AE2-022 System Impact Study Report

This System Impact Study Report (SIS) has been prepared in accordance with the PJM Open Access Transmission Tariff, 205, as well as the System Impact Study Agreement between Atlantic Shores Offshore Wind Project 1, LLC, the Interconnection Customer (IC), and PJM Interconnection, LLC (PJM), Transmission Provider (TP). The Interconnected Transmission Owner (ITO) is Atlantic City Electric.

Revision 1: March 2022 - The AE2-022 System Impact Study Report has been revised to reflect the results of PJM's retool study.

Revision 2: April 2022 - The report was further updated to correct an error in the Cost Summary.

Revision 3: November 2022 - The report was revised to reflect the results of an additional retool study. Final scope and cost estimates will be provided as part of the Facilities Study.

Revision 4: December 2022 - The report was revised to reflect the results PJM's retool study.

The intent of the System Impact is to determine a plan, with approximate cost and construction time estimates, to connect the subject generation interconnection project to the PJM network at a location specified by the Interconnection Customer. As a requirement for interconnection, the Interconnection Customer may be responsible for the cost of constructing: Network Upgrades, which are facility additions, or upgrades to existing facilities, that are needed to maintain the reliability of the PJM system. All facilities required for interconnection of a generation interconnection project must be designed to meet the technical specifications (on PJM web site) for the appropriate transmission owner.

In some instances an Interconnection Customer may not be responsible for 100% of the identified network upgrade cost because other transmission network uses, e.g. another generation interconnection or merchant transmission upgrade, may also contribute to the need for the same network reinforcement. The possibility of sharing the reinforcement costs with other projects may be identified in the Feasibility Study, but the actual allocation will be deferred until the System Impact Study is performed.

The System Impact study estimates do not include the feasibility, cost, or time required to obtain property rights and permits for construction of the required facilities. The project developer is responsible for the right of way, real estate, and construction permit issues. For properties currently owned by Transmission Owners, the costs may be included in the study.

An Interconnection Customer with a proposed new Customer Facility that has a Maximum Facility Output equal to or greater than 100 MW shall install and maintain, at its expense, phasor measurement units (PMUs). See Section 8.5.3 of Appendix 2 to the Interconnection Service Agreement as well as section 4.3 of PJM Manual 14D for additional information.

The Interconnection Customer (IC), has proposed a generating facility located in Atlantic County, New Jersey. The installed facilities will have a total capability of 300.0 MW with 52.8 MW of this output being recognized by PJM as Capacity. The proposed in-service date for this project is Sunday, December 01, 2024. This study does not imply a TO commitment to this in-service date.

AE2-022 will interconnect with on the AEC transmission system at the Cardiff 230 kV substation.

The project may be responsible for a contribution to the following costs:

Note 1: PJM Open Access Transmission Tariff (OATT) section 217.3A outline cost allocation rules. The rules are further clarified in PJM Manual 14A Attachment B. The allocation of costs for a network upgrade will start with the first Queue project to cause the need for the upgrade. Later queue projects will receive cost allocation contingent on their contribution to the violation and are allocated to the queues that have not closed less than 5 years following the execution of the first Interconnection Service Agreement which identifies the need for this upgrade.

Note 2: For customers with System Reinforcements listed: If your present cost allocation to a System Reinforcement indicates $0, then please be aware that as changes to the interconnection process occur, such as prior queued projects withdrawing from the queue, reducing in size, etc, the cost responsibilities can change and a cost allocation may be assigned to your project. In addition, although your present 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 comes into service prior to completion of the system reinforcement, an interim deliverability study for your project will be required.

See AE2-020 report for physical interconnection scope of work.

The schedule for any required Network Impact Reinforcements will be more clearly identified in future study phases. The estimated time to complete each of the required reinforcements is identified in the "System Reinforcements" section of the report.

None

The IC is responsible for all design and construction related to activities on their side of the Point of Interconnection. Site preparation, including grading and an access road, as necessary, is assumed to be by the IC. Route selection, line design, and right-of-way acquisition of the direct connect facilities is not included in this report, and is the responsibility of the IC. Protective relaying and metering design and installation must comply with ACE’s applicable standards. The IC is also required to provide revenue metering and real-time telemetering data to PJM in conformance with the requirements contained in PJM Manuals M-01 and M-14 and the PJM Tariff.

ACE requires that an IC circuit breaker is located within 500 feet of the ACE substation to facilitate the relay protection scheme between ACE and the IC at the Point of Interconnection (POI).

Additional Interconnection Customer Responsibilities:

1. An Interconnection Customer entering the New Services Queue on or after October 1, 2012 with a proposed new Customer Facility that has a Maximum Facility Output equal to or greater than 100 MW shall install and maintain, at its expense, phasor measurement units (PMUs). See Section 8.5.3 of Appendix 2 to the Interconnection Service Agreement as well as section 4.3 of PJM Manual 14D for additional information.
2. The Interconnection Customer may be required to install and/or pay for metering as necessary to properly track real time output of the facility as well as installing metering which shall be used for billing purposes. See Section 8 of Appendix 2 to the Interconnection Service Agreement as well as Section 4 of PJM Manual 14D for additional information.
3. The Interconnection Customer seeking to interconnect a wind generation facility shall maintain meteorological data facilities as well as provide that meteorological data which is required per item 5.IV of Schedule H to the Interconnection Service Agreement.

