GODDARD-PLUMVILLE 138 KV - Generation Interconnection Revised Impact Study Report for Queue Project AE1-144 80.2 MW Capacity / 120 MW Energy ...
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Generation Interconnection
Revised Impact Study Report
for
Queue Project AE1-144
GODDARD-PLUMVILLE 138 KV
80.2 MW Capacity / 120 MW Energy
January 2021Table of Contents
1 Preface ................................................................................................................................................................................................................ 3
2 General ............................................................................................................................................................................................................... 4
2.1 Point of Interconnection ................................................................................................................................................................... 5
2.2 Cost Summary........................................................................................................................................................................................ 5
3 Transmission Owner Scope of Work ..................................................................................................................................................... 6
4 Attachment Facilities ................................................................................................................................................................................... 6
5 Direct Connection Cost Estimate ............................................................................................................................................................. 6
6 Non-Direct Connection Cost Estimate................................................................................................................................................... 6
7 Incremental Capacity Transfer Rights (ICTRs) ................................................................................................................................. 7
8 Interconnection Customer Requirements ........................................................................................................................................... 8
9 Revenue Metering and SCADA Requirements ................................................................................................................................... 9
9.1 PJM Requirements ............................................................................................................................................................................... 9
9.2 EKPC Requirements ............................................................................................................................................................................ 9
10 Network Impacts.....................................................................................................................................................................................10
11 Generation Deliverability ....................................................................................................................................................................12
12 Multiple Facility Contingency ............................................................................................................................................................12
13 Contribution to Previously Identified Overloads ......................................................................................................................12
14 Potential Congestion due to Local Energy Deliverability .......................................................................................................12
15 System Reinforcements ........................................................................................................................................................................13
16 Steady-State Voltage Requirements ................................................................................................................................................13
17 Light Load Analysis ................................................................................................................................................................................13
18 Stability and Reactive Power Requirement for Low Voltage Ride Through ..................................................................13
18.1 Flow Gate Details................................................................................................................................................................................16
18.1.1 Index 1 ..........................................................................................................................................................................................17
18.2 Queue Dependencies ........................................................................................................................................................................18
18.3 Contingency Descriptions ...............................................................................................................................................................19
19 Affected Systems .....................................................................................................................................................................................21
19.1 TVA ...........................................................................................................................................................................................................21
19.2 Duke Energy Progress ......................................................................................................................................................................21
19.3 MISO ........................................................................................................................................................................................................21
19.4 LG&E ........................................................................................................................................................................................................21
20 Short Circuit ..............................................................................................................................................................................................23
© PJM Interconnection 2021. All rights 2
reserved AE1-144: GODDARD-PLUMVILLE 138 KV21 Attachment 1. Single Line Diagram .................................................................................................................................................24 1 Preface The intent of the System Impact Study 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 seeking to interconnect a wind or solar generation facility shall maintain meteorological data facilities as well as provide that meteorological data which is required per Schedule H to the Interconnection Service Agreement and Section 8 of Manual 14D. 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. © PJM Interconnection 2021. All rights 3 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
2 General
The Interconnection Customer (IC), has proposed a solar / battery storage generating facility located in
Flemingsburg, KY. The installed facilities will have a total capability of 120 MW with 80.2 MW of this output
being recognized by PJM as capacity. The capacity & energy rights are associated with the solar generating
facility only. The proposed in-service date for this project is June 1, 2022. This study does not imply a EKPC
commitment to this in-service date.
