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AF1-204 Transition Sort Retool Results -- Reprioritized to Transition Cycle #1

v1.00 released 2023-12-14 11:11

Eugene 345 kV

63.75 MW Capacity / 255.0 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 AF1-204 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 Wind generating facility located in the AEP zone Vermillion County, Indiana. The installed facilities will have a total capability of 255.0 MW with 63.75 MW of this output being recognized by PJM as Capacity.

Project Information
Queue Number AF1-204
Project Name Eugene 345 kV
Developer Name Vermilion Grove Wind, LLC
State Indiana
County Vermillion
Transmission Owner AEP
MFO 255.0 MW
MWE 255.0 MW
MWC 63.75 MW
Fuel Type Wind
Basecase Study Year 2023

Point of Interconnection

AF1-204 will interconnect with the AEP transmission system via a direct connection to the Eugene 345 kV substation.

 

To accommodate the interconnection to the Eugene 345 kV substation, one (1) new 345 kV circuit breaker will be installed. Installation of associated protection and control equipment, 345 kV line risers, SCADA, and 345 kV revenue metering will also be required. AEP reserves the right to specify the final acceptable configuration considering design practices, future expansion, and compliance requirements.

 

Installation of the generator lead first span exiting the POI station, including the first structure outside the AEP fence, will also be included in AEP's scope. In the case where the generator lead is a single span, the structure in the customer station will be the customer's responsibility.

 

Summer Peak Analysis

The Queue Project was evaluated as a 255.0 MW (Capacity 63.75 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/OVEC 05JEFRSO-06CLIFTY 345.0 kV Ckt Z1 line
242865 to 248000 ckt Z1
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 132.1 % 133.33 % 2255.0 B 3006.53 25.8
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 105.16 % 105.44 % 2255.0 B 2377.78 26.88
AEP/IPL 05SULLIVAN-16PETE 345.0 kV Ckt 1 line
247712 to 254529 ckt 1
AEP_P4_#8648_05JEFRSO 765_B
CONTINGENCY 'AEP_P4_#8648_05JEFRSO 765_B'
 OPEN BRANCH FROM BUS 242865 TO BUS 248000 CKT Z1   /*05JEFRSO     345.0 - 06CLIFTY     345.0
 OPEN BRANCH FROM BUS 243208 TO BUS 242865 CKT 2    /*05JEFRSO     765.0 - 05JEFRSO     345.0
 OPEN BRANCH FROM BUS 243208 TO BUS 243209 CKT 1    /*05JEFRSO     765.0 - 05ROCKPT     765.0
END
Breaker DC 101.74 % 102.72 % 1409.0 B 1447.32 16.06
AEP 05JEFRSO-05JEFRSO 765.0/345.0 kV Ckt 2 transformer
243208 to 242865 ckt 2
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 99.65 % 100.58 % 3039.0 B 3056.63 25.8
CE Z2-087 TAP-PONTIAC ; R 345.0 kV Ckt 1 line
917500 to 270853 ckt 1
COMED_P1-2_345-L8002___-S
CONTINGENCY 'COMED_P1-2_345-L8002___-S'
 TRIP BRANCH FROM BUS 270852 TO BUS 270668 CKT 1   /*PONTIAC  ; B 345.0 - BLUEMOUND; B 345.0
END
Single AC 100.01 % 100.28 % 1837.0 STE 1842.13 4.52
AEP 05ROCKPT-05JEFRSO 765.0 kV Ckt 1 line
243209 to 243208 ckt 1
AEP_P7-1_#11042
CONTINGENCY 'AEP_P7-1_#11042'
 OPEN BRANCH FROM BUS 243878 TO BUS 255205 CKT 1   /*05MEADOW     345.0 - 17REYNOLDS   345.0
 OPEN BRANCH FROM BUS 243878 TO BUS 255205 CKT 2   /*05MEADOW     345.0 - 17REYNOLDS   345.0
END
Tower AC 114.29 % 115.56 % 3970.0 B 4587.73 42.49
AEP 05ROCKPT-05JEFRSO 765.0 kV Ckt 1 line
243209 to 243208 ckt 1
AEP_P7-1_#11014
CONTINGENCY 'AEP_P7-1_#11014'
 OPEN BRANCH FROM BUS 243217 TO BUS 243221 CKT 1   /*05DEQUIN     345.0 - 05EUGENE     345.0
 OPEN BRANCH FROM BUS 243217 TO BUS 247712 CKT 1   /*05DEQUIN     345.0 - 05SULLIVAN   345.0
END
Tower AC 111.0 % 112.18 % 3970.0 B 4453.55 41.0

