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AG1-473 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 10:52

Shingletown-Lewistown 230 kV

32.34 MW Capacity / 53.9 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 AG1-473 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 Solar; Storage generating facility located in the PENELEC zone Huntingdon County, Pennsylvania. The installed facilities will have a total capability of 53.9 MW with 32.34 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AG1-473
Project Name Shingletown-Lewistown 230 kV
Developer Name North Corners Energy, LLC
State Pennsylvania
County Huntingdon
Transmission Owner PENELEC
MFO 53.9 MW
MWE 53.9 MW
MWC 32.34 MW
Fuel Type Solar; Storage
Basecase Study Year 2024

Point of Interconnection

The interconnection of AG1-473 will be accomplished by constructing a new 230 kV three breaker ring bus substation and looping the Lewistown - Shingletown 230 kV line into the new station. The new substation will be located approximately 13.9 miles from Lewistown Substation. The IC will be responsible for acquiring all easements, properties, and permits that may be required to construct both the new interconnection switching station and the associated facilities. The IC will also be responsible for the rough grade of the property and an access road to the proposed three-breaker ring bus site. The project will also require upgrades at Lewistown Substation and Shingletown Substation. 

Summer Peak Analysis

The Queue Project was evaluated as a 53.9 MW (Capacity 32.34 MW) injection in the PENELEC 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
PENELEC AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line
938380 to 200520 ckt 1
PL:10:P13:100618
CONTINGENCY 'PL:10:P13:100618'
 DISCONNECT BRANCH FROM BUS 208005 TO BUS 200009 CKT 2   /*JUNI BU2     230.0 - JUNIATA      500.0
 DISCONNECT BRANCH FROM BUS 208005 TO BUS 200513 CKT 1   /*JUNI BU2     230.0 - 26LEWISTWN   230.0
 DISCONNECT BRANCH FROM BUS 208005 TO BUS 207955 CKT 1   /*JUNI BU2     230.0 - DAUP TR2     230.0
 DISCONNECT BRANCH FROM BUS 208005 TO BUS 208004 CKT 1   /*JUNI BU2     230.0 - JUNI BU1     230.0
 DISCONNECT BRANCH FROM BUS 208005 TO BUS 209997 CKT 4   /*JUNI BU2     230.0 - JUNI          69.0
 REMOVE SHUNT 1 FROM BUS 208005                          /*JUNI BU2     230.0
END
Single AC 127.46 % 130.21 % 160.0 B 208.34 5.0
PENELEC AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line
938380 to 200520 ckt 1
PN-P1-2-PN-230-103AT
CONTINGENCY 'PN-P1-2-PN-230-103AT'
 DISCONNECT BRANCH FROM BUS 200513 TO BUS 208005 CKT 1   /*26LEWISTWN   230.0 - JUNI BU2     230.0
END
Single AC 126.07 % 128.81 % 160.0 B 206.1 5.0
AP/PENELEC AG1-473 TAP-26LEWISTWN 230.0 kV Ckt 1 line
966040 to 200513 ckt 1
Base Case Single AC 99.88 % 103.64 % 520.0 A 538.95 21.07
PENELEC AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line
938380 to 200520 ckt 1
PL:10:P45:102437
CONTINGENCY 'PL:10:P45:102437'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Breaker AC 179.99 % 185.0 % 160.0 B 296.0 8.33
AP/PENELEC AG1-473 TAP-26LEWISTWN 230.0 kV Ckt 1 line
966040 to 200513 ckt 1
PN-P2-3-PN-230-17B28
CONTINGENCY 'PN-P2-3-PN-230-17B28'