Queue Number AE1-144
Project Name GODDARD-PLUMVILLE 138 KV
State KY
County Fleming
Transmission Owner EKPC
MFO 120
MWE 120
MWC 80.2
Fuel Solar; Storage
Basecase Study Year 2022
© PJM Interconnection 2021. All rights 4
reserved AE1-144: GODDARD-PLUMVILLE 138 KV2.1 Point of Interconnection AE1-144 will interconnect with the EKPC transmission system along the Goddard - Plumville 138kV line. 2.2 Cost Summary The AE1-144 project will be responsible for the following costs: Description Total Cost Attachment Facilities $250,000 Direct Connection Network Upgrade $4,320,000 Non Direct Connection Network Upgrades $800,000 Allocation for New System Upgrades $0 Contribution for Previously Identified Upgrades $15,040,000 Total Costs $20,410,000 © PJM Interconnection 2021. All rights 5 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
3 Transmission Owner Scope of Work 4 Attachment Facilities The total preliminary cost estimate for the Attachment work is given in the table below. These costs do not include CIAC Tax Gross-up. Description Total Cost Install a 138 kV switch structure at the point of demarcation, $250,000 revenue metering, and attachment facility line/bus and associated hardware to accept the Interconnection Customer generator lead line/bus terminating at the AE1-144 Interconnection switching station. Total Attachment Facility Costs $250,000 5 Direct Connection Cost Estimate The total preliminary cost estimate for the Direct Connection work is given in the table below. These costs do not include CIAC Tax Gross-up. Description Total Cost Build 138kv switching station near Mt. Carmel, KY including $4,320,000 associated transmission line work. Estimated Time to Construct: 24 months Total Direct Connection Facility Costs $4,320,000 6 Non-Direct Connection Cost Estimate The total preliminary cost estimate for the Non-Direct Connection work is given in the table below. These costs do not include CIAC Tax Gross-up. Description Total Cost Goddard - Plumville 138kV line: Install a line loop to the $700,000 proposed AE1-144 interconnection switching station. Adjust remote, relaying, and metering settings at the Goddard $50,000 138 kV switchyard Adjust remote, relaying, and metering settings at the Plumville $50,000 138 kV switchyard Total Non-Direct Connection Facility Costs $800,000 © PJM Interconnection 2021. All rights 6 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
7 Incremental Capacity Transfer Rights (ICTRs) Will be determined at a later study phase © PJM Interconnection 2021. All rights 7 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
8 Interconnection Customer Requirements
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.
© PJM Interconnection 2021. All rights 8
reserved AE1-144: GODDARD-PLUMVILLE 138 KV9 Revenue Metering and SCADA Requirements 9.1 PJM Requirements 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 M- 14D, and PJM Tariff Section 8 of Attachment O. 9.2 EKPC Requirements The Interconnection Customer will be required to comply with all EKPC Revenue Metering Requirements for Generation Interconnection Customers. The Revenue Metering Requirements may be found within the “EKPC Facility Connection Requirements” document located at the following link: http://www.pjm.com/planning/design-engineering/to-tech-standards/ekpc.aspx © PJM Interconnection 2021. All rights 9 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
10 Network Impacts The Queue Project AE1-144 was evaluated as a 120.0 MW (Capacity 80.2 MW) injection into a tap of the Goddard – Plumville 138 kV line in the EKPC area. Project AE1-144 was evaluated for compliance with applicable reliability planning criteria (PJM, NERC, NERC Regional Reliability Councils, and Transmission Owners). Project AE1-144 was studied with a commercial probability of 1.00. Potential network impacts were as follows: © PJM Interconnection 2021. All rights 10 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
Summer Peak Load Flow © PJM Interconnection 2021. All rights 11 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
11 Generation Deliverability
(Single or N-1 contingencies for the Capacity portion only of the interconnection)
None
12 Multiple Facility Contingency
(Double Circuit Tower Line, Fault with a Stuck Breaker, and Bus Fault contingencies for the full energy output)
None
13 Contribution to Previously Identified Overloads
(This project contributes to the following contingency overloads, i.e. "Network Impacts", identified for earlier
generation or transmission interconnection projects in the PJM Queue)
ID FRO FROM kV FRO TO TO kV TO CK CONT NAME Type Rati PRE POST AC| MW
M BUS M BUS# BUS BUS T ng PROJE PROJE DC IMPA
BUS# BUS ARE ID MV CT CT CT
ARE A A LOADI LOADI
A NG % NG %
4275 2469 05WLD 138 AEP 2430 05HILL 138 AEP 1 DAY_P4_STUART_HH break 185. 111.66 115.31 AC 7.95
61 46 CAT .0 19 SB .0 er 0
4287 2469 05WLD 138 AEP 2430 05HILL 138 AEP 1 DEO&K-DAY-EKPC.C5 towe 185. 135.19 140.54 AC 11.66
96 46 CAT .0 19 SB .0 4541MELDAHLSPRLCKSTUARTSPUR r 0
LOCKDPLEK
14 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 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.
