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AE2-259 System Impact Study Report

v2.00 released 2024-04-22 15:47

Curdsville-Willis Mtn 115 kV

60.0 MW Capacity / 100.0 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 AE2-259 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 Virginia Electric and Power 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 Solar generating facility located in the Virginia Electric and Power Company zone — Buckingham County, Virginia. The installed facilities will have a total capability of 100.0 MW with 60.0 MW of this output being recognized by PJM as Capacity.

Project Information
New Service Request Number AE2-259
Project Name Curdsville-Willis Mtn 115 kV
Developer Name RWE Solar Development, LLC
State Virginia
County Buckingham
Transmission Owner Virginia Electric and Power Company
MFO 100.0 MW
MWE 100.0 MW
MWC 60.0 MW
Fuel Type Solar
Basecase Study Year 2022

Point of Interconnection

AE2-259 “Curdsville – Willis Mountain 115 kV” will interconnect with the Dominion’s transmission system through a new three breaker 115 kV switching station which will be adjacent to the transmission right-of-way.

Transmission Owner Analysis

PJM performed a power flow analysis of the transmission system using a 2022 load flow model and the results were verified by Dominion. Additionally, Dominion performed an analysis of its transmission system and no further deficiencies were identified.

 

Summer Peak Analysis

The Project was evaluated as a 100.0 MW (Capacity 60.0 MW) injection in the Dominion 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)

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.

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
DVP 3CLUBHSE-6CLUBHSE 115.0/230.0 kV Ckt 1 transformer
314562 to 314563 ckt 1
DVP_P1-2: LN 556
CONTINGENCY 'DVP_P1-2: LN 556'
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 1   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 2   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 3   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314906 TO BUS 314936 CKT 1   /*8CLOVER      500.0 - 8RAWLINGS    500.0
 OPEN BUS 314906                                   /*8CLOVER      500.0
 OPEN BUS 314915                                   /*8CLOVER_STC  500.0
END
OP AC 100.53 % 103.17 % 182.64 B 188.43 5.77
DVP 6BREMO-6BREMODIST 230.0 kV Ckt 1 line
314747 to 313867 ckt 1
DVP_P1-2: LN 2027-B
CONTINGENCY 'DVP_P1-2: LN 2027-B'
 OPEN BRANCH FROM BUS 314310 TO BUS 314322 CKT 1   /*6JUDES F     230.0 - 6MDLTHAN     230.0
 OPEN BRANCH FROM BUS 314310 TO BUS 314333 CKT 1   /*6JUDES F     230.0 - 6POWHATN     230.0
 OPEN BRANCH FROM BUS 933500 TO BUS 314333 CKT 1   /*AC2-165 TAP  230.0 - 6POWHATN     230.0
 OPEN BUS 314310                                   /*6JUDES F     230.0
 OPEN BUS 314333                                   /*6POWHATN     230.0
END
OP AC 102.75 % 107.58 % 661.76 B 711.92 32.12
CPLE/DVP AC1-221 TAP-6PERSON230 T 230.0 kV Ckt 1 line
927250 to 304070 ckt 1
DVP_P1-2: LN 556
CONTINGENCY 'DVP_P1-2: LN 556'
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 1   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 2   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314686 TO BUS 314906 CKT 3   /*6CLOVER      230.0 - 8CLOVER      500.0
 OPEN BRANCH FROM BUS 314906 TO BUS 314936 CKT 1   /*8CLOVER      500.0 - 8RAWLINGS    500.0
 OPEN BUS 314906                                   /*8CLOVER      500.0
 OPEN BUS 314915                                   /*8CLOVER_STC  500.0
END
OP AC 102.26 % 105.45 % 718.0 B 757.13 23.96
DVP 6BREMODIST-6MTEAGLE 230.0 kV Ckt 1 line
313867 to 314765 ckt 1
DVP_P1-2: LN 2027-B
CONTINGENCY 'DVP_P1-2: LN 2027-B'
 OPEN BRANCH FROM BUS 314310 TO BUS 314322 CKT 1   /*6JUDES F     230.0 - 6MDLTHAN     230.0
 OPEN BRANCH FROM BUS 314310 TO BUS 314333 CKT 1   /*6JUDES F     230.0 - 6POWHATN     230.0
 OPEN BRANCH FROM BUS 933500 TO BUS 314333 CKT 1   /*AC2-165 TAP  230.0 - 6POWHATN     230.0
 OPEN BUS 314310                                   /*6JUDES F     230.0
 OPEN BUS 314333                                   /*6POWHATN     230.0
END
OP AC 100.52 % 105.34 % 661.76 B 697.1 32.12
DVP 6MTEAGLE-6CHARLVL 230.0 kV Ckt 1 line
314765 to 314749 ckt 1
DVP_P1-2: LN 2027-B
CONTINGENCY 'DVP_P1-2: LN 2027-B'
 OPEN BRANCH FROM BUS 314310 TO BUS 314322 CKT 1   /*6JUDES F     230.0 - 6MDLTHAN     230.0
 OPEN BRANCH FROM BUS 314310 TO BUS 314333 CKT 1   /*6JUDES F     230.0 - 6POWHATN     230.0
 OPEN BRANCH FROM BUS 933500 TO BUS 314333 CKT 1   /*AC2-165 TAP  230.0 - 6POWHATN     230.0
 OPEN BUS 314310                                   /*6JUDES F     230.0
 OPEN BUS 314333                                   /*6POWHATN     230.0
END
OP AC 96.74 % 101.56 % 661.76 B 672.08 32.12

