AF2-166 System Impact Study Report

This System Impact Report (SIS) has been prepared in accordance with the PJM Open Access Transmission Tariff, 205, as well as the System Impact Study Agreement between Long Bridge Solar LLC, the Interconnection Customer (IC), and PJM Interconnection, LLC (PJM), Transmission Provider (TP). The Interconnected Transmission Owner (ITO) is Mid-Atlantic Interstate Transmission, LLC.

Revision 1: November 2022 - The AF2-166 System Impact Study Report was revised following re-tool analysis performed by PJM. Final scope, cost and schedule for the physical interconnection will be provided in the Facilities Study Report.

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.

The Interconnection Customer (IC), has proposed a generating facility located in Venango County, Pennsylvania. The installed facilities will have a total capability of 20.0 MW with 12.0 MW of this output being recognized by PJM as Capacity. The proposed in-service date for this project is Thursday, September 15, 2022. This study does not imply a TO commitment to this in-service date.

AF2-166 will interconnect with the PENELEC distribution system via a tap on the Emlenton Substation 34.5 kV Clark Summit circuit #00499-51 at pole # OE-16851 (Attachment 1).  The IC’s proposed generating unit site is located at GPS: 41.2499560, -79.6816130.

Attachment 1 shows a one-line diagram of the proposed primary direct connection facilities for the AF2-166 generation project to connect to the Penelec distribution system. IC will be responsible for constructing all the facilities on its side of the POI, including the attachment facilities which connect the generator to the Penelec distribution system’s direct connection facilities.

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.

AF2-166 will interconnect with the PENELEC distribution system via a tap on the Emlenton Substation 34.5 kV Clark Summit circuit #00499-51 at pole # OE-16851 (Attachment 1).  The IC’s proposed generating unit site is located at GPS: 41.2499560, -79.6816130

Attachment 1 shows a one-line diagram of the proposed primary direct connection facilities for the AF2-166 generation project to connect to the Penelec distribution system. IC will be responsible for constructing all the facilities on its side of the POI, including the attachment facilities which connect the generator to the Penelec distribution system’s direct connection facilities.

The total preliminary cost estimate is given in the table below. These costs do not include CIAC Tax Gross-up.

Based on the scope of work for the interconnection facilities, it is expected to take a range of 14 to 14 month(s) after the signing of an Interconnection Construction Service Agreement (as this is a FERC connection) and construction kickoff call to complete the installation of the physical connection work. This assumes that there will be no environmental issues with any of the new properties associated with this project, that there will be no delays in acquiring the necessary permits for implementing the defined interconnection work, and that all system outages will be allowed when requested.

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.

Penelec performed an analysis of its distribution system.  The AF2-166 project did not contribute to any overloads on the distribution system.

System Protection

An analysis was conducted to assess the impact of the Haynie-Clark Summit 34.5 kV (AF2-166) Project on the system protection requirements in the area. The results of this review show that the following relay additions will be required:

Proposed single line diagrams show Long Bridge Solar, LLC (Developer) constructing a generation facility tapping Penelec’s Emlenton Substation 34.5 kV Clark Summit circuit #00499-51 at pole # OE-16851.

The 34.5kV interconnection proposal will require Developer to meet applicable "Technical Requirements" as outlined in First Energy's document titled “Technical Requirements for the Interconnection of Customer-Owned Generation to the FirstEnergy Distribution System".  Anti-islanding system shall meet IEEE 1547 and UL 1741 Therefore no Direct Transfer Trip (DTT) will be required. 

General Concerns

It is to be understood, for abnormal operation of the Penelec system, which could cause Developer’s generation facility to be electrically isolated from the Penelec system synchronous source via the tripping of a interconnecting primary voltage line or device, Developer will, via Penelec’s direction, be required to disconnect the generation from Penelec’s system and remain disconnected (units are required to be OFF LINE), until the Penelec system normal circuitry is restored.  These abnormal conditions will be reviewed by Penelec system operators as to the need for the generation facility to be disconnected.

Requirements for Owner’s/Developer’s generation IPP Facility

The proposed interconnection Owner’s/Developer’s facilities must be designed in accordance with the document titled FirstEnergy Distribution Engineering Practices Interconnection of Customer-Owned Generation to the FirstEnergy Distribution System dated 11/17/14 located at the following link:

http://www.pjm.com/planning/design-engineering/to-tech-standards/private-firstenergy.aspx

The document is referred to as engineering practice EP (# 02-280) with section 4, part C specifically referencing the “interconnection technical requirements”.  Certain protection requirements are shown.

Additionally, Owner/Developer is responsible to provide adequate protection (for their equipment) under any distribution system operating condition' - which includes 'Separation from supply' (i.e. tripping of F.E. circuit breakers) and 'resynchronizing the generation after electric restoration of the supply' (i.e. reclosing of F.E. circuit breakers).

Owner’s/Developer’s protection must be designed to coordinate with the reclosing practices of FirstEnergy line protective devices.  The generator must cease to energize the FirstEnergy circuit to which it is connected prior to reclosing of any (FE) automatic reclosing devices.

Owners/Developer’s electrical protection and control schematics shall be provided to FE for consideration.  FE may request modifications, if required, to meet the technical requirements.

Compliance Issues

Long Bridge Solar, LLC will be responsible for meeting a power factor between 0.90 lagging (producing MVARs) to 0.95 leading (absorbing MVARs) and assure that voltage deviation will be less than 1.0 volt as measured at the POI under all Solar Gen operating conditions due to the inherent dynamic reactive power capability of this solar facility.

Generators with no inherent VAR (reactive power) control capability, or those that have a restricted VAR capability less than the defined requirements, must provide dynamic supplementary reactive support located at the generation facility with electrical characteristics equivalent to that provided by a similar sized synchronous generator.  A Dynamic Reactive Compensation (either Static VAR Compensator (SVC) or STATCOM) or other method be applied in order to maintain the required specifications at the POI.  Long Bridge Solar, LLC is responsible for the installation of equipment on its side of the POI in order to adhere to the criteria stated above by FirstEnergy.

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

• Temperature (degrees Fahrenheit)
• Atmospheric Pressure (hectopascals)
• Irradiance
• Forced outage data

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 20.0 MW (Capacity 12.0 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:

(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.

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

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

At this time light load analysis not required for this project.

At this time light load analysis not required for this project.

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

Stability analysis is not required for this queue project at this time.

A reactive assessment was not performed. The Interconnection Customer is responsible for meeting all applicable 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.