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AG1-320 Transition Sort Retool Results -- Qualifies for Expedited Process

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

Glendale-Stephensburg 69 kV

54.8 MW Capacity / 82.0 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 AG1-320 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 EKPC zone Hardin County, Kentucky. The installed facilities will have a total capability of 82.0 MW with 54.8 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AG1-320
Project Name Glendale-Stephensburg 69 kV
Developer Name CPV Stonecrop Solar, LLC
State Kentucky
County Hardin
Transmission Owner EKPC
MFO 82.0 MW
MWE 82.0 MW
MWC 54.8 MW
Fuel Type Solar
Basecase Study Year 2024

Point of Interconnection

AG1-320 will interconnect on the EKPC transmission system tapping the Glendale – Stephensburg 69 kV line.

 

Summer Peak Analysis

The Queue Project was evaluated as a 82.0 MW (Capacity 54.8 MW) injection in the EKPC 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
EKPC/LGEE 2KARGLE-2ETOWN KU 69.0 kV Ckt 1 line
341713 to 324519 ckt 1
EKPC_P2-1_4HARDIN CO 138.00 TO 4CENT HARDIN138.00
CONTINGENCY 'EKPC_P2-1_4HARDIN CO 138.00 TO 4CENT HARDIN138.00'
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
END
Single AC 186.35 % 203.13 % 86.0 B 174.69 13.54
EKPC 2CENT HARDIN-2KARGLE 69.0 kV Ckt 1 line
341287 to 341713 ckt 1
EKPC_P2-1_4HARDIN CO 138.00 TO 4CENT HARDIN138.00
CONTINGENCY 'EKPC_P2-1_4HARDIN CO 138.00 TO 4CENT HARDIN138.00'
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
END
Single AC 179.17 % 193.89 % 98.0 B 190.01 13.54
EKPC/LGEE 2KARGLE-2ETOWN KU 69.0 kV Ckt 1 line
341713 to 324519 ckt 1
Base Case Single AC 122.98 % 137.77 % 68.0 A 93.69 9.74
EKPC 2STEPHENSBRG-2UPTON T 69.0 kV Ckt 1 line
342307 to 342403 ckt 1
EXT_324308 4SHREWSBURY 138 324800 4MERE TVA 138 1
CONTINGENCY 'EXT_324308 4SHREWSBURY 138 324800 4MERE TVA 138 1'
 OPEN BRANCH FROM BUS 324308 TO BUS 324800 CKT 1   /*4SHREWSBURY  138.0 - 4MERE TVA    138.0
END
Single AC 118.4 % 134.66 % 39.0 B 52.52 6.59
EKPC/LGEE 2KARGLE-2ETOWN KU 69.0 kV Ckt 1 line
341713 to 324519 ckt 1
EXT_324244 4ETOWN 138 324261 4HARDIN CO 138 1
CONTINGENCY 'EXT_324244 4ETOWN 138 324261 4HARDIN CO 138 1'
 OPEN BRANCH FROM BUS 324244 TO BUS 324261 CKT 1   /*4ETOWN       138.0 - 4HARDIN CO   138.0
END
Single AC 119.38 % 130.27 % 86.0 B 112.04 9.11
EKPC 2CENT HARDIN-2KARGLE 69.0 kV Ckt 1 line
341287 to 341713 ckt 1
EXT_324244 4ETOWN 138 324261 4HARDIN CO 138 1
CONTINGENCY 'EXT_324244 4ETOWN 138 324261 4HARDIN CO 138 1'
 OPEN BRANCH FROM BUS 324244 TO BUS 324261 CKT 1   /*4ETOWN       138.0 - 4HARDIN CO   138.0
END
Single AC 120.65 % 130.19 % 98.0 B 127.59 9.11
EKPC 2STEPHENSBRG-2UPTON T 69.0 kV Ckt 1 line
342307 to 342403 ckt 1
EXT_B-138-115
CONTINGENCY 'EXT_B-138-115'
 OPEN BRANCH FROM BUS 324272 TO BUS 324308 CKT 1   /*4LEITCHFIELD 138.0 - 4SHREWSBURY  138.0
 OPEN BRANCH FROM BUS 324291 TO BUS 324308 CKT 1   /*4OHIO COUNTY 138.0 - 4SHREWSBURY  138.0
 OPEN BRANCH FROM BUS 324308 TO BUS 324800 CKT 1   /*4SHREWSBURY  138.0 - 4MERE TVA    138.0
END
Single AC 105.58 % 124.45 % 39.0 B 48.54 7.09
EKPC 2CENT HARDIN-2KARGLE 69.0 kV Ckt 1 line
341287 to 341713 ckt 1
Base Case Single AC 111.14 % 122.43 % 89.0 A 108.97 9.74
EKPC 2STEPHENSBRG-2UPTON T 69.0 kV Ckt 1 line
342307 to 342403 ckt 1
EXT_324213 4BONNIEVILLE 138 324800 4MERE TVA 138 1
CONTINGENCY 'EXT_324213 4BONNIEVILLE 138 324800 4MERE TVA 138 1'
 OPEN BRANCH FROM BUS 324213 TO BUS 324800 CKT 1   /*4BONNIEVILLE 138.0 - 4MERE TVA    138.0
END
Single AC 95.76 % 111.94 % 39.0 B 43.66 6.59
EKPC/LGEE 2KARGLE-2ETOWN KU 69.0 kV Ckt 1 line
341713 to 324519 ckt 1
EKPC_P2-4_CHARD W124-91T
CONTINGENCY 'EKPC_P2-4_CHARD W124-91T'
 OPEN BRANCH FROM BUS 324047 TO BUS 324260 CKT 1   /*4BLACKBRANCH 138.0 - 4HARDINSBURG 138.0