Light Load Analysis

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

Light Load Potential Congestion due to Local Energy Deliverability

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

Short Circuit Analysis

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

Stability Analysis

EXECUTIVE SUMMARY

Generator Interconnection Request AE2-259 is for a 100 MW Maximum Facility Output (MFO) Solar Facility. AE2-259 consists of 36 x 2.829 MW Power Electronics FS3000M solar inverters with a Point of Interconnection (POI) connecting to the transmission line between Curdsville DP and Willis Mountain 115 kV in Buckingham County, Virginia in the DVP transmission system.

 

The power flow scenario for the analysis was based on the RTEP 2022 summer peak case, modified to include applicable queue projects. AE2-259 has been dispatched online at maximum facility output, with approximately unity power factor at the high side of the station transformer.

 

AE2-259 was tested for compliance with NERC, PJM, Transmission Owner and other applicable criteria. For this study, 38 contingencies were simulated, each with a 20 second simulation time period. Studied faults included:

 

  • Steady-state operation (20 second simulation)
  • Three-phase faults with normal clearing time
  • Single-phase faults with a stuck breaker
  • Single-phase faults placed at 80% of the line with delayed (Zone 2) clearing at remote line end because of primary communications/relaying failure
  • Single-phase faults with loss of multiple circuit tower lines

 

The 38 fault contingencies tested on the 2022 summer peak case met the recovery criteria:

  • The AE2-259 generator was able to ride through the faults except for faults where protective actions trip one or more generator(s).
  • All generators maintained synchronism and any post-contingency oscillations are positively damped with a damping margin of at least 3%.
  • All bus voltages recover to 0.7 p.u. within 2.5 seconds and the final voltages are within the steady-state voltage ranges below per DVP’s transmission planning criteria.
  • P1 Category Contingencies:
    • 0.93 to 1.05 p.u. for 230, 138, 115, 69 kV facilities
    • 1.01 to 1.08 p.u. for 500 kV facilities
  • P2, P4, P5, and P7 Category Contingencies:
    • 0.90 to 1.05 p.u. for 230, 138, 115, 69 kV facilities
    • 1.00 to 1.08 p.u. for 500 kV facilities
  • No transmission element trips, other than those either directly connected or designated to trip as a consequence of the fault.

 

Reactive Power Analysis

Based on the Impact Study data provided, the project AE2-259 met both lagging and leading power factor requirements at the high side of the main power transformer.

Steady-State Voltage Analysis

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

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.

New Service Requests Dependencies
Project Project Name Status

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 AE2-259 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.

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.

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.

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