UNIT 1S FROM BUS 247247                    /*05HRKG1S      18.0
 REMOVE UNIT 2A FROM BUS 247248                    /*05HRKG2A      18.0
 REMOVE UNIT 2B FROM BUS 247249                    /*05HRKG2B      18.0
 REMOVE UNIT 2S FROM BUS 247250                    /*05HRKG2S      18.0
END
Breaker AC 123.68 % 125.68 % 2255.0 B 2834.08 38.51
AEP AF2-137 TAP-05MARYSV 765.0 kV Ckt 1 line
958430 to 242928 ckt 1
AEP_P4_#7334_05JEFRSO 765_A2
CONTINGENCY 'AEP_P4_#7334_05JEFRSO 765_A2'
 OPEN BRANCH FROM BUS 242865 TO BUS 243208 CKT 2    /*05JEFRSO     345.0 - 05JEFRSO     765.0
 OPEN BRANCH FROM BUS 242865 TO BUS 248000 CKT Z1   /*05JEFRSO     345.0 - 06CLIFTY     345.0
 OPEN BRANCH FROM BUS 242924 TO BUS 243208 CKT 1    /*05HANG R     765.0 - 05JEFRSO     765.0
END
Breaker AC 120.74 % 121.29 % 4142.0 B 5023.87 76.67
AEP AF2-137 TAP-05MARYSV 765.0 kV Ckt 1 line
958430 to 242928 ckt 1
AEP_P4_#6189_05HANG R 765_D1
CONTINGENCY 'AEP_P4_#6189_05HANG R 765_D1'
 OPEN BRANCH FROM BUS 242921 TO BUS 242924 CKT 1   /*05CORNU      765.0 - 05HANG R     765.0
 OPEN BRANCH FROM BUS 242921 TO BUS 242934 CKT 1   /*05CORNU      765.0 - 05CORNU      345.0
 OPEN BRANCH FROM BUS 242924 TO BUS 243208 CKT 1   /*05HANG R     765.0 - 05JEFRSO     765.0
 REMOVE UNIT 1A FROM BUS 247245                    /*05HRKG1A      18.0
 REMOVE UNIT 1B FROM BUS 247246                    /*05HRKG1B      18.0
 REMOVE UNIT 1S FROM BUS 247247                    /*05HRKG1S      18.0
 REMOVE UNIT 2A FROM BUS 247248                    /*05HRKG2A      18.0
 REMOVE UNIT 2B FROM BUS 247249                    /*05HRKG2B      18.0
 REMOVE UNIT 2S FROM BUS 247250                    /*05HRKG2S      18.0
END
Breaker AC 112.38 % 112.95 % 4142.0 B 4678.31 69.14
AEP AF2-137 TAP-05MARYSV 765.0 kV Ckt 1 line
958430 to 242928 ckt 1
AEP_P4_#1760_05JEFRSO 765_A
CONTINGENCY 'AEP_P4_#1760_05JEFRSO 765_A'
 OPEN BRANCH FROM BUS 242924 TO BUS 243208 CKT 1   /*05HANG R     765.0 - 05JEFRSO     765.0
 OPEN BRANCH FROM BUS 243207 TO BUS 243208 CKT 1   /*05GRNTWN     765.0 - 05JEFRSO     765.0
END
Breaker AC 111.53 % 112.09 % 4142.0 B 4642.77 75.48

Light Load Analysis

At this time light load analysis not required for this project.

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
b2878 Upgrade the Clifty Creek 345 kV risers $3,675,000
n4106 Replace Two (2) Switches at the Clifty Creek 345 kV Station $412,916
n4106.3 Extend One (1) Tower on the Jefferson - Clifty Creek (IKEC) 345 kV Circuit $409,714
n4106.5 Replace Clifty Bus 5"0 AL Tubular Sch 40 $100,000
b3748 Replace four Clifty Creek 345 kV 3000A switches with 5000A 345 kV switches $850,000
n3985 Upgrade three Marysville Wavetraps ( 3000A) $900,000
n7467 Replace one Marysville 765kV CB $3,000,000

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-302 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.