 OPEN BRANCH FROM BUS 324047 TO BUS 342568 CKT 1   /*4BLACKBRANCH 138.0 - 4CENT HARDIN 138.0
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
END
Breaker AC 294.58 % 327.56 % 86.0 B 281.71 27.77
EKPC 2CENT HARDIN-2KARGLE 69.0 kV Ckt 1 line
341287 to 341713 ckt 1
EKPC_P2-4_CHARD W124-91T
CONTINGENCY 'EKPC_P2-4_CHARD W124-91T'
 OPEN BRANCH FROM BUS 324047 TO BUS 324260 CKT 1   /*4BLACKBRANCH 138.0 - 4HARDINSBURG 138.0
 OPEN BRANCH FROM BUS 324047 TO BUS 342568 CKT 1   /*4BLACKBRANCH 138.0 - 4CENT HARDIN 138.0
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
END
Breaker AC 274.27 % 303.29 % 98.0 B 297.23 27.77
EKPC AF2-308 TAP-2CENT HARDIN 69.0 kV Ckt 1 line
960170 to 341287 ckt 1
EKPC_P2-3_BONNV W8-828
CONTINGENCY 'EKPC_P2-3_BONNV W8-828'
 OPEN BUS 324213   /*4BONNIEVILLE 138.0
END
Breaker AC 122.04 % 156.12 % 98.0 B 153.0 32.83
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-4_CHARD W124-91T
CONTINGENCY 'EKPC_P2-4_CHARD W124-91T'
 OPEN BRANCH FROM BUS 324047 TO BUS 324260 CKT 1   /*4BLACKBRANCH 138.0 - 4HARDINSBURG 138.0
 OPEN BRANCH FROM BUS 324047 TO BUS 342568 CKT 1   /*4BLACKBRANCH 138.0 - 4CENT HARDIN 138.0
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
END
Breaker AC 75.8 % 102.88 % 98.0 B 100.83 27.77
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-3_CHARD W124-804
CONTINGENCY 'EKPC_P2-3_CHARD W124-804'
 OPEN BRANCH FROM BUS 324047 TO BUS 324260 CKT 1   /*4BLACKBRANCH 138.0 - 4HARDINSBURG 138.0
 OPEN BRANCH FROM BUS 324047 TO BUS 342568 CKT 1   /*4BLACKBRANCH 138.0 - 4CENT HARDIN 138.0
 OPEN BRANCH FROM BUS 341287 TO BUS 342568 CKT 1   /*2CENT HARDIN  69.0 - 4CENT HARDIN 138.0
END
Breaker AC 75.78 % 102.86 % 98.0 B 100.8 27.77
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-3_CHARD W124-814
CONTINGENCY 'EKPC_P2-3_CHARD W124-814'
 OPEN BRANCH FROM BUS 324261 TO BUS 342568 CKT 1   /*4HARDIN CO   138.0 - 4CENT HARDIN 138.0
 OPEN BRANCH FROM BUS 341287 TO BUS 342568 CKT 1   /*2CENT HARDIN  69.0 - 4CENT HARDIN 138.0
END
Breaker AC 75.76 % 102.84 % 98.0 B 100.79 27.77
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-3_CHARD W124-848
CONTINGENCY 'EKPC_P2-3_CHARD W124-848'
 OPEN BRANCH FROM BUS 341287 TO BUS 342568 CKT 1   /*2CENT HARDIN  69.0 - 4CENT HARDIN 138.0
END
Breaker AC 74.43 % 101.12 % 98.0 B 99.1 27.94
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-3_BONNV W8-828
CONTINGENCY 'EKPC_P2-3_BONNV W8-828'
 OPEN BUS 324213   /*4BONNIEVILLE 138.0
END
Breaker AC 67.91 % 100.01 % 98.0 B 98.01 32.83
EKPC AF2-308 TAP-2CENT HARDIN 69.0 kV Ckt 1 line
960170 to 341287 ckt 1
EKPC_P2-2_KU HODG 69
CONTINGENCY 'EKPC_P2-2_KU HODG 69'
 OPEN BUS 341632   /*2HODGENVILLE  69.0
END
Bus AC 134.7 % 187.17 % 98.0 B 183.42 51.17
EKPC AF2-308 TAP-2CENT HARDIN 69.0 kV Ckt 1 line
960170 to 341287 ckt 1
EKPC_P2-2_BONNIE 138/69
CONTINGENCY 'EKPC_P2-2_BONNIE 138
 OPEN BUS 324213   /*4BONNIEVILLE 138.0
END
Bus AC 122.07 % 156.16 % 98.0 B 153.04 32.83
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-2_KU HODG 69
CONTINGENCY 'EKPC_P2-2_KU HODG 69'
 OPEN BUS 341632   /*2HODGENVILLE  69.0
END
Bus AC 71.23 % 121.59 % 98.0 B 119.15 51.17
EKPC/LGEE 2STEPHENSBRG-2EASTVIEW 69.0 kV Ckt 1 line
342307 to 324509 ckt 1
EKPC_P2-2_KU HODG 69
CONTINGENCY 'EKPC_P2-2_KU HODG 69'
 OPEN BUS 341632   /*2HODGENVILLE  69.0
END
Bus AC 74.68 % 105.06 % 45.0 B 47.28 15.09
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-2_CENT HARD 138
CONTINGENCY 'EKPC_P2-2_CENT HARD 138'
 OPEN BRANCH FROM BUS 341287 TO BUS 342568 CKT 1   /*2CENT HARDIN  69.0 - 4CENT HARDIN 138.0
END
Bus AC 74.45 % 101.14 % 98.0 B 99.12 27.94
EKPC AF2-260 TAP-AF2-308 TAP 69.0 kV Ckt 1 line
959690 to 960170 ckt 1
EKPC_P2-2_BONNIE 138/69
CONTINGENCY 'EKPC_P2-2_BONNIE 138
 OPEN BUS 324213   /*4BONNIEVILLE 138.0
END
Bus AC 67.94 % 100.04 % 98.0 B 98.04 32.83