ID FROM FROM kV FRO TO TO BUS kV TO CK CONT Type Ratin PRE POST AC|D MW
BUS# BUS M BUS# BUS T NAME g PROJECT PROJECT C IMPAC
BUS ARE ID MVA LOADIN LOADIN T
AREA A G% G%
42838 24694 05WLDCA 138. AEP 24301 05HILLS 138. AEP 1 EKPC_P1 operatio 185.0 111.11 114.77 AC 7.97
3 6 T 0 9 B 0 - n
2_SPUR-
STU345
© PJM Interconnection 2021. All rights 12
reserved AE1-144: GODDARD-PLUMVILLE 138 KV15 System Reinforcements
Upgrade Description Cost
Allocated Upgrade
ID Idx Facility Cost
to AE1- Number
144
A sag check will be required for the ACSR ~ 477 ~
26/7 ~ HAWK - Conductor Section 1 to determine if
the line section can be operated above its emergency
rating of 185 MVA. The sag study results show that a
distribution circuit crossing underneath structures
37-58 and 37-59 will need to be relocated to allow
the line to be operated at its MOT. An approximate
time for the sag study is 6 to 12 months after signing
an interconnection agreement. Estimated Cost is
$186K. AC1-089 is responsible for this cost. The
new expected SE rating following the sag study will
05WLDCAT be 256 MVA SE.
138.0 kV -
428796,427561 1 Note 1: AE1-144 presently does not receive cost $186K $0 N5472
05HILLSB 138.0
allocation for this upgrade.
kV Ckt 1
As changes to the interconnection process occur,
such as prior queued projects withdrawing from the
queue, reducing in size, etc, AE1-144 could receive
cost allocation.
Note 2: Although AE1-144 may not have cost
responsibility for this upgrade, AE1-144 may need
this upgrade in-service to be deliverable to the PJM
system. If AE1-144 comes into service prior to
completion of the upgrade, AE1-144 will need an
interim study.
Reconductor/rebuild 10.03 miles’ section of ACSR ~
477 ~ 26/7 ~ HAWK Conductor section 1. An
05WLDCAT approximate construction would be 24- 36 months
138.0 kV - after signing an Interconnection agreement.
428796,427561 1 $15.04M $15.04 M N5857
05HILLSB 138.0
kV Ckt 1 AE1-144 is responsible for this cost as the loading is
pushed over the 256 MVA SE rating.
16 Steady-State Voltage Requirements
(Summary of the VAR requirements based upon the results of the steady-state voltage studies)
None
17 Light Load Analysis
No violation
18 Stability and Reactive Power Requirement for Low Voltage Ride Through
(Summary of the VAR requirements based upon the results of the dynamic studies)
Executive Summary
© PJM Interconnection 2021. All rights 13
reserved AE1-144: GODDARD-PLUMVILLE 138 KVGenerator Interconnection Request AE1-144 is for a 120 MW Maximum Facility Output (MFO) solar/battery
storage generating facility, which consists of 41 Power Electronics FS3225 Solar Inverters. The batteries are
solely charged by the solar arrays (DC coupled). The AE1-144 solar generating facility will be located in Fleming
County, Kentucky.
To interconnect the AE1-144 solar generating facility, a new 138 kV switching substation with main and
transfer bus configuration will be constructed by tapping the Goddard – Plumville 138 kV line in the East
Kentucky Power Cooperative (EKPC) transmission system. The new substation will be approximately 9.90 miles
from Goddard substation and 7.00 miles from Plumville substation and adjacent to the 138 kV line. Project
AE1-144 will connect to the new substation via approximately 0.2 miles 138 kV transmission line. The Point of
Interconnection (POI) will be at the terminal frame of the disconnect switch on the Interconnection Customer
side.