 DISCONNECT BRANCH FROM BUS 200677 TO BUS 200706 CKT 3   /*26NO MESHO   115.0 - 26N.MESHPN   230.0
 DISCONNECT BRANCH FROM BUS 200706 TO BUS 200708 CKT 1   /*26N.MESHPN   230.0 - 26OXBOW      230.0
 DISCONNECT BRANCH FROM BUS 200708 TO BUS 200709 CKT 1   /*26OXBOW      230.0 - 26OXBOW       34.5
 DISCONNECT BRANCH FROM BUS 200708 TO BUS 208009 CKT 1   /*26OXBOW      230.0 - LACK         230.0
END
Breaker AC 141.18 % 146.6 % 621.0 B 910.39 35.51
AP/PENELEC AG1-473 TAP-26LEWISTWN 230.0 kV Ckt 1 line
966040 to 200513 ckt 1
PN-P2_1-PN-230-997-DRT-063
CONTINGENCY 'PN-P2_1-PN-230-997-DRT-063'
 DISCONNECT BRANCH FROM BUS 200706 TO BUS 200708 CKT 1          /*26N.MESHPN   230.0 - 26OXBOW      230.0
 DISCONNECT BRANCH FROM BUS 200708 TO BUS 200709 CKT 1          /*26OXBOW      230.0 - 26OXBOW       34.5
 SET POSTCONTRATING 498 BRANCH FROM BUS 200706 TO BUS 200924 CKT 1 /*26N.MESHPN   230.0 - 26CANYON     230.0
 SET PRECONTRATING 498 BRANCH FROM BUS 200706 TO BUS 200924 CKT 1 /*26N.MESHPN   230.0 - 26CANYON     230.0
END
Breaker AC 141.17 % 146.59 % 621.0 B 910.34 35.51
PENELEC 26SHADE GP-AE1-071-POI 115.0 kV Ckt 1 line
200522 to 938380 ckt 1
PL:10:P45:102437
CONTINGENCY 'PL:10:P45:102437'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Breaker AC 136.26 % 141.28 % 160.0 B 226.05 8.35
PENELEC 26SHAWVL 1-26ROCKTON 115.0 kV Ckt 1 line
200714 to 200713 ckt 1
AP-P2-3-WP-230-446T
CONTINGENCY 'AP-P2-3-WP-230-446T'
 DISCONNECT BRANCH FROM BUS 200726 TO BUS 235175 CKT 1    /*26SHAWVL 2   230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235158 TO BUS 235175 CKT 1    /*01CARB       230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1    /*01ELKO       230.0 - 01QUEHAN     230.0
 DISCONNECT BRANCH FROM BUS 235220 TO BUS 235236 CKT 1    /*01MOSHAN     230.0 - 01QUEHAN     230.0
 DISCONNECT BRANCH FROM BUS 235236 TO BUS 236732 CKT 81   /*01QUEHAN     230.0 - 01QUEHANNA    46.0
 OPEN BUS 235158                                          /*01CARB       230.0
END
Breaker AC 103.9 % 105.21 % 190.0 B 199.9 3.05
PENELEC 26SHAWVL 1-26ROCKTON 115.0 kV Ckt 1 line
200714 to 200713 ckt 1
AP-P2-3-WP-230-443T *
CONTINGENCY 'AP-P2-3-WP-230-443T *'
 DISCONNECT BRANCH FROM BUS 200726 TO BUS 235175 CKT 1   /*26SHAWVL 2   230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1   /*01ELKO       230.0 - 01QUEHAN     230.0
 DISCONNECT BUS 235158                                   /*01CARB       230.0
END
Breaker AC 103.83 % 105.13 % 190.0 B 199.75 3.05
PENELEC 26ROCKTON-26DUBOIS 115.0 kV Ckt 1 line
200713 to 200712 ckt 1
AP-P2-3-WP-230-446T
CONTINGENCY 'AP-P2-3-WP-230-446T'
 DISCONNECT BRANCH FROM BUS 200726 TO BUS 235175 CKT 1    /*26SHAWVL 2   230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235158 TO BUS 235175 CKT 1    /*01CARB       230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1    /*01ELKO       230.0 - 01QUEHAN     230.0
 DISCONNECT BRANCH FROM BUS 235220 TO BUS 235236 CKT 1    /*01MOSHAN     230.0 - 01QUEHAN     230.0
 DISCONNECT BRANCH FROM BUS 235236 TO BUS 236732 CKT 81   /*01QUEHAN     230.0 - 01QUEHANNA    46.0
 OPEN BUS 235158                                          /*01CARB       230.0
END
Breaker AC 102.89 % 104.19 % 190.0 B 197.97 3.05
PENELEC 26ROCKTON-26DUBOIS 115.0 kV Ckt 1 line
