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AF2-415 System Impact Study Report

v0.12 released 2024-05-13 15:24

Bergen 138 kV

150.0 MW Capacity / 150.0 MW Energy

Introduction

This project is eligible for the Expedited Study process per PJM Tariff Part VII, Subpart B, section 304 and will follow the Expedited Study Process rules outlined in PJM Manual 14H, Attachment I.3.4.

Projects in the Expedited Process will receive a retooled System Impact Study report with the Transition Cycle #1 projects (AE1-AG1) removed from the base case model used for their study. This System Impact Study (SIS) report has been prepared for the AF2-415 project using the updated case model. PJM performed reliability analysis for the project based on the serial study approach using the legacy Generator Deliverability Study method outlined in Manual 14B, Attachment C.3 (Revision 51 of M14B). Summer peak and light load load flow analysis was performed. Short circuit and dynamic stability impacts were also analyzed.

The interconnected Transmission Owner (TO) for this project is Public Service Electric and Gas Company. The TO has provided their updated TO analysis results on the lower voltage system based on their own criteria.

This System Impact Study report summarizes both the PJM and TO analysis results for your project.

Note: This updated SIS report does not include any Physical Interconnection Facilities scope or cost estimates from the TO. As this project is in the Expedited Process, a Facilities Study will be conducted by the TO (and any affected Transmission Owner(s)) for updated Physical Interconnection Facilities and System Reinforcement (Network Upgrade) costs. The Facilities Study will be issued to the Project Developers along with the Generator Interconnection Agreement (GIA) as part of the Expedited Process.

General

The developer has proposed a Storage generating facility located in the Public Service Electric and Gas Company zone — Hudson County, New Jersey. The installed facilities will have a total capability of 150.0 MW with 150.0 MW of this output being recognized by PJM as Capacity.

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Project Information
New Service Request Number AF2-415
Project Name Bergen 138 kV
Developer Name Juno Power Management LLC
State New Jersey
County Hudson
Transmission Owner Public Service Electric and Gas Company
MFO 150.0 MW
MWE 150.0 MW
MWC 150.0 MW
Fuel Type Storage
Basecase Study Year 2023

Point of Interconnection

AF2-415 will interconnect with the PSEG on transmission system at the Bergen 138 kV substation. The POI will be located on the pothead termination structure from the Developer's UG connection to the site. The cable and pothead will be provided by the Developer and PSEG will provide the structure.

Transmission Owner Analysis

None

Summer Peak Analysis

The Project was evaluated as a 150.0 MW (Capacity 150.0 MW) injection in the PSEG 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 were as follows:

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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
PSEG BERGEN_4-BERGEN_R 138.0 kV Ckt 1 line 
217162 to 217157 ckt 1
 		PS_P2-3_BERG_3-6 
CONTINGENCY 'PS_P2-3_BERG_3-6'
 DISCONNECT BRANCH FROM BUS 217047 TO BUS 217105 CKT 1   /*FAIRLAWN_2   138.0 - FAIRLAWN_L2   26.4
 DISCONNECT BUS 217156                                   /*BERGEN_3     138.0
 DISCONNECT BUS 217158                                   /*BERGEN_M     138.0
 DISCONNECT BUS 217164                                   /*BERGEN_6     138.0
END
 		Breaker AC 100.58 % 114.56 % 350.0 B 400.96 52.45 Details
×
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Details for BERGEN_4-BERGEN_R 138.0 kV Ckt 1 line l/o PS_P2-3_BERG_3-6
Bus # Bus Name Type Full MW Contribution GenDeliv MW Contribution
961241 AF2-415 O1 50/50 52.45 MW 52.45 MW
217082 WEATEXAS E Adder 0.06 MW 0.05 MW
217118 BERGEN 1 ST 50/50 11.85 MW 11.85 MW
217915 BERGEN_11 50/50 6.73 MW 6.73 MW
217916 BERGEN_12 50/50 6.73 MW 6.73 MW
217917 BERGEN_13 50/50 6.73 MW 6.73 MW
217918 BERGEN_14 50/50 6.73 MW 6.73 MW
217104 FAIRLAWN_AB Adder -7.0 MW -5.95 MW
217218 BAYON2SP2_E Adder 0.0 MW 0.0 MW
217254 BAYON2SP4_E Adder 0.0 MW 0.0 MW
217255 BAYON2SP3_E Adder 0.0 MW 0.0 MW
217572 MARIONSP1_E Adder 0.01 MW 0.01 MW
217576 MARIONSP2_E Adder 0.01 MW 0.01 MW
217583 MARIONSP3_E Adder 0.01 MW 0.01 MW
217680 NORTHASP1_E Adder 0.01 MW 0.01 MW
217689 NORTHASP2_E Adder 0.01 MW 0.01 MW
218667 NWKSWTSP1_E Adder 0.02 MW 0.01 MW
924431 AB2-092 50/50 17.87 MW 17.87 MW
NEWTON LTFEXP_NEWTON->LTFIMP_NEWTON CLTF 0.14 MW 0.14 MW
BLUEG LTFEXP_BLUEG->LTFIMP_BLUEG CLTF 0.23 MW 0.23 MW
VFT LTFEXP_VFT->LTFIMP_VFT CLTF 12.05 MW 12.05 MW
PRAIRIE LTFEXP_PRAIRIE->LTFIMP_PRAIRIE CLTF 0.34 MW 0.34 MW
O-066 LTFEXP_O-066->LTFIMP_O-066 CLTF 15.58 MW 15.58 MW
COFFEEN LTFEXP_COFFEEN->LTFIMP_COFFEEN CLTF 0.03 MW 0.03 MW
CHEOAH LTFEXP_CHEOAH->LTFIMP_CHEOAH CLTF 0.07 MW 0.07 MW
EDWARDS LTFEXP_EDWARDS->LTFIMP_EDWARDS CLTF 0.04 MW 0.04 MW
TILTON LTFEXP_TILTON->LTFIMP_TILTON CLTF 0.08 MW 0.08 MW
G-007 LTFEXP_G-007->LTFIMP_G-007 CLTF 0.22 MW 0.22 MW
GIBSON LTFEXP_GIBSON->LTFIMP_GIBSON CLTF 0.07 MW 0.07 MW
CALDERWOOD LTFEXP_CALDERWOOD->LTFIMP_CALDERWOOD CLTF 0.06 MW 0.06 MW
FARMERCITY LTFEXP_FARMERCITY->LTFIMP_FARMERCITY CLTF 0.01 MW 0.01 MW
TRIMBLE LTFEXP_TRIMBLE->LTFIMP_TRIMBLE CLTF 0.07 MW 0.07 MW
CATAWBA LTFEXP_CATAWBA->LTFIMP_CATAWBA CLTF 0.04 MW 0.04 MW

Summer Potential Congestion due to Local Energy Deliverability

PJM also studied the delivery of the energy portion of this interconnection request. Any problems identified below are likely to result in operational restrictions to the project under study. The developer can proceed with network upgrades to eliminate the operational restriction at their discretion by submitting an Upgrade Request.

Note: Only the most severely overloaded conditions are listed below. There is no guarantee of full delivery of energy for this project by fixing only the conditions listed in this section.

