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AG1-450 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 10:41

Airey-Vienna 69 kV II

25.0 MW Capacity / 25.0 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 AG1-450 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 DPL zone Dorchester County, Maryland. This project is an increase to the Interconnection Customer's original project, which will share the same point of interconnection. The AG1-450 queue position is a 25.0 MW uprate (25.0 MW Capacity uprate) to the previous project. The total installed facilities will have a capability of 125.0 MW.

Project Information
Queue Number AG1-450
Project Name Airey-Vienna 69 kV II
Developer Name RWE Solar Development, LLC
State Maryland
County Dorchester
Transmission Owner DPL
MFO 125.0 MW
MWE 25.0 MW
MWC 25.0 MW
Fuel Type Storage
Basecase Study Year 2024

Point of Interconnection

AG1-450 will interconnect on the DPL transmission system tapping the Airey - Vienna 69 kV line.

Summer Peak Analysis

The Queue Project was evaluated as a 25.0 MW (Capacity 25.0 MW) injection in the DPL 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
DP&L VIENN_69-MARDELA 69.0 kV Ckt 1 line
232241 to 232838 ckt 1
DPL_P1_2_CKT 6728
CONTINGENCY 'DPL_P1_2_CKT 6728'
 DISCONNECT BUS 230912                               /*PINEYCAP      69.0
 OPEN LINE FROM BUS 232272 TO BUS 232274 CIRCUIT 1   /*M HERMON      69.0 - PINEY_69      69.0
END
Single AC 98.96 % 104.72 % 64.0 B 67.02 4.07
DP&L VIENN_69-MARDELA 69.0 kV Ckt 1 line
232241 to 232838 ckt 1
DPL_P1_3_LORETO AT1&2
CONTINGENCY 'DPL_P1_3_LORETO AT1&2'
 OPEN LINE FROM BUS 232127 TO BUS 232275 CIRCUIT 1   /*LORETTO      138.0 - LORET_69      69.0
 OPEN LINE FROM BUS 232127 TO BUS 232275 CIRCUIT 2   /*LORETTO      138.0 - LORET_69      69.0
END
Single AC 97.09 % 103.01 % 64.0 B 65.93 4.21
DP&L VIENN_69-MARDELA 69.0 kV Ckt 1 line
232241 to 232838 ckt 1
DPL_P1_2_CKT 6711
CONTINGENCY 'DPL_P1_2_CKT 6711'
 OPEN LINE FROM BUS 232288 TO BUS 232275 CIRCUIT 1   /*FRUITLND      69.0 - LORET_69      69.0
END
Single AC 94.4 % 100.14 % 64.0 B 64.09 4.21
DP&L TODD-PRESTON 69.0 kV Ckt 1 line
232234 to 232233 ckt 1
DPL_P4-2_DP11
CONTINGENCY 'DPL_P4-2_DP11'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232004 TO BUS 232000 CKT 1   /*MILF_230     230.0 - STEELE       230.0
END
Breaker AC 201.16 % 207.22 % 93.0 B 192.72 6.07
DP&L TODD-PRESTON 69.0 kV Ckt 1 line
232234 to 232233 ckt 1
DPL_P4-2_DP12
CONTINGENCY 'DPL_P4-2_DP12'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232103 CKT 2   /*STEELE       230.0 - STEEL138     138.0
END
Breaker AC 111.73 % 117.42 % 93.0 B 109.2 5.54
DP&L PRESTON-TANYARD 69.0 kV Ckt 1 line
232233 to 232821 ckt 1
DPL_P4-2_DP11
CONTINGENCY 'DPL_P4-2_DP11'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232004 TO BUS 232000 CKT 1   /*MILF_230     230.0 - STEELE       230.0
END
Breaker AC 106.18 % 109.43 % 173.0 B 189.32 6.07
DP&L TANYARD-TALBOT 69.0 kV Ckt 1 line
232821 to 232820 ckt 1
DPL_P4-2_DP11
CONTINGENCY 'DPL_P4-2_DP11'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232004 TO BUS 232000 CKT 1   /*MILF_230     230.0 - STEELE       230.0
END
Breaker AC 103.22 % 106.47 % 173.0 B 184.19 6.07
DP&L TALBOT-TRAP ALT 69.0 kV Ckt 1 line
232820 to 232230 ckt 1
DPL_P4-2_DP11
CONTINGENCY 'DPL_P4-2_DP11'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232004 TO BUS 232000 CKT 1   /*MILF_230     230.0 - STEELE       230.0
END
Breaker AC 100.89 % 104.14 % 173.0 B 180.16 6.07
DP&L VIENN_69-TODD 69.0 kV Ckt 1 line
232241 to 232234 ckt 1
DPL_P4-2_DP11
CONTINGENCY 'DPL_P4-2_DP11'
 DISCONNECT BRANCH FROM BUS 232000 TO BUS 232005 CKT 1   /*STEELE       230.0 - VIENNA       230.0
 DISCONNECT BRANCH FROM BUS 232004 TO BUS 232000 CKT 1   /*MILF_230     230.0 - STEELE       230.0
END
Breaker AC 99.19 % 100.03 % 143.0 B 143.04 1.46
DP&L TOWNSEND-MIDLTNTP 138.0 kV Ckt 1 line
232107 to 232106 ckt 1
DPL_P7_1_DBL_1NCB_FSA
CONTINGENCY 'DPL_P7_1_DBL_1NCB_FSA'
 DISCONNECT BUS 923961                           /*AB2-037 C    230.0
 DISCONNECT BUS 923962                           /*AB2-037 E    230.0
 OPEN LINE FROM BUS 231003 TO BUS 232000 CKT 1   /*KEEN_230     230.0 - STEELE       230.0
 OPEN LINE FROM BUS 231003 TO BUS 923960 CKT 2   /*KEEN_230     230.0 - AB2-037 TAP  230.0
 OPEN LINE FROM BUS 232000 TO BUS 923960 CKT 2   /*STEELE       230.0 - AB2-037 TAP  230.0
END
Tower AC 112.94 % 114.76 % 348.0 B 399.38 5.75
DP&L CHURCH-TOWNSEND 138.0 kV Ckt 1 line
232100 to 232107 ckt 1
DPL_P7_1_DBL_1NCB_FSA
CONTINGENCY 'DPL_P7_1_DBL_1NCB_FSA'
 DISCONNECT BUS 923961                           /*AB2-037 C    230.0
 DISCONNECT BUS 923962                           /*AB2-037 E    230.0
 OPEN LINE FROM BUS 231003 TO BUS 232000 CKT 1   /*KEEN_230     230.0 - STEELE       230.0
 OPEN LINE FROM BUS 231003 TO BUS 923960 CKT 2   /*KEEN_230     230.0 - AB2-037 TAP  230.0
 OPEN LINE FROM BUS 232000 TO BUS 923960 CKT 2   /*STEELE       230.0 - AB2-037 TAP  230.0
END
Tower AC 106.12 % 107.65 % 348.0 B 374.62 5.75

