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AG1-109 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

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

Valley 138 kV

25.0 MW Capacity / 0.0 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 AG1-109 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 Storage generating facility located in the AEP zone Van Buren County, Michigan. This project is an increase to the Interconnection Customer's original project, which will share the same point of interconnection. The AG1-109 queue position is a 0.0 MW uprate (25.0 MW Capacity uprate) to the previous project. The total installed facilities will have a capability of 50.0 MW.

Project Information
Queue Number AG1-109
Project Name Valley 138 kV
Developer Name Decatur Storage LLC
State Michigan
County Van Buren
Transmission Owner AEP
MFO 50.0 MW
MWE 0.0 MW
MWC 25.0 MW
Fuel Type Storage
Basecase Study Year 2024

Point of Interconnection

AG1-109 will interconnect on the AEP transmission system at the Valley 138 kV substation.

Summer Peak Analysis

The Queue Project was evaluated as a 0.0 MW (Capacity 25.0 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:

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
AEP 05MOTTV-05E.ELKHART 138.0 kV Ckt 1 line
243346 to 243287 ckt 1
AEP_P4_#12430_05POKAGON 69.0_F
CONTINGENCY 'AEP_P4_#12430_05POKAGON 69.0_F'
 OPEN BRANCH FROM BUS 243360 TO BUS 246480 CKT 1   /*05POKAGO     138.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 244216 TO BUS 246516 CKT 1   /*05HOSP TAPSS  69.0 - 05DAILEY 8    69.0
 OPEN BRANCH FROM BUS 244216 TO BUS 246555 CKT 1   /*05HOSP TAPSS  69.0 - 05WOLVERIN    69.0
 OPEN BRANCH FROM BUS 244216 TO BUS 960980 CKT 1   /*05HOSP TAPSS  69.0 - AF2-389 TAP   69.0
 OPEN BRANCH FROM BUS 246464 TO BUS 246480 CKT 1   /*05LAKE ST     69.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246506 CKT 1   /*05POKAGON     69.0 - 05BARRETTZ    69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246516 CKT 1   /*05POKAGON     69.0 - 05DAILEY 8    69.0
 REMOVE SWSHUNT FROM BUS 246480                    /*05POKAGON     69.0
END
Breaker AC 128.03 % 129.93 % 185.0 B 240.37 3.7
AEP 05MOTTV-05E.ELKHART 138.0 kV Ckt 1 line
243346 to 243287 ckt 1
AEP_P4_#12431_05POKAGON 69.0_H
CONTINGENCY 'AEP_P4_#12431_05POKAGON 69.0_H'
 OPEN BRANCH FROM BUS 243360 TO BUS 246480 CKT 1   /*05POKAGO     138.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 243420 TO BUS 246511 CKT 1   /*05COLBY       34.5 - 05COLBY       69.0
 OPEN BRANCH FROM BUS 246464 TO BUS 246480 CKT 1   /*05LAKE ST     69.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246506 CKT 1   /*05POKAGON     69.0 - 05BARRETTZ    69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246516 CKT 1   /*05POKAGON     69.0 - 05DAILEY 8    69.0
 OPEN BRANCH FROM BUS 246505 TO BUS 246506 CKT 1   /*05BARRETT8    69.0 - 05BARRETTZ    69.0
 OPEN BRANCH FROM BUS 246506 TO BUS 246511 CKT 1   /*05BARRETTZ    69.0 - 05COLBY       69.0
 REMOVE SWSHUNT FROM BUS 246480                    /*05POKAGON     69.0
END
Breaker AC 126.83 % 128.74 % 185.0 B 238.17 3.7
AEP 05MOTTV-05E.ELKHART 138.0 kV Ckt 1 line
243346 to 243287 ckt 1
AEP_P4_#12429_05POKAGON 69.0_J
CONTINGENCY 'AEP_P4_#12429_05POKAGON 69.0_J'