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Summer Potential Congestion due to Local Energy Deliverability
Area Facility Description Contingency Name Contingency Type DC|AC Initial Loading Final Loading Rating (MVA) Rating Type MVA to Mitigate MW Contribution Details
PSEG BAYWAY-BAYONNE 345.0 kV Ckt 1 line 
217134 to 216908 ckt 1
 		Base Case OP AC 101.9 % 106.93 % 670.0 A 716.43 41.3 Details
PSEG ROSELAND-CDRGV 230.0 kV Ckt 1 line 
216950 to 216915 ckt 1
 		PS_P1-2_S-2297 
CONTINGENCY 'PS_P1-2_S-2297'
 TRIP LINE FROM BUS 216950 TO BUS 217870 CKT 1   /*ROSELAND     230.0 - WILPIPE      230.0
END
 		OP AC 98.2 % 103.46 % 887.0 B 917.69 46.98 Details
PSEG WILPIPE-CDRGV 230.0 kV Ckt 1 line 
217870 to 216915 ckt 1
 		PS_P1-2_Y-2277 
CONTINGENCY 'PS_P1-2_Y-2277'
 CLOSE BRANCH FROM BUS 216928 TO BUS 216929 CKT Z        /*CDRGV_L1      13.2 - CDRGV_L2      13.2
 DISCONNECT BRANCH FROM BUS 216915 TO BUS 216928 CKT 1   /*CDRGV        230.0 - CDRGV_L1      13.2
 TRIP LINE FROM BUS 216915 TO BUS 216950 CKT 1           /*CDRGV        230.0 - ROSELAND     230.0
END
 		OP AC 95.93 % 101.12 % 887.0 B 896.93 46.52 Details
×
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Details for BAYWAY-BAYONNE 345.0 kV Ckt 1 line l/o Base Case
Bus # Bus Name Type Full MW Contribution GenDeliv MW Contribution
218418 LINDEN_G5 50/50 1.2 MW 1.2 MW
218419 LINDEN_G6 50/50 1.2 MW 1.2 MW
218423 LINDEN_G21 50/50 3.16 MW 3.16 MW
218424 LINDEN_G22 50/50 3.16 MW 3.16 MW
218426 LINDEN_2ST 50/50 5.45 MW 5.45 MW
219035 LINDEN_G8 50/50 2.32 MW 2.32 MW
219036 LINDEN_G7 50/50 2.32 MW 2.32 MW
217104 FAIRLAWN_AB Adder -11.59 MW -9.85 MW
217675 NORTHASP1_C 50/50 0.0 MW 0.0 MW
217680 NORTHASP1_E 50/50 0.03 MW 0.03 MW
217688 NORTHASP2_C 50/50 0.0 MW 0.0 MW
217689 NORTHASP2_E 50/50 0.03 MW 0.03 MW
218318 LINDEN_26 50/50 1.42 MW 1.42 MW
218425 LINDEN_G12 50/50 3.44 MW 3.44 MW
218435 LINDEN_1GT 50/50 6.84 MW 6.84 MW
218436 LINDEN_G11 50/50 11.73 MW 11.73 MW
218664 MINUESP2_C 50/50 0.0 MW 0.0 MW
218665 MINUESP2_E 50/50 0.01 MW 0.01 MW
218666 NWKSWTSP1_C 50/50 0.01 MW 0.01 MW
218667 NWKSWTSP1_E 50/50 0.05 MW 0.05 MW
218726 LINSOLAR C 50/50 0.03 MW 0.03 MW
218727 LINSOLAR E 50/50 0.31 MW 0.31 MW
917011 Z2-002 C 50/50 1.03 MW 1.03 MW
924431 AB2-092 Adder -14.05 MW -11.94 MW
945803 AF1-245 BAT 50/50 23.17 MW 23.17 MW
961242 AF2-415 BAT 50/50 41.3 MW 41.3 MW
961252 AF2-416 BAT 50/50 1.63 MW 1.63 MW
LGEE LTFEXP_LGEE->LTFIMP_LGEE CLTF 0.03 MW 0.03 MW
CPLE LTFEXP_CPLE->LTFIMP_CPLE CLTF 0.05 MW 0.05 MW
VFT LTFEXP_VFT->LTFIMP_VFT CLTF 58.26 MW 58.26 MW
DUCKCREEK LTFEXP_DUCKCREEK->LTFIMP_DUCKCREEK LTF 0.0 MW 0.0 MW