Special Operating Requirements

1. ACE will require the capability to remotely disconnect the generator from the grid by communication from its System Operations facility. Such disconnection may be facilitated by a generator breaker, or other method depending upon the specific circumstances and the evaluation by ACE.
2. ACE reserves the right to charge the Interconnection Customer operation and maintenance expenses to maintain the Interconnection Customer attachment facilities, including metering and telecommunications facilities, owned by ACE.

The Interconnection Customer will be required to install equipment necessary to provide Revenue Metering (KWH, KVARH) and real time data (KW, KVAR) for IC's generating Resource. See PJM Manuals M-01 and M14D, and PJM Tariff Section 8 of Attachment O.

The wind generation facility shall provide the Transmission Provider with site-specific meteorological data including::

• Wind speed (meters/second) - (Required)
• Wind direction (decimal degrees from true north) - (Required)
• Ambient air temperature (Fahrenheit) - (Required)
• Air Pressure (Hectopascals) - (Required)
• Humidity (Percent) (Accepted, not required)

The IC will be required to comply with all Interconnected Transmission Owner's revenue metering requirements for generation interconnection customers located at the following link: PJM - Transmission Owner Engineering & Construction Standards.

The Queue Project was evaluated as a 300.0 MW (Capacity 52.8 MW) injection in the 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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CONTINGENCY 'AE_P4-2 AE7'
 DISCONNECT BRANCH FROM BUS 219100 TO BUS 227900 CKT 1   /*NEWFRDM      230.0 - CARDIFF      230.0
 DISCONNECT BRANCH FROM BUS 227900 TO BUS 227910 CKT 1   /*CARDIFF      230.0 - CARDIFF1      69.0
END

227955 to 206302 ckt 1

CONTINGENCY 'AE_P4-2 AE6'
 DISCONNECT BRANCH FROM BUS 219100 TO BUS 227900 CKT 1   /*NEWFRDM      230.0 - CARDIFF      230.0
 DISCONNECT BRANCH FROM BUS 227900 TO BUS 227911 CKT 1   /*CARDIFF      230.0 - CARDIFF2      69.0
END

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CONTINGENCY 'JC-P7-1-JCC-230-13'
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 1   /*28MANITOU    230.0 - 28OYSTER C   230.0
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 2   /*28MANITOU    230.0 - 28OYSTER C   230.0
 DISCONNECT BRANCH FROM BUS 206302 TO BUS 206325 CKT 1   /*28OYSTER C   230.0 - 28O C GEN     24.0
END

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CONTINGENCY 'AE_P7-1 AE3TOWER'
 DISCONNECT BRANCH FROM BUS 227900 TO BUS 227955 CKT 1   /*CARDIFF      230.0 - CEDAR        230.0
 DISCONNECT BRANCH FROM BUS 227913 TO BUS 227902 CKT 1   /*CARDIFF      138.0 - LEWIS #1     138.0
END

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 a Merchant Transmission Interconnection 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. With a Transmission Interconnection Request, a subsequent analysis will be performed which shall study all overload conditions associated with the overloaded element(s) identified.

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CONTINGENCY 'PS_P1-2_2310A'
 TRIP LINE FROM BUS 219100 TO BUS 227900 CKT 1   /*NEWFRDM      230.0 - CARDIFF      230.0
END

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CONTINGENCY 'JC-P1-2-JCC-230-022'
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 2   /*28MANITOU    230.0 - 28OYSTER C   230.0
END

206302 to 206297 ckt 2

CONTINGENCY 'JC-P1-2-JCC-230-021'
 DISCONNECT BRANCH FROM BUS 206297 TO BUS 206302 CKT 1   /*28MANITOU    230.0 - 28OYSTER C   230.0
END

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CONTINGENCY 'PS_P1-2_C-2308_LT'
 CLOSE LINE FROM BUS 219177 TO BUS 219178 CKT Z   /*CUTHBERT_L4   13.2 - CUTHBERT_L2   13.2
 DISCONNECT BUS 219753                            /*CUTHBERT_2   230.0
 MOVE 8 MW LOAD FROM BUS 219177 TO BUS 219677     /*CUTHBERT_L4   13.2 - MAPLE SHADE   13.2
 MOVE 8 MW LOAD FROM BUS 219178 TO BUS 219678     /*CUTHBERT_L2   13.2 - MAPLE SHADE   13.2
END

At this time winter peak analysis not required for this project.

At this time winter peak analysis not required for this project.

The Queue Project was evaluated as a 300.0 MW (Capacity 52.8 MW) injection in the 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)

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 a Merchant Transmission Interconnection 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. With a Transmission Interconnection Request, a subsequent analysis will be performed which shall study all overload conditions associated with the overloaded element(s) identified.

(No impacts were found for this analysis)

This project does not cause any circuit breakers to exceed their interrupting capability.

No mitigation was found to be required due to transient stability.

This project meets the power factor requirements.

Steady State Voltage analysis is not required for this queue project at this time.

The Queue 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 as earlier projects withdraw or modify their requests. This table is valid for load flow analyses only.

Files

• AE2-022-3-4 Dynamic Analysis Report.doc -- AE2-020/AE2-021/AE2-022 stability study report