 OPEN BRANCH FROM BUS 243360 TO BUS 246480 CKT 1   /*05POKAGO     138.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246464 TO BUS 246480 CKT 1   /*05LAKE ST     69.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246506 CKT 1   /*05POKAGON     69.0 - 05BARRETTZ    69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246516 CKT 1   /*05POKAGON     69.0 - 05DAILEY 8    69.0
 REMOVE SWSHUNT FROM BUS 246480                    /*05POKAGON     69.0
END
Breaker AC 126.57 % 128.48 % 185.0 B 237.69 3.7
AEP AE1-170 POI-05KENZIE 138.0 kV Ckt 1 line
939390 to 243322 ckt 1
AEP_P4_#14833_05HARTFORD 69.0_X
CONTINGENCY 'AEP_P4_#14833_05HARTFORD 69.0_X'
 DISCONNECT BUS 243307                             /*05HARTFO     138.0
 DISCONNECT BUS 246457                             /*05HARTFORD    69.0
 OPEN BRANCH FROM BUS 246455 TO BUS 246456 CKT 1   /*05HARTFDEQ   999.0 - 05HARTFORD    34.5
 OPEN BRANCH FROM BUS 246456 TO BUS 247173 CKT 1   /*05HARTFORD    34.5 - 05KEELETTE    34.5
END
Breaker AC 96.92 % 101.14 % 361.0 B 365.12 15.5
AEP 05COREY-05MOTTV 138.0 kV Ckt 1 line
243265 to 243346 ckt 1
AEP_P2-2_#12306_05COREY 69.0_1
CONTINGENCY 'AEP_P2-2_#12306_05COREY 69.0_1'
 OPEN BRANCH FROM BUS 243201 TO BUS 243265 CKT 1   /*05COREY 1EQ  999.0 - 05COREY      138.0
 OPEN BRANCH FROM BUS 243201 TO BUS 246514 CKT 1   /*05COREY 1EQ  999.0 - 05COREY       34.5
 OPEN BRANCH FROM BUS 243201 TO BUS 246515 CKT 1   /*05COREY 1EQ  999.0 - 05COREY       69.0
 OPEN BRANCH FROM BUS 244519 TO BUS 246515 CKT 1   /*05RIPPLE      69.0 - 05COREY       69.0
 OPEN BRANCH FROM BUS 246515 TO BUS 246520 CKT 1   /*05COREY       69.0 - 05FLORENCE    69.0
END
Bus AC 141.53 % 143.44 % 185.0 B 265.36 3.73
AEP 05MOTTV-05E.ELKHART 138.0 kV Ckt 1 line
243346 to 243287 ckt 1
AEP_P2-2_#12429_05POKAGON 69.0_1
CONTINGENCY 'AEP_P2-2_#12429_05POKAGON 69.0_1'
 OPEN BRANCH FROM BUS 243360 TO BUS 246480 CKT 1   /*05POKAGO     138.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246464 TO BUS 246480 CKT 1   /*05LAKE ST     69.0 - 05POKAGON     69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246506 CKT 1   /*05POKAGON     69.0 - 05BARRETTZ    69.0
 OPEN BRANCH FROM BUS 246480 TO BUS 246516 CKT 1   /*05POKAGON     69.0 - 05DAILEY 8    69.0
 REMOVE SWSHUNT FROM BUS 246480                    /*05POKAGON     69.0
END
Bus AC 126.57 % 128.48 % 185.0 B 237.69 3.7

Light Load Analysis

The Queue Project was evaluated as a 0.0 MW (Capacity 25.0 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 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
n7018 A Sag Study will be required on the 8.5 mile section of ACSR 477 26/7 HAWK [...] n time would be 24 to 36 months after signing an interconnection agreement. $34,000
n7018.1 Replace 800A Wavetrap at Mottville $50,000
n7018.2 Rebuild/reconductor 8.5 miles of ACSR ~ 795 ~ 45/7 ~ TERN conductor $12,000,000
n7017 A Sag Study will be required on the 7.8 mile section of ACSR 477 26/7 HAWK [...] n time would be 24 to 36 months after signing an interconnection agreement. $31,200

Attachments

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Uprate Chain
Project Project Status MFO MWE MWC Disposition
AF1-161 Active 50.0 50.0 25.0 Transition Cycle 1
AG1-109 Active 50.0 0.0 25.0 Transition Cycle 1

Conclusion

The Transition Sort load flow retool results indicate that AG1-109 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.