CBM-W2 LTFEXP_CBM-W2->LTFIMP_CBM-W2 CLTF 0.49 MW 0.49 MW
NY LTFEXP_NY->LTFIMP_NY CLTF 5.45 MW 5.45 MW
TVA LTFEXP_TVA->LTFIMP_TVA CLTF 0.09 MW 0.09 MW
WEC LTFEXP_WEC->LTFIMP_WEC CLTF 0.02 MW 0.02 MW
O-066 LTFEXP_O-066->LTFIMP_O-066 CLTF 109.36 MW 109.36 MW
CBM-S2 LTFEXP_CBM-S2->LTFIMP_CBM-S2 CLTF 0.41 MW 0.41 MW
CBM-S1 LTFEXP_CBM-S1->LTFIMP_CBM-S1 CLTF 0.53 MW 0.53 MW
G-007 LTFEXP_G-007->LTFIMP_G-007 CLTF 0.34 MW 0.34 MW
MADISON LTFEXP_MADISON->LTFIMP_MADISON CLTF 0.0 MW 0.0 MW
MEC LTFEXP_MEC->LTFIMP_MEC CLTF 0.09 MW 0.09 MW
CBM-W1 LTFEXP_CBM-W1->LTFIMP_CBM-W1 CLTF 0.7 MW 0.7 MW
×
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Details for ROSELAND-CDRGV 230.0 kV Ckt 1 line l/o PS_P1-2_S-2297
Bus # Bus Name Type Full MW Contribution GenDeliv MW Contribution
217104 FAIRLAWN_AB Adder -24.44 MW -20.77 MW
924431 AB2-092 Adder -16.01 MW -13.61 MW
945803 AF1-245 BAT 50/50 58.6 MW 58.6 MW
961242 AF2-415 BAT 50/50 46.98 MW 46.98 MW
961252 AF2-416 BAT 50/50 3.47 MW 3.47 MW
LGEE LTFEXP_LGEE->LTFIMP_LGEE CLTF 0.32 MW 0.32 MW
CPLE LTFEXP_CPLE->LTFIMP_CPLE CLTF 0.36 MW 0.36 MW
G-007A LTFEXP_G-007A->LTFIMP_G-007A CLTF 1.74 MW 1.74 MW
CBM-W2 LTFEXP_CBM-W2->LTFIMP_CBM-W2 CLTF 4.58 MW 4.58 MW
NY LTFEXP_NY->LTFIMP_NY CLTF 4.81 MW 4.81 MW
TVA LTFEXP_TVA->LTFIMP_TVA CLTF 0.78 MW 0.78 MW
WEC LTFEXP_WEC->LTFIMP_WEC CLTF 0.18 MW 0.18 MW
O-066 LTFEXP_O-066->LTFIMP_O-066 CLTF 232.91 MW 232.91 MW
CBM-S2 LTFEXP_CBM-S2->LTFIMP_CBM-S2 CLTF 3.19 MW 3.19 MW
CBM-S1 LTFEXP_CBM-S1->LTFIMP_CBM-S1 CLTF 4.75 MW 4.75 MW
MEC LTFEXP_MEC->LTFIMP_MEC CLTF 0.89 MW 0.89 MW
CBM-W1 LTFEXP_CBM-W1->LTFIMP_CBM-W1 CLTF 7.04 MW 7.04 MW
×
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Details for WILPIPE-CDRGV 230.0 kV Ckt 1 line l/o PS_P1-2_Y-2277
Bus # Bus Name Type Full MW Contribution GenDeliv MW Contribution
217104 FAIRLAWN_AB Adder -24.2 MW -20.57 MW
924431 AB2-092 Adder -15.85 MW -13.47 MW
945803 AF1-245 BAT 50/50 58.02 MW 58.02 MW
961242 AF2-415 BAT 50/50 46.52 MW 46.52 MW
961252 AF2-416 BAT 50/50 3.43 MW 3.43 MW
LGEE LTFEXP_LGEE->LTFIMP_LGEE CLTF 0.32 MW 0.32 MW
CPLE LTFEXP_CPLE->LTFIMP_CPLE CLTF 0.36 MW 0.36 MW
G-007A LTFEXP_G-007A->LTFIMP_G-007A CLTF 1.73 MW 1.73 MW
CBM-W2 LTFEXP_CBM-W2->LTFIMP_CBM-W2 CLTF 4.54 MW 4.54 MW
NY LTFEXP_NY->LTFIMP_NY CLTF 4.76 MW 4.76 MW
TVA LTFEXP_TVA->LTFIMP_TVA CLTF 0.77 MW 0.77 MW
WEC LTFEXP_WEC->LTFIMP_WEC CLTF 0.17 MW 0.17 MW
O-066 LTFEXP_O-066->LTFIMP_O-066 CLTF 230.61 MW 230.61 MW
CBM-S2 LTFEXP_CBM-S2->LTFIMP_CBM-S2 CLTF 3.16 MW 3.16 MW
CBM-S1 LTFEXP_CBM-S1->LTFIMP_CBM-S1 CLTF 4.71 MW 4.71 MW
MEC LTFEXP_MEC->LTFIMP_MEC CLTF 0.88 MW 0.88 MW
CBM-W1 LTFEXP_CBM-W1->LTFIMP_CBM-W1 CLTF 6.98 MW 6.98 MW