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
n6238.5 Replace the 1200A disconnect switches W124-623 and W124-625 at Central Hardin substation and W80-605 at the Kargle tap location.. $300,000
n6238.4 Replace the 750 MCM ACSR jumpers at the Central Hardin substation using bundled 500 MCM copper or equivalent $15,000
n6238.2 Rebuild the Central Hardin-Kargle 69 kV line section using 954 MCM ACSS conductor at 392 degrees F (0.6 miles) $450,000
n6238.1 Replace the 556 MCM ACSR jumpers at the Central Hardin substation using bundled 500 MCM copper or equivalent $15,000
n6238 Increase the maximum operating temperature of the 556 MCM ACSR conductor in the Central Hardin-Kargle 69 kV line section to 302 degrees F (0.6 miles) $40,000
n6238.3 Change the Zone 3 relay setting at Central Hardin associated with the line protection to at least 228 MVA LTE rating. $10,000
(TBD) Rebuild the Central Hardin-Kargle line section with bundled 556 ACSS $1,400,000
n7036.6 Replace the 1200A disconnect switches W124-633 and W124-635 at Central Hardin substation. $145,000
n7036.5 Replace the 750 MCM copper jumpers at the Central Hardin substation using bundled 500 MCM copper or equivalent $25,000
n7036.4 Change the Zone 3 relay setting at Central Hardin associated with the line protection to at least 187 MVA LTE rating. $0
n7036.3 Rebuild the AF2-308 Tap-Central Hardin 69 kV line section using 954 MCM ACSS conductor at 392 degrees F (4.15 miles) $4,110,000
n7036.2 Replace the 556 MCM ACSR jumpers at the Central Hardin substation using bundled 500 MCM copper or equivalent $25,000
n7036.1 Increase the maximum operating temperature of the 556 MCM ACSR conductor in the AF2-308 Tap-Central Hardin 69 kV line section to 302 degrees F (4.15 miles) $1,730,000
(TBD) LGEE violation (non PJM area). EKPC emergency rating at 56 MVA The externa [...] Owner, LGEE, will not evaluate this violation until the facilities study phase. $0
(TBD) Change the Zone 3 relay setting at KU Elizabethtown substation associated with the line protection to at least 228 MVA LTE rating. $0
n7035.4 Rebuild the Kargle-KU Elizabethtown 69 kV line section using 954 MCM ACSS conductor (2.85 miles) $4,475,000
n7035.2 Rebuild the 556 MCM ACSR conductor section of the Kargle-KU Elizabethtown 69 kV line section using 954 MCM ACSR conductor (1.45 miles) $2,650,000
n7035.1 Increase the maximum operating temperature of the 556 MCM ACSR conductor in the Kargle-KU Elizabethtown 69 kV line section to 302 degrees F (1.45 miles) $100,000
n7035.5 Replace the 1200A disconnect switch W80-615 at the Kargle tap location $110,000
(TBD) Rebuild the Kargle-KU Elizabethtown 69 kV line section using 556.5 MCM ACSS bundled (2/phase) conductor (2.85 miles) $4,300,000
n8009 Increase the maximum operating temperature of the 4/0 ACSR conductor in the Stephensburg-Upton Tap 69 kV line section to 212 degrees F (10.75 miles) $730,000
n7149.1 Increase the maximum operating temperature of the 556 MCM ACSR conductor in the AF2-260 Tap-AF2-308 Tap 69 kV line section to 302 degrees F (1.0 miles) $70,000

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-320 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.