Light Load Analysis

The Queue Project was evaluated as a 255.0 MW (Capacity 63.75 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.
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
AEP 05ALLEN-05RPMONE 345.0 kV Ckt 1 line
243211 to 242933 ckt 1
AEP_P1-2_#7441
CONTINGENCY 'AEP_P1-2_#7441'
 OPEN BRANCH FROM BUS 242928 TO BUS 246999 CKT 1   /*05MARYSV     765.0 - 05SORENS     765.0
END
Single DC 126.65 % 128.04 % 897.0 B 1148.52 11.34
AEP 05ALLEN-05RPMONE 345.0 kV Ckt 1 line
243211 to 242933 ckt 1
AEP_P4_#7445_05MARYSV 765_B
CONTINGENCY 'AEP_P4_#7445_05MARYSV 765_B'
 OPEN BRANCH FROM BUS 242922 TO BUS 242928 CKT 1   /*05FLTLCK     765.0 - 05MARYSV     765.0
 OPEN BRANCH FROM BUS 242928 TO BUS 246999 CKT 1   /*05MARYSV     765.0 - 05SORENS     765.0
END
Breaker AC 106.21 % 107.27 % 897.0 B 962.21 11.24

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
n7964 Replace 765/345 Transformer $6,000,000
n6497.4 AEPI0002e: Replace 3 3000A Wavetraps at Rockport $150k; AEPI0002f Replace 3 3000A Wavetraps at Jefferson $150k $426,497
s2280 Replace Rockport CBs B, B2, C and C2 with 765kV SFMT 4000A Cbs $0
n6497.1 An engineering study will need to be conducted to determine if the Rockport [...] ll be required if the settings cannot be adjusted, Estimated Cost: $600,000 $50,144
n6497.2 Replace 6 Rockport Current Transformers 3000Amps $4,800,000
n6497.3 Replace 2 Rockport 3000A non-oil Breakers at Rockport $6,000,000
n4106.5 Replace Clifty Bus 5"0 AL Tubular Sch 40 $100,000
n4106.3 Extend One (1) Tower on the Jefferson - Clifty Creek (IKEC) 345 kV Circuit $409,714
n4106 Replace Two (2) Switches at the Clifty Creek 345 kV Station $412,916
n4106.4 Rebuild 0.75 miles of ACSR ~ 2156 ~ 64/19 ~ BLUEBIRD conductor to mitigate the overload. $2,500,000
b3748 Replace four Clifty Creek 345 kV 3000A switches with 5000A 345 kV switches $850,000
b2878 Upgrade the Clifty Creek 345 kV risers $3,675,000
n8196.1 AEP will replace two (2) existing double circuit towers with steel double circuit single pole structures on the Allen - RPMone 345kV line. $916,437
n6740 Sag Study - Allen and Rpmone 345 kV line (12.25 miles). Completed, Rate B should be 1057MVA. $49,000
n6781 A Sag Study will be required on the ~0.5 miles section of 954 2x Rail Condu [...] t sag study) and $0.75 million (complete line reconductor/rebuild required) $25,000
n7941 Pontiac - Z2-087 (McLean) Sag Mitigation $10,500,000

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