This report describes a dynamic simulation analysis of AE1-144 as part of the overall system impact study. The
load flow scenario for the analysis was based on the RTEP 2022 peak load case, modified to include applicable
queue projects. AE1-144 has been dispatched online at maximum power output, with unity power factor and
approximately 1.0 pu voltage at the generator terminals.
AE1-144 was tested for compliance with NERC, PJM, Transmission Owner, and other applicable criteria. 113
contingencies were studied, each with a 20 second simulation time period (with 1.0 second initial run prior to
any events). Studied faults included:
a) Steady state operation (Category P0);
b) Three phase faults with normal clearing time on the intact network (Category P1);
c) Single phase to ground faults with delayed clearing due to a stuck breaker (Category P4);
d) Single phase faults placed at 80% of the line with delayed (Zone 2) clearing at line end remote from the
fault due to primary communications/relay failure (Category P5);
e) Single phase to ground faults with normal clearing for common structure (Category P7).
For all 113 fault contingencies tested on the 2022 peak load case:
a) AE1-144 was able to ride through the faults (except for faults where protective action trips a
generator(s)).
b) Post-contingency oscillations were positively damped with a damping margin of at least 3%.
c) Following fault clearing, all bus voltages recover to a minimum of 0.7 per unit after 2.5 seconds (except
where protective action isolates that bus).
d) No transmission element trips, other than those either directly connected or designed to trip as a
consequence of that fault.
No mitigations were found to be required.
Please also note that the project AE1-144 meets the 0.95 leading and lagging reactive power requirement at
the high side of facility main transformer.
© PJM Interconnection 2021. All rights 14
reserved AE1-144: GODDARD-PLUMVILLE 138 KV© PJM Interconnection 2021. All rights 15 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
18.1 Flow Gate Details The following indices contain additional information about each facility presented in the body of the report. For each index, a description of the flowgate and its contingency was included for convenience. The intent of the indices is to provide more details on which projects/generators have contributions to the flowgate in question. All New Service Queue Requests, through the end of the Queue under study, that are contributors to a flowgate will be listed in the indices. Please note that there may be contributors that are subsequently queued after the queue under study that are not listed in the indices. Although this information is not used "as is" for cost allocation purposes, it can be used to gage the impact of other projects/generators. It should be noted the project/generator MW contributions presented in the body of the report are Full MW Impact contributions which are also noted in the indices column named "Full MW Impact", whereas the loading percentages reported in the body of the report, take into consideration the PJM Generator Deliverability Test rules such as commercial probability of each project as well as the ramping impact of "Adder" contributions. The MW Impact found and used in the analysis is shown in the indices column named "Gendeliv MW Impact". © PJM Interconnection 2021. All rights 16 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
18.1.1 Index 1
ID FROM FROM FRO TO TO BUS TO CK CONT NAME Type Ratin PRE POST AC|D MW
BUS# BUS M BUS# BUS T g PROJEC PROJEC C IMPAC