Light Load Analysis

The Project was evaluated as a 150.0 MW (Capacity 150.0 MW) injection in the PSEG 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 were as follows:

(No impacts were found for this analysis)

Light Load Potential Congestion due to Local Energy Deliverability

(No impacts were found for this analysis)

Short Circuit Analysis

PJM Short Circuit Analysis did not identify any new overduty breakers or >3% contribution to previously identified overduty breakers.

Stability Analysis

Generator Interconnection Request AF2-415 is for a 150 MW Maximum Facility Output (MFO) Battery Energy Storage System (BESS) generating facility. AF2-415 consists of 77 x 1.9675 MW SMA SCU-2200-US inverters with a Point of Interconnection (POI) directly connecting at Bergen 138 kV Substation in the Public Service Enterprise Group (PSEG) transmission system, Hudson County, New Jersey.

 

The power flow scenario for the analysis was based on the Regional Transmission Expansion Plan (RTEP) 2023 Summer Peak case, modified to include applicable queue projects. AF2-415 and generations within the vicinity of AF2-415 has been dispatched online at maximum facility output.

 

AF2-415 was tested for compliance with North American Electric Reliability Corporation (NERC), PJM, Transmission Owner (TO) and other applicable criteria. For this study, 118 contingencies were simulated, each with a minimum of 20 second simulation time period. Studied faults included:

 

  1. Steady-state operation (20 second simulation)
  2. Three-phase faults with normal clearing time
  3. Single-phase faults with a stuck breaker
  4. Single-phase faults with delayed clearing at remote end

 

The 118 contingencies tested on the RTEP 2023 Summer Peak case met the recovery criteria:

 

  1. The AF2-415 generator was able to ride through the faults except for faults where protective actions trip one or more generator(s).
  2. All generators maintained synchronism and any post-contingency oscillations are positively damped with a damping margin of at least 3%.
  3. All bus voltages recovered to 0.7 p.u. within 2.5 seconds and the final voltages were within the range of 0.95 p.u. to 1.05 p.u. excluding 500 kV buses. The final voltage for 500 kV buses was within 0.97 p.u. to 1.10 p.u.
  4. No transmission element tripped, other than those either directly connected or designated to trip as a consequence of the fault.

 

The AF2-415 queue project met the 0.95 lagging and 0.95 leading power factor requirements measured at the high side of main transformer.