Light Load Analysis

The Queue Project was evaluated as a 25.0 MW (Capacity 25.0 MW) injection in the DPL 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.
Light Load Analysis
Area Facility Description Contingency Name Contingency Type DC|AC Initial Loading Final Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
DP&L INDRV2&3-NELSON 138.0 kV Ckt 1 line
232121 to 232119 ckt 1
DPL_P4-2_DPIR235
CONTINGENCY 'DPL_P4-2_DPIR235'
 DISCONNECT BRANCH FROM BUS 232006 TO BUS 232004 CKT 1   /*INDRIV 4     230.0 - MILF_230     230.0
 DISCONNECT BRANCH FROM BUS 232007 TO BUS 232006 CKT 1   /*PINEY GR     230.0 - INDRIV 4     230.0
 DISCONNECT BRANCH FROM BUS 232007 TO BUS 232128 CKT 1   /*PINEY GR     230.0 - PINEY138     138.0
END
Breaker AC 102.36 % 103.84 % 193.0 B 200.41 3.82

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
n7100 ds13833r0001: CHURCH to TOWNSEND 138 kV line overload will require substation reinforcements at Church Substation. $500,000
n7101 ds13833r0002: CHURCH to TOWNSEND 138 kV line will require substation reinforcements (on top of ds13833r001) at Church Substation. $200,000
n6407 Rebuild small portion of TOWNSEND -MIDLTNTP 138 kV line and substation reinforcements at Townsend & Middletown Tap Substation. $100,000
n6451 Upgrade disconnect switch at Middletown Tap $100,000
n7039 Replace terminal equipment at Nelson $250,000
n7038 Rebuild Indian River to Nelson 138 kV circuit. $43,000,000
n7105 Rebuild the (DP&L) Preston - Tanyard 69 kV line. This includes installation of new poles, foundations, insulators and OPGW. $11,000,000
n7106 To mitigate the (DP&L) Preston - Tanyard 69 kV line by replacing the terminal equipment at the Tanyard Tap. $100,000
n5788 Substation reinforcements at Todd Substation. Replace 600A Disconnect Switch at Todd $100,000
n6231 Substation reinforcements at Preston Substation and Todd Substation. $100,000
n7097 Rebuild (DP&L) Preston - Todd 69 kV line with installation of new poles, conductor, foundations, insulators and OPGW. $9,000,000
n7040 Rebuild Tanyard - Talbot 69 kV line. $7,499,000
n7095 Upgrading the relays at both Todd and Vienna $450,000
n7749 Rebuild line and replace disconnect switch. $4,750,000
n7784 Rebuild Vienna - Mardela - Hebron $15,000,000
b2946 PJM baseline upgrade b2946 conversion of Preston station to a Ring Bus $6,000,000

Attachments

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Uprate Chain
Project Project Status MFO MWE MWC Disposition
AF2-358 Active 100.0 100.0 60.0 Transition Cycle 1
AG1-450 Active 125.0 25.0 25.0 Transition Cycle 1

Conclusion

The Transition Sort load flow retool results indicate that AG1-450 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.