BUS ARE ID MVA T T T
ARE A LOADIN LOADIN
A G% G%
42879 24694 05WLDC AEP 24301 05HILLS AEP 1 DEO&K-DAY-EKPC.C5 towe 185.0 135.19 140.54 AC 11.66
6 6 AT 9 B 4541MELDAHLSPRLCKSTUARTSPURLOCK r
DPLEK
Bus # Bus Gendeliv MW Impact Type Full MW Impact
916272 Z1-080 E 0.5617 Merchant Transmission 0.5617
918802 AA1-099 E 0.3745 Merchant Transmission 0.3745
925981 AC1-074 C O1 2.7384 Adder 3.22
925982 AC1-074 E O1 1.1736 Adder 1.38
926101 AC1-089 C O1 38.8312 50/50 38.8312
(Suspended)
926102 AC1-089 E O1 63.3562 50/50 63.3562
(Suspended)
932551 AC2-075 C 0.6504 Adder 0.77
932552 AC2-075 E 0.3276 Adder 0.39
936381 AD2-048 C 3.3999 Adder 4.0
936382 AD2-048 E 1.6963 Adder 2.0
939141 AE1-144 C O1 6.6214 Adder 7.79
939142 AE1-144 E O1 3.2859 Adder 3.87
LGEE LGEE 1.1281 Confirmed LTF 1.1281
CIN CIN 1.3034 Confirmed LTF 1.3034
CPLE CPLE 0.1402 Confirmed LTF 0.1402
IPL IPL 0.7308 Confirmed LTF 0.7308
CBM-W2 CBM-W2 13.3463 Confirmed LTF 13.3463
CBM-W1 CBM-W1 0.9438 Confirmed LTF 0.9438
WEC WEC 0.1450 Confirmed LTF 0.1450
O-066 O-066 0.8816 Confirmed LTF 0.8816
CBM-S2 CBM-S2 0.5133 Confirmed LTF 0.5133
CARR CARR 0.0526 Confirmed LTF 0.0526
CBM-S1 CBM-S1 2.9366 Confirmed LTF 2.9366
G-007 G-007 0.1365 Confirmed LTF 0.1365
MEC MEC 1.6355 Confirmed LTF 1.6355
RENSSELAER RENSSELAER 0.0415 Confirmed LTF 0.0415
© PJM Interconnection 2021. All rights 17
reserved AE1-144: GODDARD-PLUMVILLE 138 KV18.2 Queue Dependencies
The Queue Projects below are listed in one or more indices 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.
Queue Number Project Name Status
AA1-099 Clinton Co. 34.5kV In Service
AC1-074 Jacksonville-Renaker 138kV I Active
AC1-089 Hillsboro-Wildcat 138kV Suspended
AC2-075 Great Blue Heron Solar Active
AD2-048 Cynthia-Headquarters 69 kV Active
AE1-144 Goddard-Plumville 138 kV Active
Z1-080 Clinton County 34.5kV In Service
© PJM Interconnection 2021. All rights 18
reserved AE1-144: GODDARD-PLUMVILLE 138 KV18.3 Contingency Descriptions
Contingency Name Contingency Definition
CONTINGENCY 'DAY_P4_STUART_HH'
OPEN LINE FROM BUS 253077 TO BUS 342838 CKT 1 / 253077 09STUART 345
342838 7SPURLOCK 345 1
DAY_P4_STUART_HH
OPEN LINE FROM BUS 253077 TO BUS 253076 CKT 1 / 253077 09STUART 345
253076 09STUART 138 1
END
CONTINGENCY 'DEO&K-DAY-EKPC.C5 4541MELDAHLSPRLCKSTUARTSPURLOCKDPLEK'
DEO&K-DAY-EKPC.C5
OPEN BRANCH FROM BUS 342838 TO BUS 249581 CKT 1
4541MELDAHLSPRLCKSTUARTSPUR
OPEN BRANCH FROM BUS 253077 TO BUS 342838 CKT 1
LOCKDPLEK
END
CONTINGENCY 'EKPC_P1-2_SPUR-STU345' /* SPURLOCK - STUART
OPEN BRANCH FROM BUS 253077 TO BUS 342838 CKT 1 /* 253077 09STUART
EKPC_P1-2_SPUR-STU345
345.00 342838 7SPURLOCK 345.00
END
© PJM Interconnection 2021. All rights 19
reserved AE1-144: GODDARD-PLUMVILLE 138 KVAffected Systems © PJM Interconnection 2021. All rights 20 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
19 Affected Systems 19.1 TVA None 19.2 Duke Energy Progress None 19.3 MISO None 19.4 LG&E A LG&E Affected System Study will be required for AE1-144. The AE1-144 customer will need to sign onto a LG&E Affected System Study Agreement. © PJM Interconnection 2021. All rights 21 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
Short Circuit © PJM Interconnection 2021. All rights 22 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
20 Short Circuit The following Breakers are overduty None. © PJM Interconnection 2021. All rights 23 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
21 Attachment 1. Single Line Diagram © PJM Interconnection 2021. All rights 24 reserved AE1-144: GODDARD-PLUMVILLE 138 KV
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