200713 to 200712 ckt 1
AP-P2-3-WP-230-443T *
CONTINGENCY 'AP-P2-3-WP-230-443T *'
 DISCONNECT BRANCH FROM BUS 200726 TO BUS 235175 CKT 1   /*26SHAWVL 2   230.0 - 01ELKO       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1   /*01ELKO       230.0 - 01QUEHAN     230.0
 DISCONNECT BUS 235158                                   /*01CARB       230.0
END
Breaker AC 102.81 % 104.12 % 190.0 B 197.82 3.05
PENELEC 26LEWISTWN-26REED TAP 115.0 kV Ckt 1 line
200512 to 200519 ckt 1
PL:10:P45:102437
CONTINGENCY 'PL:10:P45:102437'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Breaker AC 96.94 % 100.21 % 225.0 B 225.47 7.45
PENELEC AE1-071-POI-26ROXBURY 115.0 kV Ckt 1 line
938380 to 200520 ckt 1
PL:10:P24:100548
CONTINGENCY 'PL:10:P24:100548'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Bus AC 179.99 % 185.0 % 160.0 B 296.0 8.33
PENELEC 26SHADE GP-AE1-071-POI 115.0 kV Ckt 1 line
200522 to 938380 ckt 1
PL:10:P24:100548
CONTINGENCY 'PL:10:P24:100548'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Bus AC 136.5 % 141.49 % 160.0 B 226.38 8.35
PENELEC 26SHAWVL 1-26ROCKTON 115.0 kV Ckt 1 line
200714 to 200713 ckt 1
AP-P2-2-WP-230-001T
CONTINGENCY 'AP-P2-2-WP-230-001T'
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 200726 CKT 1   /*01ELKO       230.0 - 26SHAWVL 2   230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235158 CKT 1   /*01ELKO       230.0 - 01CARB       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1   /*01ELKO       230.0 - 01QUEHAN     230.0
END
Bus AC 103.76 % 105.06 % 190.0 B 199.62 3.05
PENELEC 26ROCKTON-26DUBOIS 115.0 kV Ckt 1 line
200713 to 200712 ckt 1
AP-P2-2-WP-230-001T
CONTINGENCY 'AP-P2-2-WP-230-001T'
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 200726 CKT 1   /*01ELKO       230.0 - 26SHAWVL 2   230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235158 CKT 1   /*01ELKO       230.0 - 01CARB       230.0
 DISCONNECT BRANCH FROM BUS 235175 TO BUS 235236 CKT 1   /*01ELKO       230.0 - 01QUEHAN     230.0
END
Bus AC 102.75 % 104.05 % 190.0 B 197.69 3.05
PENELEC 26LEWISTWN-26REED TAP 115.0 kV Ckt 1 line
200512 to 200519 ckt 1
PL:10:P24:100548
CONTINGENCY 'PL:10:P24:100548'
 DISCONNECT BUS 208004   /*JUNI BU1     230.0
 DISCONNECT BUS 208005   /*JUNI BU2     230.0
END
Bus AC 96.88 % 100.14 % 225.0 B 225.32 7.45

Light Load Analysis

The Queue Project was evaluated as a 53.9 MW (Capacity 32.34 MW) injection in the PENELEC 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
(TBD) FAC-008 Rating Increase (Scheduled 6/2024) $0
n6816.1 Rebuild 11.84 miles of the Lewistown - Reeds Gap Switching Station 115 kV Line $37,890,000
n8219 Reconductor 13.9 miles of transmission line on the AG1-473 (Shingletown) - Lewistown 230 kV Line. $59,794,920
n7652 Replace line trap at Shawville. $200,000
b3751 Rebuild 6.4 miles of the Roxbury - Shade Gap 115 kV line from Roxbury to the AE1-071 115 kV ring bus with single circuit 115 kV construction $15,030,000
b3752 Rebuild 7.2 miles of the Shade Gap - AE1-071 115 kV line section of the Roxbury - Shade Gap 115 kV line $17,430,000

Attachments

Conclusion

The Transition Sort load flow retool results indicate that AG1-473 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.