 

The reactive power for AF2-415 was observed to not settle for some contingencies (e.g. P1.05, P1.06, P1.28, etc.) during the 20 second simulation. The settling appears to be small and does not affect stability. It is recommended that the Interconnection Customer (IC) tune the model parameters to allow the reactive power for AF2-415 to reach steady-state within 20 seconds.

 

The AF2-415 queue project met the 0.95 lagging and 0.95 leading power factor requirements measured at the high side of main transformer.

Reactive Power Analysis

This project meets the power factor requirements.

Steady-State Voltage Analysis

Steady State Voltage Analysis showed no impacts to project AF2-415.

New Service Request Dependencies

The Projects below are listed in one or more dispatch for the overloads identified in your report. These projects contribute to the loading of the overloaded facilities identified in your report. The percent overload of a facility and cost allocation you may have towards a particular reinforcement could vary depending on the action of these earlier projects. The status of each project at the time of the analysis is presented in the table. This list may change if any earlier projects withdraw. This table is valid for load flow analyses only.

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New Service Requests Dependencies
Project Project Name Status
AB2-092 Bergen 138kV Partially in Service - Under Construction

Affected Systems

Midcontinent Independent System Operator (MISO) Not required
New York Independent System Operator (NYISO) Not required
Tennessee Valley Authority (TVA) Not required
Louisville Gas & Electric (LG&E) Not required
Duke Energy Carolinas (DUKE) Not required
Duke Energy Progress – East (CPLE) Not required
Duke Energy Progress – West (CPLW) Not required

System Reinforcements

The AF2-415 project may be responsible for a contribution to the following estimated System Reinforcement (Network Upgrade) costs as shown below. The Network Upgrades listed below are required to alleviate a reliability criteria violation identified in the Network Impact analysis that PJM has performed for this System Impact Study. No physical Interconnection Facilities costs are included in this cost table.

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AF2-415 System Reinforcements Cost Allocation
RTEP ID Title MW Impact Percent Allocation Allocated Cost ($USD)
Grand Total: $0

Note 1: PJM Open Access Transmission Tariff (OATT) Part VI, section 217.3A outlines cost allocation rules for the Expedited Process projects. These rules are further clarified in PJM Manual 14A, Attachment B.

Note 2: To Project Developers with System Reinforcements listed: If your present cost allocation to a System Reinforcement indicates $0, then please be aware that if a prior project in the Expedited Process withdraws from the cycle, the cost responsibilities can change and a cost allocation may be assigned to your project. In addition, although the cost allocation to a System Reinforcement is presently $0, your project may need this system reinforcement completed to be deliverable to the PJM system. If your project desires to possibly come into service prior to completion of the system reinforcement, you would need to request an interim deliverability study to determine if all or a portion of your project would be deliverable.

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System Reinforcement Details
RTEP ID Title Total Cost Time Estimate
b3737.39 Upgrade the Bergen 138 kV ring bus (Replaced n7129 - Projected 12/31/2027) $5,530,000 Dec 31 2027

Contingent

Note: Although AF2-415 may not presently have cost responsibility for this upgrade, AF2-415 may need this upgrade in-service to be deliverable to the PJM system. If AF2-415 desires to come into service prior to completion of the upgrade, the Project Developer will need to request PJM to perform an interim study to determine if they would be deliverable for all or a portion of their output for each delivery year until the upgrade is complete.

Description: Bergen subproject: Upgrade the Bergen 138 kV ring bus by installing a 80 kA breaker along with the foundation, piles, and relays to the existing ring bus, install breaker isolation switches on existing foundations and modify and extend bus work. NJ OSW SAA baseline upgrade

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Flowgates Addressed by this Reinforcement
Facility Contingency
(Any) PS_P2-3_BERG_3-6

Attachments

The one line included in this refreshed System Impact Study report was originally developed prior to the Transition Date. Therefore, not all verbiage on the one line may align with the current Tariff definitions. An updated one line diagram will be provided in the Facilities Study report for the Expedited Process projects.

AF2-415 One Line.PNG

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